STANDARDS
PUBLIC
MDP_STD_0002
Validating, Estimating
and Editing
Standards for Validating, Estimating
and Editing of Revenue Metering Data
in the IMO-Administered Market
Issue 3.0
This standard provides the principles,
accountabilities, and requirements for validation of
revenue metering data.
Public
Disclaimer
The posting of documents on this Web site is done for the convenience of market participants and
other interested visitors to the IMO Web site. Please be advised that, while the IMO attempts to have
all posted documents conform to the original, changes can result from the original, including changes
resulting from the programs used to format the documents for posting on the Web site as well as from
the programs used by the viewer to download and read the documents. The IMO makes no
representation or warranty, express or implied, that the documents on this Web site are exact
reproductions of the original documents listed. In addition, the documents and information posted on
this Web site are subject to change. The IMO may revise, withdraw or make final these materials at
any time at its sole discretion without further notice. It is solely your responsibility to ensure that you
are using up-to-date documents and information.
This document may contain a summary of a particular market rule. Where provided, the summary has
been used because of the length of the market rule itself. The reader should be aware, however, that
where a market rule is applicable, the obligation that needs to be met is as stated in the “Market
Rules”. To the extent of any discrepancy or inconsistency between the provisions of a particular
market rule and the summary, the provision of the market rule shall govern.
Document ID
MDP_STD_0002
Document Name
Validating, Estimating and Editing
Issue
Issue 3.0
Reason for Issue
Release for Baseline 11.1
Effective Date
June 2, 2004
Validating, Estimating and Editing
Document Change History
Document Change History
Issue
Reason for Issue
Date
1.0
Unapproved version released for Baseline
January 8, 2001
2.0
Release for Baseline 7.0
January 22, 2002
3.0
Release for Baseline 11.1
June 2, 2004
Related Documents
Document ID
Document Title
MM 3.2
Meter Point Registration and Maintenance
MDP_STD_0004
Wholesale Revenue Metering Standard - Hardware
Issue 3.0 – June 2, 2004
Public
Document Control
MDP_STD_0002
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
Table of Contents
Table of Contents
Table of Contents...................................................................................................... i
List of Figures .......................................................................................................... ii
List of Tables ........................................................................................................... iii
Table of Changes .................................................................................................... iv
1.
Introduction ...................................................................................................... 1
1.1
Scope ...................................................................................................... 1
1.2
Who Should Use This Document ............................................................. 1
1.3
Conventions ............................................................................................. 1
2.
Validation .......................................................................................................... 3
2.1
Overview .................................................................................................. 3
2.2
Validation Requirements for Main/Alternate Metering.............................. 4
2.2.1
2.2.2
2.3
2.4
2.5
3.
Data from the Main Meter....................................................................... 4
Data from the Alternate Meter ................................................................ 5
Tests Required ........................................................................................ 5
Validation Requirements for Check Metering .......................................... 7
Validation Requirement for Stand Alone Metering ................................... 8
Estimating ....................................................................................................... 11
3.1
Main/Alternate Metering ......................................................................... 11
3.2
Check Metering...................................................................................... 11
3.3
Stand Alone Metering ............................................................................ 12
3.3.1
3.3.2
Gaps One Hour or Less ....................................................................... 12
Gaps Over One Hour ........................................................................... 12
4.
Editing ............................................................................................................. 13
4.1
Background ........................................................................................... 13
4.2
Main Data Is Correct .............................................................................. 13
4.3
Failure Limited to Main Meter Only ........................................................ 13
4.4
No Reliable Data Available .................................................................... 13
5.
Glossary of Terms .......................................................................................... 15
References ............................................................................................................... 1
Issue 3.0 – June 2, 2004
Public
i
List of Figures
MDP_STD_0002
List of Figures
None
ii
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
List of Tables
List of Tables
Table 2.1: Data Channels for Main Meters ............................................................................ 4
Table 2.2: Data Channels for Alternate Meters ...................................................................... 5
Table 2.3: Data Channel Requirements for Check Meters ..................................................... 8
Issue 3.0 – June 2, 2004
Public
iii
Table of Changes
MDP_STD_0002
Table of Changes
Reference
(Section and
Paragraph)
Description of Change
Section 2.2.1
Add channels 11 to 16 or channels 9 to 16 must be set to unconnected
Section 2.2
Add channels 5 to 16 must be set to unconnected
Deleted table 2.3
Section 2.3
Energy Comparison was revised to separate predefined limits for conforming
meters and non-conforming meters.
Voltage Check was redefined
Current Check was redefined
Combination of Voltage and Current Check was redefined
Time Tolerance was redefined
Section 5.0
Defined main, alternate, standalone meters
Defined non-conforming meter
iv
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
1. Introduction
1. Introduction
Revenue metering data shall be checked for reasonableness by the IMO before being passed on to the
settlement system.
If the data does not satisfy preset validation criteria, a trouble call shall be issued to resolve any
potential measurement problems and estimated data shall be provisionally substituted for the suspect
data until the trouble call is resolved. The estimate shall be prepared by a combination of manual and
automated software systems.
If resolution of the trouble call confirms a problem with the revenue metering, the estimated data shall
be edited as required then passed on to the rest of the settlement process.
If the revenue metering data is confirmed to be correct, the estimate shall be manually undone. On
other occasions the data may have to be manually adjusted for other reasons.
1.1
Scope
This document applies to revenue metering data collected by the IMO’s MV90/Star data collection
system for use in settlement of wholesale transactions in the IMO-administered market.
1.2
Who Should Use This Document
This document presents essential information for use by metering service providers, metered market
participants, and staff designing and testing IMO processes and software.
1.3
Conventions
The following conventions are used throughout this document:

The word “shall” denotes a mandatory requirement.

Italics is used to indicate titles of acts or publications.
– End of Section –
Issue 3.0 – June 2, 2004
Public
1
1. Introduction
2
MDP_STD_0002
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
2. Validation
2. Validation
2.1
Overview
The validation software must be able to handle three types of metering installation:
1.
Main/Alternate
2.
Main/Check
3.
Stand Alone
Only conforming meters make up a Main/Alternate, Main/Check and Stand Alone metering
installations.
Non-conforming meters make up a Non-conforming Main/Alternate, Non-conforming Main/Check
and Non-conforming Standalone metering installations.
The main meter in any of these installations transmits the data to be validated. There are two general
methodologies for validating the main data:
1.
Comparing it to another meter measuring the same power flow; or
2.
Comparing it to data previously gathered from the main. Data previously gathered from
the main is often referred to as historical data.
Data from the alternate meter in a main/alternate installation is of revenue quality and can be
substituted for the main meter data without legal implications. Because the two meters measure the
same power flow, and the loss between the installations is essentially zero, direct comparison to
alternate data provides the strongest possible assurance that the main data is correct.
Substitution of data from the alternate for the main is revenue quality. The system will record the
source of the data as redundant until the meter trouble report process resolves the cause of validation
failure.
Comparing the main data to data from the check meter provides an alternative, although less rigorous,
test. The check data is not of revenue quality and some electrical loss between the main and check
meters may occur. The check data must be adjusted for the difference.
Use of check data for settlement is permitted only when the main meter in a main/check or nonstandalone installation has failed. The use of check metering data must be recorded as an estimate
prepared from a non-revenue-approved source. The cumulative total amount of all estimates from
non-revenue metering is one of several important measures indicating how well the metering system
is performing.
The IMO shall limit comparison checks to two meters. If both alternate and check meters are
installed, the installation is defined as main/alternate and the IMO shall collect data from the
alternate only.
In stand alone installations, no alternate or check data exists. The validation criteria are based on the
historical load pattern and alarms from the stand-alone meter.
For stand-alone installations, the metered market participant shall specify the criteria for some
validation tests. The metered market participant shall select the actual test criteria from the list of
options provided in the following sections and shall notify the IMO of the chosen process at the time
Issue 3.0 – June 2, 2004
Public
3
2. Validation
MDP_STD_0002
of registration. The default values specified below are based on operating experience and may be used
if the metered market participant has not specified test criteria.
Some validation criteria, deemed essential by the IMO, shall be mandatory. Trigger values for these
criteria may also be set by the IMO.
The above also applies to Non-conforming Main/Alternate, Non-conforming Main/Check and Nonconforming Stand Alone metering installations.
2.2
Validation Requirements for Main/Alternate
Metering
2.2.1
Data from the Main Meter
Main meters will provide the following data channels:
Interval Data
Normal Channel
1.
kWh delivered
1
2.
kVARh delivered
2
3.
kWh received
3
4.
kVARh received
4
5.
V2h per phase
5, 6, 7
6.
I2 h per phase
8, 9, 10
7.
Energy (Encorder) self reads for channels 1, 2, 3,
and 4
Does not use a
channel
8.
Error messages from the event log, normally hex
codes as returned by the TIM file
Does not use a
channel
Table 2.1: Data Channels for Main Meters
The channel numbers shown shall be the assignment for the wholesale market.
Meters installed in delta power systems may have two current transformers and two voltage
transformers instead of three as shown above. In this case, channel 5 and channel 6 is V2h per phase
and channel 7 and channel 8 is I2 h per phase.
Since MV90 has the capability to record up to 16 channels, channels 11 to 16 for a three element
meter or channels 9 to 16 for a two element meter shall be set to unconnected (code 42) and flagged
to omitted on upload.
4
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
2.2.2
2. Validation
Data from the Alternate Meter
Alternate meters will provide the following data channels:
Interval Data
Normal Channel
1.
kWh delivered
1
2.
kVARh delivered
2
3.
kWh received
3
4.
kVARh received
4
5
Energy (encoders) self-reads for channels 1, 2, 3,
and 4
Does not use a
channel
6
Error messages from the event log, normally hex
codes as returned by the TIM file
Does not use a
channel
Table 2.2: Data Channels for Alternate Meters
Since MV90 has the capability to record up to 16 channels, channel 5 to 16 must be set to
unconnected (code 42) and flagged to omitted on upload.
For non-conforming meters, channel numbers assignment are preferred but not manadatory.
2.3
Tests Required
The following tests are required for validation of main/alternate meter installations. .
The assignment of channel numbers of Table 2.1 and Table 2.2 ensures the main and alternate meters
carry the same unit of measure and in the same direction of energy flow.
If the assignment of channel numbers for non-comforming main and alternate meters are different
than Table 2.1 and Table 2.2, the IMO should be consulted.1
Energy Comparison in a main/alternate metering installation, for each one hour interval, the value in
channel 1 of the main shall be compared to the value in channel 1 of the alternate. If the difference
exceeds a predefined limit, validation fails and a meter trouble report shall be issued. The process
shall be repeated for channels 2, 3, and 4 of the main. The predefined limit shall be associated with
the main meter. The trigger level shall be changeable by the IMO and shall have a default value of
2% for channels 1 and 3 (kWH Delivered and kWH Received repectively) and a default value of
10% or less for channels 2 and 4 (kVARH Delivered and kVARH Received repectively).
In a non-conforming main/alternate metering installation, for each one hour interval, the value of the
non-conforming main shall be compared to the corresponding value of the alternate. If the difference
exceeds a predefined limit, validation fails and a meter trouble report shall be issued. The process
1
The assignment of channel numbers for a non-conforming main/alternate is much more difficult and
should be discussed with IMO staff prior to implementation.
Issue 3.0 – June 2, 2004
Public
5
2. Validation
MDP_STD_0002
shall be repeated for all kWH channels of the main The predefined limit shall be associated with the
main meter. The trigger level shall be changeable by the IMO and shall have a default value of ±3%
for all kWH channels (Delivered and Received). The kVARH channels are not compared.
Voltage Check
The presence of V2h is performed for each one hour interval on main meters only.
The V2h check consists of three steps(example for a three element meter):
1. All three channels are summed and divided by three to calculate the average V2h value.
2. Validation shall succeed, if the calculated average V2h value is between 17425 (132volts)
and 10000 (100volts). In addition, validation shall succeed if the calculated average V2h
value equals zero. This validation is termed V2Havg.
3.
Each V2h channel (channel 5, 6, 7) is compared to the calculated average V2h value.
Validation for each channel shall succeed, if the value is between  6%. This validation is
termed V2H CHnn.
If the validation fails, a meter trouble report shall be issued indicating that loss of measuring voltage
is suspected.
Meters installed in delta power systems may have two voltage transformers instead of three.. The
voltage check would be carried out on two channels but the process is identical.
Current Check
The presence of I2h is performed for each one hour interval on main meters only.
The current check consists of three steps that are procedurally the same as the voltage check (three
element meter):
1. All three channels are summed and divided by three to calculate the average I2h value.
2. Validation shall succeed, if the calculated average I2h value is less than 56.25 (7.5amps).
This validation is termed I2Havg.
Each I2h channel (channel 8, 9, 10) is compared to the calculated average I2h value.
Validation for each channel shall succeed, if the value is between  50%. This validation is
termed I2H CHnn.
If the validation fails, a meter trouble report shall be issued indicating that loss of measuring current
is suspected.
Meters installed in delta power systems may have two current transformers instead of three. In this
case, the current check would be carried out on two channels but the process is identical.
3.
Combination of Voltage and Current Check
4. The presence of V2h and I2h together is performed for each one hour interval on main
meters only. Validation shall fail, if the calculated average V2h value equals zero and the
calculated average I2h value is greater than zero. This validation is termed I2H V2H.
If the validation fails, a meter trouble report shall be issued indicating that loss of measuring voltage
is suspected.
6
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
2. Validation
Event Log Check
Main Meter: The main meter will return several error messages in the event log or as a channel
status flag. Error messages are collected at the same time as the interval data; however, they may not
require a channel and are not channel data. Messages vary in detail from meter to meter. The event
log shall be checked for error messages that indicate:

a problem with a current transformer;

a problem with a voltage transformer;

a critical problem with the meter, including but not limited to:

pulse count over flow,

hardware reset, and
 parity error.
If any of the above error messages are detected, a meter trouble report shall be issued.
Alternate Meter: If the data is available in the event log of the alternate meter, the test shall be
repeated for the alternate meter.
For non-conforming meters, voltage and current checks are not validated.
Time Tolerance
All registered wholesale revenue meters will be validated for time tolerance. Three possible condition
may occur:
1) The meter is within  5 seconds, a time reset is not performed..
2) The meter is greater than  5 seconds but less than  60 seconds, a time reset is
performed.2
3) Meter is greater than  59 seconds, a meter trouble report is issued..
Other Validation Checks
The metered market participant or the IMO may request other additional checks that are standard in
MV90, as deemed appropriate.
2.4
Validation Requirements for Check Metering
A check-metered installation consists of two meters: a main meter and a check meter. These meters
are supplied from different instrument transformers. The check need not be supplied from instrument
transformers or meters approved by Measurement Canada.
Data from Check Metering
The check meter shall provide active and reactive power channels to match each active or reactive
power channel in the main, and shall have the same interval length.
2
Numerous time resets may indicate a defective meter
Issue 3.0 – June 2, 2004
Public
7
2. Validation
MDP_STD_0002
New check meters shall provide at least the following data channels where reverse power flows may
occur:
Interval Data
Normal Channel
1.
kWh delivered
1
2.
kVARh delivered
2
3.
kWh received
3
4.
kVARh received
4
Table 2.3: Data Channel Requirements for Check Meters
All data from the check meter shall be compatible with automated processing by the IMO’s validation
software.
Tests Required for Check Metering
The following test shall be executed for validation of meter installations using check metering.
Channel numbers provided are examples and assignment in the main and the check must be the
same.
Main Meter: The main meter shall be tested as specified above, except for the energy comparison
test as described next.
Check Meter: The interval data from the check meter channels 1, 2, 3, and 4 shall be compared to
that of the main meter. The test shall fail if the comparison of energy exceeds a predefined limit.
The Market Rules require a mathematical relationship between the main and the check meter. This
relationship will normally be a constant percentage. The initial value of the predefined validation
limit shall be the mathematical relationship multiplied by 1.2.
The limit shall be user changeable on a per-meter basis.
2.5
Validation Requirement for Stand Alone Metering
With stand alone metering (both conforming and non-conforming), no second source of comparison
data exists. Validation must be based on the characteristics of the data at hand. The following list of
checks and criteria shall be considered by the metered market participant for validation of data
collected by the IMO:
Validation Tests for All Metering Installations
The data collection system will carry out the following validation tests on the metering data
immediately following the data collection and delivery processes. These tests, which indicate possible
hardware concerns, will be carried out if supported by the remote end metering hardware and will be
applied to data originating from main, alternate, check and non-conforming meters.
1.
Data Not Collected or Delivered
Validation failure if the data was not collected, or delivered, to the IMO and is termed
missing data.
2.
8
Current and Voltage Check
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
2. Validation
Detects loss of current and or voltage to the meter due to a failure of the supply from
one or more instrument transformers or tampering.
3.
Meter Reading Vs Load Profile Type M
Checks for corruption introduced by the telecom system and checks the meter multiplier
If the meter can provide energy self reads this test is automated (Chapter 6 Section,
7.2.6 of the Market Rules). If the meter does not support energy self reads the Metering
Service Provider provides readings according to Chapter 6 Section, 7.2.5 of the Market
Rules.
4.
Intervals Found Vs Intervals Expected
Calculates the number of intervals expected if meter is replaced.
5.
Time Tolerance
Checks for synchronism of meter clock to EST
6.
Number of Power Outage Intervals
Allows periods of zero primary power to be identified
7.
Missing Intervals
Allows periods of missing data to be identified.
8.
CRC/ROM RAM
Flag generated by the meter indicating failure of the internal electronics
9.
Meter Clock Over Flow
Flag generated by the meter indicating failure of the internal electronics
10.
Hardware Reset
Flag generated by the meter indicating failure of the internal electronics
11.
Time Reset
Indicates the interval in which the meter clock time has been changed by an MV90
system, creating either a shorter or longer interval
12.
Data Overflow on an Interval
Indicates that the meter is creating more pulses than it can record in an interval or
MV90 can accommodate in an interval
13.
Number of Channels
The actual number of data channels from the meter does not match the number expected
at the data collector
14.
Changed Device ID
The internal device identifier does not match the value registered at the data collector
15.
Watch Dog Time Out
Reported by some recorders when a watchdog register is tripped or activated.
16.
Issue 3.0 – June 2, 2004
Parity Error
Public
9
2. Validation
MDP_STD_0002
Determined by a parity error bit that is set by a recorder on a channel of data during
status check or read/write function.
Additional Tests for Stand Alone Metering Installations
Parameters for these validation tests are normally MSP defined, and submitted during registration of
the metering installation.
1.
High/Low Limit on Interval
Specifies maximum and minimum interval demand, which if exceeded results in a
trouble report.
2.
High/Low Limit on Energy
Specifies maximum and minimum energy, which if exceeded over the time period
being validated, results in a trouble report.
3.
Percentage Change on Interval
Flags validation failure if consecutive intervals differ by more than the specified
amount
4.
Load Factor Tolerance
Flags a validation failure when the average load divided by the maximum load over the
time period being validated exceeds the prescribed level
5.
Power Factor Limit
Flags a validation failure when the average power factor over the time period being
validated is less than the specified minimum.
6.
Zero Interval Tolerance
Flags a validation failure of the total number of intervals containing zeroes over the
time period being validated exceeds the tolerance limit.
7.
Power Outage Intervals
Checks for power outage intervals within the data file versus a limit of tolerance
number of occurrences.
Additional Validation Tests for Main/Alternate or Main/Check Metering
Installations
The IMO reserves the right to carry out tests in addition to those selected by the metered market
participant.
– End of Section –
10
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
3. Estimating
3. Estimating
Should validation indicate that data from the main meter might be incorrect, the MV90 software will
automatically prepare a provisional estimate for communication failures and gaps. Data from an
alternate (flagged as redundant) or check (flagged as estimated) would be substituted if that data
passed validation. If no other data is available, or if alternate or check data is also suspect, an estimate
shall be prepared based on the historical load pattern.
3.1
Main/Alternate Metering
When the energy comparison test fails validation, a meter trouble report shall be initiated.
Examination of the alarms registered in the event log of the main meter shall be used to assess
whether failure of the main meter is the most likely cause of the problem. If all tests carried out on the
main do not indicate a problem, no substitution from the alternate to the main shall be carried out.
If, however, a test carried out on the main indicates a problem, data from the alternate shall be
substituted for each of the intervals in which the energy comparison test fails.
If the V2 and I2 data, normally used for site-specific loss adjustments, are unavailable, loss
adjustments shall be computed from the active and reactive demand using assumed voltage, current
and/or power factor as appropriate. These would be applied to the loss coefficients that would
normally be used.
The substituted data may be used in the preliminary price determination and settlement processes.
Any decision to substitute or not substitute data in the final price determination and settlement
procedures shall be based on the results of the meter trouble report investigation.
The above also applies to Non-conforming main/alternate metering.
3.2
Check Metering
When the energy comparison test fails validation, a meter trouble reportc shall be initiated to establish
which of the meters is correct.
If one of the meters has failed and is as likely to be in trouble as the other, examination of the alarms
registered in the event log of the main meter shall be used to assess which meter is healthy.
If all tests carried out on the main do not indicate a failure, there shall be no substitution from the
check to the main. Otherwise, data from the check meter shall first be adjusted by the predefined
mathematical adjustment factor and then substituted for each of the hours in which the energy
comparison test fails.
If the V2 and I2 data, normally used for site-specific loss adjustments, are unavailable, loss
adjustments shall be computed from the active and reactive demand using assumed voltage, current,
and/or power factor as appropriate. These would be applied to the loss coefficients that would
normally be used.
Issue 3.0 – June 2, 2004
Public
11
3. Estimating
3.3
MDP_STD_0002
Stand Alone Metering
Since no other source of data exists, estimating shall be based on historical data.
3.3.1
Gaps One Hour or Less
Active and Reactive Energy
The data in channels 1, 2, 3, and 4 shall be estimated using linear interpolation. A straight line,
joining the demand reading at the beginning of the interval to the demand reading at the end of the
interval, shall be used to estimate the demands in the intervening intervals.
Site-Specific Loss Adjustments
If the loss adjustments for the installation are computed using active and reactive five-minute
demand, the estimated data shall be used to compute the losses.
If the V2 and I2 data normally used for site-specific loss adjustment are unavailable, loss adjustments
shall be computed from the active and reactive demand using appropriate assumptions for voltage,
current and power factor and the loss coefficients that would normally be used.
3.3.2
Gaps Over One Hour
The gap will have a start and stop time and a day type: weekday, weekend, and holiday. The energy
data for the three previous comparable periods (start and stop times and day type match) shall be
compared. The meter requires to have at least three weeks of data.
If the meter has not been installed long enough, three comparable periods may not be found. In this
case, the IMO shall contact the metered market participant for information upon which an estimate
may be based.
If the installation is a load, the maximum energy shall be used as the basis of standard MV90 load
shape scaling.
At generators lacking alternate or check metering, the minimum energy shall be used as the basis of
standard MV90 load shape scaling if the metered market participant can prove that the generator was
in production during the period. Otherwise the estimate shall be zero.
– End of Section –
12
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
4. Editing
4. Editing
4.1
Background
Manual substitution and scaling routines shall be used for editing. Editing may be required when the
meter trouble report process determines the cause and resolution of the problem.
Occasionally a meter installation, even though it is otherwise operating normally, may provide
incorrect data owing to events such as power system switching or application of mobile emergency
generation. Manual editing would then be required to revise the incorrect data.
4.2
Main Data Is Correct
If the main data is found to be correct and the alternate or check metering is found to be faulty, an edit
may be required to undo or the result of an estimate.
4.3
Failure Limited to Main Meter Only
If the main meter has failed in a way that does not affect the alternate or check meters and these are
operating normally, data from the alternate or check shall be used to provide the final settlement data,
using registered adjustment factors.
4.4
No Reliable Data Available
Editing Options
If the data from the main meter is incorrect or unobtainable, and data from the alternate or check
metering data is also incorrect or unobtainable, the metering service provider shall either:
1.
provide an adjustment factor that truly reflects the actual transaction, or
 ask the IMO to prepare an estimate based on historical data.
The submission of an adjustment shall consist of:
1.
a multiplier

an optional additive constant

the specific period to which the adjustment applies
 documentation supporting the adjustment
The IMO shall retain the documentation of the adjustment to support audit requests that may be
initiated by the metered market participant or the IMO.
The adjustment shall be subject to IMO approval and in a format acceptable to the IMO.
Issue 3.0 – June 2, 2004
Public
13
4. Editing
MDP_STD_0002
Problem Repaired
If the metering service provider is able to repair the problem while on site, and chooses to submit an
adjustment, the adjustment shall be based on “as-found” and “as-left” readings.
The adjustment factor shall be confirmed by comparison with an independent measurement made or
available on site, such as panel metering, SCADA, performance metering, cross phase readings taken
from test links supplied by protective relaying instrument transformers, or a primary clip-on ammeter
reading.
Problem Not Yet Repaired
If the problem will be resolved within time lines specified in the Market Rules and data can be still be
obtained from the main, the metering service provider may provide an adjustment factor to be applied
to the metering data collected.
The adjustment factor shall be determined from “as-found” readings, metering theory, and
independent measuring devices on-site.
- End of Section -
14
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
5. Glossary of Terms
5. Glossary of Terms
The following terms are used in this standard:
Alternate meter: A conforming meter as described on the list of conforming meters. In a
main/alternate installation, the Alternate data may be substituted when valid data from the main meter
is unavailable. The term implies full compliance with the requirements of Measurement Canada.
Check metering: As defined in the Market Rules.
Current transformer: As defined in the Market Rules.
Editing: Manually changing the interval data for a particular revenue meter.
Estimating: An automated process for substituting provisional interval data in the place of data that
failed predefined validation criteria.
Main meter: A conforming meter as described on the list of conforming meters .In a main/alternate
installation, the meter used for settlement unless valid data is unavailable.
Non-Conforming meter: A meter that complies with Chapter six-Appendicies, Appendix 6.2,
section 1.1A.1,section 1.4 and sections 1.5. The meters form the non-conforming main/alternate, nonconforming main/check, and non-conforming stand alone metering installations.
Meter installation: As defined in the Market Rules.
Meter: As defined in the Market Rules.
Metered market participant: As defined in the Market Rules.
Standalone metering: A metering installation that has no alternate or check metering such as main
meter. The meter is used for settlement.
Non-Conforming Standalone metering: A metering installation that has no alternate or check
metering such a non-conforming meter. The meter is used for settlement.
Pulse multiplier: The product of CT Ratio x VT Ratio x Meter KI / 1000.
Main/Alternate metering: The use of two conforming meters as described on the list of conforming
meters measuring power flow at the same point in the power system. The meters may be connected to
the same or different instrument transformers. As described on the conforming list, meters shall be
designated main, the other alternate. If two mains are used, one of the meter is arbitrarily designated
alternate and treated as such.
Non-Conforming Main/Alternate metering: The use of two non-conforming meters measuring
power flow at the same point in the power system. The meters may be connected to the same or
different instrument transformers.
Register multiplier: The product of CT Ratio x VT Ratio x Meter Multiplier.
Registration: The entry of metering information into the IMO data collection system databases after
comprehensive on-site and end-to-end testing to verify remote access to metered data and accurate
replication of meter parameters and measured quantities at the IMO.
Revenue metering: As defined in the Market Rules.
Site-specific loss adjustment: If the actual meter point is not at the defined meter point, the meter
readings shall be adjusted to account for the difference. Application of the loss adjustment results in
the readings that would have been obtained if the meter had been installed at the defined meter point.
Issue 3.0 – June 2, 2004
Public
15
5. Glossary of Terms
MDP_STD_0002
Validation: The automated process of comparing the collected interval data, and its characteristics,
against predefined constant limits and checking the meter’s event log for messages indicating a
problem with the instrument transformers or the meter.
- End of Section -
16
Public
Issue 3.0 – June 2, 2004
Validating, Estimating and Editing
References
References
Document Name
Document ID
Ontario Market Rules Transmitted to the IMO, 15 April 1999
– End of Document –
Issue 3.0 – June 2, 2004
Public
References–1