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Validation of Generation Meter Data in
MV-90 xi
Patrick Vinton Supervisor, Meter Data Acquisition &
Renewable Energy Credit Trading Programs
Itron Utility Week
October, 2013
2 Itron Utility Week - October 2013
AGENDA
• ERCOT Overview
• Metering in the ERCOT Market
• EPS Meter Data Collection
• Validation Requirements
• Meter Events – Important?
• Specific Validation Examples
• Results of Validation Checks
• Reference Information
• Questions?
4
ERCOT Timeline
Itron Utility Week - October 2013
History of the Electric Reliability Council of Texas (ERCOT)
• 1941 – Utilities band together to aid war effort
• 1970 – Texas Interconnected System (TIS) forms ERCOT to comply with
North American Electric Reliability (NERC) requirements
• 1981 – ERCOT assumes central operating coordinator role
• 1995 – Texas legislature votes to deregulate wholesale generation
• 1996 – ERCOT becomes first Independent System Operator (ISO) in US
• 1999 – Legislature votes to deregulate retail electric market
• 2001 – Ten control centers merged into one control center
• 2002 – Retail electric market opens, enabling customer choice for 6.1 million
• 2010 – ERCOT implements Nodal Markets
• 2012 – ERCOT has about 600 employees and an annual budget of about
$170 million
5
ERCOT Quick Facts
Itron Utility Week - October 2013
• Market size: about $34 billion
• All generation data is collected and processed using
MV-90 xi
• ERCOT covers 75% of Texas land
• ERCOT handles 85% of Texas load (23 million consumers)
• More than 40,500 miles of transmission lines
• 550+ generation units (more than 74,000 MWs of capacity)
• Peak Demand in ERCOT was set on August 3, 2011 at 68,305
MWs
• Physical assets are owned by transmission providers and
generators, including Municipal Utilities and Cooperatives
6
ERCOT Quick Facts
Itron Utility Week - October 2013
Responsibilities:
The Texas Legislature restructured the Texas electric market in
1999 by unbundling the investor-owned utilities and creating
retail customer choice in those areas, and assigned ERCOT four
primary responsibilities:
• System reliability – planning and operations
• Open access to transmission
• Retail switching process for customer choice
• Wholesale market settlement for electricity production and
delivery.
7
The Texas Competitive Model
Itron Utility Week - October 2013
Generation T&D (“Wires”) End Users
REP
Retailers
REP
Competitive Production Regulated Open Access Competitive Sales
8
ERCOT is one of 10 North American ISOs/RTOs
Itron Utility Week - October 2013
ISOs/RTOs serve 67% of U.S. population with the goal of providing:
• Reliability
• Efficiency
• Transparency
• Impartiality
ERCOT connections to other grids are limited to direct
current (DC) ties, which allow control over flow of electricity.
11
ERCOT Polled Settlement (EPS) Meter
• Generation metering points
– Transmission Connected
– Distribution Connected (optional)
• Non-Opt-in-Entity (NOIE) metering points
– Bi-directional
– Radial point (optional)
Meter Types
Itron Utility Week - October 2013
TDSP Metered & Read
• Distribution Connected Generation (can be EPS)
• Radial NOIE Metering point (can be EPS)
• Competitive Loads
12
• TDSP Approves Meter Type, as long as it
conforms with;
– ERCOT Protocols
– Applicable ANSI Standards
– Settlement Metering Operating Guide (SMOG)
EPS Meters
Itron Utility Week - October 2013
• Back-up Meters
– Required (with a couple minor exceptions)
– Same or different manufacturer/type/model
14
1250 meters with 19 Different Utilities
EPS Meter Data Collection
Itron Utility Week - October 2013
– Austin Energy
– AEP-Central
– AEP-West Texas
– Brazos Electric
– Big Country Co-op
– Bryan Texas Utilities
– College Station Utilities
– City Public Service San Antonio
– Denton Municipal Electric
– Garland Electric
– Greenville Electric Utility System
– Lower Colorado River Authority
– Brownsville Public Utilities
– CenterPoint Energy
– Sharyland Electric
– South Texas Electric Co-op
– Texas Municipal Power Authority
– Texas-New Mexico Power Co
– Oncor
15
• Performed DAILY by ERCOT
– 7 days a week (yes, weekends AND holidays!)
• Validation, Editing and Estimation (VEE)
– ERCOT Protocols
– Settlement Metering Operating Guide
– Uniform Business Practices (UBP)
• 19 TDSP’s must assist ERCOT in repairing metering
issues and correcting missing or bad data
EPS Meter Data Collection – continued
Itron Utility Week - October 2013
17
Why do Extensive Validation of your Meter Data?
Validation, Editing & Estimation (VEE)
Itron Utility Week - October 2013
18
• Per ERCOT Protocols Section 11.1.4, the validation
process will include, but not be limited to, the
following tests:
– Flagging of intervals with missing data;
– Exception reporting if the total number of zero values for any
channel exceeds the tolerance limit;
– Exception reporting if the total number of power outage intervals
exceeds the tolerance limit;
– Channel level exception reporting if any single interval breaches the
upper or lower threshold of the limit;
– Channel level validation of the percent change between two
consecutive intervals being greater than the established tolerance
limit;
Validation, Editing & Estimation (VEE)
Itron Utility Week - October 2013
19
• Per ERCOT Protocols Section 11.1.4, the validation
process will include, but not be limited to, the
following tests:
– Data overlap validation test, which rejects validations when the
current interrogation of data overlaps data previously collected;
– Channel level energy tolerance test, which reports exceptions of
total energy accumulated from the interval data not being equivalent
to the energy calculated from the meter register’s start and stop
readings;
– Validation that the number of expected intervals equals the number
of actual intervals collected during the interrogation process; and
– Validation of data between primary, backup and check meters
where available.
Validation, Editing & Estimation (VEE) – continued
Itron Utility Week - October 2013
20
• What check in MV-90 xi is this?
– Flagging of intervals with missing data;
• Missing data
– Exception reporting if the total number of zero values for any channel
exceeds the tolerance limit;
• Zero Interval Tolerance
– Exception reporting if the total number of power outage intervals exceeds
the tolerance limit;
• Power Outage Interval Tolerance
– Channel level exception reporting if any single interval breaches the upper
or lower threshold of the limit;
• High/Low Limit (Demand)
– Channel level validation of the percent change between two consecutive
intervals being greater than the established tolerance limit;
• Interval Percent (%) Change
Validation, Editing & Estimation (VEE) – continued
Itron Utility Week - October 2013
21
• What check in MV-90 xi is this?
– Data overlap validation test, which rejects validations when the current
interrogation of data overlaps data previously collected;
• Data overlap
– Channel level energy tolerance test, which reports exceptions of total
energy accumulated from the interval data not being equivalent to the
energy calculated from the meter register’s start and stop readings;
• Usage/Energy Tolerance
– Validation that the number of expected intervals equals the number of
actual intervals collected during the interrogation process;
• Interval Tolerance
– Validation of data between primary, backup and check meters where
available.
• Redundant Channel Tolerance
Validation, Editing & Estimation (VEE) – continued
Itron Utility Week - October 2013
23
• AC Power Down
• AC Power Up
• Power Outage (Pulse Status
Report)
• Lapse in Data (Pulse Status
Report)
• Battery Failure
• Start of Test Mode
• End of Test Mode
• RAM Buffer Overflow
• Watchdog Timer Error/Reset
• Time Tolerances
Events in Support of Validating Data
Itron Utility Week - October 2013
• The following events are also reviewed
by the MV-90 xi Operator;
• Phase Drop-out
• Phase Failure
• Phase Angle Limit
• Phase Restoration
• Potential A Inactive
• Potential B Inactive
• Potential C Inactive
• D80 Interval Errors (fatal errors
on ION meters)
25
Zero Interval Tolerance
Itron Utility Week - October 2013
• Used to Detect the following;
– When the number of intervals containing a value of
zero exceeds a defined number
• Base Load units generally should not have any zero
intervals
• Non-Base Load units can have zero values and the
tolerance value will be unit specific
26
Zero Interval Tolerance – continued
Itron Utility Week - October 2013
• GOOD for;
– Base Load Units
• Nuclear Plants
• Coal Plants
• Any unit with an excepted steady energy curve
• NOT GOOD for;
– Peaker Units
– Pumping/Switching Units
– Weather Sensitive Units (wind, solar, etc)
• Defined in Channel Master File
27
Zero Interval Tolerance – continued
Itron Utility Week - October 2013
Which meter is a good candidate for this check?
28
High/Low Limit (Demand)
Itron Utility Week - October 2013
• Monitors an Interval’s Maximum and Minimum value
– Ensures equipment in metering circuit is not being
overloaded or exceeding circuit’s design capacity
– Catches erroneous spikes/dips in data
– Identify energy flow on a line that should not have energy
flow
• Defined in Channel Master File
29
High/Low Limit (Demand) – continued
Itron Utility Week - October 2013
• Interval Max: Max Capacity of Metering Point +10%
• Interval Min: Depends on unit type, i.e., Base Load
units may be set to fail if the interval value drops below
75% of previous 3 years average value.
– Non-Base Load Units may not use this check.
30
High/Low Limit (Demand) – continued
Itron Utility Week - October 2013
• Interval Max: Max Capacity of Metering Point +10%,
i.e.,
– 850MW Unit = 935MW (850+85=935)
31
High/Low Limit (Demand) – continued
Itron Utility Week - October 2013
• Interval Min: Depends on unit type, i.e., Base Load units
may be set to fail if the interval value drops below 75% of
previous 3 years average value.
– Is unit specific
– Non-Base Load Units may not use this check if the unit regularly
drops to zero
• For this unit, anything below 1200MW is set to fail validation
32
Interval Percent (%) Change
Itron Utility Week - October 2013
• Used to Detect the following;
– Ramp rate exceeds specifications
• Nuclear & Coal Plants generally have slower ramp
rates than Gas or Weather-Sensitive Units
– Loss of Phase (LOP) or Transformer
• Balanced circuits would see a 33% drop
– Setting this tolerance to 25% would catch a LOP or
a loss of a Current Transformer
33
Interval Percent (%) Change – continued
Itron Utility Week - October 2013
• GOOD for;
– Base Load Units
• Nuclear Plants
• Coal Plants
• Any Relatively Steady Energy Curve
• NOT GOOD for;
– Peaker Units
– Pumping/Switching Units
– Weather Sensitive Units (wind, solar, etc)
• Defined in Channel Master File
34
Interval Percent (%) Change – continued
Itron Utility Week - October 2013
Which meter is a good candidate for this check?
35
Redundant Channel Tolerance
Itron Utility Week - October 2013
• Compares, on an Interval-by-Interval basis, the KW
(demand) values between a “PRIMARY” meter and the
designated “BACKUP” meter that shares the same
electrical connection
• Ensures a backup data source where data is deemed
financially critical, such as;
– Grid-Level Monitoring
– Generators
– Inter-Tie Points
• Helps identify meter problems at “critical” points in the Utility Grid
36
Redundant Channel Tolerance - continued
Itron Utility Week - October 2013
There are two (2) options in MV-90 xi
–“Absolute Difference”
–“Channel Tolerance %”
37
Redundant Channel Tolerance - continued
Itron Utility Week - October 2013
• “Absolute Difference” Option
– ERCOT uses this option when comparing interval data between 2 meters
– Absolute Difference is in KW
• This is the ‘Absolute Difference’ the 2 meters can differ
on an interval-by-interval basis and still pass Validation
• Defined in Channel Master File
39
Redundant Channel Tolerance - continued
Itron Utility Week - October 2013
• Factors ERCOT uses to determine “Absolute
Difference” value:
– Meter Point Capacity
– Meter Uncertainties
– Allowable Time Drift between meters
– Transformer Uncertainties (PT’s and CT’s)
• Meter Point Capacity x (meter uncertainties + allowable time drift between meters + PT uncertainty + CT uncertainty) – PT and CT uncertainties can be ignored if BOTH
meters share the same transformers as any error will effect both meters in the same direction
40
Redundant Channel Tolerance - continued
Itron Utility Week - October 2013
• Example:
– Meter Point Capacity = 850 MW
– Meter Uncertainties = 0.15% (per meter)
– Allowable Time Drift = 1% of Interval Length (9 seconds per meter)
– Transformer Uncertainties = N/A as they are shared
850 x (0.3% + 2% + N/A) =
850 x 2.3% = 19.55 MW (19,550 KW)
• For this meter point, the meters can differ up to 19.55MW and meet all accuracy requirements
As MV-90 xi is in KW, the value entered in the channel master file would be 19550
41
Redundant Channel Tolerance - continued
Itron Utility Week - October 2013
For this meter point, the meters can differ up to 19.55MW and meet all accuracy requirements
But the actual difference is 24.1MW, thereby failing the redundant validation check
42
Redundant Channel Tolerance - continued
Itron Utility Week - October 2013
• “Channel Tolerance %” Option
– This option is used when comparing channels
within the SAME meter to identify issues such as
a loss of a current transformer, i.e.,
• If current channels are programmed in meter
channels 5-7, compare Chan 5 to Chan 6, Chan 6
to Chan 7
– Using 25% would catch a loss of a current
transformer or a meter issue
• Defined in Channel Master File
43
Redundant Channel Tolerance (Helpful Hints)
Itron Utility Week - October 2013
• The “Channel Tolerance %” method does not work well
on pulse meters when the pulses per interval are low • Example: tolerance set to +/-5%. If one meter has 10
pulses and another meter has 9 pulses, there is a 10%
difference and the validation check fails
• IF Possible, use the same meter type for the Backup
meter and program it the SAME as the Primary meter
• Editing: do not have to scale data because of different
multipliers when editing/copying from one to the other
• Set “Call Time” in Backup Meter’s Master File to dial
BEFORE the Primary Meter
• If Primary dials first, the Redundant Check will fail as
there is no Backup meter data to compare to.
44
Results of Validation Checks
Itron Utility Week - October 2013
•EPS Meter Data is the Baseline data in which the ERCOT
Market settles
•All “Load” Data is matched to Generation Data
•Key Performance Indicator (KPI) requirement is that >99.5%
of EPS Meter Data remain unchanged after the settlement
process occurs
•Tracked by Quarter and YTD
•2012 Year-End – 99.89200%
•For 2013;
•1St Qtr 2013 – 99.95381%
•2nd Qtr 2013 – 99.99944%
•3rd Qtr 2013 – 99.99955%
•YTD 2013 – 99.98446%
45
• EPS Metering Protocols
• http://www.ercot.com/mktrules/nprotocols/current
–Section 10 & 11
• Settlement Metering Operating Guide (SMOG)
– http://www.ercot.com/mktrules/guides/settlement/smog
• Metering Documentation/Forms
– http://www.ercot.com/mktinfo/metering/eps/index
Reference Information
Itron Utility Week - October 2013