agenda

2. Agenda REGISTRY TOPICS Outside Jurisdiction Interest Update ERCB TOPICS Directive 007 Updates Gas Inventory Adjustments SAGD Well Shut In�s/Suspensions Water Portfolio INDUSTRY TOPICS Crown Inventory Reporting Registry/IBC Report Committee Royalty Attribute Change Report Managing Allowable Costs DOE Oil Penalties Proper Use of PURREC/PURDISP DID YOU KNOW? Registry Training Update Project �Don�t Click Again� Upcoming Change to Passwords Pipeline Spit Current Report Registry Service Desk Items: Pipeline Splits � Submit from Edit Page Popup Blocker Issues Reporting of Load Fluid at a Gas Plant QUESTIONS

3. 1. REGISTRY TOPICS

4. Registry Topics

5. 2. ERCB TOPICS

6. Directive 007 Updates

7. Directive 007 Updates Directive 007 has been renamed from �Production Accounting Handbook� to �Volumetric and Infrastructure Requirements� Now there are two parts to it: Regulations and Requirements Portion The On-Line Supplement Portion � The How to Section The Supplement will be updated as necessary to reflect new changes, additions and deletions.

8. Where Directive 007 Supplement is found on the ERCB Web

9. Directive 007 Update Highlights All references to: Guides Information Letters (IL�s) Interim Directives (ID�s) have been rescinded or superseded.

10. A Notable Update to Section 1 in Directive 007 Effective January 31, 2008, the ERCB is no longer accepting �S� Reports for the September 2002 production month or earlier, unless directed by the ERCB under special circumstances. Amended volumetric submissions are subject to a closed five-year reporting period.

11. Directive 007 Updates, Section 1 Cont�d S30�s � Monthly Gas Processing Plant Sulphur Balance Report The previous S30 information in Directive 007 has been superseded by Bulletin 2007-37.

12. Highlights of Bulletin 2007-37 Effective January 2008 production, companies must submit S-30 reports electronically through the ERCB DDS system. The ERCB will no longer accept S-30 reports submitted by mail, e-mail, or fax covering the reporting periods of January 2008 and thereafter. Please refer to Bulletin 2007-37 for more information.

13. S-30 and DDS System Contacts For questions about submitting S-30 reports using the DDS system, please contact the ERCB S-30 DDS Support desk by: Telephone at (403) 297-8468 or by e-mail at S30Support@ercb.ca. Inquiries may also be directed to the ERCB Customer Contact Centre by: Telephone at (403) 297-8311 or by e-mail at Inquiries@ercb.ca.

14. Directive 007 Updates Cont�d The Commingling verbiage in Section 3.1.2 has been revised to align with Directive 065 (Resources Applications for Conventional Oil and Gas Reservoirs) requirements.

15. Directive 007 Updates Cont�d Section 5 Compliance and Enforcement Old information has been replaced with a direct reference and link to Directive 019 (Compliance Assurance-Enforcement) . Error Messages Identifier Description listing has been added.

16. Directive 007 Updates Cont�d Section 3: Definitions of 14 facility subtypes have been added and or revised.

17. Gas Inventory Adjustments

18. Directive 007 on Inventory Adjustments (INVADJ) Inventory Adjustments in general, are used to report gains and losses that cannot be identified by a specific activity and/or production month. If an operator finds out the cause of the gain or loss, an amendment must be filed.

19. Directive 007 on Inventory Adjustments (INVADJ) Cont�d An operator may also use inventory adjustment when an adjustment to closing inventory is required due to: Water tank cleanout Loss of sulphur from sulphur pad Oil Theft Oil Fires (Use AB MC for Gas Fires) Spills

20. Gas Inventory Adjustments ERCB has determined that the following facilities should not maintain gas inventories: Gas Plants Gathering Systems Batteries Others - Injection/Disposal As a result, Gas Inventory Adjustments (INVADJ) must not be reported at these facilities. ERCB will be contacting the few companies who are reporting Inventory Adjustments for these facilities.

21. Gas Inventory Adjustments Cont�d Only 2 AB PL subtypes will be allowed to report GAS INVADJ: 204 - Gas Transporter 206 � Gas Distributor Also, note that Gas Inventories or Gas Inventory Adjustments (INVADJ) are not reported in the Registry for AB IF subtype 505 (Underground Gas Storage) facilities.

22. Gas Inventory Adjustments Cont�d For a new facility needing line fill (filling lines with gas): Report this gas under metering difference (DIFF), depending on circumstances, the non-compliance charges may be waived. Not as Closing Inventory (INVCL) Not as Inventory Adjustment (INVADJ) Please contact the ERCB PA helpdesk for more details.

23. Gas Inventory Adjustments Cont�d Gas Inventory Adjustments should not be used to lower metering differences at: Batteries Gathering Systems Gas Plants Others - Injection/Disposal

24. Gas Inventory Adjustments Cont�d When there is a Gas Metering Difference, the operator is required to: Check the calibration on their meters. Ensure that they are using the right size orifice plates and they are not damaged. Ensure that all Gas and Gas Equivalent Volumes of all products Receipts and Dispositions are properly accounted for. Ensure that all Gas Flared, Vented, and Lease Fuel are accounted for. Ensure that the Gas Equivalent Volume of recombined condensate (if any) is accounted for. Use the gathering system and gas plant gas inlet volumes rather than the battery gas disposition volume. Refer to Directive 17 (Measurement requirements for Upstream Oil and Gas Operations) or contact the PA helpline for clarification.

25. Steam Assisted Gravity DrainageSAGD

26. What is SAGD?

27. Reporting of SAGD There are two ways of reporting SAGD depending on circumstances: Under one well Under two wells

29. Reporting of SAGD What is unique about a well with SAGD status in the Registry? No Fluid Codes in the Well Status (N/A N/A SAGD N/A) A well with SAGD status is required to be linked to two facilities in the Registry: A Battery (To report production) An Injection Facility (To report Injection) The Registry allows total Injected and Produced hours to exceed 744 in a 31 day month or 720 in a 30 day month.

30. Reporting of SAGD cont�d Currently, a SAGD well can be linked to one of the following Battery Subtypes: 311 - CRUDE OIL SINGLE-WELL BATTERY 321 - CRUDE OIL MULTIWELL GROUP BATTERY 322 - CRUDE OIL MULTIWELL PRORATION BATTERY 331 - CRUDE BITUMEN SINGLE-WELL BATTERY 341 - CRUDE BITUMEN MULTIWELL GROUP BATTERY 342 - CRUDE BITUMEN MULTIWELL PRORATION BATTERY 344 - IN-SITU OIL SANDS

31. Reporting of SAGD cont�d Currently, a SAGD well can be linked to one of the following Injection Facility subtypes: 501 � ENHANCED RECOVERY SCHEME 506 � IN-SITU OIL SANDS

32. Reporting of SAGD Under One Well

33. Reporting of SAGD Under Two Wells

34. How To Change to SAGD Status

35. Well Shut In�s and Suspensions

36. The General Rule on Well Suspensions If a well is shut in for 12 consecutive months, it is required by ERCB Directives 007* and 13* to be suspended. Directive 007* (Volumetric Infrastructure Requirements) Directive 13* (Suspension Requirements for Wells) More details to follow�

37. Directive 007on Well Suspensions For a well in which production or injection operations have ceased for an indefinite period of time, you are required to suspend it within 12 months after the last production or injection has occurred.

38. Directive 007 on Well Suspensions Cont�d Volumetric information for a suspended well is not required. The only valid activity is �shut-in�, although not recommended.

39. Inactive Wells as definedin Directive 13 Inactive critical sour and inactive acid gas wells: Wells that have not reported any type of volumetric activity (production, injection, or disposal) for 6 consecutive months; and All other inactive wells: Wells that have not reported any type of volumetric activity (production, injection, or disposal) for 12 consecutive months.

40. Exceptions to Directive 13 Suspension Requirement A well does not need to be suspended after 12 consecutive months of non production under the following circumstances: When a well is produced only to supply a seasonal market. When a well is shut in to make up for overproduction. When the well type code is �observation.� When a well is approved for �deliveries equals production� until all production has been allocated to the well. (Well statuses with Crude Bit as fluid type)

41. Oil and Gas Conservation Regulation 12.020(1) �The operator of a well must, when required by Directive 007, Production Accounting Handbook*, keep and file a record with the Board relating to the status of a well in accordance with Directive 007, Production Accounting Handbook and any amendments to Directive 007, as published by the Board.� * Production Accounting Handbook is now renamed to �Volumetric and Infrastructure Requirements� in Directive 007

42. Updates on Well Suspensions By the last count made on January 24th,2008, there were 11,066 potential suspended wells which were not suspended in the Registry. Almost every company in Industry has 1 or more wells that need potentially to be suspended. ERCB will be following up with Industry over the next few months to address the problem.

43. Water Portfolio

44. Water Error Count Going Up

45. Stats On Water Error Count By the last count made on February 13th, 2008 there were: Total 8,793 water errors outstanding since the Registry went live (2002). 222 companies with water errors 2,598 facilities ERCB will be contacting the affected companies in the coming months.

46. Two Water Facility Subtypes Redefined In order to correctly track the water source being used for oilfield injection (subtypes 501(EOR) and 506 (in Situ), ERCB has redefined two water facility subtypes in Directive 007: 901 AB WS � Water Source. 902 AB BT � Water Source (used to be called Miscellaneous).

47. Water Definitions Brackish Water (Saline water) Water that has more than 4000 milligrams per liter [mg/L] of TDS (Total Dissolved Solids). Fresh Water (Non-Saline Water) All other groundwater and surface water that does not meet the definition of saline groundwater and has a TDS level less than 4000 mg/l. Water S&W that is recovered in association with the production of oil and gas.

48. 901 AB WS - Water Source The source of fresh (non-saline) water can either come from a shallow drilled source well (<150m), river, lake, or other surface locations. In all cases, the location/source of water is reflected by a specific geographic location and is licensed by Alberta Environment. It is not a reporting facility (WS). Water Source needs to be reported at a receiving facility with the activity of REC and the product Fresh Water (FSHWTER). A new edit will be added to the Registry to ensure only Fresh Water can be reported for a WS receipt.

49. 902 AB BT � Water Source(used to be called Miscellaneous) A facility type set up to link one or more ERCB licensed freshwater source wells (fresh [non-saline] or brackish [saline]). Most of these wells are deep (>150 m). It is a reporting facility (BT) � These batteries can report production of Fresh Water (FSHWTER) and/or Brackish Water (BRKWTR). A new edit will be added to the Registry to ensure only Fresh and Brackish water can be reported at these batteries.

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

51. 3. INDUSTRY TOPICS

52. Crown Inventory Reporting

53. Crown Inventory Reporting Effective with the production month of January 2008 (reported in February 2008), the Registry has been enhanced with two new functions: Edit Crown Oil Inventory. Query Crown Oil Inventory. These processes replace the APMC 122 paper form. Operators of batteries that have Crown Oil held in Inventory and not delivered must use the Edit Crown Oil Inventory function to report these volumes to the Crown.

54. Crown Inventory Reporting Cont�d The Crown Oil Inventory information for the current production month will be extracted automatically and sent to the APMC. Reporting of the Crown Oil Inventory is subject to a submission deadline. The deadline is the same date as the ERCB volumetric deadline approximately the 18th to the 20th of each month. Please refer to the Registry reporting calendar for the specific Crown Oil Inventory Deadline for each month. Crown Oil Inventory volumes reported after the applicable Crown Oil Inventory Deadline (a prior production month) will not be extracted and you must contact your APMC Oil analyst to ensure they receive the information.

55. Crown Inventory Reporting Cont�d To facilitate the transition from a paper form to the Registry, the paper APMC 122 form/email will continue to be accepted by the APMC until April 25, 2008. Additional information about this process can be found on the Registry website under Tips/Current/Monthly Reporting: Pipeline/Reporting Crown Oil Inventory, and Training � Module 4.12a&b has been updated to include the Crown Inventory Reporting function.

61. REGISTRY/IBC REPORTING COMMITTEE

62. Registry/IBC Reporting Committee The Registry, along with the Industry Benefits Committee, (IBC) has formed a new Reporting Committee to look at: Improvements to existing Registry reports. Validate if previously requested report changes are still desired. Expansion of the # & size of daytime running reports. New Registry reports. The Committee�s first meeting is scheduled: On February 28, 2008 1:30 � 3:30 p.m. At Registry offices 3rd floor � 801 Sixth Avenue S.W. If you would like to join the Committee please contact: Ann Hagedorn via email: ann.hagedorn@gov.ab.ca

63. ROYALTY ATTRIBUTE CHANGE REPORT

64. Royalty Attribute Change Report Starting on February 7, 2008, the Registry has a new report available for operated facilities and PEs, called the Royalty Attribute Change Report, which will list all the Royalty changes captured since January 4, 2008. The Royalty Attribute Change Report is designed to help users calculate their Crown Oil royalties using the latest information supplied by the DOE Oil group to the Registry. The new Royalty Attribute Change Report will list changes to the Crown interest and Vintage of Production Entities (PEs - wells, units etc.) that impact the Crown Oil royalty calculations. The Registry has been tracking these types changes since January 4, 2008, therefore changes prior to that date will not be available on the report.

65. NOTE: During the time period January 4 to February 7, 2008 the Registry did not capture all changes to Vintage when the change affected more than one vintage over the well�s history. For example, if a well has a vintage of Old from inception 2005-01 to 2005-12 and New vintage from 2006-01 to EOT (end of time displayed as blank), only the first record with a start date of 2005-01 and an end date of 2005-12 will be displayed on the report. Users who see this scenario; a record with an end date and no following record with a blank end date will need to use the Query Production Entity menu item to see the correct final record. This problem has been addressed and any changes of this type subsequent to February 7, 2008 will be captured correctly.

66. Royalty Attribute Change Report Cont�d Clients must be aware of the start and end date when requesting the Royalty Attribute Change Report. The default end date will be the current date and the start date will be one month prior. If you need to request for a longer period you may do so and will need to adjust the start date to an earlier date. Remember the Registry was not capturing these changes for the report prior to January 4, 2008 and any requests for changes prior to that date will return no records found. For more information on this report see: Tips & Alerts � Alerts Current - New Royalty Attribute Change Report

72. Managing allowable costs

73. Managing Allowable Costs Key Principles for Managing Allowable Costs Use Registry and DOE reports to manage the submission process. Rely on Registry edits in determining if your initial AC filings are correct. Understand the DOE�s �grace period� rules in managing incorrect filings after the deadline. Understand the Registry�s new AC1 Delete process. Be aware that Registry hours of operation are extended to accommodate filing near Allowable Cost deadlines.

74. Managing Allowable Costs cont�d 1. Registry and DOE Reports Expected AC2 Report Generated by the DOE and delivered to Registry Ministry Invoices and Statements. Identifies FCCs where a BA is required to file AC2s. Registry AC2 Summary Report Identifies all FCCs that a BA operates and FCCs where a BA has been named as an owner and their filing status (confirmed, unconfirmed, missing or rejected). This report similar to the DOE Expected AC2 report when requested for your BA only.

75. Managing Allowable Costs cont�d DOE Missing AC4 Reminder Notice Generated by the DOE and delivered to Registry Ministry Invoices and Statements. Identifies FCCs where a BA is required to file AC4s. Registry AC4 Summary Report Identifies all FCCs that require an AC4 submission that a BA operates and FCCs where a BA has been named as an owner and their filing status (confirmed, unconfirmed, missing or rejected). Effective Mar 5, 2008 If requested for only your BA only FCCs that require an AC4 submission will be on this report.

76. Managing Allowable Costs cont�d DOE expected AC5 Report Generated by the DOE and delivered to Registry Ministry Invoices and Statements. Identifies all FCCs where a BA has been allocated custom user volumes on an AC2 or AC3. Energy Adjusted Gas Equivalent Volumes Report Generated by the DOE and delivered to Ministry Invoices and Statements. Identifies all ERCB facilities where a BA has delivered volumes. A BA should ensure that an AC2 and/or an AC5 has been filed for each facility listed on this report.

77. Managing Allowable Costs cont�d Rely On Registry edits Last year only 1.4% of AC submissions that passed Registry edits were subsequently rejected by the DOE. Edits in the Registry have been reviewed and will be updated Mar. 5, 2008 to reduce even this small percentage of rejections. In the unlikely event that the DOE identifies an error the operator can make a correction at that time. If the error is discovered after the deadline, the operator can make a correction within the DOE grace period.

78. Managing Allowable Costs cont�d DOE grace period AC2 and AC5 forms are granted a 15 day grace period if forms are submitted by the due date but are rejected by the DOE. The grace period refers to 15 days following the month in which the invoice that included the penalty warning was issued. Due to the AC deadlines and the timing of the invoice run operators actually have well in excess of the 15 days grace.

79. Managing Allowable Costs cont�d AC1 Delete 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 is only one operator for the FCC. The FCC Id has not been referred to on any other FCC ID (ie previous FCC Id). If you need to delete an AC1 but cannot due to the above rules then you must do the two step process of shutting in the FCC then terminating it.

80. Managing Allowable Costs cont�d Registry Hours The Registry will be open 6:00 am to 5:30 pm the following Sundays: March 16 and 30 April 20 and 27 May 11 The Registry is also open to midnight on deadline days.

81. Doe oil penalties

82. Industry Government Reporting Statistics DOE Oil Delivery Penalties ($MM)

83. DOE Oil Penalties Key Principles to Avoid DOE Oil Penalties Calculate Crown�s oil royalty share correctly. Submit pipeline splits including Crown oil royalty share on time. Report any Crown Royalty volume held in inventory. Identify the differences of volume or facilities reported. Understand DOE appeal or waiver process.

84. DOE Oil Penalties cont�d Calculate Crown�s oil royalty share correctly Before calculating crown ensure your data is current. Confirm fixed data matches the data the DOE used for calculating crown the previous month. Use the Royalty program report to determine: which program applies to a well. when the program starts and/or terminates. the program limits. Request the Royalty Attribute Change Report from the Registry which details changes to: Oil crown royalty vintage. Oil crown interest.

85. DOE Oil Penalties cont�d Submit pipeline splits including Crown oil royalty share on time. To avoid late filing penalties ensure your splits to the pipeline or terminal and the Registry are on time. Review the Transportation Allowance and Overdelivery Claims (TAOC) Report to confirm that all crown royalty volumes have been reported in the Registry correctly.

86. DOE Oil Penalties cont�d Report any Crown Royalty held in Inventory Crown royalty volumes that have not been delivered in a production month need to be reported in the Crown Royalty Inventory section of the Registry (previously APMC 122). The deadline for this reporting is the same as the ERCB volumetric deadline.

87. DOE Oil Penalties cont�d Identify differences Confirm what you report to the Registry for crown volume is the same as what the pipeline/terminal told the APMC using the following reports: Royalty Delivery Confirmation Report Found in Registry Ministry Invoices and Statements between 20th and 25th each month. These volumes should match what you reported to the terminal/pipeline operator for the APMC. APMC Transportation and Overdelivery Report Lists the APMC volume reported in the Registry. Compare this report to above report which will identify any discrepancies in either volume or facility. Discrepancies will result in penalties for inaccurate reporting.

88. DOE Oil Penalties cont�d Compare your Crown royalty calculations and deliveries to the DOE�s calculations using the APMC Operator DOE Reconciliation Report. Found in Registry Ministry Invoices and Statements generally the 1st or 2nd day each month. Details at the facility level : Crown oil royalty calculated by DOE. Deliveries reported by the Pipeline. Difference. Amendment deadline date.

89. DOE Oil Penalties cont�d Negative differences is an over delivery of crown royalty. an amendment is required by the amendment deadline date regardless of the volume. If not claimed is subject to a Failure to amend Penalty. Positive differences Is an under delivery of crown royalty. APMC will invoice you or ask you to deliver the volume in another month.

91. DOE Oil Penalties cont�d Understand the rules and processes to file objections to a DOE Oil non-compliance penalty. Before a penalty invoice is issued: �Informal Review Period� From the issue date of the Preliminary Late /Non-Receipt/Failure-to-Amend Report at month end to approximately the 20th day of the following month. Onus is on the operator to contact their DOE Oil Analyst to review potential penalties and seek to resolve them prior to the penalty invoice.

92. DOE Oil Penalties cont�d After a penalty invoice is issued: Waiver of Penalty The APMC can only grant a waiver when: The failure to report by the deadline was due to circumstances beyond the Applicant�s control or that the Applicant could not have reasonably foreseen. The late report was filed within a reasonable time after it was due.

93. DOE Oil Penalties cont�d Appeal of Penalty The APMC can only grant an appeal when: A request to have a late filing penalty waived was denied by the APMC. Inaccurate reporting, under deliveries or over deliveries that were not avoidable by the Appellant, for example: Royalty data element changes( vintage, density etc). Production information change ( new volumetric data). Crown percentage change. EOR well not included in unit or scheme.

94. DOE Oil Penalties cont�d For more information on appeals and waivers of Crude Oil Penalties review the Registry tip �Reducing the Risk of Receiving DOE Oil Penalties� which includes links to the DOE�s Instructions - Applications for Waiver of Penalty or Appeal of Penalty.

95. PURDISP AND PURREC

97. PURDISP AND PURREC When do you use PURREC and PURDISP? When there is a sale of gas (transfer of ownership) within the royalty network (gas does not reach a meter station). For example: If a Battery sells gas to another Battery this is considered an �in Royalty network� sale and crown royalties are assessed on this transaction. In order for the Registry and the DOE to recognize this sale: The receiving battery operator must report a PURREC. This will auto populate a PURDISP at the delivering battery. The operator must then file an SAF/OAF for the PURDISP.

98. PURDISP AND PURREC cond�t It is important to note: If gas has been sent to the gas plant from a battery and the gas plant has returned gas to the same battery (example: a return fuel situation). There are no royalty triggers so this would be a REC at the battery not a PURREC.

99. DID YOU KNOW?

100. REGISTRY TRAINING UPDATE PROJECT

101. REGISTRY TRAINING UPDATE PROJECT The Registry Training Team is currently reviewing the entire on-line Training system and looking for ways to improve accessibility to training information, and assist users in meeting their requirements in their daily interaction within the Registry. This will ensure that the Training System, which is in actual fact an on-line Registry business process and procedures user interface library, reflects current Registry functionalities, processes and business logic. These improvements include: Sorting the Modules Available into Business Functions that mirror the Registry Menu. Ensure training modules are updated with information provided in Tips and Alerts and all new enhancements promoted to the Registry. Watch for more details via Broadcast Messages, etc.

102. DON�T CLICK AGAIN

103. �DON�T CLICK AGAIN� Double Clicking is a �No-No�. The Registry Team has identified that users submitting a second request while waiting for the Registry to respond, may be the cause of up to a quarter of the �error pages�. This is particularly noticeable on look-up screens. The Registry will be modified to prevent the second request being processed. In the meantime, you are encouraged not to �Double Click�.

104. UPCOMING CHANGES TO PASSWORDS

105. UPCOMING CHANGES TO PASSWORDS Strong Passwords have been used in the Registry since early 2007. The Alberta Auditor General has indicated that all Alberta Government systems will be updated to include even stronger passwords. Passwords will still require 3 of the following four elements: Lower Case Letters Upper Case Letters Numbers Special Characters Changes to the current Strong Password requirements include: Need to be at least 8 characters rather than 6. Cannot include words found in most dictionaries (example: Summer12) The timing of this change has not yet been determined. Further details will be communicated once the actual implementation date has been identified.

106. PIPELINE SPLIT CURRENT REPORT

115. REGISTRY SERVICE DESK ITEMS

116. PIPELINE SPLITS - SUBMIT from the edit page

117. This Owner/Shipper screen is Saved to WIP. Click Cancel to return to previous screen.This Owner/Shipper screen is Saved to WIP. Click Cancel to return to previous screen.

118. Returned to the edit pipeline split showing the entered volumes. Returned to the edit pipeline split showing the entered volumes.

119. At this point, if the pipeline split is completed, the data must be SUBMITTED to the Registry. It is successful when the messages CME0002 Submitted Successfully and CME0004 Data from Registry appear.At this point, if the pipeline split is completed, the data must be SUBMITTED to the Registry. It is successful when the messages CME0002 Submitted Successfully and CME0004 Data from Registry appear.

120. Popup Blockers Internet Explorer 7 (IE7) There are some new features of Internet Explorer 7 that might have some bearing on the look and feel of the PRA. These features should have minimal impact as to the usability of the Registry but changes the style of the address bar on some of the pages and causes an extra step when opening some attachments and running some client side JavaScript.There are some new features of Internet Explorer 7 that might have some bearing on the look and feel of the PRA. These features should have minimal impact as to the usability of the Registry but changes the style of the address bar on some of the pages and causes an extra step when opening some attachments and running some client side JavaScript.

121. In IE7 every new window, whether it is a pop-up or standard window, will present an address bar to the user, helping to block malicious sites from emulating trusted sites. In IE7 every new window, whether it is a pop-up or standard window, will present an address bar to the user, helping to block malicious sites from emulating trusted sites.

122. When opening some notification details, the file is blocked because IE7 identifies it as a potentially dangerous item. The user is able to download the file by simply clicking on the information bar.When opening some notification details, the file is blocked because IE7 identifies it as a potentially dangerous item. The user is able to download the file by simply clicking on the information bar.

123. The browser also blocks some JavaScript. Again the user is able to run the script by clicking on the information bar.The browser also blocks some JavaScript. Again the user is able to run the script by clicking on the information bar.

124. Add the Registry to Trusted Sites The IE7 user can add the Registry as a trusted site.The IE7 user can add the Registry as a trusted site.

125. Add the Registry to Trusted Sites cont�d The address must start with HTTPS and �Require server verification (https:) for all sites in this zone� must be checked. HTTPS: identifies the site as secured. This would eliminate the security issues.The address must start with HTTPS and �Require server verification (https:) for all sites in this zone� must be checked. HTTPS: identifies the site as secured. This would eliminate the security issues.

126. Lookups would display without address bar

127. Explorer User Prompt will open without being blocked

128. LOAD FLUID INJECTION/RECOVERY IN GAS WELL There are some new features of Internet Explorer 7 that might have some bearing on the look and feel of the PRA. These features should have minimal impact as to the usability of the Registry but changes the style of the address bar on some of the pages and causes an extra step when opening some attachments and running some client side JavaScript.There are some new features of Internet Explorer 7 that might have some bearing on the look and feel of the PRA. These features should have minimal impact as to the usability of the Registry but changes the style of the address bar on some of the pages and causes an extra step when opening some attachments and running some client side JavaScript.

129. Load Fluid Injection/Recovery in Gas Well Load condensate received, injected down a gas well and recovered in the gas stream in the same month. Facility Activity Screen: Enter the condensate receipt Enter the C5-SP disposition to AB GE Enter the Gas receipt from AB GE Gas Equivalency of Condensate/C5-SP: Condensate volume X 0.20575 The C5-SP will balance with the condensate.The C5-SP will balance with the condensate.

130. The condensate gas equivalency: 10 X 0.20575 = 2.1The condensate gas equivalency: 10 X 0.20575 = 2.1

131. In the Well Activity Screen Enter Activity LDINJ, product COND to show the load injection. Enter Activity LDREC, product COND to show the load recovered. The gas production volume should not include the gas equivalent volume of the recovered condensate.

133. The load fluid condensate/C5-SP is balanced. Note the load injection and recovery of condensate.The load fluid condensate/C5-SP is balanced. Note the load injection and recovery of condensate.

135. Load Fluid Injection/Recovery in Gas Well cont�d Load condensate received, injected down a gas well and recovering a portion of the condensate in the gas stream. Facility Activity Screen: Enter the condensate receipt Enter the C5-SP disposition to AB GE Enter the Gas receipt from AB GE Gas Equivalency of Condensate/C5-SP: Condensate volume X 0.20575

136. The condensate gas equivalency: 5.0 X 0.20575 = 1.0 Enter the condensate receipt of 10.0 Enter the C5-SP disposition of 5.0 to AB GE Enter the gas receipt of 1.0 from AB GEThe condensate gas equivalency: 5.0 X 0.20575 = 1.0 Enter the condensate receipt of 10.0 Enter the C5-SP disposition of 5.0 to AB GE Enter the gas receipt of 1.0 from AB GE

137. In the Well Activity Screen: Enter Activity LDINJ, product COND to show the load injection. Enter Activity LDREC, product COND to show the load recovered. The gas production volume should not include the gas equivalent volume of the recovered condensate. The LDINVCL will be auto-populated by the Registry.

138. Inject 10.0 of Condensate and Recover 5.0. The Registry auto populates the LDINVCL of 5.0.Inject 10.0 of Condensate and Recover 5.0. The Registry auto populates the LDINVCL of 5.0.

139. The condensate/C5-SP is balanced.The condensate/C5-SP is balanced.

140. For the submission of the Allocation for the load fluid volume recovered, the BA will have to contact their Gas Royalty Client Services representative to get permission to use the Royalty Paid code.

142. QUESTIONS