Transcript No Slide Title

Measurement Error Correction (MEC)
 Voltage transformers (VTs) and current transformers (CTs) that do
not meet the 0.3 Accuracy Class of IEEE Std C57.13 Standard
Requirements for Instrument Transformers¹;
 ¹A Measurement Error Correction will not be applied to VTs
and CTs with accuracy's greater than 0.3 ANSI accuracy class
until May 1, 2006. After May 1, 2006 a Measurement Error
Correction equal to the ANSI accuracy class will be applied for
each individual set of VTs and CTs. For example, VTs with a
0.6 ANSI and CTs with a 0.6 ANSI with give a Measurement
Error Correction equal to 1.12 and the correction will always
be in favour of the Market.
Measurement Error Correction (MEC)-continued
• For FCFkVAR the cosine function in the
FCFkW are replaced by the sine function².
– ²At this time all MEC for Reactive Power
kVAR is not used in the IMO system and
therefore, maybe omitted.
PROCEDURE
PUBLIC
MDP_PRO_0010
Market Manual 3: Metering
Part 3.4: Measurement
Error Correction
Issue 5.1
This document provides guidance to metering
service providers on how to calculate and submit
Measurement Error Correction (MEC) to the IMO.
Public
Measurement Error Correction Register
Please complete this form for each facility. This form and accompanying documents may be
submitted by mail, courier, or fax.
Mail this form and accompanying documents to:
Independent Electricity Market Operator
Attention: Wholesale Metering Group
Station A, P.O. Box 4474
Toronto, ON M5W 4E5
Courier this form and accompanying documents to:
Independent Electricity Market Operator
Attention: Wholesale Metering Group
655 Bay Street, Suite 410
Toronto, ON M5G 2K4
Fax this form and accompanying documents to:
Fax No.: (905) 855-8688
Attention: Wholesale Metering Group
All information submitted in this process will be used by the IMO solely in support of its obligations
under the Electricity Act, 1998, the Ontario Energy Board Act, 1998, the market rules and associated
policies, standards and procedures and its licence. All submitted information will be assigned the
appropriate confidentiality level upon receipt.
Terms and acronyms used in this Form that are italicized have the meanings ascribed thereto in
Chapter 11 of the market rules.
PART 1 – GENERAL INFORMATION
Metering Service Provider (MSP)
MSP Name:
MSP No.:
Prepared By:
Date Submitted (Y/M/D):
Meter Point Information
Rated Burden
*Defined Meter Point ID:
PT and CT operating within rated Burden
Meter Point ID No.:
* As listed in PLC
Type YES to confirm
PART 4 – CORRECTION FACTORS
Cable Correction Factors
Red Phase
Correction Factor (CLCF1)
Phase Angle (c1) in minutes
Yellow Phase
Correction Factor (CLCF2)
Phase Angle (c2) in minutes
Blue Phase
Correction Factor (CLCF3)
Phase Angle (c3) in minutes
IMO-Defined Correction Factors
Average Cable Loss Correction Factor (CLCF)
Average Ratio Correction Factor VT (RCF E)
Average Ratio Correction Factor CT (RCF I)
Combined Ratio Correction Factor (RCF K)
Combined Phase Angle Correction Factor (PACF K)
Final Correction Factor Active Power (FCFkW)
Final Correction Factor Reactive Power (FCFkVar)
Other Correction Factors
Non-Blondel Final Correction Factor - Active Power
(FCFkW Non-Blondel)
Non-Blondel Final Correction Factor - Reactive Power
(FCFkVarNon-Blondel)
VT/CT Separation Final Correction Factor - Active Power
(FCFkW VT/CT Separation)
VT/CT Separation Final Correction Factor - Reactive
Power (FCFkVar VT/CT Separation)
MEC1 Final Correction Factor - Active Power
(FCFkWMEC1)
MEC1 Final Correction Factor - Reactive Power
(FCFkVarMEC1)
Market Rules--Chapter Six
4.2.2 The IMO shall permit a metering
installation to be registered in respect of a
facility notwithstanding that the meter point
is not located at the defined meter point
provided that all transfers of energy at any
points of supply or consumption for the
facility to which the metering installation
relates are separately metered in a manner
satisfactory to the IMO.
Satisfactory to the IMO
• All consumption must be metered
• losses must be applied correctly as per market
rules
– radial line losses
• express feeders, no taps
– transformation losses
– total loss factor (TLF)
• embedded, therefore must have a primary RWM
meter
• MMP’s area of responsibility does not change
DMP
IMO Grid
DP 210350
DP 210465
J BUS
T3
TO
MMP 1
DMP = Bay-230.T3
M
Bay TS
SS2
TO MMP
2
M
F2
Pole1
Pole2
MMP2 boundary
Polenn
F1
DMP-continued
IMO Grid
DP 210350
DP 210465
J BUS
T3
TO
MMP 1
DMP = Bay-230.T3
M
Bay TS
SS2
F2
Pole1
Pole2
MMP2 boundary
Polenn
M
F1
DMP-continued
IMO Grid
DP 210350
DP 210465
DMP = Bay-230.T3
J BUS
T3
Bay TS
SS2
F2
F1
Pole1
Pole2
MMP2 boundary
M
Polenn
M
Pole1
Pole2
TO
MMP 1