Registry Information Session The Petroleum Registry of Alberta Energizing the flow of information Registry Information Session September 24, 2007

Agenda REGISTRY TOPICS EUB TOPICS INDUSTRY TOPICS DID YOU KNOW? Outside Jurisdiction Interest Update CAPPA Conference Presentation EUB TOPICS Shale Reporting added to the Registry Gas Equivalent Factors (GEF) Updates “S” Report Submissions Deadlines EUB Organization Update Misc (AB MC) Codes INDUSTRY TOPICS Industry Planning Process & Outcomes 2008 Allowable Costs Update APMC Penalty Process DID YOU KNOW? Amalgamations – Impact on Facility Operator Changes Registry Training Module Updates & Managing Red Folders Registry Service Desk Stats and Services Provided QUESTIONS OIL/LPG PIPELINE SPLITS PROCESS

1. REGISTRY TOPICS

Registry Topics a) Interest from Outside Jurisdictions British Columbia Formal discussions continue. Yukon Sponsorship alignment achieved. Registry Presence at 2007 CAPPA Conference (October 25, 2007). 5th Anniversary Commemoration Breakout Session and Registry booth

2. EUB TOPICS

a) Shale Gas Reporting at the Registry

What is Shale Gas? Shale gas is natural gas stored in organic rich rocks such as dark-colored shale, interbedded with layers of shaley siltstone and sandstone. EUB defines shale in Section 1.020(2) 27.1 of the Oil and Gas Conservation Regulations (OGCR) as a “lithostratigraphic unit having less than 50% by weight organic matter, with: less than 10% of the sedimentary clasts having a grain size greater than 62.5 micrometers; and more than 10% of the sedimentary clasts having a grain size less than 4 micrometers”.

Why Shale Reporting? EUB to distinguish gas production from different structures: Conventional Gas Coal bed Methane Gas Shale Gas

When Will Shale Be Available? December 2007 Calendar month for the production month of November 2007.

EUB will introduce three new fluid types for shale: Infrastructure - under Well Status: SHG - Shale Gas Only (Fluid Code 25) SHGOT - Shale Gas and other Sources (Fluid Code 24) CBMSHGOT - CBM & Shale & Other Sources (Fluid Code 26)

Shale Gas Only (SHG) For production from wells completed in shale(s) only. Wells that are producing gas from the following formations are considered to be potential Shale Gas Only wells. Muskwa, Duvernay, Ireton, Fort Simpson, Exshaw, Fernie, Rierdon, Moosebar, Wilrich, Joli Fou, Harmon, Shaftesbury, Blackstone, Wapiabi, Kaskapau, Muskiki, Lea Park, Pakowki, Battle, Fish Scale, Second White Speckled Shale, Colorado Shale and First White Speckled Shale.

Shale Gas and Other Sources (SHGOT) For production from wells completed in both shale(s) and other lithology; not including coal(s). Perforations in the following formations/members are mainly non-marine and/or have low organic contents are not considered to contain shale gas but is other lithology. Whyte, Snake Indian, Stephen, Earlie, Deadwood, Sullivan, Bison Creek and Whitemud.

CBM, Shale Gas and Other Sources (CBMSHGOT) For production from wells completed in coal(s), shale(s) and other lithology (eg. sandstone). The EUB defines coal in Section 1.020(2) 3.1 of the OGCR as: ‘a lithostratigraphic unit having 50% or greater by weight organic matter and being thicker than 0.30 metres’. Perforations in the following organic horizons are not considered to contain shale gas. Glauconitic, Upper Mannville (and Provost equivalents), Foremost, Oldman, Dinosaur Park, Horseshoe Canyon, Scollard and Paskapoo.

Shale Reporting Volumetric Reporting: Same reporting process as conventional Gas.

b) Gas Equivalent Factor (GEF) Updates in the Registry

What Is It? Gas Equivalent Factors (GEFs) are used to convert a liquid volume to a gas equivalent volume, which ensures proper metering balances. The PRA uses these factors to derive the activity shrinkage (SHR) at a gas plant or a gathering system. The GEFs are obtained from the Gas Processors Association (GPA) Engineering Data Book.

Why is it Being Changed? Since the Registry went live, the GEF’s have not been changed. The GPA had published modifications in 2003 but changes were not significant enough to adopt. Until now ...

What are the Changes? Liquid component GEFs – current GEFs - new CO2-MX 0.28148 0.440295 C1-MX, LITE-MX C2-MX, C2-SP 0.28151 C3-MX, C3-SP 0.27221 0.27222 C6-MX, C6-SP 0.20575 0.18216 GEFs for all other liquid components not mentioned above will remain unchanged. This will affect your metering differences at your facilities.

When Will These Changes Take Effect? Effective date: January Production An alert will be posted on the Registry one month prior to implementation. Derived gas equivalents already in the Registry will not be changed. (No retroactive changes) Gas equivalent calculations for any amendments prior to production month January 2008 will use the old GEF values. Gas equivalent calculations for submissions and amendments starting January 2008 production month will use the new GEF values.

c) “S” Report Submissions Deadline

“S” Report Submissions Deadline S-doc amendments until January 31st, 2008. For production months prior to October 2002. Allows clients to process documents amended from the fifth year. Audit to review and submit any amendments they deem necessary. After January 31st, 2008, you will not be able to amend production months prior to October 2002.

d) EUB Organization Update

EUB Organization Update Effective January 1st, 2008 EUB will be split into two different organizations: Energy Resources Conservation Board (ERCB). Alberta Utilities Commission (AUC). There will be no impact to the Industry except for the new names and logos. There will be two different web sites. Other changes will follow – watch for EUB communication updates.

e) Miscellaneous (AB MC) Codes

Use Of Miscellaneous (AB MC) Codes In The Registry Miscellaneous Codes (AB MC) can be used in the following circumstances: For Gas Fires. For Oil deliveries to “downstream” facilities that are not on the Registry, such as an Asphalt Plant. Water received from or delivered to a pit. For your “unique” situation, please call the PA Helpdesk.

MIS-USE Of Miscellaneous Codes In The Registry Miscellaneous Codes (AB MC) should NOT be used in the following circumstances: To balance facilities. For outside Province or State deliveries or receipts. Use province or state codes e.g. SK, BC or TX. For Oil Fire, Theft or Spill. Show as INVADJ.

Ensure AB MC Codes Are Used Correctly Proper source documents MUST be kept on file such as Meter or Truck Tickets. Usage of MC codes may be subject to an audit.

MC Oil DISP Usage Volume M3 PRODUCTION MONTH

MC Oil REC Usage Volume M3 PRODUCTION MONTH

For More Help… Contact the EUB PA Helpdesk @ EUB 297-8952 option 3 email: PA.help@eub.ca. Can provide more information and instructions on all of the topics covered today. Wells Records Helpdesk@ EUB 297-8696

INDUSTRY TOPICS

a) Industry Registry Planning Process and Outcomes 2008

Industry Planning Process Overview Industry’s Registry Priorities for 2008

Industry Planning Process for the Registry 1a. Priority Identification On an annual basis, the CAPP/SEPAC Industry Benefits Committee (IBC) identifies and prioritizes Registry-related areas of focus for the IBC and the Industry Registry Team (IRT). “Focus Priorities” can be grouped as: a. Operational and O&M Change Management Items b. Major Registry Enhancements c. Registry-related Business Support Priorities The IBC rates its priorities on a scale ranging from: 0 = no value, to 5 = highest value Note that perspectives summarized in this presentation are consensus views. Opinions vary between companies.

Industry Planning Process for the Registry 1b. Approval Process The IBC’s priorities are reviewed and endorsed by: CAPP Accounting Committee CAPP Fiscal EPG SEPAC Finance Committee These groups also review and make decisions on IRT staffing and funding for the coming year. Note that Industry’s Registry governance processes require business cases to be prepared and reviewed with the CAPP Fiscal EPG and SEPAC Finance Committee where any Industry funding and/or significant Industry time resources are required. Endorsement of “priorities” during the annual planning exercise does not constitute project approval.

Industry’s Registry Priorities for 2008 2a Industry’s Registry Priorities for 2008 2a. Operational and Change Management Items Initiative Industry Rating Comments/ Status Operational Items Very High Performance Training Testing Industry operational support O&M Change Management Items Strong support for pursuing priorities as identified on an ongoing basis by the IBC. Specific mention given to: Daytime running of reports APMC 122

Industry’s Registry Priorities for 2008 2b. Major Registry Enhancements Initiative Industry Rating Comments/ Status BC Very High BC is currently following the Registry’s protocol for outside jurisdictions interested in using the Registry. Saskatchewan Strong support ongoing. RMF2 High Significant pre-project work complete. Waiting on DOE funding. Manitoba Moderate Higher priority for companies with MB focus. Yukon YK is in the early stages of the Registry’s protocol for outside jurisdictions interested in using the Registry.

Industry’s Registry Priorities for 2008 2c Industry’s Registry Priorities for 2008 2c. Registry-related Business Support Items Initiative Industry Rating Comments/ Status Pipeline Splits Very High Registry functionality is in place. IBC signalling need for additional pipelines to adopt Registry processes. Partner Reporting Registry functionality is in place. IBC signalling need for greater Industry use of Registry processes. GCA Support Registry functionality is in place and highly valued by Industry. IBC, GCA subcommittee, IRT and DOE are focused on continued enhancement and training. PA Software Vendor Interface High IBC signalling need for additional work to improve vendor software capabilities to interface with the Registry DOE Oil Industry Issues IBC signalling need for ongoing support on Deliveries and Forecasting issues.

Industry’s Registry Priorities for 2008 Summary and Conclusions The annual planning process is valuable in identifying and prioritizing areas for focus by the IBC and IRT. The IBC is a valuable forum for providing input to senior CAPP and SEPAC committees, the IRT and the Registry. The IBC is also a valuable venue for Industry companies to share best practices in working with the Registry. Your company’s involvement is encouraged! (Contact an IRT or IBC rep for information on how to get involved). The Registry has other venues for providing input: Service Desk calls Online Suggestion Forms available on the Registry website

Allowable Costs

Allowable Cost Update GCA Subcommittee Update AC1 Delete Allowable Cost Submission Tools And Tips

GCA Subcommittee Update The GCA Subcommittee is a subcommittee of the CAPP/SEPAC Industry Benefits Committee (IBC). Overall the GCA Subcommittee provided very positive feedback on the 2006 GCA season. The Industry Registry Team (IRT) and the GCA Subcommittee are working with the DOE Gas Royalty group on a number of matters (joint meeting planned for early October). Any new developments will be communicated subsequent to that meeting.

AC1 Delete Effective October 4, 2007, an AC1 can be deleted from the Registry under the following circumstances There have been no AC2s, AC3s or AC4s filed for this FCC Id. There has been only one operator for the FCC. The FCC Id has not been referred to on any other FCC (ie previous FCC Id). If you need to delete an AC1 but cannot due to the above rules then you must perform the current two step process of: shutting in the FCC. terminating it.

AC Submission Tools and Tips DOE reports delivered to Ministry Invoices and Statements. Energy Adjusted Gas Equivalent Volumes Report (EGAV). Identifies all royalty trigger facilities where a BA has been allocated volumes. Use this report to ensure that an AC2 and/or an AC5 has been filed for each facility listed on this report. Expected AC5 Report Identifies facilities where a BA has been named as a Custom user on an AC2 You may still file an AC5 if a facility where you have paid custom processing fees is not on the Expected AC5 Report IF it is listed on the EGAV Report.

AC Submission Tools and Tips (Cont’d) 3. Expected AC2 Report. Identifies FCCs where a BA is the operator. To avoid penalties the BA must make an AC2 submission.

AC Submission Tools and Tips (Cont’d) Registry on request reports 1. Registry AC2 Summary Report. Identifies all FCCs that a BA operates and FCCs where a BA has been named as an owner along with their filing status (confirmed, unconfirmed, missing or rejected). This report (when requested for your BA only) may be used in conjunction with the Expected AC2 Report. This overnight report may be requested at any time.

AC Submission Tools and Tips (Cont’d) Summary To avoid having lines rejected on an AC5 be sure to file only for facilities identified on the ‘Energy Adjusted Gas Equivalent Volumes Report’. These are the only facilities that will be accepted by the DOE. All other facilities will be rejected. To ensure that all AC2s have been submitted and confirmed by the DOE, request the AC2 Summary Report for the submitting BA only. To get a summary of all AC2s that a BA has an interest in, request the AC2 Summary Report for All Operators.

APMC PENALTY PROCESS

APMC Penalty Process 1. Oil Royalty Changes Royalty Program Report Oil Low Prod Reactivated Well Royalty Exemption Horizontal Re-entry Well Royalty Reduction Royalty Program Report APMC Penalty Statistics

Oil Royalty Changes (effective Sept, 2007) Oil Low Prod (DOE Information Letter 2006-23) Conversion of the existing 16,000 m3 production volume cap to a $50,000 royalty value cap Existing wells will have their accumulated royalty reduction volume under the program converted to a dollar amount based on the monthly par price starting with the effective date of the reduction. The royalty reduction for existing wells exceeding the maximum royalty value cap will be terminated effective August 31, 2007. Creation of three well production ranges with corresponding threshold quantities. The well production range for existing wells will be determined based on historical well productivity.

Oil Royalty Changes (Cont’d) The royalty rates will be calculated based on the lower of actual production or threshold quantity for each well. The low prod flat 5% royalty rate no longer exists.

Oil Royalty Changes (Cont’d) Reactivated Well Royalty Exemption (DOE information Letter 2006-22) Conversion of the existing 8,000 m3 production volume cap to a $150,000 royalty value cap Existing wells will have their accumulated royalty reduction volume under the program converted to a dollar amount based on the monthly par price from the effective date of the application. The royalty reduction for existing wells exceeding the maximum royalty value cap will be terminated effective August 31, 2007.

Oil Royalty Changes (Cont’d) Horizontal Re-entry Well Royalty Reduction (DOE Information Letter 2006-24) No new wells have been approved for the program since November 1, 2006. A maximum royalty value cap of $900,000 Existing wells will have their accumulated royalty reduction volume under the program converted to a dollar amount based on the monthly par price from the effective date of the application. The royalty reduction for existing wells exceeding the maximum royalty value cap will be terminated effective August 31, 2007. The program will be terminated effective September 1, 2012. No royalty reductions will be received by wells under this program after that date.

Royalty Program Report

The September report should be available September 26, 2007

APMC Penalty Statistics

DID YOU KNOW?

Amalgamations: Impact on Facility Operator Changes Prior to the “Amalgamation Established Date”, the Facility Operator MUST do an operator change for ALL operated facilities. If the “Amalgamation Established Date” has passed, the Almagamatee BA will no longer have access to make current month submissions to the Registry. There has been a Change Request raised to allow the Amalgamator to make current month and prior period submissions on behalf of the Amalgamatee after the “Amalgamation Established Date” has elapsed.

Registry Training System Updates and Managing Red Folders

Registry Training System Registry users should remember that the Training System is always available through the website even outside the Registry hours of operation. The modules are maintained and updated throughout the year to reflect any changes to Registry functionality. This year, we are reviewing all modules, to ensure that they reflect the current Registry functionality processes. The following slides show how to use the training system effectively.

Registry Training System The initial page shows a status summary of modules for the user. White Folders have not yet been completed. Black Folders indicate modules that have been successfully completed. Red Folders are modules that have been revised since the module was completed and contains new information for review.

To access a training module either click on a folder, which will open and display as above, or use the Modules Available listing and click “Training Module”.

Once you are in a module, clicking on Index opens the module table of contents, which allows you to move from section to section or even page to page.

If a module has been updated and shows up in your profile as a Red Folder, the module Summary page links to the changed pages so you don’t have to complete the entire module again.

Registry Training System There is still merit in going back to review your profile. WHY? To identify changes to the current system (red folders - Summary of Change document located as link on Training Website). To search specific topics (Table of Contents). This system is the mechanism used to train users on new functionality or changes to existing functionality. Reminder – supervisors can use the tracking process to review staff training requirements and completions to ensure staff are keeping current. If you have any questions or suggestions on using the training system better, please send these to the Registry Service Desk.

Registry Service Desk Services Provided and Stats

Registry Service Desk There are three Service Desk Analysts and one Team Lead. Service Desk hours are 7:30 AM to 5:00 PM Monday to Friday. During weekdays, after hour voice mail calls will be responded to the following business day morning. On Saturdays the voice mail is checked every three hours by the on-call Analyst. Calls will be returned if the client leaves a message and phone number. Additional services include: assisting with acceptance testing and Industry inter-operability (inter-op) testing upon client’s request. The Service Desk is staffed with analysts who have industry and production accounting knowledge, as well as Registry application expertise. The Analysts have their CAPPA certificates. You can email your files to us and we will test them.

Registry Service Desk The Service Desk Analyst’s Registry access is limited due to the Registry Security. The Analyst has query access only. They can not see anything in the Edit or WIP functions. The Analyst will guide the clients to find data they are looking for, but will not give out information that the client cannot see or is not entitled to. The Analyst will inform the client of what the Registry can and cannot do. For any questions related to interpretation of Regulations and Business Rules, the user will be directed to the appropriate Dept of Energy or Energy and Utilities Board HelpDesk. Allocations or pipeline splits is an example of where the Analyst will guide the client to the information.

Registry Service Desk The Service Desk analyst will attempt to resolve as many incidents as possible during the initial telephone conversation with the client. One of the tools the Analyst will use is our test environment to walk a client through the steps to resolve the client’s issue. The Analyst will request screen prints from the client when necessary. There will be times when the Analyst will require more time to investigate the issue. In these situations, you will receive a call-back from the Analyst with the resolution. If the nature of the incident or question requires more specialized expertise, the incident will be assigned to a Subject Matter Expert (SME) within one of the Registry support teams (EUB, DOE, IRT and Registry Operations). All calls are tracked in our HEAT (Helpdesk Expert Automation Tool) System which is why the client is requested to supply their BA ID and name. A HEAT number is generated for each call and can be provided to the client upon request. The allocation of SME resources will be prioritized based on the business impact (level of severity) of the incidents captured via the Service Desk. Contact information is not shared. It used for the HEAT system only.

HEAT Ticket The HEAT ticket system is used to track the calls and issues. There is a description box where the issue is described. The Initial call categories include Volumetric, Allocations, Reports, etc. The Impact and Urgency is very important when the ticket is assigned to another Subject mater expert. When required the VI number is entered in the Other Reference Number/System. When required, files are attached to the HEAT tickets.

Registry Service Desk Stats The total number of contacts with the Service Desk in 2006 was 16,410. 10,832 were answered in person. 616 calls came in after hours (evenings, weekends or early morning hours). 1,771 e-mails came into the Service Desk. 3,191 follow up phone calls.

Registry Service Desk Breakdown of the monthly contacts. The majority of the contacts are the incoming phone calls. Outgoing calls are follow-up work or returning phone calls.

Registry Service Desk Incoming Call Types Volumetric questions are the most frequent. We also get a fair number of questions regarding the well infrastructure and facility infrastructure. Misc includes tickets on Security (BA USA set-up or change, passwords, roles), general questions, notifications, communication, wrong number, business associate (WIO flag, roles, status). The types of call categories can vary depending on the time of year or if there are changes promoted to the Registry. Information comes from the HEAT tickets that are created.

Contact Information The Service Desk is the focal point for communications with the Registry regarding access to, utilization of the Registry and the training modules. The Service Desk will supply clients with contact information for the EUB, DOE and APMC. In rare instances when a client calls and is held in the phone system for an extended period of time, they are provided with a phone number to leave a message. These messages are responded within a four hour period during normal business hours. For future calls clients should not call this line directly as you will not receive an immediate response. Calling a Service Desk Analyst on their direct line is not advised as the call may not be answered in a timely manner. When calling the IRT Team or PRA Communications/ Training Co-ordinator and the call is directed to voice mail, the client will have the option to dial 0 (zero), to be directed to the Registry Service Desk. Calling the overflow line directly does not guarantee that your call will be answered any sooner. Our first priority are the calls coming in on the Service desk phone system. If you stay on the line, your call will be answered sooner than if you dial the overflow number.

Contact Information The Service Desk can be reached via the telephone, email, website or facsimile, as follows: Phone:          (403) 297-6111 (Calgary) Phone:          1-800-992-1144 (other locations) Fax:               (403) 297-3665 Email: petroleumregistry.energy@gov.ab.ca Website: http://www.petroleumregistry.gov.ab.ca/

QUESTIONS

Oil/LPG Pipeline Splits Process

Pipeline Splits Back to the Basics Background Pipeline Split reporting has for the most part been optional in the Registry since go live October 2002. Between October 2002 and March 2007 the only pipeline split volume required to be input to the Registry was the APMC (crown royalty) volume. Effective April 2007 production, all split volumes on the Cremona system are to be entered into the Registry and not communicated directly to Cremona. This impacted 4 pipeline/terminal facilities and all the operators who delivered to them. ABPL0000034 Cremona Pipeline ABTM0000815 Elkton Terminal ABTM0000816 Crossfield Terminal ABTM0000817 Harmatton Terminal More pipelines are expected to adopt Registry splits in 2008

Pipeline Splits Back to the Basics Background (cont’d) With this change for reporting pipeline splits, certain rules that previously were “soft” have now become “hard”. For example: Forecasted shippers must match shippers on the pipeline splits. Volumes split to shippers must balance to the total volume that needs to be split. Facility Ids and product reported on the split must match the facility Ids and product forecasted. Based on our recent experience with Cremona, there appears to be a need for: Better understanding about how the pipeline split process works. Additional communication between Marketers and Production Accountants involved in the process.

Pipeline Splits Back to the Basics A. Overview of the Process Forecasts Production / Deliveries Split reporting Payments B. Who are the Players? Producing facility operators Pipeline / Terminal operators Shippers Purchasers Owners C. Who Does What? D. How is the Reporting Done?

A. Overview of the Process The Pipeline splits process: Is a monthly process. Starts before the production month begins with volumes being forecasted for delivery. Identifies the volume delivered and sold during the production month. Identifies who is buying and who is selling the volume (splits the volume delivered). Ensures the correct parties are paid for their volume. Is complete after the production month ends and payment has been received.

B. Who are the Players? Producing / Delivering facility operators Operate facilities that produce and/or deliver a volume to be sold (split) Pipeline / Terminal operators Operate facilities where ownership of the volume changes (sale of the volume occurs at these facilities). The volume is moved to market via these facilities. These facilities are also called Custody Transfer Point (CTP) facilities. Shippers Take possession of the volume on the pipeline and ship it to market. They often buy (purchase) the product as well. Purchasers Purchase the volume. They may or may not be a shipper on the pipeline. Owners The producers and/or royalty owners that produced the volume for sale (and “take in kind”). They are paid for these volumes by the shipper or the purchaser.

C. Who Does What? Forecasting / Form A / Shipper Lists The producing / delivering facility operator MUST provide a forecast of the expected delivery volumes to the pipeline/terminal operators prior to the start of the production month. Since the forecasting may be done by non production accountants in the company, such as someone in marketing or the field, internal communication is very important. Identifying the Volume to be Split Total The pipeline/terminal facility operator who received the volume will report to the producing/delivering facility operator the total volume to be split. Cascades The producing/delivering facility operator reports the volume to be split to all other facility operators who delivered to them (facility receipts). This volume is a portion of the total volume and is called a cascade to the other facility operator.

C. Who Does What? (cont’d) Splitting the Total and/or Cascaded Volume Total Volume The producing/delivering facility operator calculates and reports the volumes cascaded to other facilities to the operators of those other facilities. The producing/delivering facility operator also calculates and reports the shippers, purchasers and owners volumes produced by their own facility (not the cascaded portion). The operator who created the cascade must monitor and ensure that the cascaded volume is ultimately split to shippers, purchasers and owners and are included when balancing back to the total volume. The pipeline operator will look to the facility operator who directly delivered to them to provide a split that balances to the total volume.

C. Who Does What? (cont’d) Cascaded Volume The cascaded “to” producing/delivering facility operator calculates and reports the split for the volume cascaded to them. The cascaded volume needs to be split to shippers, purchasers and owners. The facility operator who created the cascade monitors to ensure that the cascaded volume is split to shippers, purchasers and owners by the cascaded “to” facility operator. IF the cascaded “to” facility operator does not provide the split information for the cascaded volume then the operator who created the cascade will report (based on the best data available to them) the cascaded volume, split to shippers, purchasers and owners.

D. How is the Reporting Done? Forecasting / Form A / Shipper Lists Per the Crude Oil Logistics Committee (COLC) producers are required to: Forecast volumes they expect to ship on the various pipelines and terminals. For each volume identify the associated shipper. Forecasts are done on the Form A according to COLC rules. Submit initial Forecasts to the pipeline and/or terminal the 1st week of the month before production/delivery month. For complete information regarding due dates and methods for calculating the forecasted volumes, please refer to the COLC website at: http://www.colcomm.com

This the paper Form A that is submitted to the CTP operators Operator & Month Identification Delivering & Receiving Facility Identification Shipper & Volume Identification

D. How is the Reporting Done? (cont’d) Once a forecast has been submitted, the pipeline and/or terminal operator will inform the shippers of the expected volumes. When the production/delivery month commences, producers should ensure their deliveries match the information submitted on the Form A. If the deliveries go to a different facility or a new shipper has been identified, updates/revisions to the Form A should be submitted to the pipeline/terminal operator. Revisions to the Form A can be done until the last day of the production month. If a forecast is not in place, potentially the pipeline/terminal operator could refuse to allow the volume to be unloaded/delivered at their facility. If a shipper is not identified on the forecast, the pipeline/terminal operator may potentially reject a split volume to the unforecasted shipper.

D. How is the Reporting Done? (cont’d) When a pipeline/terminal operator has elected to use the Petroleum Registry for reporting pipeline splits (Full pipeline split participation level), the following rules WILL BE enforced regarding forecasts and subsequent pipeline splits. The pipeline/terminal operator will load all the forecasted information (shippers and volumes) for each delivering facility into the Registry. If no forecast data exists for a delivering facility at the pipeline/terminal the Registry will reject any pipeline split submission done by the delivering facility operator. If a shipper is not identified on the forecast the Registry will reject any volume split to the unforecasted shipper.

Note there is no ability to add another shipper. In the Registry the Form A data is displayed on the Edit Pipeline Split screen. Note there is no ability to add another shipper.

In the Registry the Form A data can also be seen on the Pipeline Split Current report. This report returns results for all pipeline split data including Full, Lite & Non participating CTP facilities.

D. How is the Reporting Done? (cont’d) Identifying the Volume to be Split Total At the end of each production month the pipeline/terminal operator will communicate the total volume delivered to each of the delivering facility operators. Outside the Registry this is often a paper/fax process. In the Registry this is done as part of volumetric submissions by recording a Receipt at the pipeline/terminal This receipt creates a volume to be split record.

The activity REC at a TM or PL is reported as part of Volumetrics

The REC volume is copied to Pipeline Splits as the Volume Requiring Split

D. How is the Reporting Done? (cont’d) Splitting the Volume Creating the Cascade Once the Total volume to be split has been identified by the Pipeline/terminal operator, the delivering operator is responsible for splitting the volume to shippers and owners. If there were receipts from other facilities into the delivering facility, then the volumes belonging to those other facilities must be identified and communicated to those operators. Outside the Registry this is done via paper/fax or phone. In the Registry cascades to the other facilities are created.

Cascades to Other Facilities are done on line by clicking the Facilities button

Inputting another facility and Volume will create a Volume to be split record for the other facility

Be sure to Submit the data not just Save to WIP Once the cascade to the other facility has been done, the responsibility for providing the split on that portion of the total volume is temporarily transferred to the operator of the other facility Be sure to Submit the data not just Save to WIP

D. How is the Reporting Done? (cont’d) Identifying the Split Volume to Shippers, Owners, Purchasers & Wells Total Minus Cascade Once the Cascade volume(s) has been identified and communicated to the other operators, the balance of the total volume must be split to shippers, owners, purchasers and wells. The delivering operator calculates the shippers, owners, purchasers and associated wells. This calculation is done by the various PA systems or spreadsheets. Outside the Registry the facility operator who delivered directly to the PL/TM waits for the cascaded operators to report back to him. In the Registry the delivering operator reports his shippers, owners and if necessary purchasers and wells.

To report the non cascaded volumes select the owner button beside the appropriate shipper. Note since a shipper list is in place additional shippers cannot be added by the delivering facility operator.

For each shipper the owners are listed and the volume is reported For each shipper the owners are listed and the volume is reported. Note the APMC is both the shipper and the owner of the Crown royalty volume BA ID 0PMC (zero PMC)

For each shipper the owners are listed by well if desired and the volume is reported. If the purchaser is different than the shipper they would be identified on this screen as well.

D. How is the Reporting Done? (cont’d) Identifying the Split Volume to Shippers, Owners, Purchasers & Wells Responding to a Cascade Outside the Registry, once a cascade has been communicated to the other facility operator, that operator calculates the split to shippers and owners and communicates back to the facility operator they delivered their volume through. This process is done by paper/fax or phone (sometimes via internal PA systems when both facilities are operated by the same company) The facility operator that delivered the volume directly to the pipeline, combines the splits to their shippers and owners with the splits provided by the other facility operator, and reports the results to the pipeline/terminal operator. In the Registry, once a cascade has been created there is an email notification sent to the other facility operator telling them a volume to be split has been created. The other facility operator would calculate and report to the Registry the split to shippers and owners.

To respond to the cascade the process is the same as for a regular split except that the Delivering Facility is the “Cascaded to” facility and the Receiving Facility will be the “Cascaded from” facility. The CTP facility does not change.

This is how a completed split would look that is in response to a cascade

D. How is the Reporting Done? (cont’d) Total including Cascades The Registry will roll up (balance together), all associated splits and cascade splits to balance back to the total volume. Both outside and in the Registry, it is the delivering facility operator that directly delivered to the pipeline/terminal that is responsible for ensuring the splits are done completely and balance to the total. If the pipeline/terminal is set to the Registry’s Full pipeline split participation level, then the Oil/LPG Missing/Incomplete Report should be used to identify errors or missing pipeline split data. This report will identify whether a cascaded volume has been responded to.

For CTP facilities set to Full pipeline split participation level, the Missing/Incomplete Report is available: Automatically once a month prior to the pipeline split deadline and On request by the user at anytime and will run during the day.

D. How is the Reporting Done? (cont’d) If the CTP facility is set to Full in the Registry and the “Cascaded to” facility operator has not done their split, then the delivering facility operator who created the cascade can enter the split information for that cascade into the Registry. The screens are the same as shown previously with the cascaded to facility listed as the delivering facility, the cascaded from facility listed as the receiving facility and the CTP facility is unchanged. This change in security (allowing one operator to input on behalf of another) is necessary, since it is the operator who directly delivered to the pipeline/terminal who is responsible for splitting the total volume even if a portion came from other facilities.

D. How is the Reporting Done? (cont’d) Communicating split information Outside the Registry, once the pipeline split deadline has passed the pipeline/terminal operator will no longer take split data from the delivering operator. In the Registry, split data is locked when deadlines are reached and only the CTP operator can unlock the data to allow a delivering operator to add or change split data. Outside the Registry, once the splits have been sent to the pipeline/terminal (CTP) operator, the delivering operator needs to send via paper/fax etc. the data to partners (owners), shippers and purchasers. In the Registry for Full participating pipeline/terminals, there are automatic reports generated and distributed to all those named in the split data when the deadline is reached. For Non or Lite participating CTP facilities, operators, shippers, owners, and purchasers can request overnight reports at anytime. Once all the reporting has been done and balanced either outside or inside the Registry, the shippers and/or purchasers will issue cheques to the owners/producers by the 25th day after the production month.

D. How is the Reporting Done? (cont’d) The bottom line is that the pipeline split calculations are the same whether the reporting of the results is done in the Registry or not. In the Registry the rules are enforced (hard). These are the same rules that were previously in place but may not have been enforced (soft). Even those producers who do not deliver to the Cremona system should become familiar with the Registry’s pipeline process, and use it for partner reporting purposes. Using the Registry will help standardize pipeline split reporting and provide a single source for this information. We expect more pipelines to use the Registry’s Full pipeline split process in 2008.

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