gas royalty calculation information bulletin - july 2002 · 2016. 4. 8. · information bulletin...

ENERGY

Petroleum Plaza – North Tower 9945 – 108 Street Edmonton, Alberta Canada T5K 2G6 02-07

GAS ROYALTY CALCULATION INFORMATION BULLETIN

July 2002

A. PRICING RATES AND TRANSPORTATION INFORMATION Pricing, Royalty Rates and Transportation Information – May 2002................................................... 2 B. NOTICES Royalty Payers Only............................................................................................................................ 2 Alberta Natural Gas and Natural Gas Liquids Royalty (NGL) Framework Change ............................ 4 Late Filing Penalty Changes ............................................................................................................... 9 RMF3 Calculation and Examples ........................................................................................................ 9 C. MONTHLY INFORMATION May 2002 Royalty Due August 31..................................................................................................... 11 June 2002 OAS and VA4 Due August 15 ........................................................................................ 11 Interest Rate July 2002 ..................................................................................................................... 12 April Provisional Assessment Charge ............................................................................................... 12 April Penalty Charges........................................................................................................................ 12 Alberta Royalty Tax Credit Program Quarterly Rate .........................................................................12 D. INFRASTRUCTURE DATA CHANGES Client ID Listing ................................................................................................................................. 13 Projects/Blocks.................................................................................................................................. 13 Struck Clients .................................................................................................................................... 13 Operator Changes............................................................................................................................. 13 New EUB Plants ................................................................................................................................ 13 Nova Tolls – Multiple Gas Reference Prices..................................................................................... 14 E. REMINDERS Royalty Payers Only.......................................................................................................................... 14 Royalty Deposit Adjustment .............................................................................................................. 15 How to Use the Petroleum Registry: for “Royalty Payers Only”....................................................... 15

Implementation of the Petroleum Registry of Alberta ....................................................................... 16 F. PRINCIPLES AND PROCEDURES Updates ............................................................................................................................................. 16 G. POINTS OF CONTACT Department of Energy Hotline & Internet .......................................................................................... 16 Gas Royalty Calculation .................................................................................................................... 17 Calgary Information Centre .............................................................................................................. 17 Alberta Royalty Tax Credit Information ............................................................................................ 17

PLEASE ENSURE YOUR PRODUCTION ACCOUNTANTS RECEIVE A COPY OF THIS DOCUMENT.

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

http://www.energy.gov.ab.ca

INFORMATION BULLETIN – July 2002

A. PRICING RATES AND TRANSPORTATION INFORMATION

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

B. NOTICES

Royalty Payers Only (Companies and individuals that are not operators of facilities, but do currently receive information from industry partners, or invoices, statements and other correspondence from the Department of Energy (DOE) have been deemed “Royalty Payers Only” by the Petroleum Registry of Alberta) 7-Digit to 4-Character Code Conversion Complete Cross Reference Table (new 4-character codes which replaces existing 7-digit codes) Now Available! Due to implementation of the Petroleum Registry of Alberta in October 2002, the Ministry of Energy is enacting a process to create a standard 4-character reporting code for all companies/individuals. Currently, any royalty payer who sends or receives information from the Department of Energy (DOE) with a 7-digit Royalty Client Code will be issued a new 4-character Business Associate (BA) identifier. The complete table of all converted 7-digit client IDs to the new standardized 4-character ID is now available at:

• The Petroleum Registry web site: www.petroleumregistry.gov.ab.ca • The Department of Energy web site: www.energy.gov.ab.ca • Attachment 13

Prior to October 2002, either the 7-digit or 4-character code can be used in making submissions to the DOE. However, royalty payers should realize that the DOE’s output documentation from these submissions will only display the new 4-character BA identifier for that royalty client. The DOE will accept the new 4-character identifier after August 1, 2002 for those clients who wish to make changes to their systems before Registry implementation. Applying for a New Code After the Registry is up and running, companies and/or individuals will be able to use the system to request a 4-character BA identifier. An application form can be submitted via the Registry, with a hard copy letter (with signature) requesting the new identifier be sent to the DOE’s Client Registry group. Royalty clients without access to the Registry can submit a written request for a 4-character BA identifier to the DOE’s Client Registry group. Written requests can be made to:

Alberta Department of Energy Client Registry 9945 108 Street, 3rd Floor Edmonton, AB T5K 2G6 Fax: 780-422-9522

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http://www.petroleumregistry.gov.ab.ca/http://www.energy.gov.ab.ca/NaturalGas/743.asp


To obtain more information about securing a new BA code, please contact the Client Registry at (780) 422-1395. Note: In addition to the 4-character BA identifier, any industry client who wishes to conduct business through the Registry must also have a User Security Administrator who will manage company User IDs and passwords. To learn more about this process, read the Registry User Security Administrator (USA): Set-up Process story in this bulletin or go to the Registry web site at: www.petroleumregistry.gov.ab.ca. Registry User Security Administrator (USA): Set-up Process A guiding principle of the Registry is that “the data must be secure”. A key component of the Registry’s application security is the role of User Security Administrator (USA). Each company or individual, also known as a Business Associate (BA), who requires access to the Registry, must assign an individual to perform the role of USA. The USA has the responsibility for setting up and managing security for all users of the Registry for that BA. It is very important for each BA to secure a USA ID and password. Without it, a BA will not have access to the Registry. Before the Registry begins operation in October 2002, it must:

• Collect the information for the individual assigned the role of USA. The Registry can create the initial information about the BA from existing EUB or DOE files, but does not have any information about the USA.

• The Registry must then communicate the USA’s Registry User ID and password back to the USA in a secure manner.

The USA Set-up Procedure When the Registry team begins its ramp-up to implementation in the first week of September 2002, BA information, including USA information, will be the first set of data loaded into the database. The objective of the Registry team is to collect all USA information from July 1st to August 30th, 2002. However, a system will be in place to capture any USA data that arrives from September 1st to 30th, 2002. The process to obtain a USA is outlined on the Registry web site (www.petroleumregistry.gov.ab.ca). If you have any questions about this process, please contact the Registry offices at (403) 297-6111(Calgary) or 1-800-992-1144 (other locations) or e-mail [email protected]. When the Registry is operational, new BAs will request a BA USA ID and Password through a Registry online function called Request BA Application. A BA can also manage existing BA USA information through a Registry online function called Request a BA Change. If a BA USA is required after the BA ID has been issued, contact the DOE’s Client Registry at (780) 422-1395. Note: At the time of implementation of the Petroleum Registry of Alberta (Phase 1 – October 2002) the general public will not have access to public data on the Registry. Only those individuals who have a legitimate business reason for using the Registry will be issued the USA ID, which will allow them access to public and secure data in the Registry. All public information on the Registry can be obtained from existing Ministry of Energy sources, either on the DOE or Energy and Utilities Board (EUB) web sites or via EUB’s Data Dissemination program.

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http://www.petroleumregistry.gov.ab.ca/


Alberta Natural Gas and Natural Gas Liquids Royalty (NGL) Framework Change The Department’s Information Letter 2002-19 and Gas Royalty Calculation June Information Bulletin, 02-06A introduced the Alberta Natural Gas and Natural Gas Liquids (NGL) Royalty Framework Change. This change initiative is expected to be effective with September 2002 production, along with the implementation of the Petroleum Registry of Alberta (the Registry). Refer to the Gas Royalty Calculation June Information Bulletin, 02-06A for information on the Registry. This article addresses the following key outcomes of the Alberta Natural Gas and NGL Royalty Framework Change: • Volumetric Submission of In Stream Components • In Stream Component Product List • Facility Average Royalty Rate Calculation and Supporting Details • Low Productivity Allowance Adjustment • Raw Gas Average Royalty Rate Calculation and Supporting Details • Facility Average Price Calculation and Supporting Details • ISC Balancing and Discrepancy Notice • Default Royalty Variables and Supporting Details • Royalty Calculation and Crown Royalty Detail Report

Volumetric Submission of In Stream Components (ISC) Volumetric information on in stream components (ISC) in the gas stream is used by the Crown to determine the appropriate component weightings in the calculation of the ‘facility average’ royalty rate and ‘facility average’ price that will be used to assess gas royalty under the Natural Gas and NGL Royalty Framework Change. Basically, ISC information is required on volumetric information that is a royalty trigger. See In Stream Component Product List and Product Codes included in this article for the complete list of ISC products. The ISC volumetric information, where required, is submitted to the Registry, like all the other volumetric submissions. The ISC is submitted as an additional link to the Gas volumetric information. Both volume and energy (where applicable) must be reported. The reporting is to three decimal places for desired precision. The aggregate ISC volume and energy must equal the Gas volume and energy, or the Registry will reject both the Gas and ISC submissions. There is a volumetric tolerance on the Gas and ISC totals. The tolerance on volume difference is +/- 0.100. The tolerance on energy difference is +/- 1.000. Refer to the Registry Training Modules (available via the Registry web site http://www.petroleumregistry.gov.ab.ca) for details on volumetric submissions to the Registry. ISC information is primarily required from pipeline operators. In some cases, meter station operators or their common stream operators, facility operators and sellers of raw gas are also required to report. The Registry ISC Reporting Table in Attachment 7 identifies the submitters and their volumetric reporting requirements. ISC reporting is only required for the receipts and dispositions identified in the Attachment 7. In Stream Component Product List and Product Codes

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Industry has identified the following list of potential in stream components present in a gas stream, with Methane, Ethane ISC, Propane ISC, Butanes ISC and Pentanes Plus ISC being the primary ISC products. Remaining products are the inerts. Operators are required to report the components



that their current metering equipments are able to measure. There is no requirement for operators to install new equipments to satisfy the molecular level defined in the product list.

ISC Product Name ISC Product Code Methane C1-IC Ethane ISC C2-IC Propane ISC C3-IC Butanes ISC C4-IC Pentanes Plus ISC C5+-IC Carbon Dioxide ISC C02-IC Helium ISC HE-IC Hydrogen ISC H2-IC Nitrogen ISC N2-IC Oxygen ISC O2-IC Sulphur ISC SUL-IC Hydrogen Sulphide ISC H2S-IC

Facility Average Royalty Rate (FARR%) Calculation and Supporting Details Under the Natural Gas and NGL Royalty Framework Change, the Department calculates the gas royalty rate at the facility level. This Facility Average Royalty Rate (FARR%) is the weighted average royalty rate based on the ISC content within the royalty-triggered gas. Gas production with Old vintage will be assessed at the Old FARR%. Gas production with New vintage will be assessed at the New FARR%. Royalty triggered gas production at a facility, with some exceptions, will be assessed at FARR%. See ‘Points to remember for FARR% and FAP calculations’ in this article for exceptions. • Old FARR% =

Sum of (ISC Product Energy times ISC Product Old R%) Divided by

Sum of ISC Product Energy

• New FARR% = Sum of (ISC Product Energy times ISC Product New R%)

Divided by Sum of ISC Product Energy

The Department will publish ISC product royalty rates in the monthly Gas Royalty Calculation Information Bulletins. The Old/New vintage for the ISC products will be consistent with Old/New vintage for the extracted products. Methane, Ethane ISC and Pentanes Plus ISC have Old/New vintage. Propane and Butanes do not have Old/New vintage. The facility average royalty rates will not be generated until invoice calculation. Royalty clients will receive supporting details on the FARR% calculations in their monthly invoice package. Attachment 8 is a sample of the FARR% Supporting Details that royalty clients will receive. Low Productivity Well Allowance The low productivity well allowance continues to apply to gas and ethane production that meet the low productivity criteria. Refer to the September 1, 2001 edition of the Alberta Natural Gas Royalty Principles and Procedures on Low Productivity Well Allowance for eligibility. The low productivity rate adjustment for Gas and Ethane will be calculated using the royalty rate for Methane.

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For Gas and Ethane production eligible for low productivity well allowance, the crown royalty rate is calculated as: R% = RC - (RM – 5) x (16.9 – ADP)2 16.9 RC is the Methane Old/New royalty rate if production is Gas and the Ethane Old/New royalty rate if production is Ethane. ADP is the average daily production of natural gas from the well event for the production month divided by 100m.

RM is the Old/New royalty rate for Methane.

Raw Gas Average Royalty Rate (RARR%) Calculation and Supporting Details Facility average royalty rates will be used to assess gas royalty, but there are some exceptions. Raw gas sales that are subsequently processed and raw gas sales that are subsequently used for lease fuel are assessed at the raw gas average royalty rate (RARR%), rather than FARR%. The raw gas average royalty rate is based on the ISC factors identified by the seller on the Raw Gas Allocation (RGA) submission, rather than the ISC composition of the royalty trigger quantities at the facility. The RGA is a new Registry submission that is filed when there are ownership changes of gas quantities within the royalty network. Refer to Appendix N of the September 1, 2001 edition of the Alberta Natural Gas Royalty Principles and Procedures for the definition of royalty network. Refer to the Gas Royalty Calculation June Information Bulletin, 02-06A for raw gas reporting information.

Only ISC factors from Methane, Ethane ISC, Propane ISC, Butanes ISC and Pentanes Plus ISC are included in the RARR% calculation. Raw gas sales with Old vintage will be assessed at the Old RARR%. Raw gas sales with New vintage will be assessed at the New RARR%.

• Old RARR% =

Sum of (ISC Product Factor on RGA times ISC Product Old R%) Divided by

Sum of ISC Product Factor on RGA

• New RARR% = Sum of (ISC Product Factor on RGA times ISC Product New R%)

Divided by Sum of ISC Product Factor on RGA

The raw gas average royalty rates will not be generated until invoice calculation. Royalty clients will receive supporting details on the RARR% calculations in their monthly invoice package. Attachment 9 is a sample of the RARR% Supporting Details that royalty clients will receive. Facility Average Price (FAP) Calculation and Supporting Details Under the Natural Gas and NGL Royalty Framework Change, the valuation price for gas will be calculated at the facility level. This Facility Average Price (FAP) is the weighted average reference price based on the ISC content within the royalty-triggered gas, less the facility gas transportation deduction. Royalty triggered gas production at a facility, with some exceptions, will be assessed at FAP. See ‘Points to remember for FARR% and FAP calculations’ for exceptions.

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• FAP =

Facility Reference Price Minus

Facility Gas Transportation Adjustment

o Facility Reference Price = Sum of (ISC Product Energy times ISC Product Reference Price)


o Gas Transportation Adjustment = [Royalty Trigger Factor minus 1]

Multiply by Facility Adjusted IATD

o Royalty Trigger Factor =

Sum of (ISC Product Energy times Meter Station Factor) Divided by

Sum of ISC Product Energy

o Facility Adjusted IATD = Sum of (ISC Product Energy times Adjusted IATD of ISC)


The Department will publish ISC product-pricing information in the monthly Gas Royalty Calculation Information Bulletins. The facility reference prices will not be generated until invoice calculation. Royalty clients will receive supporting details on the FAP calculations in their monthly invoice package. A sample of the FAP Supporting Details that royalty clients will receive is included in Attachment 10.

Points to remember for FARR% and FAP calculations: • Same ISC product energy is used in calculation • ISC product energy refers to the ISC dispositions at the charge facility that are royalty triggers.

However, if charge facility is an injection facility, ISC product energy refers to the ISC receipts rather than the dispositions.

• Injection Credits are valued at the FARR% of the injection facility and the FAP of the reproducing facility.

• Only C1-IC, C2-IC, C3-IC, C4-IC, C5+-IC product energies are used in calculation. • Facility averages are different each production month because they are based on volumetric

submissions and published royalty variables (royalty rates, reference prices, adjusted intra-Alberta transportation deductions, meter station factors). Once calculated and invoiced for a production month, facility averages will only change for that facility and production month if amendments are processed for volumetrics and meter station factors (this occurs very rarely).

• The Crown Royalty calculation of raw gas that is injected is valued at the FARR% of the injection facility and the FAP of the reproducing facility.

• Exceptions to FARR% and FAP: o� Raw gas sale subsequently processed is assessed at raw gas average royalty rate and

80% of Gas Reference Price. o� Raw gas sale subsequently used for lease fuel is assessed at raw gas average royalty rate

and 100% of Gas Reference Price.

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ISC Balancing and Discrepancy Notice Gas deliveries from a plant to a pipeline meter station are subject to royalties. The ISC quantities of the gas deliveries may be reported by the meter station operator or its common stream operator, rather than by the operator of the linked pipeline. Refer to the Registry Training Modules (available via Registry web site http://www.petroleumregistry.gov.ab.ca) for common stream operator reporting in the Registry Volumetric Submission process for information on meter station operator and common stream operator reporting. An ISC balancing process will occur at pipeline meter stations to ensure there are no volumetric discrepancies between the ISC allocations reported at the pipeline meter station and the ISC allocations reported at the linked pipeline. The ISC allocations at the pipeline meter stations affect the component weightings in the FARR% and FAP calculations. The ISC balancing process will compare the ISC product receipts to the ISC product dispositions at each pipeline meter station. ISC Product discrepancies will be reported on a discrepancy notice (Monthly Statement of ISC Imbalances at Meter Stations) that will be sent to the meter station operator or its common stream operator (as submitter of the ISC receipts) approximately 35 days following the production month. Failure to correct the discrepancy will result in the product quantity being valued at C5+-IC R% and C5+-IC Reference Price in the FARR% and FAP calculations. Attachment 11 is a sample of the ISC discrepancy notice to the meter station or common stream operators. Default Royalty Variables and Supporting Details Certain situations may necessitate the use of default royalty variables by the Crown for royalty assessment. Currently, when default royalty variables are used, clients receive notification in the Defaults Report, which is included in the monthly invoice package. The following new default situations will be added to the Defaults Report because of the Natural Gas and NGL Royalty Framework Change.

Information on Defaults Report Default Situation Default Item Form Default Description ISC balancing discrepancy Facility Averages Volumetric ISC Imbalance: C5+-IC No FARR% calculated, ISC not available

FARR

Volumetric ISC not filed: C1-IC

No FAP calculated, ISC not available

FAP Volumetric ISC not filed: GRP

No FAP calculated at reproducing facility, ISC not available

FAP Volumetric ISC not filed at Reproducing Facility: FAP at IF

No RARR% calculated, RGA not available

RARR RGA RGA not filed: FARR

Attachment 12 is a sample of the Default Report that royalty clients will receive if the Department has used default royalty variables in their royalty assessment.

Royalty Calculation and Crown Royalty Detail Report

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The Natural Gas and NGL Royalty Framework Change has resulted in the assessment of gas royalty using facility average royalty rates and facility average prices (adjusted for transportation), and in some cases, using raw gas average royalty rates and 80% or 100% of gas reference prices. There is no change to the Crown Royalty Detail Report, or its User Defined File (UDF), because of this change initiative. However, the Crown Royalty Detail Volumetric Report and the Crown Royalty UDF are impacted by the developments of the Registry. Refer to the Gas Royalty Calculation June Information Bulletin, 02-06A for information on Gas Crown Invoice Changes.



Late Filing Penalty Changes The Business Design Team recommended that a Penalty Review Committee consisting of Department and Industry representatives be formed to review the penalty process. The objective of the Penalty Review Committee was to examine the current penalty process, identify the common reasons for penalty occurrences and recommend changes to enhance the penalty process. The recommendations made must be consistent with the stated objective of the penalty process, which is to ensure timely and accurate reporting while maintaining the interest of both the department and Industry. Evaluation Criteria: The review of potential options and recommendations made to improve the penalty process were evaluated against the following criteria:

• Timeliness and accuracy of information is maintained • Interests of the Department and Industry clients (including third parties) are maintained. • Administrative burden of penalties is reduced for both the Department and Industry.

Penalty Changes: As a result of the recommendations of the Penalty review Committee, the following changes will be made to late filing penalty. These changes are effective for the filing of the 2002 production year annual allowable cost forms. AC2 Form – Capital Cost Allowance:

• Move the due date from April 15 to April 30 of the year following the production year to which the form relates.

• Grant 15 days grace period for penalty levy if the AC2 form was received on or before April 30 of the year following the production year to which the form relates but was rejected because of MRIS edits.

AC4 Form – Annual Allowable Operating Cost:

• Reduce the penalty from $1000 per year to $ 200 per year for failing to file a valid AC4 form on or before March 31 of the year following the production year to which the form relates.

AC5 Form – Allowable Cost, Custom Processing Fees Paid:

• Assess the penalty of $100 per month or part of a month on the receipt of the AC5 form after the due date of May 15 of the year following the production year to which the form relates, rather than the current penalty of $100 per month or part of a month for failing to file the expected AC5 form by the prescribed due date.

• Grant 15 days grace period for penalty levy if the AC5 form was received on or before May 15 of the year following the production year to which the form relates but was rejected because of MRIS edits.

RMF3 Calculation and Examples The RMF3 document allows operators of a well, that has a Crown interest greater than 0% but less than 100%, to report the working interest % and Crown interest % for the working interest owners. The Crown Share % for each client will be used in the royalty calculation instead of the Provincial Crown interest% for the well.

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Here are three calculation rules that apply to an RMF3 document:

• Total Working Interest Owner % must equal 100. • WIO% multiplied by the Crown% must equal the Crown Share for each client. • Total Crown Share must equal the Total Crown % reported in Field 2.6.

Note: The Crown Share is not reported on the RMF3 – the Department will calculate the Crown Share for each client by multiplying Field 2.9 by Field 2.10, and ensure that the Total Crown Share for the well agrees with the Provincial Crown interest % for the well. The following examples are provided for clarification when calculating the Crown % when completing an RMF3 document (field 2.10): Example 1. Well is 75% Crown, 25% Freehold. Total spacing for the well is 256 hectares. Client A holds 64 hectares (25%) which are 100% Crown. Client B holds 64 hectares (25%) which are 100% Crown. Client C holds 64 hectares (25%) which are 100% Freehold. Client D holds 64 hectares (25%) which are 100% Crown. RMF3 should be filed as:

(2.7) Client (2.9) WIO% (2.10) Crown % Calculated Crown Share A 25.00 100.00 25.00 B 25.00 100.00 25.00 C 25.00 0.00 0.00 D 25.00 100.00 25.00

Total 100.00 75.00 Example 1a. Client D acquires Client C’s share of the property. Revised ownership is: Client A holds 64 hectares (25%) which are 100% Crown. Client B holds 64 hectares (25%) which are 100% Crown. Client D now holds 128 hectares (50%) which are 50% Crown. {Crown % = (64.0 / 128.0) x100}. Revised RMF3 should be filed as:

(2.7) Client (2.9) WIO% (2.10) Crown % Calculated Crown Share % A 25.00 100.00 25.00 B 25.00 100.00 25.00 D 50.00 50.00 25.00

Total 100.00 75.00

Example 2. Well is 25% Crown, 75% Freehold. Total spacing for well = 256 hectares Client A holds 18.944 hectares (7.40%) which are 100% Crown. Client B holds 139.904 hectares (54.65%) of which 39.168 are Crown hectares. {Crown % = (39.168/139.904) x100}. Client C holds 91.264 hectares (35.65%) which are 100% Freehold. Client D holds 5.888 hectares (2.30%) which are 100% Crown.

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RMF3 should be filed as: (2.7) Client (2.9) WIO% (2.10) Crown % Calculated Crown Share %

A 7.40 100.0000000 7.40 B 54.65 27.9963403 15.30 C 35.65 0.0000000 0.00 D 2.30 100.0000000 2.30

Total 100.00 25.00 Example 2a. Client B acquires Client C’s share. Client B now holds 231.168 hectares (90.30%) Crown hectares for Client B = 39.168 ha. The new Crown Interest for Client B = (39.168/231.168) x 100 = 16.9435216% Revised RMF3 should be filed as:

(2.7) Client (2.9) WIO% (2.10) Crown% Calculated Crown Share %A 7.40 100.0000000 7.40 B 90.30 16.9435216 15.30 D 2.30 100.0000000 2.30

Total 100.00 25.00 C. MONTHLY INFORMATION

May 2002 Royalty Due August 31

• Royalty clients are to remit the total amount payable shown on the August 2002 Statement of Account by August 31, 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 August 2002 Statement of Account shows your amount payable as of the Statement issue date. It includes any outstanding balances from your previous statement, your May 2002 Invoice amount and any applicable current period interest charges. It also identifies refunds resulting from overpayments.

• Current period interest will not be charged on current invoice charges for the production month of May 2002 if it is paid in full by August 31, 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.

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

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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 July 2002 The Department of Energy’s interest rate for July 2002 is 5.25%.

April Provisional Assessment Charge

The net Provisional Assessment Charge for the April 2002 billing period was $10,344,393.31. This includes $50,999,723.55 in first time provisional assessments and ($40,655,330.24) in reversals of provisional assessments for all production periods.

April Penalty Charges The following are the Penalty Charges by form type for the April 2002 billing period:

FORM Penalties Charged AC2 $20,400 AC4 $1,000 AC5 $51,000 GR2 $0 NGL1 $0 VA2 $0 VA3 $0 VA4 $0 Total Charged $72,400 Total Reversed ($25,100)

Net Penalties Charged for 2002/04 $47,300

Alberta Royalty Tax Credit Program Quarterly Rate

For the third quarter of 2002, the Alberta Royalty Tax Credit rate will be .2500. This rate is based on a royalty tax credit reference price of $249.61 per cubic metre. The Alberta Royalty Tax Credit rates for the past year were:

Second Quarter, 2002 .2500 First Quarter, 2002 .2500 Fourth Quarter, 2001 .2500 Third Quarter, 2001 .2500

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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 August 2002 Information Bulletin. If further information is required on any other projects, please contact Isabelle Warwa at (780) 422-8966.

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 struck clients:

Company Name Client ID Struck Date 231310 Alberta Ltd. 0DJ7 June 2, 2002 Barclay Energy Corporation 0LL9 June 2, 2002 Capco Resources Ltd. 0KN2 June 2, 2002 National Petroleum Corporation 0104 June 2, 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.

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http://www.energy.gov.ab.ca/NaturalGas/743.asp


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 E. REMINDERS

Royalty Payers Only (Companies and individuals that are not operators of facilities, but do currently receive information from industry partners, or invoices, statements and other correspondence from the Department of Energy have been deemed “Royalty Payers Only” by the Petroleum Registry of Alberta) Ease of Use The Petroleum Registry of Alberta has been designed to make it easier for stakeholders to receive and submit data to Industry partners and the Ministry of Energy. To increase ease of use of the Registry, free “Royalty Payers Only” training modules are being developed and will be posted to the Registry web site by the end of July. To obtain a training ID and password for these modules, visit the “Online Industry Training” section in the Training area of the Registry web site at www.petroleumregistry.gov.ab.ca. A major benefit of using the Registry is eliminating paper from the process, as users will have the capability of electronically submitting and receiving data through the Registry from their computer at home or office. Royalty payers who do not have their own computer can use any computer with Internet access. One location that provides computers with Internet access to the public is the local library. Below is a list of the minimum client technical configuration for any computer used to access the Registry. Hardware - Pentium 133 Mhz - 32 MB Win 95/98 or 64 MB for Microsoft Windows NT or 2000 Software - Microsoft Windows 95/98/NT 4.0/2000/XP - Internet Explorer 4.0+ or Netscape 4.0+ (both support 128bit encryption) - JavaScript enabled - Screen size 800x600 Networking - Internet Access at 28.8 kbps or greater There is also a minimum requirement that users of the Registry have 128-bit encryption built into their Internet browser. Without this level of encryption, a user will not be able to access the work area of the Registry.

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http://www.energy.gov.ab.ca/NaturalGas/1141.asphttp://www.petroleumregistry.gov.ab.ca/


This encryption level provides security for those using the system and the information contained in the Registry. To ensure that your browser version has 128 bit encryption, or if you just want to upgrade your browser, we have included instructions for this upgrade.

For Netscape

• Go to www.netscape.com • Click the “New Download” Button. • Click the “Netscape Communicator Series” link. • Click the “English” link. • Click the “Windows 95, 98, NT, or 2000” link. • Click the “4.79 latest version” link. • Choose either the “base” or “complete” link and click it. • Click the “Download It Now” button. • Follow the instructions on the page.

For Internet Explorer

• Go to www.microsoft.com/windows/ie/default.asp • Click the “Downloads” button. • Click the “Microsoft Internet Explorer 6” link. • Click the “Go” button at the far right side of the screen. • Follow the instructions on the page. A reminder: Users must have a minimum of version four of their browser (Netscape or Internet Explorer) to use the Registry. As a company or individual that will perform work processes, or communicate within the Registry, you must also be identified as a 'Business Associate' (BA). Any royalty payer who sends or receives information from the Ministry of Energy already has a 7 digit Royalty Client Code. These 7-digit codes have been converted into new four-digit Business Associate codes. Refer to Attachment 13.

Royalty Deposit Adjustment The royalty deposit recalculation for 2002 is the lesser of 1/6 of a client's net royalty for 2001 and the amount determined by multiplying the current deposit maintained by the client by a price factor. The factor of (1.00) was calculated by dividing the current year long-term gas reference price for 2002 ($3.50) by the long-term gas reference price used in the 2001 ($3.50) calculation.

How to Use the Petroleum Registry: for “Royalty Payers Only” Web based training modules are being developed to help stakeholders learn how to use the Petroleum Registry of Alberta. Royalty payers will be able to access the free “Starter” training package, which is available through the Registry web site (www.petroleumregistry.gov.ab.ca). A special module is being developed and targeted to those companies and individuals that are exclusively non-operators (what we call “Royalty Payers Only”).

15

http://www.netscape.com/http://www.microsoft.com/windows/ie/default.asphttp://www.petroleumregistry.gov.ab.ca/


If you are a “Royalty Payer Only”, and are wondering how the Registry will affect you, check out the Registry web site, and stay tuned…we have training and communications being prepared…just for you! PLEASE NOTE!! Some “Royalty Payer Only” companies may wish nonetheless to receive the full Comprehensive Training Package. Please contact the Registry to arrange for invoicing and registration.

Implementation of the Petroleum Registry of Alberta

Consolidated Single Well Group Set-up/Change Form - RMF1 Please be advised that prior to the implementation of the Petroleum Registry of Alberta in October, 2002 the Gas Royalty Calculation unit will be dismantling all active Consolidated Well groups that were set-up via the RMF1 form. Well group operators will be contacted prior to the dismantling of their well groups. When reporting stream allocations in the Petroleum Registry, Consolidated Well group ID’s cannot be used. The wells that are currently in these well groups will have to be reported as single wells. If you wish to terminate a well group prior to this time, you may file an amended RMF1. Single Well/Injection Scheme Setup/Change Form - RMF3 Part 2 - Working Interest Ownership, Field 2.3 - RMF3 form must be filed for all gas and gas products (field must be left blank). The Department will no longer accept documents for a specific product type. The Department will contact those clients who have previously filed RMF3s this way to have them revised. In addition, there is no requirement to file an RMF3 document when there is only one working interest owner for the single well. The Department will generate the correct Crown interest for this working interest owner based on the single well crown percentage.

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 July 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

16

http://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.

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

17

INFORMATION BULLETIN – July 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 2.71 3.17 2.71 3.17 202.39 182.71 88.14 61.67 133.59 85.58 2.08

MAR 3.23 2.71 3.23 2.71 238.61 188.93 115.54 89.46 151.29 120.48 6.81

APR 3.91 3.23 3.91 3.23 266.20 228.29 127.52 119.33 165.92 142.78 4.43

MAY 3.91 3.91 3.91 3.91 267.65 255.79 125.63 109.72 161.03 132.84 6.94

JUN

JUL

AUG

SEPT

OCT

NOV

DEC

DETAIL OF THE MAY 2002 GAS REFERENCE PRICE SELECT PRICE 2002 Weighted Average Price of Alberta 4.190 $/GJ New Gas ($per GJ)

Old Gas ($per GJ)

Pentanes ($per m3)

Deductions: Intra – Alberta Transportation 0.277 $/GJ 1.252 0.372 45.30

Marketing Allowance 0.029 $/GJ New Ethane($per GJ)

Old Ethane ($per GJ)

Price Before Pipeline Factor 3.884 $/GJ 1.252 0.372

Pipeline Fuel/Loss Factor 0.987 Price before Special Adjustment 3.834 $/GJ

Special Adjustment 0.000 $/GJ Price before 2% amendment limitation or rounding 3.834 $/GJ Weighted Average Reference Weighted Average OMAC Amendments:Carry forward (from previous RP month) -0.002 $/GJ Price ($/GJ) ($/GJ) Prior Period Amendment Adjustment (current RP month) 0.250 $/GJ

5.111 0.021 Calculated RP after Amendments 4.082 $/GJ MAY 2002 Reference Price 3.91 $/GJ Difference = value carried forward to next RP month 0.172 $/GJ

Adjusted IATD (before Prior Period Amendments) 0.274 $/GJ ANNUAL SULPHUR DEFAULT PRICE Prior period Amendments (IATD and Pipeline Fuel Loss) 0.000 $/GJ 1997 1998 1999 2000 2001 Adjusted IATD (after Prior Period Amendments) 0.274 $/GJ $9.98 $6.01 $10.54 $10.96 $0.30


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 10.24 12.31 15.91 19.03 9.42 4.64 7.92* 11.27 9.87 17.05 24.66 9.89 8.75

MAR 11.82 7.51 11.69 11.92 6.47 3.08 5.43* 7.48 13.28 16.64 27.47 16.61 8.75

APR 8.41 8.99 15.55 13.48 -0.40 -5.55 -2.00* 3.54 7.46 11.14 18.38 7.57 8.75

MAY 6.40 9.39 16.71 12.61 6.36 -1.34 3.93* 7.52 8.86 15.73 15.95 8.55 8.75

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 – July 2002 ATTACHMENT 2A

PRIOR PERIOD AMENDMENT EFFECTS

NGL REFERENCE PRICES MAY 2002

Propane Butane Pentanes

Price before amendments 125.628291 161.030685 267.646332

Opening Rollover (from prior business month) -0.002906 -0.003765 0.002220

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 125.63 161.03 267.65

TRANSPORTATION ALLOWANCES MAY 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) 0.002146 -0.004869 0.003932 -0.001837 -0.004394 0.001250 -0.002675 -0.000713 0.003844 -0.004121 0.003889 0.004790

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 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000

Total Amendment Effect 0.002146 -0.004869 0.003932 -0.001837 -0.004394 0.001250 -0.002675 -0.000713 0.003844 -0.004121 0.003889 0.004790

Calculated Transp. Differential 6.402616 9.396307 16.704091 12.608341 6.367667 -1.337290 3.931183* 7.520406 8.851990 15.731296 15.945080 8.549204

Calculated Transp. Differential after Total

Amendments

6.404762 9.391438 16.708023 12.606504 6.363273 -1.336040 3.928508* 7.519693 8.855834 15.727175 15.948969 8.553994

Published Transportation Allowance 6.40 9.39 16.71 12.61 6.36 -1.34 3.93* 7.52 8.86 15.73 15.95 8.55 * 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.


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 35.00000 30.00000 35.00000 30.00000 43.05785 31.77686

MAR 35.00000 28.45018 35.00000 28.45018 43.28640 31.88297

APR 35.00000 30.00000 35.00000 30.00000 44.44391 32.42039

MAY 35.00000 30.00000 35.00000 30.00000 45.04124 32.69772

JUN

JUL

AUG

SEPT

OCT

NOV

DEC

INFORMATION BULLETIN - July 2002 FACILITY OPERATOR CHANGE FORM OC1 ATTACHMENT 4

EUB FACILITY FACILITY NAME PREVIOUS OPERATOR NAME PREVIOUS CLIENT ID CURRENT OPERATOR NAMECURRENT CLIENT ID

EFFECTIVE DATE

AB-GP-1025 DEVON NORMANDVILLE DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GP-1464 PROVIDENT CRAIGMYLE DEVON CANADA 0F3F PROVIDENT ACQUISITIONS L P 0X0T 2002-05AB-GP-1525 PENN WEST GENESEE GAS PLANT DEVON CANADA 0F3F PENN WEST PETROLEUM LTD 0BP8 2002-04AB-GP-1546 PROVIDENT CESSFORD DEVON CANADA 0F3F PROVIDENT ACQUISITIONS L P 0X0T 2002-05AB-GP-1691 RENAISSANCE TABER SOUTH NUMAC ENERGY INC 0307 RENAISSANCE ENERGY LTD 0BN9 1998-01AB-GP-1691 HUSKY TABER SOUTH RENAISSANCE ENERGY LTD 0BN9 HUSKY OIL OPERATIONS LIMITED 0R46 2001-01AB-GP-1755 DEVON BERWYN GAS PLANT 8-36 DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GP-1800 AEC SUFFIELD A2 SOLUTION GAS FACILITY ENCANA OIL & GAS CO LTD 0TT5 ALBERTA ENERGY COMPANY LTD 0R61 2002-05AB-GS-2968 DEVON NORMANDVILLE DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-3396 ARC JENNER MERIT ENERGY LTD 0TJ8 ARC RESOURCES LTD 0G30 200008AB-GS-3477 DEVON BAPTISTE ULSTER PETROLEUMS LTD 0K16 DEVON AXL 0WC8 200110AB-GS-3477 DEVON BAPTISTE DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-3833 CNRL GRIMSHAW ENERPLUS RESOURCES CORPORATION 0JD4 CANADIAN NATURAL RESOURCES LIMITED 0HE9 200102AB-GS-3844 PENN WEST PEMBINA DEVON CANADA 0F3F PENN WEST PETROLEUM LTD 0BP8 2002-04AB-GS-4113 CNRL DRUMHELLER 07-22 TALISMAN ENERGY INC 0039 CANADIAN NATURAL RESOURCES LIMITED 0HE9 1998-10AB-GS-4220 ADDISON MORNINGSIDE DEVON CANADA 0F3F ADDISON ENERGY INC 0XK3 2002-05AB-GS-4225 DEVON LLOYDMINSTER DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-4252 RENAISSANCE TABER SOUTH NUMAC ENERGY INC 0307 RENAISSANCE ENERGY LTD 0BN9 1998-01AB-GS-4252 HUSKY TABER SOUTH RENAISSANCE ENERGY LTD 0BN9 HUSKY OIL OPERATIONS LIMITED 0R46 2001-01AB-GS-4255 DEVON LEDDY DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-4278 DEVON JACK DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-4361 DEVON PARADISE DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-4736 DEVON FERRIER 10-24-039-08W5 GGS NUMAC ENERGY INC 0307 DEVON AXL 0WC8 2001-09AB-GS-4736 DEVON FERRIER 10-24-039-08W5 GGS DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-4737 DEVON WESTROCK FERRIER 9-22-39-8W5 GGS NUMAC ENERGY INC 0307 DEVON AXL 0WC8 2001-09AB-GS-4737 DEVON WESTROCK FERRIER 9-22-39-8W5 GGS DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-4738 DEVON FERRIER 7-13-039-08W5 GGS NUMAC ENERGY INC 0307 DEVON AXL 0WC8 2001-09AB-GS-4738 DEVON FERRIER 7-13-039-08W5 GGS DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-4739 DEVON FERRIER 9-22-39-8W5 GGS NUMAC ENERGY INC 0307 DEVON AXL 0WC8 2001-09AB-GS-4739 DEVON FERRIER 9-22-39-8W5 GGS DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-4793 DEVON LEAHURST 14-18 NORTHSTAR ENERGY CORPORATION 0BK8 DEVON CANADA 0F3F 2002-04AB-GS-6069 DEVON BIRCH GGS DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04AB-GS-6286 ARC JENNER GGS 15-31 PROMAX ENERGY INC 0YL7 ARC RESOURCES LTD 0G30 2002-03AB-GS-6359 DEVON BINGO GAGE 11-28 DEVON AXL 0WC8 DEVON CANADA 0F3F 2002-04


NEW PLANTS

EUB FACILITY CODE

FACILITY NAME

TRANSPORTATION REGION

PLANT TYPE

PLANT TYPE

EFFECTIVE DATE

AB-GP-1841 CANADIAN HUNTER BERLAND SWEET PLANT 4 2 2002-05

AB-GS-6410 CONOCO WESTERN 6-25 GGS 1 1 2002-04

AB-GS-6453 HUSKY MARWAYNE 16-27 1 1 2002-05

AB-GS-6454 CANADIAN HUNTER BERLAND SWEET PLANT 4 1 2002-05

AB-GS-6455 AUBURN WHITE FISH 14-12 1 1 2002-05

AB-GS-6456 CRESTSAR WEMBLEY SOUTH GAS GATHERING SYSTEM 4 1 2002-06

AB-GS-6457 AEC DIMSDALE 10-10 LEG 4 1 2002-06

AB-GS-6459 CNR COLD LAKE 10-18 1 1 2002-06

INFORMATION BULLETIN - July 2002 ATTACHMENT 6

Facility ID

Facility Operator

IDProduction

Period Billing Period

Royalty Trigger Factor

Pipeline Operator

Meter Station ID

Meter Station Factor

Deleted Tie

Facility to Meter Tie

DateFacility to Meter

Termination Date

Meter Factor Effective

Date

Meter Factor Termination

DateAB-GP-1838 0A0C 2002-04-01 2002-05-01 1.2 NOVA 2751 1.2 2002/04/01 3000-01-01 2002-04-01 3000-01-01AB-GS-6246 0NX9 2001-07-01 2002-05-01 1.08 NOVA 2066 1.08 2001-07-01 3000-01-01 2001-07-01 2001-10-01AB-GS-6246 0NX9 2001-10-01 2002-05-01 1.13 NOVA 2066 1.13 2001-07-01 3000-01-01 2001-10-01 3000-01-01AB-GS-6355 0WY9 2002-02-01 2002-05-01 1.06 NOVA 1833 1.06 2002-02-01 3000-01-01 2001-11-01 3000-01-01

There are no changes to this month's Injection and Reproducing Facility Ties Report

Multiple Gas Valuation Factors

Injection and Reproducing Facility Ties


Registry ISC Reporting Table

For activity at reporting facility and from/to location, submitter must report

ISC, along with the Gas volumetric submission to the Registry.

Submitter Reporting

Facility

Activity From/To

Location

Pipeline Operators

AB PL REC AB MS sub type 631

Meter Station Operators, or Common Stream Operators

AB MS with link to a non reporting PL, AB MS where Registry auto population is not elected

REC AB BT, AB GS, AB GP

Mainline Straddle Plant Operators

AB GP sub type Mainline Straddle


Field Straddle Plant Operators

AB GP sub type Field Straddle


Injection Facility Operators

AB IF REC AB BT, AB GS, AB GP

Battery, Gathering System or Gas Plant Operators

AB BT, GS, or GP

DISP AB RE, AB CO, AB IN, AB EG, AB R1, AB R2

Battery, Gathering System or Gas Plant Operators

AB BT, GS, or GP

DISP Any non AB location

Raw Gas Sellers

Report ISC factors of raw gas stream on RGA Submission

AB Alberta BT Battery CO Commercial DISP Disposition EG Electrical Generation GP Gas Plant GS Gathering System IF Injection Facility IN Industrial MS Meter Station PL Pipeline RE Residential REC Receipt R1/R2 Residential Pipeline


Meter Station/Common Stream Operator: FRANKS PETROLEUM COMPANY LTD (OJPA)


Original 7-Digit Reporting Code

4-Digit Code To Be Used After Aug 1, 2002 Legal Name

Current BA Status (as of July

16, 2002)0000001 0D6Y ABBOTT CHARLES R ACTIVE0000002 0M0G ROYAL TRUST CORPORATION INACT0000006 0W5A PARK, HELEN G TERM0000010 0Y9G TRILOGY RESOURCE CORPORATION TERM0000056 0Y7E BLUE RANGE RESOURCES (USE EB6) TERM0000111 0F1N CYNTHIA PEMBINA SHIPPING TERMINAL ACTIVE0000113 0W1B DEKALB PETROLEUM TERM0000163 0Y7Z KOCH OIL CO LTD TERM0000204 0X8T PANCONTINENTAL OIL INACT0000222 0Y8J PETROL PROPERTIES TERM0000273 0X6G SIPCO OIL LTD TERM0000299 0W7N UNIVERSAL EXPLORATIONS LTD TERM0000322 0M5K SMITH, GEORGE IRVIN INACT0000325 0R4C SMITHSON, FRIEDA INACT0000346 0R5E TOMAHAWK NO 521 MUNCIPAL DISTRICT OF INACT0000348 0R6B WAWRINCHUK, WILLIAM INACT0000459 0Z1A WABASH OIL & GAS LTD INACT0000669 0K5A NIELSON DALE MELVIN ACTIVE0000839 0M5W SMYLIE, JOHN KENNETH ESTAE OF; ECKSTRAND, FRANCES ET AL EXECUTORS INACT0000852 0Y1G PRC PETROLEUM (1984) LTD TERM0000877 0M7Y STEWART, HAZEL MRYTLE ACTIVE0001029 0P4A CAMERON, UNA INACT0001040 0X2W SMITH, WILLIAM M. ACTIVE0001095 0H2G JENSEN JOHN E ACTIVE0001098 0H6A KLAUS, PAUL ET AL ACTIVE0001205 0W7H THE HORSHAM CORPORATION TERM0001220 0E3N B. PEDERSEN RESOURCES LTD ACTIVE0001262 0T9W CENTRAL TRUST COMPANY TERM0001300 0R6E WHEATLAND COUNTY INACT0001307 0T9X CHADON RESOURCES LTD TERM0001312 0X2P PETROL OIL & GAS COMPANY LIMITED INACT0001338 0F7H ENGBERG, LILA ACTIVE0001457 0M7R STEFURA, ANNA ACTIVE0001486 0M0L RUSSELL, MYRTLE ACTIVE0001517 0Y9T RENAISSANCE ENERGY LTD INACT0001562 0T0F CLIFTON C. CROSS AND COMPANY LIMITED STRUCK

Business Associate 7-Digit to 4-Digit Conversion Table

Page 1 of 80





16, 2002)0001573 0X8W PEYTO OILS LTD ACTIVE0001615 0N1N THOMPSON HARLAN TRENHOLM ACTIVE0001623 0L9M RONDEAU LUCILLE INACT0001624 0J5X BOURGEOIS FLORENCE INACT0001653 0P6M FAYANT, LUCY INACT0001681 0H3C JONSSON, DIANE ACTIVE0001789 0T9G CAMELOT MINERALS LTD TERM0001835 0W7G THE CANADA TRUST COMPANY TERM0001837 0N7A WESTERN JOINT VENTURES LTD ACTIVE0001852 0J4L MATEJKA, ALBERT: ESTATE OF MATEJKA, CHARLES & MATEJKA, ALBERT T. EXECUTORS ACTIVE0001956 0L4H R. P. RESOURCES LTD. ACTIVE0001981 0J6K BRERETON, ALEXANDER MCPHEE ACTIVE0002027 0R5N UNION OIL COMPANY OF CANADA LIMITED INACT0002061 0G2L GIBSON, THOMAS ET AL ACTIVE0002077 0T4W ROBERT T. MCDONALD LTD. (STRUCK EFF: 99/08/01) STRUCK0002080 0D2T 333916 ALBERTA LTD ACTIVE0002090 0M2D SCHMITZ, CLYDE D ACTIVE0002119 0E9F COMEAUX, JEAN ACTIVE0002150 0R1N NV RESOURCES CORPORATION LTD INACT0002171 0K0H MCJANNET RICH ACTIVE0002199 0L5K CARMICHAEL KENNETH CARL ACTIVE0002242 0P9R LINDSAY, VERONA ALBERTA INACT0002303 0G3Z GRAFF, JOHN M. ACTIVE0002306 0Y5E UNICORN AGRI-OIL LTD ACTIVE0002403 0G9J HUGHES CATHERINE GAIL ACTIVE0002421 0G2P GILBERT, JOHN HENRY ACTIVE0002559 0M5F SMITH ARTHUR ROBERT ET AL ACTIVE0002621 0M2A SCHMIDT EDMUND INACT0002626 0K2J MONAGHAN, JOHN TERENCE ACTIVE0002724 0H4N KELNDORFER, BETTY LOUISE ACTIVE0002726 0R2T POLS, JOYCE CATHERINE INACT0002757 0K0W MCMILLAN, ANGELINE M. ESTATE, POTOLICKI, MAXINE MARIE ET AL ADMINISTRATRICES ACTIVE0002777 0G9Z IMAGE OIL & GAS LTD ACTIVE0002817 0E7P CHRISTIANSEN, DOROTHEA CHRISTINE ACTIVE0002945 0L7G REBUS, MICHAEL S. ESTATE ET AL REBUS, ANNIE EXECUTRIX ACTIVE0002949 0L5L CAROLINE PETROLEUMS (1985) LTD ACTIVE0002963 0E5K BECHTHOLD, GEORGE ESTATE OF; BECHTHOLD, MYRTLE TILLIE EXECUTRIX ACTIVE0002964 0Y8B MISSI ENERGY LIMITED TERM0002968 0D3X 419258 ONTARIO LIMITED ACTIVE0002984 0T9Z CHESAPEAKE RESOURCES LTD TERM

Page 2 of 80





16, 2002)0002986 0K3H MORRIS VENTURES NO.1 LIMITED ACTIVE0002987 0F3D DERWENT PETROLEUM LTD ACTIVE0003002 0N2C TIPPETT, ROBERT GRAHAM ACTIVE0003007 0E5F BDO DUNWOODY LIMITED ACTIVE0003012 0J4X MCALLISTER WINNIFRED ACTIVE0003045 0W3M LEIGH FRANCIS LESTER TERM0003049 0D3B 353726 ALBERTA LTD ACTIVE0003050 0R3X SEABOARD LIFE INSURANCE COMPANY INACT0003098 0K7K OSBALDESTON, GARTH ALLISON ACTIVE0003126 0W3H KNAUT BUILDING LTD TERM0003189 0E1R BISHOP SHIRLEY ACTIVE0003190 0H5N KILLEN, DAVID ACTIVE0003191 0H5P KILLEN, DEBORAH ACTIVE0003192 0H5R KILLEN, RICHARD JOHN ACTIVE0003194 0P3P BRETT HAROLD B INACT0003198 0H2X JOHANSON URBON KENNETH ET AL INACT0003201 0J0B LINBERG, AUDREY BERNICE ACTIVE0003206 0P5W DUNCAN THOMAS BRAIDWOOD INACT0003209 0R4A SMART, GWENDOLYN F. INACT0003211 0K0C MCDONELL, DUNCAN A. ACTIVE0003219 0F6G ELGOOD LOIS INACT0003238 0P5X DZIURA ANTONIA ESTATE INACT0003249 0H4D KAY, VERNON ACTIVE0003253 0F6A EDGAR, WILLIAM JOHN ACTIVE0003255 0F5T ECKVILLE CO-OPERATIVE ASSOCIATION LIMITED ACTIVE0003256 0H4C KAY CHARLES INACT0003258 0J8E BUTTERFIELD, THOMAS ACTIVE0003300 0W1M ELLIOTT CHARLES RAINFORTH ET AL TERM0003305 0M7M STEELE, WASHBURN W. ET AL ESTATE OF STEELE, HARRIET A. EXECUTOR ACTIVE0003309 0P5Z EDITH ALICE MARGARET SPEIDEL INACT0003313 0H6Y KUEBER, EDMOND J ACTIVE0003316 0H2E JENKINS, ELIZABETH ACTIVE0003318 0J2A MACGREGOR, MARGARET ACTIVE0003319 0G8E HILKER AGNES Y INACT0003323 0J1P LYSAK, EVELYN MAY ACTIVE0003329 0E9E COMEAU, IDA ACTIVE0003333 0D9R AMPHLETT, CHARLES E. ACTIVE0003344 0H5F KERR, ELLIOT ACTIVE0003348 0P4T CLARKE, BRENDA INACT0003349 0E7Z CHURCHILL, LOIS M. ACTIVE

Page 3 of 80





16, 2002)0003351 0F2L DAVID LESLIE BEDDOES ACTIVE0003355 0E7H CHILIBECK, ELSIE ESTATE; GIEBELHAUS, SHIRLEY EXECUTRIX ACTIVE0003356 0E2K BODDY, VERONA ESTHER ACTIVE0003358 0F2N DAVIDSON, NANCY E. ACTIVE0003367 0R3F ROBERTS, DARYL J. INACT0003369 0P3A BAXANDALL, JOSEPH SENIOR ESTATE; BAXANDAL, DONALD ET AL ADMINISTRATORS INACT0003377 0G8P HODGES, ROBERT E. ET EL ACTIVE0003381 0H5X KINSELLA ELKS LODGE #364 ACTIVE0003384 0D7K AIDE FINANCIAL CORPORATION LTD ACTIVE0003387 0L5H RAWN BEATRICE INACT0003398 0L2B PREHN, LARRY RONALD ACTIVE0003430 0L6Z CHAPIN DONALD HAROLD INACT0003438 0P7W HEMEYER, WILFRED LESTER INACT0003444 0W3L LANG BAY RESOURCES LTD TERM0003453 0W2Z INEXCO ENERGY (CANADA) LIMITED TERM0003454 0R8W 89505 CANADA LIMITED STRUCK0003455 0R2L PERMEZ PETROLEUMS LTD. INACT0003456 0L5Y CARTWRIGHT OIL & GAS LTD ACTIVE0003457 0Y7D AUSTEX OIL AND GAS LTD TERM0003471 0R4X THALON PETROLEUMS LIMITED INACT0003500 0X2Z TARCO OIL AND GAS LTD. AMALG0003512 0N9Y YOUNG, EDWARD ET AL ACTIVE0003520 0M5J SMITH, CHARLES ESTATE; FERGUSSON, ROSE A. ET AL EXECUTORS ACTIVE0003577 0N5C VAN SLYKE, FLOYD ACTIVE0003586 0E0H ARBITRON ENGINEERING LTD ACTIVE0003629 0N7N WHITLA, WALTER R. ACTIVE0003647 0N9N YANDA VICTOR E INACT0003657 0H9Y LIGHTFOOT, ALICE MARY ACTIVE0003699 0Y9K VANGUARD ENERGY CORPORATION TERM0003756 0M3F SEVCON MANUFACTURING INC. ACTIVE0004028 0L7W REGLIN, ARLINE GRACE ACTIVE0004049 0F8K FAIRHEAD, PHYLLIS MARY ACTIVE0004075 0K0A MCCUNE, MOLLY ACTIVE0004078 0E1K BILTON ARTHUR HASTINGS ET AL ACTIVE0004118 0G5D GUARANTY TRUST COMPANY OF CANADA RE SNIDER BROS TRUST INACT0004160 0M2X SEARS, GEORGE EDGAR ACTIVE0004223 0Y9H ULSTER PETROLEUMS LTD TERM0004241 0J3X MARION ELIZABETH MCDONELL ACTIVE0004286 0P7A GARDINER, FRANCES INACT0004290 0W2M HOTCHKISS, HARLEY N. TERM

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16, 2002)0004366 0H6F KOBLUK, WILLIAM D. ACTIVE0004367 0K3K MORTON, ARNOLD NEWMAN II ACTIVE0004417 0Y3T PEMOCO EXPLORATION LTD ACTIVE0004419 0T9N CANENCO LTD (START EFF: 97/06/01) TERM0004435 0G4X GRIFFIN, CHRISTINE BERIT ACTIVE0004476 0D9K AMCAL RESOURCES LTD ACTIVE0004607 0G2R GILLELAND, JOHN L. ACTIVE0004608 0R1Y PAFFORD, MARTHA A. INACT0004622 0H8N LAZARUK, JEAN ACTIVE0004674 0Y2K HUSKY OIL LTD (FOR MIN TAX ONLY) ACTIVE0004675 0G63 HUSKY OIL (ALBERTA) LTD TERM0004686 0N6J WATSON & WATSON RESOURCES LTD ACTIVE0004693 0L6P CENTRAL GUARANTY TRUST COMPANY ACTIVE0004728 0F2J DARLINGTON, LAURA JEAN ACTIVE0004753 0M6D SOMMER, FERN T. ACTIVE0004767 0E50 HARISTON CORPORATION STRUCK0005184 0H7N LAJEUNESSE EDNA INACT0005323 0P06 399900 ALBERTA LTD TERM0005403 0T2L L HOLM MECHANICAL LTD STRUCK0005406 0P1B 392544 ALBERTA INC INACT0005412 0M1J SAPPHIRE INVESTMENTS INC ACTIVE0005433 0M0A ROSS RESOURCES INC. ACTIVE0005450 0J0J LIVINGSTONE, STANLEY VERDUN RICHARD INACT0005470 0J9T CANADIAN IMPERIAL BANK OF COMMERCE ACTIVE0005477 0J0L LOBB, RONALD E ACTIVE0005642 0Y3D MAGRATH ENERGY CORPORATION ACTIVE0005652 0L8E RICHARDS,HAZEL IRENE INACT0005707 0N5Z WACKER, EDNA MARLENE ACTIVE0005717 0F8D EWART, DAVID ERICK ACTIVE0005732 0G8N HOCHHAUSEN, EUGENE F. ACTIVE0005743 0H7M LABRE, DARLENE ACTIVE0005744 0K9F PEARSON, ROYCE ACTIVE0005770 0H8C LANK, ALGIE W. ET AL ACTIVE0005847 0R7W 338507 ALBERTA INC STRUCK0005879 0F3H DEWITT, RUTH LILLIAN ACTIVE0005909 0X2F CHAUVCO OIL AND GAS LTD INACT0005917 0Y6E MISSI RESOURCES LTD INACT0005948 0E4Y BATEMAN, BRIAN ACTIVE0005973 0K7H ORLICK, THOMAS JOHN INACT0006075 0J6L BRETT, MADELINE MAE ACTIVE

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16, 2002)0006109 0G7W HERING, PEARL TROST ACTIVE0006114 0K2T MONTREAL TRUST COMPANY (CALGARY) ACTIVE0006124 0K6W OLESEN, BRUCE EDWIN ET AL ACTIVE0006198 0H8M LAZARENKO, RUSSEL M. ACTIVE0006209 0G1L GABERT, MORLEY REINHARD ACTIVE0006210 0G1K GABERT, MARLEN RICKY ACTIVE0006211 0K8Z PASSEY, MARION ALICE ACTIVE0006276 0P9C KOETSIER, ALBERTINA M. INACT0006298 0L5G RATHWELL, JOHN HERBERT WILLIAM ACTIVE0006331 0G0D FORET MANAGEMENT LTD. ACTIVE0006355 0K0X MCMILLAN, GRACE ELIZABETH ACTIVE0006411 0W2H HARMAN RESOURCES LTD. TERM0006453 0R6C WEREZUK. SAM INACT0006486 0Y4R STAR OIL LTD ACTIVE0006525 0Y3Y PENNZOIL OIL COMPANY ACTIVE

0006554 0L2DPRESBYTERIAN CHURCH IN CANADA BOARDOF WORLD MISSION THE TRUSTEE BOARD OF THE INACT

0006565 0T6G TRANSAMERICA OIL COMPANY STRUCK0006566 0L8R ROBERT L. MCNAMARA LEASEHOLDS LTD ACTIVE0006615 0M5P SMITH, WILLIAM M. INACT0006644 0732 NETHERLANDS INVESTMENT COMPANY OF CANADA LIMITED ACTIVE0006665 0G2C GATEMAN, VICTOR CLARENCE ACTIVE0006681 0E1W BJERKLIEN ARTHUR ACTIVE0006685 0P6Z GAMMON CORPORATION INACT0006695 0T6W WEST FORTY DRILLING AND EXPLORATION LTD STRUCK0006696 0W7X WEE-L-R PETROLEUM LTD. TERM0006707 0D3Z 423904 ALBERTA LTD ACTIVE0006717 0J3E MANNING, MARGARET JEAN ACTIVE0006718 0J3B MANNING, BETTY L. ACTIVE0006726 0F5Y EDGAR, DAVID ET AL ACTIVE0006737 0F5H E. J. PARRENT AND ASSOCIATES INC ACTIVE0006738 0J1Z MACEDONIA HOLDINGS LTD ACTIVE0006739 0D2A 297408 ALBERTA LTD ACTIVE0006741 0D2C 297915 ALBERTA LTD ACTIVE0006742 0L3R PYXIS RESOURCES INC ACTIVE0006749 0E0D ANSLEY V BAGNELL ACTIVE0006752 0N9P YATES, RICHARD R ET AL ACTIVE0006852 0P0W 290343 ALBERTA LTD INACT0006942 0N4A TURNER, HAZEL ACTIVE0006943 0G6H HARLEY, WENDY ACTIVE

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16, 2002)0006944 0E9X COOPER, ROBERT ACTIVE0006945 0E9W COOPER, GORDON ACTIVE0006994 0T8A 413964 ALBERTA LTD TERM0006996 0T0Y DOVER ENTERPRISES LTD STRUCK0007037 0X6C THE CANADA TRUST COMPANY TERM0007059 0R1X PADDON HUGHES INACT0007091 0X2M PANCANADIAN PETROLEUM LIMITED ACTIVE0007124 0E07 PAULSON STANLEY M INACT0007138 0J7M BRUCE, MARGARET OLWEN ACTIVE0007166 0G1R GALLELLI, HELEN MARGRETTA ACTIVE0007167 0R7P 316238 ALBERTA LTD. STRUCK0007220 0H9D LEFSRUD, HARALD ANTON ACTIVE0007229 0D4E 486247 ALBERTA LTD. ACTIVE0007246 0L0Z PHILLIPS, ROBERT WILLIAM ACTIVE0007250 0H9N LESHENKO, PATRICIA ACTIVE0007261 0J3R MARGARET MCDONELL ACTIVE0007262 0F9X FLORENCE EVELYN IRVINE ACTIVE0007263 0D9G ALVIN ANTHONY FLYNN ACTIVE0007264 0N0N TERESA MARY BRACKE ACTIVE0007265 0K2C MILTON CHARLES FLYNN INACT0007399 0T8R BESS RESOURCES LTD TERM0007429 0K7B OLSON, MARIE G INACT0007430 0N8J WILSON, ETHYLE BEATRICE ACTIVE0007431 0Y8P PROVO GAS PRODUCERS LTD TERM0007443 0N1G THE PRUDENTIAL INSURANCE COMPANY OF AMERICA ACTIVE0007455 0D4K 498531 ALBERTA LTD ACTIVE0007487 0J2J MACPHERSON, M. STUART ACTIVE0007488 0E6G BERCUVITZ, MARK ACTIVE0007489 0J8Z CAMPBELL, GORDON DOUGLAS ACTIVE0007490 0G5J H R SHAW HOLDINGS LTD ACTIVE0007627 0K0D MCDONNEL, ISOBEL MAUDE INACT0007764 0T7T 376101 ALBERTA LTD. TERM0007826 0M0E ROTHWELL PAUL A ESTATE EXECUTRIX ROTHWELL MARJORIE A ACTIVE0007878 0Y1L ADM AGRI-INDUSTRIES LTD ACTIVE0007892 0L3M PURDIE, ROBERT HUNTER ACTIVE0007895 0L3L PURDIE, ALEXANDER WILLIAM INACT0007936 0T7Y 410555 ALBERTA LTD TERM0007938 0P9Y LUTSKY, WILLIAM INACT0007939 0G33 LUTSKY, JOSEPH INACT0008041 0P7T HAWK'S NEST RESOURCES LTD INACT

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16, 2002)0008082 0Y6N TAKU GAS LIMITED INACT0008090 0M1W SAWYER, RUTH LAVINA ACTIVE0008098 0D9H AMAR RESOURCES LTD ACTIVE0008099 0M5N SMITH, NORMAN E ET AL ACTIVE0008104 0G7X HERR, LAWRENCE DONALD ACTIVE0008115 0W3D KACEE EXPLORATION INC TERM0008132 0W1C DELOITTE & TOUCHE INC RECEIVER AND MANAGER OF CAVALIER ENERGY LIMITED TERM0008164 0H5W KING, NORMA MAE ACTIVE0008229 0H2R JEVNE, THOMAS CARL ACTIVE0008230 0H2P JEVNE, DONALD NICHOLAS ACTIVE0008296 0H0D INDUS CANADA PETROLEUM LTD ACTIVE0008298 0K5K NORDIN, ADOLPH ESTATE; NORDIN, CHRISTINE EXECUTRIX (DO NOT MAIL) ACTIVE0008396 0T8M BAKKEN HOLDINGS CO. LTD. TERM0008441 0Y4A PROFCO RESOURCES LTD (MIN TAX PURPOSES ONLY) INACT0008547 0E5N BEINGESSNER, ALPHONSE ESTATE; EXECUTOR BEINGESSNER, MAXWELL H. ACTIVE0008550 0Y3C MAGRATH ENERGY CORPORATION ACTIVE0008606 0T7H 272566 ALBERTA INCORPORATED TERM0008712 0R7A 258286 ALBERTA LTD STRUCK0008715 0W1Z GENTRY PETROLEUMS INC. TERM0008718 0N1R THOMPSON, RIGMOR KAREN CATHRINE ET AL ACTIVE0008737 0X9B 584693 ALBERTA INC AMALG0008738 0W0F CN EXPLORATION INC TERM0008741 0M4M SIMCORP RESOURCES LTD ACTIVE0008768 0N4C TURNER, MARY RUTH ACTIVE0008769 0N4D TURNER, THEODORE JONATHON ACTIVE0008770 0N3Z TURNER, EDWARD FRANKLIN ACTIVE0008771 0N4B TURNER, JAMES FREDERICK ACTIVE0008773 0G6B HANSEL, LARRY ACTIVE0008806 0D1T BIG SKY HOLDINGS INC ACTIVE0008894 0H7Z LANDMARK ENERGY CORPORATION ACTIVE0008985 0K5L NORTH AMERICAN TRUST COMPANY INACT0009000 0W6N SKOCDOPOLE RANCHES LTD TERM0009001 0E8E CLARKE, THEODORE J. ACTIVE0009002 0P9W LOCKETT, JAMES INACT0009046 0G3K GOLDFELDT, DORA M ACTIVE0009154 0E0Y ARTHUR, ALVIN LAYNE ACTIVE0009221 0N4E TURNER, WILLIAM CALVIN ACTIVE0009317 0Y7K ENCAL OIL AND GAS LTD TERM0009552 0N5A URQUHART EXPLORATION LTD ACTIVE0009734 0Y1B PETROTERRA NATURAL RESOURCES LTD, DELOITTE & TOUCHE RECEIVER ACTIVE

Page 8 of 80





16, 2002)0009762 0J6W BRINGTON HOLDINGS LTD. ACTIVE0009763 0D4T 576496 ALBERTA LTD ACTIVE0009764 0Y5F WINTERBURN OIL AND GAS LTD. ACTIVE0009790 0L0C PETRO-CANADA EXPLORATION INC ACTIVE0009846 0E9L CONOCO CANADA ENERGY PARTNERSHIP ACTIVE0009911 0Y5G ZEUS OILS & HOLDINGS LTD ACTIVE0010005 0G6D HARGRAVE, HERBERT THOMAS ACTIVE0010022 0Y2A CANADIAN WESTERN POWER & FUEL COMPANY LIMITED ACTIVE0010036 0H2Z JOHNSON HENRY SAMUEL ESTATE ADMINISTRATRIX JOHNSON MARGARET J INACT0010039 0P7P H H RANCHES LTD INACT0010051 0Y5X GOODYEAR GAS WELL 5-130 LTD (USE 145) INACT0010053 0Y1C MANY ISLAND PIPELINES TERM0010056 0R5P UNITED OILS LIMITED INACT0010082 0G8X HOME OIL LTD INACT0010137 0N3N TRENHOLM ANNA EDITH ACTIVE0010196 0M1T SAWCHUK BARBARA INACT0010203 0Y2Z LINCOLN MCKAY DEVELOPMENT ACTIVE0010213 0F8T FARTHING, JENNY LYNN ACTIVE0010246 0J7X BULLEMER, REUBEN A. ACTIVE0010258 0P3N BRENNEIS, LIZZIE INACT0010278 0R0L MICHELS, WILLIAM ESTATE; EXECUTORS HARLE GRAHAM L & STAUFFER ALFRED INACT0010296 0E3B BONNELLO MONA ACTIVE0010298 0P3R BROOMFIELD JOSEPH LAING INACT0010327 0P5J DAVIDSON, ELLA INACT0010354 0Y1E NORTHWESTERN UTILITIES LIMITED TERM0010378 0M3H SHAREK ANTONY ACTIVE0010415 0K7L OSBALDESTON, GEORGE EDWARD ACTIVE0010428 0T4B PEARMAC LIMITED STRUCK0010437 0M5D SLATER, BARBARA COLLINS ACTIVE0010458 0P7C GILLELAND, LOUISE INACT0010464 0W7T WALROTH & DAUGHTERS HOLDINGS LTD TERM0010505 0E9A COLLINS, JAMES L. ACTIVE0010609 0L3P PURVIS STUART S INACT0010655 0Y5P CANADIAN WESTERN NATURAL GAS (USE 144) INACT0010657 0F1E CROWN TRUST COMPANY ACTIVE0010766 0E4M BARLOW BROS. LTD ACTIVE0010767 0J8T CALGARY WESTERN INVESTMENT COMPANY LIMITED ACTIVE0010804 0R6R 14111 ALBERTA LTD STRUCK0010887 0J9F CANADA PERMANENT TRUST COMPANY INACT0010947 0Y8X SCURRY - RAINBOW OIL LIMITED TERM

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16, 2002)0010959 0Y1R ARTICANA RESOURCES LTD ACTIVE0010977 0704 172746 CANADA INC. STRUCK0010985 0E4N BARLOW DEVELOPMENT LTD ACTIVE0010986 0G1N GALE, IVY V ACTIVE0011000 0J9B CAMERON PETROLEUM INC ACTIVE0011001 0N9B WOODLOCK, MARGARET ANNE ACTIVE0011002 0J8M CAIN, PATRICIA KATHRYN ACTIVE0011086 0J4Y MCARTHUR, MARJORIE ISABEL ACTIVE0011092 0G7E HECK, MERLA HOPE ACTIVE

0011094 0L2RPOOLING ORDER #87 THE PUBLIC TRUSTEE FOR THE PROVINCE OF ALBERTA, ADMINISTRATOR ACTIVE

0011096 0K3Z MURTO, ALEXANDER ACTIVE0011098 0Y4E RED DEER 23, COUNTY OF ACTIVE0011100 0E1L BIRCH COVE FARMS LTD ACTIVE0011115 0W1J EDITH HOLDINGS LTD (STRUCK EFF: 78/06/30) TERM0011131 0Y9L VANGUARD PETROLEUMS LTD TERM0011196 0R6K WRAY, ARTHUR HENRY ET AL INACT0011238 0K2R MONTREAL TRUST COMPANY (EDMONTON) ACTIVE0011356 0J0H LITTLE, WILLIAM CHARLES (ESTATE OF) ACTIVE0011370 0F8A EUNICE MARGARET MADVID ACTIVE0011373 0H2K JENSEN, JENS OLLING ACTIVE0011376 0B5A DELBURNE, VILLAGE OF ACTIVE0011420 0Y4J SCOTIA OILS LIMITED ACTIVE0011437 0M2C SCHMIDT, SIEGFRIED ACTIVE0011438 0M2B SCHMIDT, RAYMOND FREDERICK ACTIVE0011469 0H4G KEEN EMMA INACT0011559 0J1L LUND BERNICE JEANNETTE INACT0011616 0M4B SIEBENS OIL & GAS LTD ACTIVE0011669 0N1J THE ROYAL TRUST COMPANY (CALGARY) ACTIVE0011726 0M21 ROSELAND DEVELOPMENT LTD ACTIVE0011862 0W2G GUARANTY TRUST COMPANY TERM0012095 0J4D MARSHALL, JAMES H. ACTIVE0012279 0J8R CALGARY PETROLEUMS CONSULTANTS LTD ACTIVE0012314 0Y8Z SIMPSON RESOURCES LIMITED TERM0012367 0Y7W HOPE GAS & OIL LTD TERM0012372 0D9C ALTON, ROBERT JOSEPH WILLIAM ACTIVE0012409 0G1C FULLER, EDITH KATHERINE ACTIVE0012427 0M5X SNETHUN, KRISTEN ACTIVE0012433 0L4T RAE, CLIFFORD A ACTIVE0012435 0J0F LINTUS RESOURCES LIMITED ACTIVE

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16, 2002)0012438 0R5B THE ROYAL TRUST COMPANY (EDMONTON) INACT0012485 0M1N SASKATOON LEASEHOLDS LIMITED ACTIVE0012587 0M6P SPOONER, ROBERT J. ACTIVE0012681 0T8F ALBERTA CONFERENCE CORPORATION OF THE SEVENTH-DAY ADVENTIST CHURCH TERM0012744 0E8W COLE, TERENCE K ACTIVE0012787 0W0P CORVAIR OILS LTD (PREVIOUSLY CONSOL UNDER TUNDRA OIL AND GAS LTD. (0AW7) TERM0012835 0Y1Y CANADIAN HUNTER EXPLORATION LTD ACTIVE0012947 0J3D MANNING, JOHN CHESTER ESTATE OF; MANNING, MARGARET JEAN EXECUTRIX ACTIVE0013104 0G0H FORSTER, FREDERICK A. ESTATE, INGRAM, DOREEN ET AL EXECUTORS ACTIVE0013120 0P0E ZIMMERMAN, CLARENCE R. ACTIVE0013121 0G2H GEY, MARY M. ACTIVE0013130 0F5E DURWARD, ALICE CHRISTINE MARY ACTIVE0013139 0E0Z ARTHUR, GEORGE CLARE ACTIVE0013304 0W3Z MANSON OIL & GAS LTD. TERM0013384 0N1A THE CANADA TRUST COMPANY ACTIVE0013428 0F1M CYMBALUK, DENNIS JOHN ACTIVE0013881 0M9H SWEENEY, MITCHELL HECTOR ACTIVE0013885 0M9G SWEENEY, CHARLES AARON; ESTATE OF SWEENEY, LARRY EXECUTOR ACTIVE0013912 0E4L BARLOTT, MICHAEL ET AL ACTIVE0013948 0T8J ANNE B. DOLL HOLDINGS LTD. TERM0013997 0J1Y MACE, SEAN RICHARD ACTIVE0014025 0T9T CANPAR HOLDINGS LTD TERM0014082 0L9E RODE, DANNY DOUGLAS ACTIVE0014083 0L9F RODE, GREGORY MILES ACTIVE0014164 0K0E MCGOWAN, ELSIE BERYL ACTIVE0014283 0Y1D NORCEN ENERGY RESOURCES TERM0014374 0H8R LEBEDKIN, GEORGE E ACTIVE0014429 0H8L LAZARENKO, JOSEPH M. ACTIVE0014469 0T8L BAKER, DONALD WILLIAM TERM0014472 0E3X BAKER, JOE ACTIVE0014560 0L9P ROPCHAN, WILLIAM ACTIVE0014662 0D9W ANDERSEN, KAREN KRISTIAN INACT0014676 0Y6M RANGER OIL LIMITED INACT0014806 0K0L MCLEAN INVESTMENTS LTD. ACTIVE0014827 0F1Z DAISY OILS LTD ACTIVE0014833 0L8G RICHARDSON, VIOLET LUCILE INACT0014859 0N7K WHITE, SHIRLEE ACTIVE0015043 0E6W CHARRON, PIERRE O ACTIVE0015057 0G5M HAGEMANN, DOROTHY ACTIVE0015146 0Y7H CANADA NORTHWEST ENERGY LTD TERM

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16, 2002)0015160 0W5H PLACER CEGO PETROLEUM HOLDINGS TERM0015201 0E2R BOLSTAD, EDITH ACTIVE0015213 0E6E BENNION, JESSIE KATHERINE ACTIVE0015237 0K4W NEWTON, EVELEINE ESTHER INACT0015317 0D8Z ALSOP, VELMA ACTIVE0015337 0T7F 236655 ALBERTA LTD TERM0015391 0K0N MCLEAN, HAMILTON JAMES ACTIVE0015422 0J4M MATHESON AGNES R INACT0015434 0W6J SCOTSTOUN HOLDINGS LTD TERM0015537 0F4N DUART DEVELOPMENTS LTD ACTIVE0015565 0M3Y SHORT, HELEN ESTATE; SHORT, LAWRENCE GEORGE EXECUTOR ACTIVE0015589 0T32 RANDLE RANCHES LIMITED ACTIVE0015592 0W4D MCLEAN (KEITH) OIL PROPERTIES LIMITED TERM0015600 0G0B FOREMAN, HAZEL JOYCE ACTIVE0015638 0G7D HECHT, ROGER ALLEN ACTIVE0015707 0M0D ROTH, OLIVE ACTIVE0015776 0G5X HAMBRE ENERGY LTD ACTIVE0015803 0M7X STERLING, BETTY JANE ACTIVE0015896 0H0X ISEKE, FLORIAN INACT0015900 0H6T KRUSE, CECILIA ACTIVE0015901 0H0W ISEKE, ANTHONY ACTIVE0016011 0G8G HILLABY, ARLYN INACT0030001 0M3A SEIVERTSON AL INACT0030003 0W0B CHIPMAN MINING AND ENERGY CORPORATION LTD TERM0030018 0Y3E MAXWELL ENGINEERING LIMITED ACTIVE0030019 0K4K NEALE MANAGEMENT CONSULTANTS LTD ACTIVE0030033 0AJ9 BURTEX LTD STRUCK0030037 0D0J 241231 ALBERTA INC ACTIVE0030038 0T9B BRONDYKE ROBERT A TERM0030042 0Y5R CANADIAN-MONTANA GAS COMPANY LIMITED INACT0030043 0P4N CHIMO CONSTRUCTION LTD INACT0030047 0J1M LUND, RUSSELL T. OIL TRUST ACTIVE0030048 0G1D FULTON, JOE KIRK ACTIVE0030049 0N25 CARIBOU MINERAL RESOURCES LTD (STRUCK EFF:1984/09/01) INACT0030053 0G1E FULTON, JOE KIRK JR ACTIVE0030055 0L6M CENTIPEDE HOLDINGS LTD ACTIVE0030057 0G1F FULTON, KYLE LANCE ACTIVE0030058 0Y1M ALBA PETROLEUM CORPORATION ACTIVE0030061 0W0G CO-ENERCO RESOURCES LTD TERM0030062 0F1G CUMULUS INVESTMENTS LTD ACTIVE

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16, 2002)0030064 0E9J CONCEPT RESOURCES LTD (USE L29) INACT0030068 0Y1P ANCEL MANAGEMENT LTD ACTIVE0030072 0T0M CULLEN RESOURCES LTD STRUCK0030074 0W3J LABRADOR MINING AND EXPLORATION COMPANY LIMITED TERM0030079 0M1R SAUNDERS MINERALS LTD ACTIVE0030080 0D2Y 340157 ALBERTA LTD. ACTIVE0030081 0F6W EMI RESOURCES LTD ACTIVE0030082 0R14 EAGLE OIL EQUIPMENT LTD STRUCK0030088 0NZ7 FALCON RESOURCES LTD STRUCK0030092 0G8Z HONEY BEAR PETROLEUM LTD ACTIVE0030094 0F7C ENERCAN RESOURCES LTD ACTIVE0030095 0Z1B F O G RESOURCES LTD INACT0030097 0R9Z CANLEX PETROLEUM CORP STRUCK0030101 0X8M GENESIS RESOURCES LTD ACTIVE0030105 0E8T COIL RESOURCES LTD ACTIVE0030107 0G0Y FRIO PIPE LINE COMPANY ACTIVE0030110 0W1A DANJOLYN RESOURCES LTD TERM0030114 0Y7T HARVARD INTERNATION RESOURCES LTD TERM0030118 0L3G CAN-WEST 1972 GAS PARTNERSHIP ACTIVE0030119 0Y8C NORTHLAND BANK TERM0030120 0H1K JADAK MANAGEMENT LTD ACTIVE0030121 0H1Z JANUS PROPERTIES LTD ACTIVE0030122 0H2A JANVAL OIL COMPANY ACTIVE0030124 0H2N JETHRO DEVELOPMENT LTD ACTIVE0030125 0T7E 232191 ALB

gas royalty calculation information bulletin - july 2002 · 2016. 4. 8. · information bulletin...

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