Transcript Accuracy

SZAWG Final Report
October 5, 2006
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SZAWG Members
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AESO
Chris Connoly, Peter Wong
AltaLink
Paul Lee, Shemin Merali
ATCO Electric
Bruce Ramsay, Blair Morton
Encana
Marie Gallant, Wynn Trumpour
Department of Energy
Kathryn Wood, Bob Deyl
EPCOR Distribution
Bob Deyl, Greg Rosychuk
FortisAlberta
Angela Corsi
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Mandate
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To provide recommendations that will correct
problems contributing to inaccuracies in the
settlement zone totals.
•
To provide reasonable certainty that all existing
errors in settlement zone totals have been found,
so that the suspended PFAMs can be released.
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Importance of System Level Metering
Since the opening of the market in
2001, the market has settled
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252,000 GW.h in energy. (from WSI)
363 GW.h processed as PFAMs
error rate of approximately 0.14%
Using average Pool Price of $61.62 that’s
$22,368,060
(does not include all amounts re-settled in 2002 through the
mandated “Final Final” settlement run)
If we do nothing
• continued large errors and adjustments to retailers
• inaccurate zone totals leading to inaccurate load
settlement (e.g. NSLS shape for zone is incorrect)
• inaccurate zone totals leading to inaccurate
transmission loss allocations
• loss of confidence in settlement process and results
• inefficient processes in industry
• increased retailer risk
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Definition
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• “system level” is hourly values for
distribution interchange, distributed
generation, and border customer
consumption that are needed to describe the
total hourly energy flow on the AIES at the
transmission level and the inputs and outputs
to each and every distribution settlement
zone for each hour.
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System Level PFAM issues:
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Gathers small errors over a long period
Long lag time
No site level detail in final outcome
Coordination with RDS regulation is an issue
Impact not manageable
Undermines market confidence
Causes and consequences of these kinds of
errors affect different parties
• Was intended for occasional use only
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Recommendations
Objectives:
– Reduce the number of errors made in the
future through improved processes,
controls, and testing procedures, and
– Identify and correct errors prior to Final
Settlement.
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SZAWG did not exhaustively test or vet these across industry as a whole, and
expects implementing agencies will gather broader stakeholder feedback
on the Final Report.
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Business Elements
Metering
Accountability
Logical Layer
(modeled reality)
M–1 Testing of
Metering
Priority: A
Impact: Highest
P–1 Roles &
responsibilities
for metering
Priority: A
Impact: Highest
L–1 Energy flow into the
transmission system due to
large DG
Priority: A
Impact: Highest
D–1 Meter Data Controls
Priority: B
Impact: Highest
R–1 Provincial
Reconciliation
Priority: A
Impact: Highest
M–2 Metering
Inventory
Priority: B
P–2 MSS
integration with
SSC
Priority: A
Impact: Highest
L–2 Verifying MPDR
Calculations
Priority: A
D–2 VEE
Priority: B
R–2 Report Card
Priority: B
M–3 Interval
Meter
Thresholds
Priority: D
P–3 MDM
Relationship
with Meter and
MPDR
Priority: A
L–3 MPDR Development
Process
Priority: B
D–3 DST Conversion
Standard
Priority: B
R–3 Non–Load
Settlement Meter
Points
Priority: D
P–4 Settlement
Responsibility
Priority: A
L–4 Temporary Operating
Situations
Priority: C
D–4 Data Restatement
Tracking
Priority: C
P–5 MPDR
Definition
Priority: B
L–5 Notification of ISD–to–
Wire Owner connectivity
changes
Priority: C
D–5 TAA sign
conventions
Priority: C
P–6 Post Final
Processing
Obligations
Priority: B
L–6 Disallowing Backdating
Business Arrangements
Priority D
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Data Improvements
Reporting and Market
Confidence
Metering
M–1 Testing
of
Metering
Implement standardized end-to-end
testing of metering systems on a
defined and regular basis.
AESO testing
EUB rules
M–2 Metering
Inventory
Compile and maintain a complete
inventory of all System Level
Metering points.
AESO
M–3 Interval
Establish thresholds at which
Meter
interval meters are required for
Thresholds
System Level Metering Points.
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EUB
Accountability
P–1 Roles & responsibilities
for metering
Amend the EUA to identify and assign all of the
responsibilities for metering.
DOE
P–2 MSS integration with
SSC
Rationalize the SSC and the MSS to cover all
System Level Metering Points.
EUB
P–3 MDM Relationship with
a Meter and MPDR
Amend the SSC to address the relationships
among MDMs, meters and MPDRs.
EUB
P–4 Settlement
Responsibility
Amend the SSC to clearly and uniquely assign
load settlement responsibility.
EUB
P–5 MPDR Definition
Amend the SSC to adopt the MPDRs disciplines
for Load Settlement.
EUB
P–6 Post Final Processing
Obligations
Amend the SSC to require MDM’s to report all
system level data variances by way of the
PFAM process.
EUB
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Logical Layer
L–1 Energy flow into the
transmission system
due to large DG
Develop a standardized solution for the accommodation of flow into the
transmission system due to large Distributed Generation
EUB
L–2 MPDR Calculation
Verification
Develop a process that will verify that MPDR calculations are being
performed correctly by MDMs.
AESO
L – 3 MPDR Development
Process
Implement an approval process for any MPDR used in load settlement
that includes review and acceptance by LSA, MDM, and AESO.
EUB
L–4 Temporary Operating
Situations
Amend the rules for load settlement to ensure that energy flow during
temporary operating situations are accounted for.
EUB
L–5 Notification of ISD-toWire Owner
connectivity changes
Require Wires Owners and ISDs to notify the AESO of any changes
regarding connectivity of ISDs to Wire Owners.
EUB
L–6 Disallowing
Backdating Business
Arrangements
Adopt an AESO policy that states that business arrangements that
impact measurement point data provision are not to be backdated
prior to the 1st of the current month.
AESO
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Data Improvements
D–1 Meter Data
Controls
Ensure that automated data controls are put in place to confirm
that meter data sent by the MDM to other parties is
received correctly, to the satisfaction of both the MDM and
the receiving parties.
EUB
D–2 Validation,
Editing and
Estimating
Establish a working group to improve VEE standards.
EUB
D–3 Daylight
Savings Time
(DST)
Conversion
Standard
Clarify Settlement System Code to address the differing
interpretations of the existing wording on DST.
EUB
D–4 Data
Restatement
Tracking
The process for submitting restated system level data after the
initial monthly settlement runs to be enhanced to permit the
gathering of metrics.
EUB
D–5 TAA sign
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Amend TAA adjustments in the SSC to clarify sign conventions EUB
and to make s B.6.6.1 and s B 6.6.3 consistent.
Reporting and Market
Confidence
R–1 Provincial
Reconciliation
Review and improve Provincial Reconciliation.
AESO
R–2 Report Card
Develop comprehensive market reporting of load
settlement indicators.
AESO
R-3 Non-Load
Settlement Meter
Points
Review the processes and standards for system
level metering and data not involved in load
settlement.
AESO
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Other Issues
Micro-Generation
Discussion includes related issues and input for
DOE policy development
DOE
Status Report
Develop a process to keep industry informed of
progress on recommendations
EUB
AESO
DOE
Audit Field
DSM transaction needs audit tracking field
EUB
MPDR Process
Same MPDRs to be used in LS and in TA
functions
EUB
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Conclusion
• These recommendations will:
– reduce error overall,
– catch most remaining errors prior to Final
Settlement
– reduce PFAM to occasional use – as was
intended.
• No reason, from SZAWG point of view, to
continue the PFAM suspension.
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– Things will get better gradually as
recommendations are implemented
Next Steps
• Written feedback to be provided by
October 19, 2006 to:
– [email protected]
– [email protected]
– [email protected]
• Implementing agencies to
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– accept recommendations,
– establish a plan to implement, and
– develop a process to measure and report progress.