The Petroleum Registry of Alberta The Petroleum Registry of Alberta Energizing the flow of information Registry Information Session February 22, 2008

The Petroleum Registry of Alberta

The Petroleum Registry of Alberta Energizing the flow of information

Registry Information Session

February 22, 2008


Agenda1. REGISTRY TOPICS

Outside Jurisdiction Interest Update

2. ERCB TOPICSa) Directive 007 Updatesb) Gas Inventory Adjustmentsc) SAGDd) Well Shut In’s/Suspensionse) Water Portfolio

3. INDUSTRY TOPICSa) Crown Inventory Reportingb) Registry/IBC Report Committeec) Royalty Attribute Change Reportd) Managing Allowable Costse) DOE Oil Penaltiesf) Proper Use of PURREC/PURDISP

4. DID YOU KNOW?a) Registry Training Update Projectb) “Don’t Click Again”c) Upcoming Change to Passwordsd) Pipeline Spit Current Reporte) Registry Service Desk Items:

i. Pipeline Splits – Submit from Edit Pageii. Popup Blocker Issuesiii. Reporting of Load Fluid at a Gas Plant

5. QUESTIONS


1. REGISTRY TOPICS


Registry Topics

a) Interest from Outside Jurisdictions British Columbia

• Post Business Case completion discussions continue.

Yukon• Opportunity Assessment/Evaluation activities in

progress. Manitoba

• Meeting held with the Manitoba Ministry of Science, Technology, Energy & Mines in early January.

Saskatchewan• Meeting held with the Saskatchewan Ministry of

Energy & Resources at the end of January.


2. ERCB TOPICS


Directive 007 Updates


Directive 007 Updates

• Directive 007 has been renamed from “Production Accounting Handbook” to “Volumetric and Infrastructure Requirements”

• Now there are two parts to it:1. Regulations and Requirements Portion

2. The On-Line Supplement Portion – The How to Section

• The Supplement will be updated as necessary to reflect new changes, additions and deletions.

Where Directive 007 Supplement is found on the ERCB Web

This Supplement will be updated as necessary


Directive 007 Update Highlights

• All references to:

1. Guides

2. Information Letters (IL’s)

3. Interim Directives (ID’s)

have been rescinded or superseded.


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.


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.


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.


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 [email protected].

• Inquiries may also be directed to the ERCB Customer Contact Centre by:

• Telephone at (403) 297-8311 or by

• e-mail at [email protected].

mailto:[email protected]



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.



• 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.



• Section 3: Definitions of 14 facility subtypes have been added and or revised.


Gas Inventory Adjustments


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.


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


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.


Gas Inventory Adjustments Cont’d

• Only 2 AB PL subtypes will be allowed to report GAS INVADJ:

1. 204 - Gas Transporter

2. 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.



• 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.



• Gas Inventory Adjustments should not be used to lower metering differences at:

• Batteries

• Gathering Systems

• Gas Plants

• Others - Injection/Disposal



• When there is a Gas Metering Difference, the operator is required to:

1. Check the calibration on their meters.2. Ensure that they are using the right size orifice plates and

they are not damaged.3. Ensure that all Gas and Gas Equivalent Volumes of all

products Receipts and Dispositions are properly accounted for.

4. Ensure that all Gas Flared, Vented, and Lease Fuel are accounted for.

5. Ensure that the Gas Equivalent Volume of recombined condensate (if any) is accounted for.

6. 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.


Steam Assisted Gravity DrainageSAGD


What is SAGD?

• SAGD stands for Steam Assisted Gravity Drainage.

1. Usually, two parallel horizontal wells drilled into the formation.

2. The upper well injects steam and the lower one collects the water that results from the condensation of the injected steam and the crude oil or bitumen.

3. The injected steam heats the crude oil or bitumen and lowers its viscosity which allows the oil to gravitate down into the lower wellbore.


Reporting of SAGD

• There are two ways of reporting SAGD depending on circumstances:

1. Under one well

2. Under two wells


An Example of SAGD Operation (Two Wells)


Reporting of SAGD

What is unique about a well with SAGD status in the Registry?

1.No Fluid Codes in the Well Status (N/A N/A SAGD N/A)

2.A well with SAGD status is required to be linked to two facilities in the Registry:

1. A Battery (To report production)

2. An Injection Facility (To report Injection)

3.The Registry allows total Injected and Produced hours to exceed 744 in a 31 day month or 720 in a 30 day month.


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


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

Reporting of SAGD Under One Well

Same well linked to both facilities

Reporting of SAGD Under Two Wells

Both wells linked to both facilities

How To Change to SAGD Status

Before

After


Well Shut In’s and Suspensions


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…


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.


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.


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.


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)


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


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.


Water Portfolio

Water Error Count Going Up


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.


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).


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.


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.


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.


For More Help…

Contact the ERCB

• PA Helpdesk @ ERCB 297-8952 option 3 email: [email protected]

– Can provide more information and instructions on all of the ERCB topics covered today.

• Wells Records Helpdesk @ ERCB 297-8696



3. INDUSTRY TOPICS


CROWN INVENTORY REPORTING


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.


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.


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.



The Edit and Query Crown Oil Inventory functions are located on the Registry Menu: Monthly Reporting – Oil/LPG Pipeline Splits



When Editing users must input the Facility ID and Production Month and then click Go.

Note: Production months prior to January 2008 will be rejected in the Registry.



The screen opens displaying:• An Opening Inventory (if applicable)• The Anticipated Delivery month



The User:• Inputs the Undelivered volume. • Changes or leaves the Anticipated Delivery

month as applicable.• Clicks Submit.



• The Registry will calculate the Closing Inventory and display the Successful submission message.

• If the data is for the current production month the Registry will automatically send it to the APMC on the deadline.


REGISTRY/IBC REPORTING COMMITTEE


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: [email protected]


ROYALTY ATTRIBUTE CHANGE REPORT


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.


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.

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



To request the report users select the Submit Report Request function on the Registry menu.


Using the report dropdown list the user selects the Royalty Attribute Change Report and Clicks Go.


• The User makes their selections and clicks Submit.

• This report runs during the day and an email notification will be sent once the report is ready.



• This is a new Registry report, and there are a few issues that the Registry team is currently addressing.

• In particular the .csv version of this report is being enhanced to make it more user friendly and easier to filter and sort.

• If you use this specific report and have any suggestions for improvements, please contact the Registry Service Desk at [email protected].



MANAGING ALLOWABLE COSTS


Managing Allowable CostsKey Principles for Managing Allowable Costs

1. Use Registry and DOE reports to manage the submission process.

2. Rely on Registry edits in determining if your initial AC filings are correct.

3. Understand the DOE’s “grace period” rules in managing incorrect filings after the deadline.

4. Understand the Registry’s new AC1 Delete process.

5. Be aware that Registry hours of operation are extended to accommodate filing near Allowable Cost deadlines.


Managing Allowable Costs cont’d

1. Registry and DOE Reports

a) 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.

b) 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.



c) 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.

d) 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.



e) 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.

f) 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.



2. 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.



3. 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.



4. 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.



5) 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.


DOE OIL PENALTIES

Industry Government Reporting Statistics

DOE Oil Delivery Penalties ($MM)

Penalty Statistics*Note: Does not include Failure to Amend as there is a 60 day grace period

$0.00

$50,000.00

$100,000.00

$150,000.00

$200,000.00

$250,000.00

Jul-07* Aug-07* Sep-07 Oct-07 Nov-07 Dec-07Business Period

Crow n Split reporting

Over/Under delivery

Fail-to-Amend

Total

•.


DOE Oil Penalties

Key Principles to Avoid DOE Oil Penalties

1. Calculate Crown’s oil royalty share correctly.

2. Submit pipeline splits including Crown oil royalty share on time.

3. Report any Crown Royalty volume held in inventory.

4. Identify the differences of volume or facilities reported.

5. Understand DOE appeal or waiver process.


DOE Oil Penalties cont’d

1. Calculate Crown’s oil royalty share correctly

a) Before calculating crown ensure your data is current.

b) Confirm fixed data matches the data the DOE used for calculating crown the previous month.

c) Use the Royalty program report to determine:

• which program applies to a well.

• when the program starts and/or terminates.

• the program limits.

d) Request the Royalty Attribute Change Report from the Registry which details changes to:

• Oil crown royalty vintage.

• Oil crown interest.



2. Submit pipeline splits including Crown oil royalty share on time.

a) To avoid late filing penalties ensure your splits to the pipeline or terminal and the Registry are on time.

b) Review the Transportation Allowance and Overdelivery Claims (TAOC) Report to confirm that all crown royalty volumes have been reported in the Registry correctly.



3. Report any Crown Royalty held in Inventory

a) 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).

b) The deadline for this reporting is the same as the ERCB volumetric deadline.



4. Identify differencesa) 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.



b) 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.



• 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.




5. Understand the rules and processes to file objections to a DOE Oil non-compliance penalty.a) Before a penalty invoice is issued:

i. “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.



b) After a penalty invoice is issued:i. 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.



ii. 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.



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.


PURDISP AND PURREC

Gathering

System 1 Gas

Plant 1 Battery 1

Battery 2

Well 1

Well 2

Terminal Pipeline Meter Station

Royalty Network

PURDISP AND PURREC

Rec Disp

Purrec

Purdisp

Operator A

Operator B


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:

1. The receiving battery operator must report a PURREC.

2. This will auto populate a PURDISP at the delivering battery.

3. The operator must then file an SAF/OAF for the PURDISP.


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.


DID YOU KNOW?


REGISTRY TRAINING UPDATE PROJECT


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:oSorting the Modules Available into Business Functions that mirror the Registry Menu.oEnsure training modules are updated with information provided in Tips and Alerts and all new enhancements promoted to the Registry.oWatch for more details via Broadcast Messages, etc.


DON’T CLICK AGAIN


“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”.


UPCOMING CHANGES TO PASSWORDS


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.


PIPELINE SPLIT CURRENT REPORT


Pipeline Split Current Report

• The Registry team would like to remind users about the Pipeline Split Current Report.

• This report lists all the pipeline split data in the Registry for your facilities for the current production month.

• The report includes:

• Details for all splits regardless of their pipeline splits participation level.

• Volume and energy to be split (reported by the PL, TM or MS)

• Shipper lists reported by the PL, TM or MS

• The actual split volumes you have submitted

• Any cascades to other facilities you created

• The report runs during the day to provide almost immediate feedback.

Pipeline Split Current Report Cont’d

To request the report users select the Submit Report Request function on the Registry menu.

• Using the report dropdown list the user selects the Pipeline Split Current Report and clicks Go.

Pipeline Split Current Report Cont’d

• Users make the selections and then click Submit.

• Note you cannot change the production month.

The above report shows how the data would look if:• The PL has submitted:

• The Volume to be Split (Volume Requiring Split - VRS).• The Delivering Operator (Del) has submitted:

• Nothing.


• The Shipper data.• The Volume to be Split (Volume Requiring Split - VRS).

• The Delivering Facility Operator (Del) has submitted:• Nothing.

This report shows how the data would look if:• The PL has submitted:

• The Volume to be Split (Volume Requiring Split - VRS).• The Delivering Facility Operator has submitted:

• Actual Split Volumes.


• The Shipper data.• The Volume to be Split (Volume Requiring Split - VRS).

• The Delivering facility operator has submitted: • Cascades to other facilities.• Actual Split Volumes.


REGISTRY SERVICE DESK ITEMS


PIPELINE SPLITS - SUBMIT FROM THE EDIT

PAGE


Popup Blockers

Internet Explorer 7 (IE7)

Add the Registry to Trusted Sites

Add the Registry to Trusted Sites cont’d

Lookups would display without address bar

Explorer User Prompt will open without being blocked


LOAD FLUID INJECTION/RECOVERY IN GAS

WELL


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


• 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.

Load Fluid Injection/Recovery in Gas Well cont’d

The gas equivalent volume of 2.1 is included in the REC volume of 255.3

The gas equivalent volume of 2.1 is included in the REC volume of 255.3



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


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.



• 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.



Contact Information

For any questions regarding the Registry please contact the Service Desk via telephone, email, website or facsimile, as follows:

Phone: (403) 297-6111 (Calgary)Phone: 1-800-992-1144 (other locations)Fax: (403) 297-3665Email: [email protected]: http://www.petroleumregistry.gov.ab.ca/


QUESTIONS

Documents

The Petroleum Registry of Alberta The Petroleum Registry of Alberta Energizing the flow of information Registry Information Session February 22, 2008