Schneider Electric Marine Instruments PM810 User Guide

PowerLogic™ Series 800 Power Meter  
PM810, PM820, PM850, & PM870  
User Guide  
63230-500-225A2  
03/2011  
 
TM  
63230-500-225A2  
3/2011  
PowerLogic Series 800 Power Meter  
HAZARD CATEGORIES AND SPECIAL SYMBOLS  
Read these instructions carefully and look at the equipment to become familiar with the  
device before trying to install, operate, service, or maintain it. The following special  
messages may appear throughout this bulletin or on the equipment to warn of potential  
hazards or to call attention to information that clarifies or simplifies a procedure.  
The addition of either symbol to a “Danger” or “Warning” safety label indicates that an  
electrical hazard exists which will result in personal injury if the instructions are not  
followed.  
This is the safety alert symbol. It is used to alert you to potential personal injury hazards.  
Obey all safety messages that follow this symbol to avoid possible injury or death.  
DANGER  
DANGER indicates an imminently hazardous situation which, if not  
avoided, will result in death or serious injury.  
WARNING  
WARNING indicates a potentially hazardous situation which, if not  
avoided, can result in death or serious injury.  
CAUTION  
CAUTION indicates a potentially hazardous situation which, if not  
avoided, can result in minor or moderate injury.  
CAUTION  
CAUTION, used without the safety alert symbol, indicates a potentially  
hazardous situation which, if not avoided, can result in property  
damage.  
NOTE: Provides additional information to clarify or simplify a procedure.  
PLEASE NOTE  
Electrical equipment should be installed, operated, serviced, and maintained only by  
qualified personnel. No responsibility is assumed by Schneider Electric for any  
consequences arising out of the use of this material.  
CLASS A FCC STATEMENT  
This equipment has been tested and found to comply with the limits for a Class A digital  
device, pursuant to part 15 of the FCC Rules. These limits are designed to provide  
reasonable protection against harmful interference when the equipment is operated in a  
commercial environment. This equipment generates, uses, and can radiate radio frequency  
energy and, if not installed and used in accordance with the instruction manual, may cause  
harmful interference to radio communications. Operation of this equipment in a residential  
area is likely to cause harmful interference in which case the user will be required to correct  
the interference at his own expense. This Class A digital apparatus complies with Canadian  
ICES-003.  
© 2011 Schneider Electric. All Rights Reserved.  
iii  
 
TM  
PowerLogic Series 800 Power Meter  
63230-500-225A2  
3/2011  
© 2011 Schneider Electric. All Rights Reserved.  
iv  
 
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Contents  
Contents  
v
© 2011 Schneider Electric. All Rights Reserved.  
 
 
PowerLogicTM Series 800 Power Meter  
Contents  
63230-500-225A2  
3/2011  
Advanced Power Quality Evaluation System Configuration  
and Status Registers [EN50160 and SEMI-F47/ITI (CBEMA)] - - - - - - - - - - - - - - - -99  
Index - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -109  
vi  
© 2011 Schneider Electric. All Rights Reserved.  
 
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 1—Introduction  
Chapter 1—Introduction  
This user guide explains how to operate and configure a PowerLogic Series 800 Power  
Meter. Unless otherwise noted, the information contained in this manual refers to the  
following power meters:  
Power meter with integrated display  
Power meter without a display  
Power meter with a remote display  
numbers. For a list of supported features, see “Features” on page 7.  
NOTE: The power meter units on the PM810, PM810U, and the PM810RD are functionally  
equivalent.  
Topics Not Covered In This Manual  
Some of the power meter’s advanced features, such as on-board data logs and alarm log  
files, can only be set up via the communications link using PowerLogic software. This  
power meter user guide describes these advanced features but does not explain how to set  
them up. For information on using these features, refer to your software’s online help or  
user guide.  
What is a Power Meter?  
A power meter is a multifunction, digital instrumentation, data acquisition and control  
device. It can replace a variety of meters, relays, transducers, and other components. This  
power meter is equipped with RS485 communications for integration into any power  
monitoring/control system and can be installed at multiple locations within a facility.  
These are true rms meters, capable of exceptionally accurate measurement of highly  
non-linear loads. A sophisticated sampling technique enables accurate measurements  
through the 63rd harmonic . You can view over 50 metered values, plus minimum and  
maximum data, either from the display or remotely using software. Table 1–1 summarizes  
the readings available from the power meter.  
Table 1–1: Summary of power meter instrumentation  
Real-time Readings  
Power Analysis  
Current (per phase, residual, 3-Phase)  
Voltage (L–L, L–N, 3-Phase)  
Real Power (per phase, 3-Phase  
Reactive Power (per phase, 3-Phase  
Apparent Power (per phase, 3-Phase  
Power Factor (per phase, 3-Phase  
Frequency  
Displacement Power Factor (per phase, 3-Phase  
Fundamental Voltages (per phase)  
Fundamental Currents (per phase)  
Fundamental Real Power (per phase)  
Fundamental Reactive Power (per phase)  
Unbalance (current and voltage)  
Phase Rotation  
THD (current and voltage)  
Current and Voltage Harmonic Magnitudes and  
Angles (per phase)  
Sequence Components  
Energy Readings  
Demand Readings  
Accumulated Energy, Real  
Accumulated Energy, Reactive  
Accumulated Energy, Apparent  
Bidirectional Readings  
Reactive Energy by Quadrant  
Incremental Energy  
Demand Current (per phase present, 3-Phase  
avg.)  
Average Power Factor (3-Phase total)  
Demand Real Power (per phase present, peak)  
Demand Reactive Power (per phase present,  
peak)  
Conditional Energy  
Demand Apparent Power (per phase present,  
peak)  
Coincident Readings  
Predicted Power Demands  
Individual harmonics are not calculated in the PM810. The PM810 with PM810LOG, and the PM820,  
calculate distortion to the 31st harmonic. The PM850 and PM870 calculate distortion to the 63rd harmonic.  
1
© 2011 Schneider Electric. All Rights Reserved.  
 
           
TM  
PowerLogic Series 800 Power Meter  
63230-500-225A2  
3/2011  
Chapter 1—Introduction  
Power Meter Hardware  
Power Meter With Integrated Display  
Figure 1–1: Parts of the Series 800 Power Meter with integrated display  
Bottom View  
2
4
3
8
1
5
6
7
Back View  
Table 1–2: Parts of the Series 800 Power Meter with integrated display  
No. Part  
Description  
1
2
3
4
Control power supply connector  
Connection for control power to the power meter.  
Voltage metering connections.  
Voltage inputs  
I/O connector  
Heartbeat LED  
KY pulse output/digital input connections.  
A green flashing LED indicates the power meter is ON.  
The RS-485 port is used for communications with a monitoring and  
control system. This port can be daisy-chained to multiple devices.  
5
RS-485 port (COM1)  
6
7
8
Option module connector  
Current inputs  
Used to connect an option module to the power meter.  
Current metering connections.  
Integrated display  
Visual interface to configure and operate the power meter.  
2
© 2011 Schneider Electric. All Rights Reserved.  
 
     
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 1—Introduction  
Power Meter Without Display  
Figure 1–2: Parts of the Series 800 Power Meter without display  
Bottom View  
3
4
2
1
5
6
7
Back View  
Table 1–3: Parts of the Series 800 Power Meter without display  
No. Part Description  
1
2
3
4
Control power supply connector  
Connection for control power to the power meter.  
Voltage metering connections.  
Voltage inputs  
I/O connector  
Heartbeat LED  
KY pulse output/digital input connections.  
A green flashing LED indicates the power meter is ON.  
The RS-485 port is used for communications with a monitoring and  
control system. This port can be daisy-chained to multiple devices.  
5
RS-485 port (COM1)  
6
7
Option module connector  
Current inputs  
Used to connect an option module to the power meter.  
Current metering connections.  
3
© 2011 Schneider Electric. All Rights Reserved.  
 
 
TM  
PowerLogic Series 800 Power Meter  
63230-500-225A2  
3/2011  
Chapter 1—Introduction  
Power Meter With Remote Display  
NOTE: The remote display kit (PM8RD) is used with a power meter without a display. See  
“Power Meter Without Display” on page 3 for the parts of the power meter without a display.  
Figure 1–3: Parts of the remote display and the remote display adapter  
1
2
4 5 6 7 8  
3
TX/RX  
PM8RDA Top View  
Table 1–4: Parts of the remote display  
No. Part  
Description  
Provides the connection between the remote display and the  
1
Remote display adapter (PM8RDA) power meter. Also provides an additional RS232/RS485  
connection (2- or 4-wire).  
2
3
4
Cable CAB12  
Connects the remote display to the remote display adapter.  
Visual interface to configure and operate the power meter.  
Use to select the communications mode (RS232 or RS485).  
Remote display (PM8D)  
Communications mode button  
When lit, the LED indicates the communications port is in RS232  
mode.  
5
Communications mode LED  
This port is used for communications with a monitoring and control  
system. This port can be daisy-chained to multiple devices.  
6
7
8
RS232/RS485 port  
Tx/Rx Activity LED  
CAB12 port  
The LED flashes to indicate communications activity.  
Port for the CAB12 cable used to connect the remote display to  
the remote display adapter.  
4
© 2011 Schneider Electric. All Rights Reserved.  
 
 
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 1—Introduction  
Power Meter Parts and Accessories  
Table 1–5: Power Meter Parts and Accessories  
Model Number  
Description  
Schneider  
Square D  
Electric  
Power meters  
PM810  
PM820  
PM850  
PM870  
PM810MG  
PM820MG  
PM850MG  
PM870MG  
Power meter with integrated display  
PM810U  
PM820U  
PM850U  
PM870U  
PM810UMG  
PM820UMG  
PM850UMG  
PM870UMG  
Power meter without display  
PM810RD  
PM820RD  
PM850RD  
PM870RD  
PM810RDMG  
PM820RDMG  
PM850RDMG  
PM870RDMG  
Power meter with remote display  
Accessories  
Remote display with remote display  
adapter  
PM8RD  
PM8RDMG  
Remote display adapter  
PM8RDA  
Input/Output modules  
PM810 logging module  
PM8M22, PM8M26, PM8M2222  
PM810LOG  
Cable (12 feet) extender kit for  
displays  
RJ11EXT  
Retrofit gasket (for 4 in. round hole  
mounting)  
PM8G  
CM2000 retrofit mounting adapter  
PM8MA  
The power meter units for these models are identical and support the  
same features (see “Features” on page 7).  
The power meter units for these models are identical and support the  
The power meter units for these models are identical and support the  
same features (see “Features” on page 7).  
The power meter units for these models are identical and support the  
same features (see “Features” on page 7).  
5
© 2011 Schneider Electric. All Rights Reserved.  
 
       
TM  
PowerLogic Series 800 Power Meter  
63230-500-225A2  
3/2011  
Chapter 1—Introduction  
Box Contents  
Table 1–6: Box contents based on model  
Model Description  
Box Contents  
Power Meter with integrated display  
Hardware kit (63230-500-16) containing:  
— Two retainer clips  
— Template  
Power Meter with Integrated Display  
— Plug set  
— Terminator MCT2W  
Power Meter installation guides (EN, FR, ES, DE)  
Power Meter specification guide  
Power Meter without display  
Hardware kit (63230-500-16) containing:  
— Two retainer clips  
— Template  
— DIN Slide (installed at factory)  
— Plug set  
Power Meter without Display  
— Terminator MCT2W  
Power Meter installation guides (EN, FR, ES, DE)  
Power Meter specification guide  
Power Meter without display  
Remote display (PM8D)  
Remote display adapter (PM8RDA)  
Hardware kit (63230-500-16) containing:  
— Two retainer clips  
— Template  
— DIN Slide (installed at factory)  
— Plug set  
— Terminator MCT2W  
Power Meter with Remote Display  
Hardware kit (63230-500-96) containing:  
— Communication cable (CAB12)  
— Mounting screws  
Hardware kit (63230-500-163) containing:  
— Com 2 RS-485 4-wire plug  
— Crimp connector  
Power Meter installation guides (EN, FR, ES, DE)  
Power Meter specification guide  
6
© 2011 Schneider Electric. All Rights Reserved.  
 
   
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 1—Introduction  
Features  
Table 1–7: Series 800 Power Meter Features  
PM810 PM820 PM850 PM870  
True rms metering to the 63rd harmonic  
Accepts standard CT and PT inputs  
(3)  
(3)  
600 volt direct connection on voltage inputs  
High accuracy — 0.075% current and voltage (typical conditions)  
Min/max readings of metered data  
Input metering (five channels) with PM8M22, PM8M26, or PM8M2222  
installed  
Power quality readings — THD  
Downloadable firmware  
Easy setup through the integrated or remote display (password protected)  
Setpoint-controlled alarm and relay functions  
On-board alarm logging  
Wide operating temperature range: –25° to +70°C for the power meter  
unit  
Communications:  
On-board: one Modbus RS485 (2-wire)  
PM8RD: one configurable Modbus RS232/RS485 (2- or 4-wire)  
Active energy accuracy: ANSI C12.20 Class 0.2S and IEC 62053-22  
Class 0.5S  
Non-volatile clock  
(1)  
(2)  
On-board data logging  
80 KB 800 KB 800 KB  
Real-time harmonic magnitudes and angles (I and V):  
To the 31st harmonic  
(3)  
To the 63rd harmonic  
Waveform capture  
Standard  
Advanced  
EN50160 evaluations  
NOTE: The PM850 performs EN50160 evaluations based on  
standard alarms, while the PM870 performs EN50160 evaluations  
based on disturbance alarms.  
ITI (CBEMA) and SEMI-F47 evaluations  
NOTE: The PM870 performs ITI (CBEMA) and SEMI-F47  
evaluations based on disturbance alarms.  
Current and voltage sag/swell detection and logging  
(1) The Time Clock in the PM810 with PM810LOG is non-volatile. However, it is volatile in the PM810.  
(2) The on-board data logging memory in the PM810 with PM810LOG is 80 KB, but it is not available in the PM810.  
(3) The PM810 with PM810LOG and the PM820 monitor distortion to the 31st harmonic. Harmonic distortion is not  
monitored in the PM810.  
Firmware  
This user guide is written to be used with firmware version 11.xx and above. See  
on how to determine the firmware version. To download the latest firmware version, follow  
the steps below:  
1. Using a web browser, go to http://www.Schneider-Electric.com.  
2. Locate the Search box in the upper right corner of the home page.  
3. In the Search box enter “PM8”.  
4. In the drop-down box click on the selection “PM800 series”.  
5. Locate the downloads area on the right side of the page and click on  
“Software/Firmware”.  
6. Click on the applicable firmware version title (i.e. “PowerLogic Series 800 Power Meter  
Firmware version 12.100”).  
7. Download and run the “xxx.exe” firmware upgrade file provided.  
7
© 2011 Schneider Electric. All Rights Reserved.  
 
       
TM  
PowerLogic Series 800 Power Meter  
63230-500-225A2  
3/2011  
Chapter 1—Introduction  
8
© 2011 Schneider Electric. All Rights Reserved.  
 
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 2—Safety Precautions  
Chapter 2—Safety Precautions  
DANGER  
HAZARD OF ELECTRIC SHOCK, EXPLOSION OR ARC FLASH  
• Apply appropriate personal protective equipment (PPE) and follow safe electrical  
practices. For example, in the United States, see NFPA 70E.  
• This equipment must only be installed and serviced by qualified electrical  
personnel.  
• NEVER work alone.  
• Before performing visual inspections, tests, or maintenance on this equipment,  
disconnect all sources of electric power. Assume that all circuits are live until they  
have been completely de-energized, tested, and tagged. Pay particular attention to  
the design of the power system. Consider all sources of power, including the  
possibility of backfeeding.  
• Turn off all power supplying this equipment before working on or inside equipment.  
• Always use a properly rated voltage sensing device to confirm that all power is off.  
• Beware of potential hazards and carefully inspect the work area for tools and  
objects that may have been left inside the equipment.  
• Use caution while removing or installing panels so that they do not extend into the  
energized bus; avoid handling the panels, which could cause personal injury.  
• The successful operation of this equipment depends upon proper handling,  
installation, and operation. Neglecting fundamental installation requirements may  
lead to personal injury as well as damage to electrical equipment or other property.  
• Before performing Dielectric (Hi-Pot) or Megger testing on any equipment in which  
the power meter is installed, disconnect all input and output wires to the power  
meter. High voltage testing may damage electronic components contained in the  
power meter.  
• Always use grounded external CTs for current inputs.  
Failure to follow these instructions will result in death or serious injury.  
9
© 2011 Schneider Electric. All Rights Reserved.  
 
 
PowerLogicTM Series 800 Power Meter  
Chapter 2—Safety Precautions  
63230-500-225A2  
3/2011  
10  
© 2011 Schneider Electric. All Rights Reserved.  
 
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
Chapter 3—Operation  
This section explains the features of the power meter display and the power meter setup  
procedures using this display. For a list of all power meter models containing an integrated  
display or a remote display, see Table 1–5 on page 5.  
Power Meter Display  
The power meter is equipped with a large, back-lit liquid crystal display (LCD). It can  
display up to five lines of information plus a sixth row of menu options. Figure 3–1 shows  
the different parts of the power meter display.  
Figure 3–1: Power Meter Display  
A. Type of measurement  
A
B
C
D
B. Screen title  
C. Alarm indicator  
D. Maintenance icon  
E. Bar chart (%)  
F. Units (A, V, etc.)  
G. Display more menu items  
H. Menu item  
ꢑꢆꢒ  
ꢂꢅꢀꢃꢆꢀꢄꢇꢆꢀꢁꢂꢃꢄ  
ꢏꢏꢏꢏꢏꢐꢐꢐꢐꢐꢐ  
E
F
ꢈꢖꢆꢆꢆꢆꢗꢖꢆꢆꢆꢈꢖꢖ  
ꢀꢁꢂ  
ꢀꢃꢂ  
ꢀꢁꢄ  
ꢂꢆ  
M
L
ꢏꢏꢏꢏꢏꢐꢐꢐꢐꢐꢐ  
ꢈꢖꢆꢆꢆꢆꢗꢖꢆꢆꢆꢈꢖꢖ  
ꢂꢆ  
ꢏꢏꢏꢏꢏꢐꢐꢐꢐꢐꢐ  
ꢈꢖꢆꢆꢆꢆꢗꢖꢆꢆꢆꢈꢖꢖ  
I. Selected menu indicator  
J. Button  
ꢀꢅꢃ  
ꢆꢈꢉ  
ꢀꢁꢂꢃꢄ ꢊꢆꢋꢅꢋꢌ ꢍꢍꢍꢎ  
K. Return to previous menu  
L. Values  
G
M. Phase  
K
J
I
H
How the Buttons Work  
The buttons are used to select menu items, display more menu items in a menu list, and  
return to previous menus. A menu item appears over one of the four buttons. Pressing a  
button selects the menu item and displays the menu item’s screen. When you have  
reached the highest menu level, a black triangle appears beneath the selected menu item.  
To return to the previous menu level, press the button below 1;. To scroll through the menu  
items in a menu list, press the button below ###:(see Figure 3–1).  
NOTE: Each time you read “press” in this manual, press and release the appropriate button  
beneath the menu item. For example, if you are asked to “Press PHASE,” you would press  
the button below the PHASE menu item.  
Changing Values  
When a value is selected, it flashes to indicate that it can be modified. A value is changed  
by doing the following:  
Press +(plus) or -(minus) to change numbers or scroll through available options.  
If you are entering more than a single-digit number, press <--to move to the next  
higher numeric position.  
To save your changes and move to the next field, press OK.  
Menu Overview  
Figure 3–2 on page 12, shows the first two levels of the power meter menu. Level 1  
contains all of the top level menu items. Selecting a Level 1 menu item takes you to the  
corresponding Level 2 menu items. Additional menu levels may be provided, depending on  
the specific meter features and options.  
NOTE: Press ###:to scroll through all menu items on a given level.  
11  
© 2011 Schneider Electric. All Rights Reserved.  
 
               
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
63230-500-225A2  
3/2011  
Figure 3–2: Abbreviated List of PM800 Menu Items in IEEE (IEC) Mode  
LEVEL 1  
LEVEL 2  
AMPS (I)  
PHASE  
I - DMD  
UNBAL  
V L-L (U)  
V L-N (V)  
VOLTS (U-V)  
PWR (PQS)  
ENERG (E)  
PF  
PWR (PQS)  
PHASE  
VARh  
P - DMD  
1
Wh  
VAh  
INC  
TRUE  
DISPL  
HZ (F)  
THD  
V L-L (U)  
V L-N (V)  
I
MINMX  
MINMX  
AMPS (I)  
V L-N (V)  
VOLTS (U-V)  
I
UNBAL  
PWR (PQS)  
PF  
HZ (F)  
THD V  
THD I  
1
HARM  
V L-L (U)  
ALARM  
I/O  
ACTIV  
D OUT  
HIST  
D IN  
A OUT  
A IN  
PM8M2222  
TIMER  
2
CONTR  
3
MAINT  
RESET  
SETUP  
DIAG  
METER  
ENERG (E)  
DMD  
MINMX  
MODE  
TIMER  
4
4
DATE  
TIME  
LANG  
COMMS (COM)  
METER  
ALARM  
I/O  
PASSW  
TIMER  
ADVAN  
COMM1  
4
METER  
REG  
CLOCK  
D OUT [Digital KY Out]  
D IN [Digital In]  
PM8RD  
COMM2  
PM8M2222, PM8M26, and PM8M22  
PM8M2222  
A OUT [Analog Out]  
A IN  
[Analog In]  
Available on the PM810 only when an optional Power Meter Logging Module (PM810LOG) is installed. Available on all other PM800 Series models.  
Available with some models.  
Both IEC and IEEE modes are available. Depending on the mode selected, menu labels will be different. See “Display Mode Change” on page 24 to select the  
desired mode.  
The PM810 has a volatile clock. The PM810 with an optional Power Meter Logging Module (PM810LOG), and all other PM800 Series models, have a non-volatile  
clock.  
12  
© 2011 Schneider Electric. All Rights Reserved.  
 
 
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
Power Meter Setup  
Power meter setup is typically performed by using the meter’s front panel display. To  
configure a power meter without a display, you will need a means of communication  
between the power meter and your computer. Additionally, you will need to install  
PowerLogic Meter Configuration Software or PowerLogic ION Setup Software on your  
website.  
Power meter setup is performed through the meter’s maintenance (MAINT) option. Refer to  
Figure 3–2 on page 12. Setup features may be programmed individually or in any order. To  
access the Setup features, follow these steps:  
SETUP MODE Access  
1. Press ###:to scroll through the Level 1 menu until you see MAINT.  
2. Press MAINT.  
3. Press SETUP.  
4. Enter your password, then press OK. The SETUP MODE screen will be displayed.  
NOTE: The default password is 0000.  
5. Press ###:to scroll through the setup features and select the one to be programmed.  
After programming a feature, you may continue through the remaining features by returning  
to the SETUP MODE screen and pressing ###:to scroll to additional features.  
Once you have selected the correct options for each setup parameter, press 1;until the  
SAVE CHANGES? prompt appears, then press YES. The meter will reset, briefly display  
the meter info screen, then automatically return to the main screen.  
Use the menu provided in Figure 3–2 on page 12 to locate the setup features described in  
the following topics:  
DATE Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢋꢂꢚꢄꢆꢃꢄꢚꢛꢀ  
2. Press ###:until DATE is visible.  
3. Press DATE.  
ꢆꢃ  
ꢀꢁ  
ꢅꢝꢕꢚꢁ  
ꢋꢂꢟ  
4. Enter the MONTH number.  
5. Press OK.  
6. Enter the DAY number.  
7. Press OK.  
ꢀꢆꢆꢄ  
ꢆꢃꢇꢀꢁꢇꢆꢄ ꢅꢠꢋꢠꢟ  
ꢟꢄꢂꢇ  
8. Enter the YEAR number.  
9. Press OK.  
ꢈꢉ  
ꢙꢍ  
ꢝꢞ  
10. Select how the date is displayed: M/D/Y,  
Y/M/D, or D/M/Y).  
11. Press OK to return to the SETUP MODE  
screen.  
12. Press1;to return to the main screen.  
13. To verify the new settings, press MAINT >  
DIAG > CLOCK.  
NOTE: The clock in the PM810 is volatile. Each time the meter resets, the PM810 returns  
to the default clock date/time of 12:00 AM 01-01-1980. See “Date and Time Settings” on  
page 69 for more information. All other PM800 Series meters have a non-volatile clock  
which maintains the current date and time when the meter is reset.  
13  
© 2011 Schneider Electric. All Rights Reserved.  
 
           
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
63230-500-225A2  
3/2011  
TIME Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢚꢊꢅꢄꢆꢃꢄꢚꢛꢀ  
2. Press ###:until TIME is visible.  
3. Press TIME.  
ꢀꢁ  
ꢁꢃ  
ꢂꢈ  
ꢁꢥꢦꢧ  
ꢅꢊꢕ  
4. Enter the HOUR.  
5. Press OK.  
6. Enter the MIN (minutes).  
7. Press OK.  
ꢃꢡꢢ  
ꢣꢤꢁ  
ꢝꢞ  
8. Enter the SEC (seconds).  
9. Press OK.  
ꢈꢉ  
ꢙꢍ  
10. Select how the time is displayed: 24H or  
AM/PM.  
11. Press OK to return to the SETUP MODE  
screen.  
12. Press 1;to return to the main screen.  
13. To verify the new settings, press MAINT >  
DIAG > CLOCK.  
NOTE: The clock in the PM810 is volatile. Each time the meter resets, the PM810 returns  
to the default clock date/time of 12:00 AM 01-01-1980. See “Date and Time Settings” on  
page 69 for more information. All other PM800 Series meters have a non-volatile clock,  
which maintains the current date and time when the meter is reset.  
LANG (Language) Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
2. Press ###:until LANG is visible.  
3. Press LANG.  
ꢨꢂꢕꢩꢛꢂꢩꢄ  
ꢄꢕꢩꢨꢌ  
4. Select the language: ENGL (English), FREN  
(French), SPAN (Spanish), GERMN (German),  
or RUSSN (Russian).  
5. Press OK.  
6. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
ꢈꢉ  
ꢙꢍ  
ꢝꢞ  
7. Press YES to save the changes.  
14  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
COMMS (Communications) Setup  
NOTE: If you are using PowerLogic software to set up the power meter, it is recommended  
you set up the communications features first.  
Refer to Table 3-1 for the meter’s default settings.  
Table 3–1: Communications Default Settings  
Communications Setting  
Default  
Protocol  
MB.RTU (Modbus RTU)  
Address  
Baud Rate  
Parity  
1
9600  
Even  
The same procedure is used to program the settings for the COMMS, COMM 1, and  
COMM 2 options.  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢔꢝꢅꢅꢃꢆꢃꢄꢚꢛꢀ  
2. Press ###:until COMMS (communications)  
is visible.  
ꢅꢓꢌꢇꢚꢛ  
3. Press COMMS (communications).  
4. Select the required protocol: MB.RTU (Modbus  
RTU), Jbus, MB. A.8 (Modbus ASCII 8 bits),  
MB. A.7 (Modbus ASCII 7 bits).  
ꢂꢋꢋꢇꢌ  
ꢪꢫꢦꢋ  
ꢆꢆꢉ  
ꢊꢄꢆꢆ  
5. Press OK.  
ꢄꢬꢄꢕ  
ꢝꢞ  
6. Enter the ADDR (power meter address).  
7. Press OK.  
ꢈꢉ  
ꢙꢍ  
8. Select the BAUD (baud rate).  
9. Press OK.  
10. Select the parity: EVEN, ODD, or NONE.  
11. Press OK.  
12. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
13. Press YES to save the changes.  
METER Setup  
This feature allows the user to configure the CTs, PTs, system frequency, and system  
wiring method.  
CTs Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢔꢚꢆꢇꢂꢚꢊꢝ  
2. Press ###:until METER is visible.  
3. Press METER.  
4. Press CT.  
ꢈꢆꢆ  
ꢔꢆꢚ  
ꢔꢆꢚ  
ꢀꢇꢊꢅ  
ꢃꢄꢔꢌ  
5. Enter the PRIM (CT primary) number.  
6. Press OK.  
7. Enter the SEC. (CT secondary) number.  
8. Press OK.  
ꢈꢉ  
ꢙꢍ  
ꢝꢞ  
9. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
10. Press YES to save the changes.  
15  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
63230-500-225A2  
3/2011  
PTs Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢀꢚꢆꢇꢂꢚꢊꢝ  
2. Press ###:until METER is visible.  
3. Press METER.  
ꢉꢀꢆ  
ꢉꢀꢆ  
ꢃꢔꢂꢨꢄ  
ꢀꢇꢊꢅ  
4. Press PT.  
5. Enter the SCALE value: x1, x10, x100, NO PT  
(for direct connect).  
ꢃꢄꢔꢌ  
ꢝꢞ  
6. Press OK.  
7. Enter the PRIM (primary) value.  
8. Press OK.  
ꢈꢉ  
ꢙꢍ  
9. Enter the SEC. (secondary) value.  
10. Press OK.  
11. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
12. Press YES to save the changes.  
HZ (System Frequency) Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢆꢆꢆꢒ  
ꢃꢟꢃꢚꢄꢅꢆꢮꢧꢡꢯꢦꢡꢕꢢꢰ  
2. Press ###:until METER is visible.  
3. Press METER.  
4. Press ###:until HZ is visible.  
5. Press HZ.  
ꢄꢆ  
ꢄꢆ  
ꢁꢱ  
6. Select the frequency.  
7. Press OK.  
ꢮꢇꢄꢲꢌ  
ꢝꢞ  
8. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
ꢈꢉ  
ꢙꢍ  
9. Press YES to save the changes.  
SYS (System Type) Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢆꢆꢆꢒ  
ꢳꢆꢀꢁꢂꢃꢄꢆꢃꢟꢃꢚꢄꢅ  
2. Press ###:until METER is visible.  
3. Press METER.  
A
ꢴꢊꢇꢄ  
ꢔꢚ  
4. Press ###:until SYS is visible.  
5. Press SYS.  
B
C
6. Select your system (SYS) type (D) based on  
the number of wires (A), the number of CTs (B),  
and the number of voltage connections (either  
direct connect or with PT) (C).  
ꢀꢚ  
D
ꢃꢆ  
ꢃꢟꢃꢌ  
ꢝꢞ  
ꢈꢉ  
7. Press OK.  
8. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
9. Press YES to save the changes.  
16  
© 2011 Schneider Electric. All Rights Reserved.  
 
   
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
ALARM (Alarms) Setup  
There is an extensive list of meter error conditions  
which can be monitored and cause an alarm.  
ꢆꢆꢆꢒ  
ꢝꢬꢄꢇꢆꢬꢂꢕ  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢄꢕꢂꢓꢨꢌ  
ꢁꢊꢩꢁ  
2. Press ###:until ALARM is visible.  
ꢀꢆꢇ  
ꢈꢉ  
3. Press ALARM.  
4. Press <-or ->to select the alarm option you  
ꢂꢓꢃꢝꢨ  
want to edit.  
5. Press EDIT.  
ꢙꢍ  
ꢝꢞ  
6. Select to ENABL (enable) or DISAB (disable)  
the alarm.  
7. Press OK.  
8. Select the PR (priority): NONE, HIGH, MED, or  
LOW.  
9. Press OK.  
10. Select how the alarm values are displayed:  
ABSOL (absolute value) or RELAT (percentage  
relative to the running average).  
ꢆꢆꢆꢒ  
ꢝꢬꢄꢇꢆꢬꢂꢕ  
11. Enter the PU VALUE (pick-up value).  
12. Press OK.  
ꢀꢆꢛ  
ꢅꢂꢩꢌ  
ꢉꢆꢆ  
ꢀꢆꢛ  
ꢋꢆꢝ  
ꢋꢆꢝ  
ꢈꢉ  
ꢋꢄꢨꢂꢟ  
13. Enter the PU DELAY (pick-up delay).  
14. Press OK.  
ꢅꢂꢩꢌ  
ꢋꢄꢨꢂꢟ  
ꢝꢞ  
15. Enter the DO VALUE (drop-out value).  
16. Press OK.  
ꢙꢍꢍꢍꢍ  
17. Enter the DO DELAY (drop-out delay).  
18. Press OK.  
19. Press 1;to return to the alarm summary  
screen.  
20. Press 1;to return to the SETUP MODE screen.  
21. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
22. Press YES to save the changes.  
17  
© 2011 Schneider Electric. All Rights Reserved.  
 
   
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
63230-500-225A2  
3/2011  
I/O (Input/Output) Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
2. Press ###:until I/O is visible.  
3. Press I/O.  
ꢆꢆꢆꢒ  
ꢞꢟ  
ꢕꢝꢇꢅ  
4. Press D OUT for digital output or D IN for digital  
input, or press A OUT for analog output or A IN  
for analog input. Use the ###:button to scroll  
through these selections.  
ꢀꢛꢨꢃꢄ  
ꢚꢊꢅꢄꢇ  
ꢄꢭꢚꢌ  
NOTE: Analog inputs and outputs are available  
only with the PM8222 option module.  
ꢈꢉ  
ꢙꢍ  
ꢝꢞ  
5. Press EDIT.  
6. Select the I/O mode based on the I/O type and  
the user selected mode: NORM., LATCH,  
TIMED, PULSE, or END OF.  
7. Depending on the mode selected, the power  
meter will prompt you to enter the pulse weight,  
timer, and control.  
8. Press OK.  
9. Select EXT. (externally controlled via  
communications) or ALARM (controlled by an  
alarm).  
10. Press 1;to return to the SETUP MODE screen.  
11. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
12. Press YES to save the changes.  
PASSW (Password) Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢆꢆꢆꢒ  
ꢀꢂꢃꢃꢴꢝꢇꢋꢆꢃꢄꢚꢛꢀ  
ꢆꢆꢆꢆ  
ꢆꢆꢆꢆ  
2. Press ###:until PASSW (password) is visible.  
3. Press PASSW.  
ꢃꢄꢚꢛꢀ  
ꢋꢊꢂꢩꢌ  
4. Enter the SETUP password.  
5. Press OK.  
6. Enter the DIAG (diagnostics) password.  
7. Press OK.  
ꢆꢆꢆꢆ  
ꢄꢕꢄꢇꢩ  
ꢆꢆꢆꢆ  
ꢅꢕꢠꢅꢭ  
ꢝꢞ  
8. Enter the ENERG (energy reset) password.  
9. Press OK.  
ꢈꢉ  
ꢙꢍ  
10. Enter the MN/MX (minimum/maximum reset)  
password.  
11. Press OK.  
12. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
13. Press YES to save the changes.  
18  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
TIMER (Operating Time Threshold) Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
2. Press ###:until TIMER is visible.  
3. Press TIMER.  
ꢝꢀꢄꢇꢆꢚꢊꢅꢄꢆꢃꢄꢚꢛꢀ  
ꢳꢍꢀ  
ꢊꢌꢆꢂꢬꢩ  
4. Enter the 3-phase current average.  
NOTE: The power meter begins counting the  
operating time whenever the readings are equal  
to or above the average.  
5. Press OK.  
ꢈꢉ  
ꢙꢍꢍꢍꢍ  
ꢝꢞ  
6. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
7. Press YES to save the changes.  
ADVAN (Advanced) Power Meter Setup Features  
The Advanced Feature set contains several items which need to be programmed. To  
access these features, follow these steps:  
After programming a feature, you may continue through the remaining features by returning  
to the SETUP MODE screen and pressing ###:to scroll to additional features.  
Once you have selected the correct options for each setup parameter, press 1;until the  
SAVE CHANGES? prompt appears, then press YES. The meter will reset, briefly display  
the meter info screen, then automatically return to the main screen.  
ROT (Phase Rotation) Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢀꢁꢂꢃꢄꢆꢇꢥꢵꢫꢵꢶꢥꢕ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
ꢂꢓꢔ  
3. Press ADVAN.  
4. Press ###:until ROT (phase rotation) is visible.  
5. Press ROT.  
6. Select the phase rotation: ABC or CBA.  
7. Press OK.  
ꢈꢉ  
ꢙꢍ  
8. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
9. Press YES to save the changes.  
19  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
63230-500-225A2  
3/2011  
E-INC (Incremental Energy Interval) Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢊꢕꢔꢇꢆꢄꢕꢄꢇꢩꢟ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
3. Press ADVAN.  
ꢄꢆ  
ꢊꢕꢚꢬꢨ  
4. Press ###:until E-INC (incremental energy) is  
visible.  
5. Press E-INC.  
6. Enter the INTVL (interval). Range is 00 to 1440.  
7. Press OK.  
ꢈꢉ  
ꢙꢍ  
ꢝꢞ  
8. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
9. Press YES to save the changes.  
THD Calculation Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢚꢁꢋꢆꢔꢫꢷꢢꢦꢷꢫꢵꢶꢥꢕ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
3. Press ADVAN.  
ꢸꢦꢕꢋ  
4. Press ###:until THD is visible.  
5. Press THD.  
6. Select the THD calculation: FUND or RMS.  
7. Press OK.  
ꢈꢉ  
ꢙꢍ  
8. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
9. Press YES to save the changes.  
VAR/PF Convention Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢀꢮꢆꢔꢥꢕꢹꢡꢕꢵꢶꢥꢕ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
3. Press ADVAN.  
ꢶꢡꢡꢡ  
4. Press ###:until PF is visible.  
5. Press PF.  
6. Select the Var/PF convention: IEEE or IEC.  
7. Press OK.  
ꢈꢉ  
ꢙꢍ  
8. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
9. Press YES to save the changes.  
20  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
Lock Resets Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢷꢥꢢꢺꢆꢇꢡꢻꢡꢵꢻꢼ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
ꢀꢞꢌꢋꢅꢋ  
ꢄꢕꢄꢇꢩ  
3. Press ADVAN.  
4. Press ###:until LOCK is visible.  
5. Press LOCK.  
ꢅꢽꢠꢾꢿ  
6. Select Y (yes) or N (no) to enable or disable  
resets for PK.DMD, ENERG, MN/MX, and  
METER.  
ꢅꢡꢵꢡꢧ  
ꢝꢞ  
ꢈꢉ  
ꢙꢍꢍ  
7. Press OK.  
8. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
9. Press YES to save the changes.  
Alarm Backlight Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢂꢨꢂꢇꢅꢆꢓꢂꢔꢞꢨꢊꢩꢁꢚꢼ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
3. Press ADVAN.  
ꢝꢕ  
4. Press ###:until BLINK is visible.  
5. Press BLINK.  
6. Enter ON or OFF.  
7. Press OK.  
ꢈꢉ  
ꢙꢍ  
ꢝꢞ  
8. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
9. Press YES to save the changes.  
Bar Graph Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢓꢫꢧꢆꣀꢧꢫꣁꢁꢆꢻꢢꢫꢷꢡ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
3. Press ADVAN.  
4. Press ###:until BARGR is visible.  
5. Press BARGR.  
6. Press AMPS or PWR.  
7. Select AUTO or MAN. If MAN is selected, press  
OK and enter the %CT*PT and KW (for PWR)  
or the %CT and A (for AMPS).  
ꢈꢉ  
ꢂꢅꢀꢃ  
ꢀꢴꢇ  
8. Press OK.  
9. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
10. Press YES to save the changes.  
21  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
63230-500-225A2  
3/2011  
PQ Advanced Evaluation Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢀꢲꢆꢂꢋꢹꢫꢕꢆꢃꢄꢚꢛꢀ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
ꢝꢕ  
3. Press ADVAN.  
4. Press ###:until PQADV is visible.  
5. Press PQADV.  
ꢕꢝꢅꢆꢬ  
ꢀꢁꢆ  
6. Select ON.  
7. Press OK.  
ꢈꢉ  
ꢙꢍꢍꢍꢍ  
ꢝꢞ  
8. Change the nominal voltage (NOM V) value if  
desired (the default is 230).  
9. Press OK to return to the SETUP MODE  
screen.  
10. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
11. Press YES to save your changes and reset the  
power meter.  
Power Demand Configuration Setup  
1. Perform steps 1 through 5 of the SETUP MODE  
Access procedure on page 11.  
ꢀꢥꣂꢡꢧꢆꢋꢅꢋꢆꢔꢝꢕꢮꢊꢩ  
2. Press ###:until ADVAN (advanced setup) is  
visible.  
ꢇꢔꢨꢔꢞ  
ꢊꢕꢚꢬꢨ  
ꢃꢛꢓꢍꢊ  
3. Press ADVAN.  
ꢉꢂ  
4. Press ###:until DMD is visible.  
5. Press DMD (P-DMD, I-DMD).  
6. Select the demand configuration. Choices are  
COMMS, RCOMM, CLOCK, RCLCK, IENGY,  
THERM, SLIDE, BLOCK, RBLCK, INPUT, and  
RINPUT.  
ꢈꢉ  
ꢙꢍ  
ꢝꢞ  
7. Press OK.  
8. Enter the INTVL (interval) and press OK.  
9. Enter the SUB-I (sub-interval) and press OK.  
10. At the SETUP MODE screen, continue  
programming additional setup features or  
press1;until you are asked to save changes.  
11. Press YES to save the changes.  
22  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
Power Meter Resets  
The Power Meter Resets Feature set contains several items. After resetting a feature, you  
may continue through the remaining features by returning to the RESET MODE screen and  
pressing ###:to scroll to additional features. Once you have reset the specific features,  
press 1;until the display returns to the main screen.  
Initialize the Power Meter  
Initializing the power meter resets the energy  
readings, minimum/maximum values, and  
operating times. To initialize the power meter,  
follow these steps:  
ꢊꢕꢊꢚꢌꢆꢅꢄꢚꢄꢇꢆꢼ  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
2. Press MAINT.  
3. Press RESET.  
4. Press ###:until METER is visible.  
5. Press METER.  
ꢕꢝ  
ꢟꢄꢃ  
6. Enter the password (the default is 0000).  
7. Press YES to initialize the power meter and to  
return to the RESET MODE screen.  
8. At the RESET MODE screen, continue  
resetting additional features or press1;until  
you return to the main screen.  
NOTE: We recommend initializing the power meter  
after you make changes to any of the following:  
CTs, PTs, frequency, or system type.  
Accumulated Energy Readings Reset  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
ꢇꢄꢃꢄꢚꢆꢄꢕꢄꢇꢩꢟꢆꢼ  
2. Press MAINT.  
3. Press RESET.  
ꢂꢁꢃꢅꢉꢀ  
ꢀꢂꢊꢅꢊꢆ  
ꢋꢀꢃꢅꢄꢄ  
ꢺꢴꣃ  
4. Press ###:until ENERG is visible.  
5. Press ENERG.  
ꢺꢬꢂꢇꣃ  
ꢺꢬꢂꣃ  
6. Enter the password (the default is 0000).  
7. Press YES to reset the accumulated energy  
readings and to return to the RESET MODE  
screen.  
ꢆꢄꢇꢉꢆꢇꢆꢄ  
ꢗꢖꢂ  
ꢟꢄꢃ  
ꢕꢝ  
23  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
63230-500-225A2  
3/2011  
Accumulated Demand Readings Reset  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
ꢇꢄꢃꢄꢚꢆꢋꢄꢅꢂꢕꢋꢆꢼ  
2. Press MAINT.  
3. Press RESET.  
ꢀꢺ  
ꢀꢺ  
ꢀꢺ  
ꢺꢴ꣄  
4. Press ###:until DMD is visible.  
5. Press DMD.  
ꢺꢬꢂꢇ꣄  
ꢂꢅꢀꢆꢋ  
6. Enter the password (the default is 0000).  
ꢃꢀ  
ꢆꢈꢇꢉꢆꢇꢆꢄ  
7. Press YES to reset the accumulated demand  
readings and to return to the RESET MODE  
screen.  
ꢗꢖ  
ꢟꢄꢃ  
ꢕꢝ  
Minimum/Maximum Values Reset  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
ꢇꢄꢃꢄꢚꢆꢅꢊꢕꢠꢅꢂꢭꢆꢼ  
2. Press MAINT.  
3. Press RESET.  
4. Press ###:until MINMX is visible.  
5. Press MINMX.  
6. Enter the password (the default is 0000).  
7. Press YES to reset the minimum/maximum  
values and to return to the RESET MODE  
screen.  
ꢆꢈꢇꢉꢆꢇꢆꢄ  
ꢗꢖꢂ  
ꢟꢄꢃ  
ꢕꢝ  
Display Mode Change  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
ꢇꢄꢃꢄꢚꢆꢋꢄꢮꢂꢛꢨꢚꢆꢼ  
2. Press MAINT.  
3. Press RESET.  
4. Press ###:until MODE is visible.  
5. Press MODE.  
6. Press IEEE (default for Square D branded  
power meters) or IEC (default for Schneider  
Electric branded power meters) depending on  
the operating mode you want to use.  
ꢲꢛꢊꢚ  
ꢊꢄꢄꢄ  
ꢊꢄꢔ  
NOTE: Resetting the mode changes the menu  
labels, power factor conventions, and THD  
calculations to match the standard mode selected.  
To customize the mode changes, see the register  
list.  
24  
© 2011 Schneider Electric. All Rights Reserved.  
 
       
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
Accumulated Operating Time Reset  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
ꢇꢄꢃꢄꢚꢆꢝꢀꢄꢇꢆꢚꢊꢅꢄꢆꢼ  
2. Press MAINT.  
3. Press RESET.  
ꢉꢀꢆ  
ꢉꢉ  
ꢋꢂꢟꢃ  
4. Press ###:until TIMER is visible.  
5. Press TIMER.  
ꢁꢝꢛꢇꢃ  
6. Enter the password (the default is 0000).  
ꢃꢀ  
ꢅꢊꢕꢃ  
7. Press YES to reset the accumulated operating  
time and to return to the RESET MODE screen.  
ꢕꢝ  
ꢟꢄꢃ  
NOTE: The accumulated days, hours, and  
minutes of operation are reset to zero when you  
press YES.  
Power Meter Diagnostics  
To view the power meter’s model, firmware version, serial number, read and write registers,  
or check the health status, you must access the HEALTH STATUS screen.  
After viewing a feature, you may continue through the remaining features by returning to  
the HEALTH STATUS screen and selecting one of the other options.  
Once you have viewed the specific features, press 1;until the display returns to the main  
screen.  
HEALTH STATUS screen  
ꢁꢄꢂꢨꢚꢁꢆꢃꢚꢂꢚꢛꢃ  
NOTE: The wrench icon and the health status code  
display when a health problem is detected. For  
code 1, set up the Date/Time (see “DATE Setup”  
and “TIME Setup” on pages 11 and 12). For other  
codes, contact technical support.  
ꢝꢞ  
ꢈꢉ  
ꢅꢄꢚꢄꢇ  
ꢇꢄꢩꢌ  
ꢔꢨꢝꢔꢞ  
25  
© 2011 Schneider Electric. All Rights Reserved.  
 
   
PowerLogicTM Series 800 Power Meter  
Chapter 3—Operation  
63230-500-225A2  
3/2011  
View the Meter Information  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
ꢅꢄꢚꢄꢇꢆꢊꢕꢮꢝ  
2. Press MAINT.  
3. Press DIAG (diagnostics) to open the HEALTH  
STATUS screen.  
ꢈꢂꢆ  
ꢉꢀꢅꢉꢆꢆ  
ꢉꢆꢅꢋꢆꢆ  
ꢀꢂꢆꢆꢆꢉꢊꢁ  
ꢀꢆꢅ  
ꢆꢆꢬ  
ꢅꢝꢋꢄꢨ  
ꢌ  
4. On the HEALTH STATUS screen, press  
METER (meter information).  
ꢆꢆꢬ  
ꢈꢉ  
ꢇꢄꢃꢄꢚ  
ꢃꢌꢕꢌ  
5. View the meter information.  
6. Press ###:to view more meter information.  
ꢙꢍ  
ꢍꣅ  
7. Press 1;to return to the HEALTH STATUS  
screen.  
NOTE: The wrench icon and the health status code  
display when a health problem is detected. For  
code 1, set up the Date/Time (see “DATE Setup”  
and “TIME Setup” on pages 11 and 12). For other  
codes, contact technical support.  
Read and Write Registers  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
ꢇꢠꢴꢆꢇꢄꢩꢊꢃꢚꢄꢇ  
ꢉꢆꢆꢆ  
ꢆꢆꢆꢆꢆ  
2. Press MAINT.  
3. Press DIAG (diagnostics) to open the HEALTH  
STATUS screen.  
ꢇꢄꢩꢌ  
ꢁꢄꢭ  
ꢋꢄꢔ  
4. On the HEALTH STATUS screen, Press REG  
(register).  
5. Enter the password (the default is 0000).  
6. Enter the REG. (register) number that contains  
the data you want to monitor.  
ꢝꢞ  
ꢈꢉ  
ꢙꢍ  
The register content will be displayed in both  
HEX (hexadecimal) and DEC (decimal) values.  
7. Press 1;to return to the HEALTH STATUS  
screen.  
NOTE: For more information about using registers,  
View the Meter Date and TIme  
1. Press ###:to scroll through the Level 1 menu  
until you see MAINT.  
ꢀꢅ꣆ꢆꢋꢂꢚꢄꢍꢚꢊꢅꢄ  
ꢉꢉ  
ꢃꢀ  
ꢆꢀꢇꢀꢈꢇꢆꢄ  
2. Press MAINT.  
3. Press DIAG (diagnostics) to open the HEALTH  
STATUS screen.  
ꢀꢆꢅ  
ꢆꢆꢬ  
ꢁꢝꢛꢇ  
ꢅꢊꢕ  
4. On the HEALTH STATUS screen, press  
CLOCK (current date and time).  
ꢆꢆꢬ  
ꢈꢉ  
ꢃꢄꢔ  
5. View the date and time.  
ꢚꢛꢄꢃ  
6. Press 1;to return to the HEALTH STATUS  
screen.  
ꢙꢍ  
ꢍꣅ  
26  
© 2011 Schneider Electric. All Rights Reserved.  
 
       
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
Chapter 4—Metering Capabilities  
Real-Time Readings  
The power meter measures currents and voltages, and reports in real time the rms values  
for all three phases and neutral. In addition, the power meter calculates power factor, real  
power, reactive power, and more.  
Table 4–1 lists some of the real-time readings that are updated every second along with  
their reportable ranges.  
Table 4–1: One-second, Real-time Readings  
Real-time Readings  
Current  
Reportable Range  
Per-Phase  
0 to 32,767 A  
0 to 32,767 A  
0 to 32,767 A  
0 to 100.0%  
Neutral  
3-Phase Average  
% Unbalance  
Voltage  
Line-to-Line, Per-Phase  
Line-to-Line, 3-Phase Average  
Line-to-Neutral, Per-Phase  
Line-to-Neutral, 3-Phase Average  
% Unbalance  
0 to 1,200 kV  
0 to 1,200 kV  
0 to 1,200 kV  
0 to 1,200 kV  
0 to 100.0%  
Real Power  
Per-Phase  
0 to ± 3,276.70 MW  
0 to ± 3,276.70 MW  
3-Phase Total  
Reactive Power  
Per-Phase  
0 to ± 3,276.70 MVAR  
0 to ± 3,276.70 MVAR  
3-Phase Total  
Apparent Power  
Per-Phase  
0 to ± 3,276.70 MVA  
0 to ± 3,276.70 MVA  
3-Phase Total  
Power Factor (True)  
Per-Phase  
–0.002 to 1.000 to +0.002  
–0.002 to 1.000 to +0.002  
3-Phase Total  
Power Factor (Displacement)  
Per-Phase  
–0.002 to 1.000 to +0.002  
–0.002 to 1.000 to +0.002  
3-Phase Total  
Frequency  
45–65 Hz  
23.00 to 67.00 Hz  
350–450 Hz  
350.00 to 450.00 Hz  
27  
© 2011 Schneider Electric. All Rights Reserved.  
 
           
PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
63230-500-225A2  
3/2011  
Min/Max Values for Real-time Readings  
When certain one-second real-time readings reach their highest or lowest value, the power  
meter saves the values in its non-volatile memory. These values are called the minimum  
and maximum (min/max) values.  
The power meter stores the min/max values for the current month and previous month.  
After the end of each month, the power meter moves the current month’s min/max values  
into the previous month’s register space and resets the current month’s min/max values.  
The current month’s min/max values can be reset manually at any time using the power  
meter display or PowerLogic software. After the min/max values are reset, the power meter  
records the date and time. The real-time readings evaluated are:  
Min/Max Voltage L-L  
Min/Max Voltage L-N  
Min/Max Current  
Min/Max Voltage L-L, Unbalance  
Min/Max Voltage L-N, Unbalance  
Min/Max Total True Power Factor  
Min/Max Total Displacement Power  
Factor  
Min/Max Reactive Power Total  
Min/Max Apparent Power Total  
Min/Max THD/thd Voltage L-L  
Min/Max THD/thd Voltage L-N  
Min/Max THD/thd Current  
Min/Max Frequency  
Min/Max Voltage N-ground  
(see the note below)  
Min/Max Real Power Total  
Min/Max Current, Neutral  
(see the note below)  
NOTE: Min/Max values for Vng and In are not available from the display. Use the display to  
read registers (see “Read and Write Registers” on page 26) or use PowerLogic software.  
For each min/max value listed above, the power meter records the following attributes:  
Date/Time of minimum value  
Minimum value  
Phase of recorded minimum value  
Date/Time of maximum value  
Maximum value  
Phase of recorded maximum value  
NOTE: Phase of recorded min/max only applies to multi-phase quantities.  
NOTE: There are two ways to view the min/max values. 1- Use the power meter display to  
view the min/max values since the meter was last reset. 2- Use PowerLogic software to  
view a table with the instantaneous min/max values for the current and previous months.  
Power Factor Min/Max Conventions  
All running min/max values, except for power factor, are arithmetic minimum and maximum  
values. For example, the minimum phase A-B voltage is the lowest value in the range 0 to  
1200 kV that has occurred since the min/max values were last reset. In contrast, because  
the power factor’s midpoint is unity (equal to one), the power factor min/max values are not  
true arithmetic minimums and maximums. Instead, the minimum value represents the  
measurement closest to -0 on a continuous scale for all real-time readings -0 to 1.00 to +0.  
The maximum value is the measurement closest to +0 on the same scale.  
Figure 4–1 shows the min/max values in a typical environment in which a positive power  
flow is assumed. In the figure, the minimum power factor is -0.7 (lagging) and the maximum  
is 0.8 (leading). Note that the minimum power factor need not be lagging, and the maximum  
power factor need not be leading. For example, if the power factor values ranged from  
-0.75 to -0.95, then the minimum power factor would be -0.75 (lagging) and the maximum  
power factor would be -0.95 (lagging). Both would be negative. Likewise, if the power factor  
ranged from +0.9 to +0.95, the minimum would be +0.95 (leading) and the maximum would  
be +0.90 (leading). Both would be positive in this case.  
28  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
Figure 4–1: Power factor min/max example  
Minimum  
Power Factor  
-.7 (lagging)  
Maximum  
Power Factor  
.8 (leading)  
Range of Power  
Factor Value  
Unity  
1.00  
.8  
.8  
.6  
.6  
Lead  
(+)  
Lag  
(–)  
.4  
.4  
.2  
.2  
-0  
+0  
NOTE: Assumes a positive power flow  
An alternate power factor storage method is also available for use with analog outputs and  
trending. See “Using the Command Interface” on page 83 for the applicable registers.  
Power Factor Sign Conventions  
The power meter can be set to one of two power factor sign conventions: IEEE or IEC. The  
Series 800 Power Meter defaults to the IEEE power factor sign convention. Figure 4–2  
illustrates the two sign conventions. For instructions on changing the power factor sign  
Figure 4–2: Power factor sign convention  
Reactive  
Power In  
Reactive  
Power In  
Quadrant  
2
Quadrant  
1
Quadrant  
2
Quadrant  
1
watts negative (–)  
vars positive (+)  
power factor (–)  
watts positive (+)  
vars positive (+)  
power factor (+)  
watts negative (–)  
vars positive (+)  
power factor (+)  
watts positive (+)  
vars positive (+)  
power factor (–)  
Reverse  
Power Flow  
Normal  
Power Flow  
Reverse  
Power Flow  
Normal  
Power Flow  
Real  
Power  
In  
Real  
Power  
In  
watts negative (–)  
vars negative (–)  
power factor (–)  
watts positive (+)  
vars negative (–)  
power factor (+)  
watts negative (–)  
vars negative (–)  
power factor (–)  
watts positive (+)  
vars negative (–)  
power factor (+)  
Quadrant  
3
Quadrant  
4
Quadrant  
3
Quadrant  
4
IEC Power Factor Sign Convention  
IEEE Power Factor Sign Convention  
Figure 4–3: Power Factor Display Example  
ꢆꢆꢆ  
ꢚꢧꢦꢡꢆꢀꢮ  
The power  
ꢆꢅꢋꢂꢋ  
ꢆꢅꢋꢆꢃ  
ꢆꢅꢋꢃꢃ  
factor sign is  
visible next to  
the power  
factor reading.  
ꢆꢅꢋꢁꢄ  
ꢚꢝꢚꢂꢨ  
ꢈꢉ  
ꢚꢇꢛꢄ  
ꢃꢀꢨ  
29  
© 2011 Schneider Electric. All Rights Reserved.  
 
       
PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
63230-500-225A2  
3/2011  
Demand Readings  
The power meter provides a variety of demand readings, including coincident readings and  
predicted demands. Table 4–2 lists the available demand readings and their reportable  
ranges.  
Table 4–2: Demand Readings  
Demand Readings  
Reportable Range  
Demand Current, Per-Phase, 3Ø Average, Neutral  
Last Complete Interval  
Peak  
0 to 32,767 A  
0 to 32,767 A  
Average Power Factor (True), 3Ø Total  
Last Complete Interval  
Coincident with kW Peak  
Coincident with kVAR Peak  
Coincident with kVA Peak  
Demand Real Power, 3Ø Total  
Last Complete Interval  
Predicted  
–0.002 to 1.000 to +0.002  
–0.002 to 1.000 to +0.002  
–0.002 to 1.000 to +0.002  
–0.002 to 1.000 to +0.002  
0 to ± 3276.70 MW  
0 to ± 3276.70 MW  
0 to ± 3276.70 MW  
0 to ± 3276.70 MVA  
0 to ± 3276.70 MVAR  
Peak  
Coincident kVA Demand  
Coincident kVAR Demand  
Demand Reactive Power, 3Ø Total  
Last Complete Interval  
Predicted  
0 to ± 3276.70 MVAR  
0 to ± 3276.70 MVAR  
0 to ± 3276.70 MVAR  
0 to ± 3276.70 MVA  
0 to ± 3276.70 MW  
Peak  
Coincident kVA Demand  
Coincident kW Demand  
Demand Apparent Power, 3Ø Total  
Last Complete Interval  
Predicted  
0 to ± 3276.70 MVA  
0 to ± 3276.70 MVA  
0 to ± 3276.70 MVA  
0 to ± 3276.70 MW  
0 to ± 3276.70 MVAR  
Peak  
Coincident kW Demand  
Coincident kVAR Demand  
Demand Power Calculation Methods  
Demand power is the energy accumulated during a specified period divided by the length of  
that period. How the power meter performs this calculation depends on the method you  
select. To be compatible with electric utility billing practices, the power meter provides the  
following types of demand power calculations:  
Block Interval Demand  
Synchronized Demand  
Thermal Demand  
The default demand calculation is set to sliding block with a 15 minute interval. You can set  
up any of the demand power calculation methods using PowerLogic software.  
30  
© 2011 Schneider Electric. All Rights Reserved.  
 
             
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
Block Interval Demand  
In the block interval demand method, you select a “block” of time that the power meter uses  
for the demand calculation. You choose how the power meter handles that block of time  
(interval). Three different modes are possible:  
Sliding Block. In the sliding block interval, you select an interval from 1 to 60 minutes  
(in 1-minute increments). If the interval is between 1 and 15 minutes, the demand  
calculation updates every 15 seconds. If the interval is between 16 and 60 minutes, the  
demand calculation updates every 60 seconds. The power meter displays the demand  
value for the last completed interval.  
Fixed Block. In the fixed block interval, you select an interval from 1 to 60 minutes (in  
1-minute increments). The power meter calculates and updates the demand at the end  
of each interval.  
Rolling Block. In the rolling block interval, you select an interval and a sub-interval.  
The sub-interval must divide evenly into the interval. For example, you might set three  
5-minute sub-intervals for a 15-minute interval. Demand is updated at each sub-  
interval. The power meter displays the demand value for the last completed interval.  
Figure 4–4 below illustrates the three ways to calculate demand power using the block  
method. For illustration purposes, the interval is set to 15 minutes.  
Figure 4–4: Block Interval Demand Examples  
Demand value is the  
average for the last  
completed interval  
Calculation updates  
every 15 or 60  
seconds  
15-minute interval  
Time  
(sec)  
15 30 45 60 . . .  
Sliding Block  
Demand value is  
the average for  
the last  
completed  
interval  
Calculation updates at  
the end of the interval  
15-minute interval  
15-minute interval  
15-min  
Time  
(min)  
15  
30  
45  
Fixed Block  
Demand value is  
the average for  
the last  
Calculation updates at the end of  
the sub-interval (5 minutes)  
completed  
interval  
15-minute interval  
Time  
(min)  
20  
25  
35  
40  
30  
45  
15  
Rolling Block  
31  
© 2011 Schneider Electric. All Rights Reserved.  
 
         
PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
63230-500-225A2  
3/2011  
Synchronized Demand  
The demand calculations can be synchronized by accepting an external pulse input, a  
command sent over communications, or by synchronizing to the internal real-time clock.  
Input Synchronized Demand. You can set up the power meter to accept an input such  
as a demand synch pulse from an external source. The power meter then uses the  
same time interval as the other meter for each demand calculation. You can use the  
standard digital input installed on the meter to receive the synch pulse. When setting up  
this type of demand, you select whether it will be input-synchronized block or input-  
synchronized rolling block demand. The rolling block demand requires that you choose  
a sub-interval.  
Command Synchronized Demand. Using command synchronized demand, you can  
synchronize the demand intervals of multiple meters on a communications network. For  
example, if a PLC input is monitoring a pulse at the end of a demand interval on a utility  
revenue meter, you could program the PLC to issue a command to multiple meters  
whenever the utility meter starts a new demand interval. Each time the command is  
issued, the demand readings of each meter are calculated for the same interval. When  
setting up this type of demand, you select whether it will be command-synchronized  
block or command-synchronized rolling block demand. The rolling block demand  
requires that you choose a sub-interval. See Appendix C—Using the Command  
Interface on page 83 for more information.  
Clock Synchronized Demand (Requires PM810LOG). You can synchronize the  
demand interval to the internal real-time clock in the power meter. This enables you to  
synchronize the demand to a particular time, typically on the hour. The default time is  
12:00 am. If you select another time of day when the demand intervals are to be  
synchronized, the time must be in minutes from midnight. For example, to synchronize  
at 8:00 am, select 480 minutes. When setting up this type of demand, you select  
whether it will be clock-synchronized block or clock-synchronized rolling block demand.  
The rolling block demand requires that you choose a sub-interval.  
Thermal Demand  
The thermal demand method calculates the demand based on a thermal response, which  
mimics thermal demand meters. The demand calculation updates at the end of each  
interval. You select the demand interval from 1 to 60 minutes (in 1-minute increments). In  
Figure 4–5 the interval is set to 15 minutes for illustration purposes.  
Figure 4–5: Thermal Demand Example  
The interval is a window of time that moves across the timeline.  
99%  
90%  
Last completed  
demand interval  
0%  
Time  
(minutes)  
15-minute  
interval  
next  
15-minute  
interval  
Calculation updates at the end of each interval  
Demand Current  
The power meter calculates demand current using the thermal demand method. The  
default interval is 15 minutes, but you can set the demand current interval between 1 and  
60 minutes in 1-minute increments.  
32  
© 2011 Schneider Electric. All Rights Reserved.  
 
             
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
Predicted Demand  
The power meter calculates predicted demand for the end of the present interval for kW,  
kVAR, and kVA demand. This prediction takes into account the energy consumption thus  
far within the present (partial) interval and the present rate of consumption. The prediction  
is updated every second.  
Figure 4–6 illustrates how a change in load can affect predicted demand for the interval.  
Figure 4–6: Predicted Demand Example  
Predicted demand is updated every second.  
Beginning  
of interval  
15-minute interval  
Demand  
for last  
completed  
interval  
Predicted demand if load is  
added during interval;  
predicted demand increases  
to reflect increase demand  
Partial Interval  
Demand  
Predicted demand if no load  
is added.  
Time  
1:00  
1:06  
1:15  
Change in Load  
Peak Demand  
In non-volatile memory, the power meter maintains a running maximum for the kWD,  
kVARD, and kVAD power values, called “peak demand.” The peak for each value is the  
highest average reading since the meter was last reset. The power meter also stores the  
date and time when the peak demand occurred. In addition to the peak demand, the power  
meter also stores the coinciding average 3-phase power factor. The average 3-phase  
power factor is defined as “demand kW/demand kVA” for the peak demand interval.  
Table 4–2 on page 30 lists the available peak demand readings from the power meter.  
You can reset peak demand values from the power meter display. From the Main Menu,  
select MAINT > RESET > DMD. You can also reset the values over the communications  
link by using software.  
NOTE: You should reset peak demand after changes to basic meter setup, such as CT  
ratio or system type.  
The power meter also stores the peak demand during the last incremental energy interval.  
See “Energy Readings” on page 35 for more about incremental energy readings.  
Generic Demand  
The power meter can perform any of the demand calculation methods, described earlier in  
this chapter, on up to 10 quantities that you choose using PowerLogic software. For generic  
demand, do the following:  
Select the demand calculation method (thermal, block interval, or synchronized).  
Select the demand interval (from 5–60 minutes in 1–minute increments) and select  
the demand sub-interval (if applicable).  
Select the quantities on which to perform the demand calculation. You must also  
select the units and scale factor for each quantity.  
For each quantity in the demand profile, the power meter stores four values:  
Partial interval demand value  
Last completed demand interval value  
Minimum values (date and time for each is also stored)  
Peak demand value (date and time for each is also stored)  
33  
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PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
63230-500-225A2  
3/2011  
You can reset the minimum and peak values of the quantities in a generic demand profile  
by using one of two methods:  
Use PowerLogic software, or  
Use the command interface.  
Command 5115 resets the generic demand profile. See Appendix C—Using the  
Command Interface on page 83 for more about the command interface.  
Input Metering Demand  
The power meter has five input pulse metering channels, but only one digital input. Digital  
inputs can be added by installing one or more option modules (PM8M22, PM8M26, or  
PM8M2222). The input pulse metering channels count pulses received from one or more  
digital inputs assigned to that channel. Each channel requires a consumption pulse weight,  
consumption scale factor, demand pulse weight, and demand scale factor. The  
consumption pulse weight is the number of watt-hours or kilowatt-hours per pulse. The  
consumption scale factor is a factor of 10 multiplier that determines the format of the value.  
For example, if each incoming pulse represents 125 Wh, and you want consumption data in  
watt-hours, the consumption pulse weight is 125 and the consumption scale factor is zero.  
0
The resulting calculation is 125 x 10 , which equals 125 watt-hours per pulse. If you want  
-3  
the consumption data in kilowatt-hours, the calculation is 125 x 10 , which equals 0.125  
kilowatt-hours per pulse.Time must be taken into account for demand data; so you begin by  
calculating demand pulse weight using the following formula:  
watt-hours 3600 seconds  
pulse  
second  
--------------------------- ------------------------------------ ------------------  
watts =  
pulse  
hour  
If each incoming pulse represents 125 Wh, using the formula above you get 450,000 watts.  
If you want demand data in watts, the demand pulse weight is 450 and the demand scale  
3
factor is three. The calculation is 450 x 10 , which equals 450,000 watts. If you want the  
0
demand data in kilowatts, the calculation is 450 x 10 , which equals 450 kilowatts.  
NOTE: The power meter counts each input transition as a pulse. Therefore, an input  
transition of OFF-to-ON and ON-to-OFF will be counted as two pulses. For each channel,  
the power meter maintains the following information:  
Total consumption  
Last completed interval demand—calculated demand for the last completed interval.  
Partial interval demand—demand calculation up to the present point during the interval.  
Peak demand—highest demand value since the last reset of the input pulse demand.  
The date and time of the peak demand is also saved.  
Minimum demand—lowest demand value since the last reset of the input pulse  
demand. The date and time of the minimum demand is also saved.  
To use the channels feature, first use the display to set up the digital inputs (see “I/O  
(Input/Output) Setup” on page 18). Then using PowerLogic software, you must set the I/O  
operating mode to Normal and set up the channels. The demand method and interval that  
you select applies to all channels.  
34  
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PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
Energy Readings  
The power meter calculates and stores accumulated energy values for real and reactive  
energy (kWh and kVARh) both into and out of the load, and also accumulates absolute  
apparent energy. Table 4–3 lists the energy values the power meter can accumulate.  
Table 4–3: Energy Readings  
Energy Reading, 3-Phase  
Reportable Range  
Shown on the Display  
Accumulated Energy  
Real (Signed/Absolute)  
-9,999,999,999,999,999 to  
9,999,999,999,999,999 Wh  
Reactive (Signed/Absolute)  
-9,999,999,999,999,999 to  
9,999,999,999,999,999 VARh  
0000.000 kWh to 99,999.99 MWh  
and  
Real (In)  
0 to 9,999,999,999,999,999 Wh  
0 to 9,999,999,999,999,999 Wh  
0 to 9,999,999,999,999,999 VARh  
0 to 9,999,999,999,999,999 VARh  
0 to 9,999,999,999,999,999 VAh  
Real (Out)  
0000.000 to 99,999.99 MVARh  
Reactive (In)  
Reactive (Out)  
Apparent  
Accumulated Energy, Conditional  
Real (In)  
0 to 9,999,999,999,999,999 Wh  
0 to 9,999,999,999,999,999 Wh  
0 to 9,999,999,999,999,999 VARh  
0 to 9,999,999,999,999,999 VARh  
0 to 9,999,999,999,999,999 VAh  
These values not shown on the  
display. Readings are obtained  
only through the communications  
link.  
Real (Out)  
Reactive (In)  
Reactive (Out)  
Apparent  
Accumulated Energy, Incremental  
Real (In)  
0 to 999,999,999,999 Wh  
0 to 999,999,999,999 Wh  
0 to 999,999,999,999 VARh  
0 to 999,999,999,999 VARh  
0 to 999,999,999,999 VAh  
These values not shown on the  
display. Readings are obtained  
only through the communications  
link.  
Real (Out)  
Reactive (In)  
Reactive (Out)  
Apparent  
Reactive Energy  
Quadrant 1  
0 to 999,999,999,999 VARh  
0 to 999,999,999,999 VARh  
0 to 999,999,999,999 VARh  
0 to 999,999,999,999 VARh  
These values not shown on the  
display. Readings are obtained  
only through the communications  
link.  
Quadrant 2  
Quadrant 3  
Quadrant 4  
Not shown on the power meter display.  
The power meter can accumulate the energy values shown in Table 4–3 in one of two  
modes: signed or unsigned (absolute). In signed mode, the power meter considers the  
direction of power flow, allowing the magnitude of accumulated energy to increase and  
decrease. In unsigned mode, the power meter accumulates energy as a positive value,  
regardless of the direction of power flow. In other words, the energy value increases, even  
during reverse power flow. The default accumulation mode is unsigned.  
You can view accumulated energy from the display. The resolution of the energy value will  
automatically change through the range of 000.000 kWh to 000,000 MWh (000.000 kVAh  
to 000,000 MVARh), or it can be fixed. See Appendix C—Using the Command Interface  
on page 83 for the contents of the registers.  
For conditional accumulated energy readings, you can set the real, reactive, and apparent  
energy accumulation to OFF or ON when a particular condition occurs. You can do this over  
the communications link using a command, or from a digital input change. For example,  
you may want to track accumulated energy values during a particular process that is  
controlled by a PLC. The power meter stores the date and time of the last reset of  
conditional energy in non-volatile memory.  
35  
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PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
63230-500-225A2  
3/2011  
The power meter also provides an additional energy reading that is only available over the  
communications link:  
Four-quadrant reactive accumulated energy readings. The power meter  
accumulates reactive energy (kVARh) in four quadrants as shown in Figure 4–7. The  
registers operate in unsigned (absolute) mode in which the power meter accumulates  
energy as positive.  
Figure 4–7: Reactive energy accumulates in four quadrants  
Reactive  
Power In  
Quadrant  
2
Quadrant  
1
watts negative (–)  
vars positive (+)  
watts positive (+)  
vars positive (+)  
Reverse  
Normal  
Power Flow  
Real  
Power  
In  
Power Flow  
watts negative (–)  
vars negative (–)  
watts positive (+)  
vars negative (–)  
Quadrant  
3
Quadrant  
4
Energy-Per-Shift (PM810 with PM810LOG)  
The energy-per-shift feature allows the power meter to group energy usage based on three  
groups: 1st shift, 2nd shift, and 3rd shift. These groups provide a quick, historical view of  
energy usage and energy cost during each shift. All data is stored in non-volatile memory.  
Table 4–4: Energy-per-shift recorded values  
Category  
Recorded Values  
Today  
Yesterday  
This Week  
Last Week  
This Month  
Last Month  
Time Scales  
Real  
Apparent  
Energy  
Today  
Yesterday  
This Week  
Last Week  
This Month  
Last Month  
Energy Cost  
Meter Reading Date  
Meter Reading Time of Day  
1st Day of the Week  
User Configuration  
Configuration  
The start time of each shift is configured by setting registers using the display or by using  
PowerLogic software. Table 4-5 summarizes the quantities needed to configure energy-  
per-shift using register numbers.  
36  
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PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
Table 4–5: Energy-per-shift recorded values  
Quantity  
Register Number(s)  
Description  
For each shift, enter the minutes from  
midnight at which the shift starts.  
1st shift: 16171  
2nd shift: 16172  
3rd shift: 16173  
Defaults:  
Shift Start Time  
1st shift = 420 minutes (7:00 am)  
2nd shift = 900 minutes (3:00 pm)  
3rd shift = 1380 minutes (11:00 pm)  
1st shift: 16174  
2nd shift: 16175  
3rd shift: 16176  
Cost per kWHr  
Enter the cost per kWHr for each shift.  
The scale factor multiplied by the  
monetary units to determine the  
energy cost.  
Monetary Scale Factor  
16177  
Values: -3 to 3  
Default: 0  
Power Analysis Values  
The power meter provides a number of power analysis values that can be used to detect  
power quality problems, diagnose wiring problems, and more. Table 4–6 on page 38  
summarizes the power analysis values.  
THD. Total Harmonic Distortion (THD) is a quick measure of the total distortion present  
in a waveform and is the ratio of harmonic content to the fundamental. It provides a  
general indication of the “quality” of a waveform. THD is calculated for both voltage and  
current. The power meter uses the following equation to calculate THD, where H is the  
harmonic distortion:  
2
2
2
3
2
H
4
+
+
+
H
H
x
THD =  
100%  
H
1
thd. An alternate method for calculating Total Harmonic Distortion, used widely in  
Europe. It considers the total harmonic current and the total rms content rather than  
fundamental content in the calculation. The power meter calculates thd for both voltage  
and current. The power meter uses the following equation to calculate THD, where H is  
the harmonic distortion:  
2
2
2
+
+
+
H
H
H
2
3
4
x
100%  
thd =  
Total rms  
Displacement Power Factor. Power factor (PF) represents the degree to which  
voltage and current coming into a load are out of phase. Displacement power factor is  
based on the angle between the fundamental components of current and voltage.  
Harmonic Values. Harmonics can reduce the capacity of the power system. The power  
meter determines the individual per-phase harmonic magnitudes and angles for all  
currents and voltages through the:  
— 31st harmonic (PM810 with PM810Log, and PM820) or  
— 63rd harmonic (PM850, PM870)  
The harmonic magnitudes can be formatted as either a percentage of the fundamental  
(default), a percentage of the rms value, or the actual rms value. Refer to “Operation  
calculations.  
37  
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PowerLogicTM Series 800 Power Meter  
Chapter 4—Metering Capabilities  
63230-500-225A2  
3/2011  
Table 4–6: Power Analysis Values  
Value  
Reportable Range  
THD—Voltage, Current  
3-phase, per-phase, neutral  
thd—Voltage, Current  
0 to 3,276.7%  
3-phase, per-phase, neutral  
Fundamental Voltages (per phase)  
Magnitude  
0 to 3,276.7%  
0 to 1,200 kV  
0.0 to 359.9°  
Angle  
Fundamental Currents (per phase)  
Magnitude  
0 to 32,767 A  
0.0 to 359.9°  
Angle  
Miscellaneous  
Displacement P.F. (per phase, 3-phase)  
Phase Rotation  
–0.002 to 1.000 to +0.002  
ABC or CBA  
Unbalance (current and voltage) ➀  
Individual Current and Voltage Harmonic Magnitudes ➁  
Individual Current and Voltage Harmonic Angles ➁  
Readings are obtained only through communications.  
0.0 to 100.0%  
0 to 327.67%  
0.0° to 359.9°  
Current and Voltage Harmonic Magnitude and Angles 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, and 13 are shown on the  
display.  
38  
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PowerLogicTM Series 800 Power Meter  
Chapter 5—Input/Output Capabilities  
Chapter 5—Input/Output Capabilities  
Digital Inputs  
The power meter includes one solid-state digital input. A digital input is used to detect  
digital signals. For example, the digital input can be used to determine circuit breaker  
status, count pulses, or count motor starts. The digital input can also be associated with an  
external relay. You can log digital input transitions as events in the power meter’s on-board  
alarm log. The event is date and time stamped with resolution to the second. The power  
meter counts OFF-to-ON transitions for each input. You can view the count for each input  
using the Digital Inputs screen, and you can reset this value using the command interface.  
Figure 5–1 is an example of the Digital Inputs screen.  
Figure 5–1: Digital Inputs Screen  
A. Lit bargraph indicates that the input is  
ON. For analog inputs or outputs, the  
bargraph indicates the output  
  
percentage.  
A
B. SI is common to all meters and  
  
represents standard digital input.  
  
  
  
  
C. A-S1 and A-S2 represent I/O point  
numbers on the first (A) module.  
D. Use the arrow buttons to scroll through  
  
B
  
  
the remaining I/O points. Point numbers  
beginning with “B” are on the second  
module.  
  
 C  
  
  
D     
  
  
The digital input has three operating modes:  
Normal—Use the normal mode for simple on/off digital inputs. In normal mode, digital  
inputs can be used to count KY pulses for demand and energy calculation.  
Demand Interval Synch Pulse—you can configure any digital input to accept a  
demand synch pulse from a utility demand meter (see “Demand Synch Pulse Input” on  
page 40 of this chapter for more about this topic). For each demand profile, you can  
designate only one input as a demand synch input.  
Conditional Energy Control—you can configure one digital input to control conditional  
4—Metering Capabilities for more about conditional energy).  
NOTE: By default, the digital input is named DIG IN S02 and is set up for normal mode.  
For custom setup, use PowerLogic software to define the name and operating mode of the  
digital input. The name is a 16-character label that identifies the digital input. The operating  
mode is one of those listed above.  
39  
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PowerLogicTM Series 800 Power Meter  
Chapter 5—Input/Output Capabilities  
63230-500-225A2  
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Demand Synch Pulse Input  
You can configure the power meter to accept a demand synch pulse from an external  
source, such as another demand meter. By accepting demand synch pulses through a  
digital input, the power meter can make its demand interval “window” match the other  
meter’s demand interval “window.” The power meter does this by “watching” the digital  
input for a pulse from the other demand meter. When it sees a pulse, it starts a new  
demand interval and calculates the demand for the preceding interval. The power meter  
then uses the same time interval as the other meter for each demand calculation. Figure  
Capabilities for more about demand calculations.  
When in demand synch pulse operating mode, the power meter will not start or stop a  
demand interval without a pulse. The maximum allowable time between pulses is 60  
minutes. If 66 minutes (110% of the demand interval) pass before a synch pulse is  
received, the power meter throws out the demand calculations and begins a new  
calculation when the next pulse is received. Once in synch with the billing meter, the power  
meter can be used to verify peak demand charges.  
Important facts about the power meter’s demand synch feature are listed below:  
Any installed digital input can be set to accept a demand synch pulse.  
Each system can choose whether to use an external synch pulse, but only one demand  
synch pulse can be brought into the meter for each demand system. One input can be  
used to synchronize any combination of the demand systems.  
The demand synch feature can be set up using PowerLogic software.  
Figure 5–2: Demand synch pulse timing  
Normal Demand Mode  
External Synch Pulse Demand Timing  
Billing Meter  
Billing Meter  
Demand Timing  
Demand Timing  
Utility Meter  
Synch Pulse  
Power Meter  
Demand Timing  
(Slave to Master)  
Power Meter  
Demand Timing  
Relay Output Operating Modes  
The relay output defaults to external control, but you can choose whether the relay is set to  
external or internal control:  
External (remote) control—the relay is controlled either from a PC using PowerLogic  
software or a programmable logic controller using commands via communications.  
Power meter alarm (internal) control—the relay is controlled by the power meter in  
response to a set-point controlled alarm condition, or as a pulse initiator output. Once  
you’ve set up a relay for power meter control, you can no longer operate the relay  
remotely. However, you can temporarily override the relay, using PowerLogic software.  
NOTE: If any basic setup parameters or I/O setup parameters are modified, all relay  
outputs will be de-energized.  
The 11 relay operating modes are as follows:  
Normal  
Externally Controlled: Energize the relay by issuing a command from a remote PC  
or programmable controller. The relay remains energized until a command to de-  
energize is issued from the remote PC or programmable controller, or until the  
40  
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PowerLogicTM Series 800 Power Meter  
Chapter 5—Input/Output Capabilities  
power meter loses control power. When control power is restored, the relay is not  
automatically re-energized.  
Power Meter Alarm: When an alarm condition assigned to the relay occurs, the  
relay is energized. The relay is not de-energized until all alarm conditions assigned  
to the relay have dropped out, the power meter loses control power, or the alarms  
are over-ridden using PowerLogic software. If the alarm condition is still true when  
the power meter regains control power, the relay will be re-energized.  
Latched  
Remotely Controlled: Energize the relay by issuing a command from a remote PC  
or programmable controller. The relay remains energized until a command to de-  
energize is issued from a remote PC or programmable controller, or until the power  
meter loses control power. When control power is restored, the relay will not be re-  
energized.  
Power Meter Controlled: When an alarm condition assigned to the relay occurs,  
the relay is energized. The relay remains energized—even after all alarm conditions  
assigned to the relay have dropped out—until a command to de-energize is issued  
from a remote PC or programmable controller, until the high priority alarm log is  
cleared from the display, or until the power meter loses control power. When control  
power is restored, the relay will not be re-energized if the alarm condition is not  
TRUE.  
Timed  
Remotely Controlled: Energize the relay by issuing a command from a remote PC  
or programmable controller. The relay remains energized until the timer expires, or  
until the power meter loses control power. If a new command to energize the relay is  
issued before the timer expires, the timer restarts. If the power meter loses control  
power, the relay will not be re-energized when control power is restored and the  
timer will reset to zero.  
Power Meter Controlled: When an alarm condition assigned to the relay occurs, the  
relay is energized. The relay remains energized for the duration of the timer. When  
the timer expires, the relay will de-energize and remain de-energized. If the relay is  
on and the power meter loses control power, the relay will not be re-energized when  
control power is restored and the timer will reset to zero.  
End Of Power Demand Interval  
This mode assigns the relay to operate as a synch pulse to another device. The output  
operates in timed mode using the timer setting and turns on at the end of a power  
demand interval. It turns off when the timer expires.  
Absolute kWh Pulse  
This mode assigns the relay to operate as a pulse initiator with a user-defined number  
of kWh per pulse. In this mode, both forward and reverse real energy are treated as  
additive (as in a tie circuit breaker).  
Absolute kVARh Pulse  
This mode assigns the relay to operate as a pulse initiator with a user-defined number  
of kVARh per pulse. In this mode, both forward and reverse reactive energy are treated  
as additive (as in a tie circuit breaker).  
kVAh Pulse  
This mode assigns the relay to operate as a pulse initiator with a user-defined number  
of kVAh per pulse. Since kVA has no sign, the kVAh pulse has only one mode.  
kWh In Pulse  
This mode assigns the relay to operate as a pulse initiator with a user-defined number  
of kWh per pulse. In this mode, only the kWh flowing into the load is considered.  
kVARh In Pulse  
This mode assigns the relay to operate as a pulse initiator with a user-defined number  
of kVARh per pulse. In this mode, only the kVARh flowing into the load is considered.  
41  
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PowerLogicTM Series 800 Power Meter  
Chapter 5—Input/Output Capabilities  
63230-500-225A2  
3/2011  
kWh Out Pulse  
This mode assigns the relay to operate as a pulse initiator with a user-defined number  
of kWh per pulse. In this mode, only the kWh flowing out of the load is considered.  
kVARh Out Pulse  
This mode assigns the relay to operate as a pulse initiator with a user-defined number  
of kVARh per pulse. In this mode, only the kVARh flowing out of the load is considered.  
The last seven modes in the list above are for pulse initiator applications. All Series 800  
Power Meters are equipped with one solid-state KY pulse output rated at 100 mA. The  
solid-state KY output provides the long life—billions of operations—required for pulse  
initiator applications.  
The KY output is factory configured with Name = KY, Mode = Normal, and Control =  
External. To set up custom values, press SETUP > I/O. For detailed instructions, see “I/O  
(Input/Output) Setup” on page 18. Then using PowerLogic software, you must define the  
following values for each mechanical relay output:  
Name—A 16-character label used to identify the digital output.  
Mode—Select one of the operating modes listed above.  
Pulse Weight—You must set the pulse weight, the multiplier of the unit being  
measured, if you select any of the pulse modes (last 7 listed above).  
Timer—You must set the timer if you select the timed mode or end of power demand  
interval mode (in seconds).  
Control—You must set the relay to be controlled either remotely or internally (from the  
power meter) if you select the normal, latched, or timed mode.  
For instructions on setting up digital I/Os using software, see your software documentation  
or help file.  
Solid-state KY Pulse Output  
This section describes the pulse output capabilities of the power meter. For instructions on  
wiring the KY pulse output, see “Wiring the Solid-State KY Output” in the installation guide.  
The power meter’s digital output is generated by a solid-state device that can be used as a  
KY pulse output. This solid-state relay provides the extremely long life—billions of  
operations—required for pulse initiator applications.  
The KY output is a Form-A contact with a maximum rating of 100 mA. Because most pulse  
initiator applications feed solid-state receivers with low burdens, this 100 mA rating is  
adequate for most applications.  
When setting the kWh/pulse value, set the value based on a 2-wire pulse output. For  
instructions on calculating the correct value, see “Calculating the Kilowatthour-Per-Pulse  
Value” on page 43 in this chapter.  
The KY pulse output can be configured to operate in one of 11 operating modes. See  
2-wire Pulse Initiator  
Figure 5–3 shows a pulse train from a 2-wire pulse initiator application.  
Figure 5–3: Two-wire pulse train  
Y
K
3
1
2
KY  
ΔT  
42  
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PowerLogicTM Series 800 Power Meter  
Chapter 5—Input/Output Capabilities  
In Figure 5–3, the transitions are marked as 1 and 2. Each transition represents the time  
when the relay contact closes. Each time the relay transitions, the receiver counts a pulse.  
The power meter can deliver up to 12 pulses per second in a 2-wire application.  
Fixed Pulse Output  
Fixed pulse output mode generates a fixed duration pulse output that can be associated  
with kWh consumption. Figure 5–4 shows the difference in pulse duration values when  
either TRANS mode or PULSE mode is selected. This mode selection is configured on the  
MAINT > IO > ADVAN menu.  
Figure 5–4: Fixed-pulse output  
TRANS & PULSE mode  
Pulse Weight = 0.02kWHr/pulse  
TRANS mode:  
Counts = 4  
Setting in ADV mode:  
10, 25, 50, 100, 150,  
200, 300, 500, 1000  
100 msec  
PULSE mode (100ms):  
Counts = 8  
0.02kW  
0.04kW  
0.06kW  
0.08kW  
0.1kW  
0.12kW  
0.14kW  
0.16kW  
Calculating the Kilowatthour-Per-Pulse Value  
The following example illustrates how to calculate kilowatthours per pulse (pulse weight).  
To calculate this value, first determine the highest kW value you can expect and the  
required pulse rate. Remember the maximum number of pulses is 8 per second.  
In this example, the following conditions are set:  
The metered load should not exceed 1600 kW.  
About two KY pulses per second should normally occur. (If a higher load is reached, the  
number of pulses per second can increase and still stay within the set limits.)  
Step 1: Convert 1600 kW load into kWh/second.  
(1600 kW)(1 Hr) = 1600 kWh  
(1600 kWh)  
1 hour  
X kWh  
1 second  
------------------------------ = -----------------------  
(1600 kWh)  
3600 seconds  
X kWh  
1 second  
------------------------------------ = -----------------------  
X = 1600/3600 = 0.444 kWh/second  
Step 2: Calculate the kWh required per pulse.  
0.444 kWh/second  
------------------------------------------------- = 0 . 2 2 2 kW h / p u l s e  
2 pulses/second  
Step 3: Adjust for the KY initiator (KY will give one pulse per two transitions of the relay).  
43  
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PowerLogicTM Series 800 Power Meter  
Chapter 5—Input/Output Capabilities  
63230-500-225A2  
3/2011  
0.222 kWh/second  
------------------------------------------------- = 0 . 1 1 1 1 kW h / p u ls e  
2
Step 4: Round to nearest hundredth, since the power meter only accepts 0.01 kWh  
increments.  
Pulse Weight (Ke) = 0.11 kWh/pulse  
Analog Inputs  
With a PM8M2222 option module installed, a power meter can accept either voltage or  
current signals through the analog inputs on the option module. The power meter stores a  
minimum and a maximum value for each analog input.  
For technical specifications and instructions on installing and configuring the analog inputs  
on the PM8M2222, refer to the instruction bulletin (63230-502-200) that ships with the  
option module. To set up an analog input, you must first set it up from the display. From the  
SUMMARY screen, select MAINT > SETUP > I/O, then select the appropriate analog input  
option. Then, in PowerLogic software, define the following values for each analog input:  
Name—a 16-character label used to identify the analog input.  
Units—the units of the monitored analog value (for example, “psi”).  
Scale factor—multiplies the units by this value (such as tenths or hundredths).  
Report Range Lower Limit—the value the Power Meter reports when the input  
reaches a minimum value. When the input current is below the lowest valid reading, the  
Power Meter reports the lower limit.  
Report Range Upper Limit—the value the power meter reports when the input  
reaches the maximum value. When the input current is above highest valid reading, the  
Power Meter reports the upper limit.  
For instructions on setting up analog inputs using software, see your software  
documentation or Help file.  
Analog Outputs  
This section describes the analog output capabilities when a PM8M2222 is installed on the  
Power Meter. For technical specifications and instructions on installing and configuring the  
analog outputs on the PM8M2222, refer to the instruction bulletin (63230-502-200) that  
ships with the option module.  
To set up an analog output, you must first set it up from the display. From the SUMMARY  
screen, select MAINT > SETUP > I/O, then select the appropriate analog output option.  
Then, in PowerLogic software, define the following values for each analog input  
Name—a 16-character label used to identify the output. Default names are assigned,  
but can be customized  
Output register—the Power Meter register assigned to the analog output.  
Lower Limit—the value equivalent to the minimum output current. When the register  
value is below the lower limit, the Power Meter outputs the minimum output current.  
Upper Limit—the value equivalent to the maximum output current. When the register  
value is above the upper limit, the Power Meter outputs the maximum output current.  
For instructions on setting up an analog output using software, see your software  
documentation or Help file.  
44  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
Chapter 6—Alarms  
This section describes the alarm features on all Series 800 Power Meters. For information  
about advanced alarm features, go to “Advanced Alarms” on page 53.  
Basic Alarms  
The power meter can detect over 50 alarm conditions, including over or under conditions,  
digital input changes, phase unbalance conditions, and more. It also maintains a counter  
for each alarm to keep track of the total number of occurrences. A complete list of default  
basic alarm configurations are described in Table 6–5 on page 51 . In addition, you can set  
up your own custom alarms after installing an input/output module (PM8M22, PM8M26, or  
PM8M2222).  
When one or more alarm conditions are true, the power meter will execute a task  
automatically. When an alarm is active, the !alarm icon appears in the upper-right corner  
of the power meter display. If a PM810LOG is installed on a PM810, PowerLogic software  
can be used to set up each alarm condition to force data log entries in a single data log file.  
For the PM820, PM850, and PM870 PowerLogic software can be used to set up each  
alarm condition to force data log entries in up to three user-defined data log files. See  
Chapter 7—Logging on page 57 for more about data logging.  
NOTE: PM820 only supports one data log.  
Table 6–1: Basic alarm features by model  
PM810 with  
Basic Alarm Feature  
PM810  
PM820  
PM850  
PM870  
PM810LOG  
Standard alarms  
33  
33  
33  
7
33  
7
33  
7
Open slots for additional  
standard alarms  
7
7
Digital  
12  
12  
12  
12  
12  
Custom alarms  
No  
No  
Yes  
Yes  
Yes  
Available when an I/O module with analog IN/OUT is installed.  
Requires an input/output option module (PM8M22, PM8M26, or the PM8M2222).  
Basic Alarm Groups  
When using a default alarm, you first choose the alarm group that is appropriate for the  
application. Each alarm condition is assigned to one of these alarm groups:  
Whether you are using a default alarm or creating a custom alarm, you first choose the  
alarm group that is appropriate for the application. Each alarm condition is assigned to one  
of these alarm groups:  
Standard—Standard alarms have a detection rate of 1 second and are useful for  
detecting conditions such as over current and under voltage. Up to 40 alarms can be  
set up in this alarm group.  
Digital—Digital alarms are triggered by an exception such as the transition of a digital  
input or the end of an incremental energy interval. Up to 12 alarms can be set up in this  
group.  
Custom—The power meter has many pre-defined alarms, but you can also set up your  
own custom alarms using PowerLogic software. For example, you may need to alarm  
on the ON-to-OFF transition of a digital input. To create this type of custom alarm:  
1. Select the appropriate alarm group (digital in this case).  
2. Select the type of alarm (described in Table 6–6 on page 52 ).  
3. Give the alarm a name.  
4. Save the custom alarm.  
After creating a custom alarm, you can configure it by applying priorities, setting pickups  
and dropouts (if applicable), and so forth.  
Both the power meter display and PowerLogic software can be used to set up standard,  
digital, and custom alarm types.  
45  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
63230-500-225A2  
3/2011  
Setpoint-driven Alarms  
Many of the alarm conditions require that you define setpoints. This includes all alarms for  
over, under, and phase unbalance alarm conditions. Other alarm conditions such as digital  
input transitions and phase reversals do not require setpoints. For those alarm conditions  
that require setpoints, you must define the following information:  
Pickup Setpoint  
Pickup Delay  
Dropout Setpoint  
Dropout Delay  
NOTE: Alarms with both Pickup and Dropout setpoints set to zero are invalid.  
The following two figures will help you understand how the power meter handles setpoint-  
driven alarms. Figure 6–1 shows what the actual alarm Log entries for Figure 6–2 might  
look like, as displayed by PowerLogic software.  
NOTE: The software does not actually display the codes in parentheses—EV1, EV2, Max1,  
Max2. These are only references to the codes in Figure 6–2.  
Figure 6–1: Sample alarm log entry  
(EV2)  
(Max2)  
(EV1)  
(Max1)  
Figure 6–2: How the power meter handles setpoint-driven alarms  
Max2  
Max1  
Pickup  
Setpoint  
Dropout  
Setpoint  
Pickup Delay  
Dropout Delay  
EV2  
EV1  
Alarm Period  
EV1—The power meter records the date and time that the pickup setpoint and time delay  
were satisfied, and the maximum value reached (Max1) during the pickup delay period  
(T). Also, the power meter performs any tasks assigned to the event such as waveform  
captures or forced data log entries.  
EV2—The power meter records the date and time that the dropout setpoint and time delay  
were satisfied, and the maximum value reached (Max2) during the alarm period.  
The power meter also stores a correlation sequence number (CSN) for each event (such as  
Under Voltage Phase A Pickup, Under Voltage Phase A Dropout). The CSN lets you relate  
pickups and dropouts in the alarm log. You can sort pickups and dropouts by CSN to  
correlate the pickups and dropouts of a particular alarm. The pickup and dropout entries of  
an alarm will have the same CSN. You can also calculate the duration of an event by  
looking at pickups and dropouts with the same CSN.  
46  
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63230-500-225A2  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
Priorities  
Each alarm also has a priority level. Use the priorities to distinguish between events that  
require immediate action and those that do not require action.  
High priority—if a high priority alarm occurs, the display informs you in two ways: the  
LED backlight on the display flashes until you acknowledge the alarm and the alarm  
icon blinks while the alarm is active.  
Medium priority—if a medium priority alarm occurs, the alarm icon blinks only while  
the alarm is active. Once the alarm becomes inactive, the alarm icon stops blinking and  
remains on the display.  
Low priority—if a low priority alarm occurs, the alarm icon blinks only while the alarm is  
active. Once the alarm becomes inactive, the alarm icon disappears from the display.  
No priority—if an alarm is set up with no priority, no visible representation will appear  
on the display. Alarms with no priority are not entered in the Alarm Log. See Chapter  
7—Logging for alarm logging information.  
If multiple alarms with different priorities are active at the same time, the display shows the  
alarm message for the last alarm that occurred. For instructions on setting up alarms from  
the power meter display, see “ALARM (Alarms) Setup” on page 17.  
Viewing Alarm Activity and History  
1. Press ###:until ALARM is visible.  
2. Press ALARM.  
ꢝꢬꢄꢇꢆꢬꢔꢕ  
ꢌꢍꢇꢆꢉ  
ꢉꢀꢁ  
ꢂꢅꢆ  
ꢆꢄꢇꢀꢁꢇꢆꢄ  
ꢑꢆ  
3. View the active alarm listed on the power  
meter display. If there are no active  
alarms, the screen reads, “NO ACTIVE  
ALARM.”  
ꢁꢊꢃꢚꢌ  
4. If there are active alarms, press  
ꢋꢫꢰꢻ  
<--or -->to view a different alarm.  
5. Press HIST.  
ꢳꢖ  
6. Press <--or -->to view a different  
ꢈꢉ  
ꢙꢍꢍ  
ꢍꢍꣅ  
ꢂꢔꢚꢊꢬ  
alarm’s history.  
7. Press 1;to return to the SUMMARY  
screen.  
Types of Setpoint-controlled Functions  
This section describes some common alarm functions to which the following information  
applies:  
Values that are too large to fit into the display may require scale factors. For more  
information on scale factors, refer to “Changing Scale Factors” on page 91.  
Relays can be configured as normal, latched, or timed. See “Relay Output Operating  
Modes” on page 40 for more information.  
When the alarm occurs, the power meter operates any specified relays. There are two  
ways to release relays that are in latched mode:  
— Issue a command to de-energize a relay. See Appendix C—Using the Command  
Interface on page 83 for instructions on using the command interface, or  
— Acknowledge the alarm in the high priority log to release the relays from latched  
mode. From the main menu of the display, press ALARM to view and acknowledge  
unacknowledged alarms.  
The list that follows shows the types of alarms available for some common alarm functions:  
NOTE: Voltage based alarm setpoints depend on your system configuration. Alarm  
setpoints for 3-wire systems are V values while 4-wire systems are V  
values.  
L-L  
L-N  
47  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
63230-500-225A2  
3/2011  
Under-voltage: Pickup and dropout setpoints are entered in volts. The per-phase under-  
voltage alarm occurs when the per-phase voltage is equal to or below the pickup setpoint  
long enough to satisfy the specified pickup delay (in seconds). The under-voltage alarm  
clears when the phase voltage remains above the dropout setpoint for the specified dropout  
delay period.  
Over-voltage: Pickup and dropout setpoints are entered in volts. The per-phase over-  
voltage alarm occurs when the per-phase voltage is equal to or above the pickup setpoint  
long enough to satisfy the specified pickup delay (in seconds). The over-voltage alarm  
clears when the phase voltage remains below the dropout setpoint for the specified dropout  
delay period.  
Unbalance Current: Pickup and dropout setpoints are entered in tenths of percent, based  
on the percentage difference between each phase current with respect to the average of all  
phase currents. For example, enter an unbalance of 7% as 70. The unbalance current  
alarm occurs when the phase current deviates from the average of the phase currents, by  
the percentage pickup setpoint, for the specified pickup delay. The alarm clears when the  
percentage difference between the phase current and the average of all phases remains  
below the dropout setpoint for the specified dropout delay period.  
Unbalance Voltage: Pickup and dropout setpoints are entered in tenths of percent, based  
on the percentage difference between each phase voltage with respect to the average of all  
phase voltages. For example, enter an unbalance of 7% as 70. The unbalance voltage  
alarm occurs when the phase voltage deviates from the average of the phase voltages, by  
the percentage pickup setpoint, for the specified pickup delay. The alarm clears when the  
percentage difference between the phase voltage and the average of all phases remains  
below the dropout setpoint for the specified dropout delay (in seconds).  
Phase Loss—Current: Pickup and dropout setpoints are entered in amperes. The phase  
loss current alarm occurs when any current value (but not all current values) is equal to or  
below the pickup setpoint for the specified pickup delay (in seconds). The alarm clears  
when one of the following is true:  
All of the phases remain above the dropout setpoint for the specified dropout delay, or  
All of the phases drop below the phase loss pickup setpoint.  
If all of the phase currents are equal to or below the pickup setpoint, during the pickup  
delay, the phase loss alarm will not activate. This is considered an under current condition.  
It should be handled by configuring the under current alarm functions.  
Phase Loss—Voltage: Pickup and dropout setpoints are entered in volts. The phase loss  
voltage alarm occurs when any voltage value (but not all voltage values) is equal to or  
below the pickup setpoint for the specified pickup delay (in seconds). The alarm clears  
when one of the following is true:  
All of the phases remain above the dropout setpoint for the specified dropout delay (in  
seconds), OR  
All of the phases drop below the phase loss pickup setpoint.  
If all of the phase voltages are equal to or below the pickup setpoint, during the pickup  
delay, the phase loss alarm will not activate. This is considered an under voltage condition.  
It should be handled by configuring the under voltage alarm functions.  
Reverse Power: Pickup and dropout setpoints are entered in kilowatts or kVARs. The  
reverse power alarm occurs when the power flows in a negative direction and remains at or  
below the negative pickup value for the specified pickup delay (in seconds). The alarm  
clears when the power reading remains above the dropout setpoint for the specified  
dropout delay (in seconds).  
Phase Reversal: Pickup and dropout setpoints do not apply to phase reversal. The phase  
reversal alarm occurs when the phase voltage rotation differs from the default phase  
rotation. The power meter assumes that an ABC phase rotation is normal. If a CBA phase  
rotation is normal, the user must change the power meter’s phase rotation from ABC  
(default) to CBA. To change the phase rotation from the display, from the main menu select  
Setup > Meter > Advanced. For more information about changing the phase rotation setting  
48  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
Scale Factors  
A scale factor is the multiplier expressed as a power of 10. For example, a multiplier of 10 is  
1
represented as a scale factor of 1, since 10 =10; a multiplier of 100 is represented as a  
2
scale factor of 2, since 10 =100. This allows you to make larger values fit into the register.  
Normally, you do not need to change scale factors. If you are creating custom alarms, you  
need to understand how scale factors work so that you do not overflow the register with a  
number larger than what the register can hold. When PowerLogic software is used to set up  
alarms, it automatically handles the scaling of pickup and dropout setpoints. When creating  
a custom alarm using the power meter’s display, do the following:  
Determine how the corresponding metering value is scaled, and  
Take the scale factor into account when entering alarm pickup and dropout settings.  
Pickup and dropout settings must be integer values in the range of -32,767 to +32,767. For  
example, to set up an under voltage alarm for a 138 kV nominal system, decide upon a  
setpoint value and then convert it into an integer between -32,767 and +32,767. If the under  
voltage setpoint were 125,000 V, this would typically be converted to 12500 x 10 and  
entered as a setpoint of 12500.  
Six scale groups are defined (A through F). The scale factor is preset for all factory-  
configured alarms. Table 6–2 lists the available scale factors for each of the scale groups.  
If you need either an extended range or more resolution, select any of the available scale  
factors to suit your need. Refer to “Changing Scale Factors” on page 91 of  
Appendix C—Using the Command Interface.  
Table 6–2: Scale Groups  
Scale Group  
Measurement Range  
Scale Factor  
Amperes  
0–327.67 A  
–2  
Scale Group A—Phase Current  
0–3,276.7 A  
–1  
0–32,767 A  
0 (default)  
1
0–327.67 kA  
Amperes  
0–327.67 A  
–2  
Scale Group B—Neutral Current  
0–3,276.7 A  
–1  
0–32,767 A  
0 (default)  
1
0–327.67 kA  
Voltage  
0–3,276.7 V  
–1  
Scale Group D—Voltage  
0–32,767 V  
0 (default)  
0–327.67 kV  
1
2
0–3,276.7 kV  
Power  
0–32.767 kW, kVAR, kVA  
0–327.67 kW, kVAR, kVA  
0–3,276.7 kW, kVAR, kVA  
0–32,767 kW, kVAR, kVA  
0–327.67 MW, MVAR, MVA  
0–3,276.7 MW, MVAR, MVA  
0–32,767 MW, MVAR, MVA  
–3  
–2  
–1  
Scale Group F—Power kW, kVAR, kVA  
0 (default)  
1
2
3
49  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
63230-500-225A2  
3/2011  
Scaling Alarm Setpoints  
This section is for users who do not have PowerLogic software and need to set up alarms  
from the power meter display. It explains how to scale alarm setpoints.  
When the power meter is equipped with a display, most metered quantities are limited to  
five characters (plus a positive or negative sign). The display will also show the engineering  
units applied to that quantity.  
To determine the proper scaling of an alarm setpoint, view the register number for the  
associated scale group. The scale factor is the number in the Dec column for that register.  
For example, the register number for Scale D to Phase Volts is 3212. If the number in the  
1
Dec column is 1, the scale factor is 10 (10 =10). Remember that scale factor 1 in  
Table 6–3 on page 50 for Scale Group D is measured in kV. Therefore, to define an alarm  
setpoint of 125 kV, enter 12.5 because 12.5 multiplied by 10 is 125. Below is a table listing  
the scale groups and their register numbers.  
Table 6–3: Scale Group Register Numbers  
Scale Group  
Register Number  
Scale Group A—Phase Current  
3209  
3210  
3211  
3212  
3214  
Scale Group B—Neutral Current  
Scale Group C—Ground Current  
Scale Group D—Voltage  
Scale Group F—Power kW, kVAR, kVA  
Alarm Conditions and Alarm Numbers  
This section lists the power meter’s predefined alarm conditions. For each alarm condition,  
the following information is provided.  
Alarm No.—a position number indicating where an alarm falls in the list.  
Alarm Description—a brief description of the alarm condition  
Abbreviated Display Name—an abbreviated name that describes the alarm condition  
but is limited to 15 characters that fit in the window of the power meter’s display.  
Test Register—the register number that contains the value (where applicable) that is  
used as the basis for a comparison to alarm pickup and dropout settings.  
Units—the unit that applies to the pickup and dropout settings.  
Scale Group—the scale group that applies to the test register’s metering value (A–F).  
For a description of scale groups, see “Scale Factors” on page 49.  
Alarm Type—a reference to a definition that provides details on the operation and  
configuration of the alarm. For a description of alarm types, refer to Table 6–6 on page  
Table 6– 4 lists the default alarm configuration - factory-enabled alarms.  
Table 6– 5 lists the default basic alarms by alarm number.  
Table 6– 6 lists the alarm types.  
Table 6–4: Default Alarm Configuration - Factory-enabled Alarms  
Pickup  
Dropout  
Limit Time  
Delay  
Alarm  
No.  
Pickup  
Limit  
Dropout  
Limit  
Standard Alarm  
Limit Time  
Delay  
19  
20  
53  
55  
Voltage Unbalance L-N  
20 (2.0%)  
300  
300  
0
20 (2.0%)  
300  
300  
0
Max. Voltage Unbalance L-L  
End of Incremental Energy Interval  
Power-up Reset  
20 (2.0%)  
20 (2.0%)  
0
0
0
0
0
0
50  
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63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
Table 6–5: List of Default Basic Alarms by Alarm Number  
Alarm  
Number  
Abbreviated  
Display Name Register  
Test  
Scale Alarm  
Group Type  
Alarm Description  
Units  
Standard Speed Alarms (1 Second)  
01  
02  
03  
04  
05  
06  
07  
08  
09  
10  
11  
12  
13  
14  
15  
16  
17  
18  
19  
20  
Over Current Phase A  
Over Current Phase B  
Over Current Phase C  
Over Current Neutral  
Over Ia  
1100  
1101  
1102  
1103  
1110  
3262  
1124  
1125  
1126  
1120  
1121  
1122  
1124  
1125  
1126  
1120  
1121  
1122  
1136  
1132  
Amperes  
Amperes  
Amperes  
Amperes  
Tenths %  
Amperes  
Volts  
A
A
010  
010  
010  
010  
010  
053  
010  
010  
010  
010  
010  
010  
020  
020  
020  
020  
020  
020  
010  
010  
Over Ib  
Over Ic  
A
Over In  
B
Current Unbalance, Max  
Current Loss  
I Unbal Max  
Current Loss  
Over Van  
A
Over Voltage Phase A–N  
Over Voltage Phase B–N  
Over Voltage Phase C–N  
Over Voltage Phase A–B  
Over Voltage Phase B–C  
Over Voltage Phase C–A  
Under Voltage Phase A  
Under Voltage Phase B  
Under Voltage Phase C  
Under Voltage Phase A–B  
Under Voltage Phase B–C  
Under Voltage Phase C–A  
Voltage Unbalance L–N, Max  
Voltage Unbalance L–L, Max  
D
D
D
D
D
D
D
D
D
D
D
D
Over Vbn  
Volts  
Over Vcn  
Volts  
Over Vab  
Over Vbc  
Volts  
Volts  
Over Vca  
Volts  
Under Van  
Under Vbn  
Under Vcn  
Under Vab  
Under Vbc  
Under Vca  
V Unbal L-N Max  
V Unbal L-L Max  
Volts  
Volts  
Volts  
Volts  
Volts  
Volts  
Tenths %  
Tenths %  
Voltage Loss (loss of A,B,C, but  
not all)  
21  
Voltage Loss  
3262  
Volts  
D
052  
22  
23  
24  
25  
26  
27  
28  
29  
30  
31  
32  
33  
Phase Reversal  
Phase Rev  
3228  
2151  
1163  
1207  
1208  
1209  
1211  
1212  
1213  
2181  
1143  
1151  
kW  
F
051  
011  
055  
010  
010  
010  
010  
010  
010  
011  
011  
011  
Over kW Demand  
Over kW Dmd  
Lag True PF  
Lagging true power factor  
Thousandths  
Tenths %  
Tenths %  
Tenths %  
Tenths %  
Tenths %  
Tenths %  
kVA  
F
Over THD of Voltage Phase A–N Over THD Van  
Over THD of Voltage Phase B–N Over THD Vbn  
Over THD of Voltage Phase C–N Over THD Vcn  
Over THD of Voltage Phase A–B Over THD Vab  
Over THD of Voltage Phase B–C Over THD Vbc  
Over THD of Voltage Phase C–A Over THD Vca  
Over kVA Demand  
Over kW Total  
Over kVA Dmd  
Over kW Total  
Over kVA Total  
kW  
F
Over kVA Total  
kVA  
F
Reserved for additional analog  
alarms ➂  
34-40  
34-40  
Reserved for custom alarms.  
Digital  
End of incremental energy  
interval  
01  
End Inc Enr Int  
N/A  
070  
02  
03  
04  
End of power demand interval  
Power up/Reset  
End Dmd Int  
Pwr Up/Reset  
DIG IN S02  
N/A  
N/A  
2
070  
070  
060  
Digital Input OFF/ON  
Reserved for additional digital  
alarms ➂  
05-12  
05-12  
Reserved for custom alarms  
Scale groups are described in Table 6–2 on page 49 .  
Alarm types are described in Table 6–6 on page 52 .  
Additional analog and digital alarms require a corresponding I/O module to be installed.  
51  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
63230-500-225A2  
3/2011  
Table 6–6: Alarm Types  
Type Description  
Operation  
Standard Speed  
If the test register value exceeds the setpoint long enough to satisfy the pickup  
delay period, the alarm condition will be true. When the value in the test register  
falls below the dropout setpoint long enough to satisfy the dropout delay period,  
the alarm will drop out. Pickup and dropout setpoints are positive, delays are in  
seconds.  
010 Over Value Alarm  
If the absolute value in the test register exceeds the setpoint long enough to  
satisfy the pickup delay period, the alarm condition will be true. When absolute the  
value in the test register falls below the dropout setpoint long enough to satisfy the  
dropout delay period, the alarm will drop out. Pickup and dropout setpoints are  
positive, delays are in seconds.  
011 Over Power Alarm  
If the absolute value in the test register exceeds the setpoint long enough to  
satisfy the pickup delay period, the alarm condition will be true. When absolute the  
value in the test register falls below the dropout setpoint long enough to satisfy the  
dropout delay period, the alarm will drop out. This alarm will only hold true for  
reverse power conditions. Positive power values will not cause the alarm to occur.  
Pickup and dropout setpoints are positive, delays are in seconds.  
Over Reverse  
012  
Power Alarm  
If the test register value is below the setpoint long enough to satisfy the pickup  
delay period, the alarm condition will be true. When the value in the test register  
rises above the dropout setpoint long enough to satisfy the dropout delay period,  
the alarm will drop out. Pickup and dropout setpoints are positive, delays are in  
seconds.  
020 Under Value Alarm  
021 Under Power Alarm  
051 Phase Reversal  
If the absolute value in the test register is below the setpoint long enough to  
satisfy the pickup delay period, the alarm condition will be true. When the absolute  
value in the test register rises above the dropout setpoint long enough to satisfy  
the dropout delay period, the alarm will drop out. Pickup and dropout setpoints are  
positive, delays are in seconds.  
The phase reversal alarm will occur whenever the phase voltage waveform  
rotation differs from the default phase rotation. The ABC phase rotation is  
assumed to be normal. If a CBA phase rotation is normal, the user should  
reprogram the power meter’s phase rotation ABC to CBA phase rotation. The  
pickup and dropout setpoints for phase reversal do not apply.  
The phase loss voltage alarm will occur when any one or two phase voltages (but  
not all) fall to the pickup value and remain at or below the pickup value long  
enough to satisfy the specified pickup delay. When all of the phases remain at or  
above the dropout value for the dropout delay period, or when all of the phases  
drop below the specified phase loss pickup value, the alarm will drop out. Pickup  
and dropout setpoints are positive, delays are in seconds.  
052 Phase Loss, Voltage  
053 Phase Loss, Current  
The phase loss current alarm will occur when any one or two phase currents (but  
not all) fall to the pickup value and remain at or below the pickup value long  
enough to satisfy the specified pickup delay. When all of the phases remain at or  
above the dropout value for the dropout delay period, or when all of the phases  
drop below the specified phase loss pickup value, the alarm will drop out. Pickup  
and dropout setpoints are positive, delays are in seconds.  
The leading power factor alarm will occur when the test register value becomes  
more leading than the pickup setpoint (such as closer to 0.010) and remains more  
leading long enough to satisfy the pickup delay period. When the value becomes  
equal to or less leading than the dropout setpoint, that is 1.000, and remains less  
054 Leading Power Factor leading for the dropout delay period, the alarm will drop out. Both the pickup  
setpoint and the dropout setpoint must be positive values representing leading  
power factor. Enter setpoints as integer values representing power factor in  
thousandths. For example, to define a dropout setpoint of 0.5, enter 500. Delays  
are in seconds.  
The lagging power factor alarm will occur when the test register value becomes  
more lagging than the pickup setpoint (such as closer to –0.010) and remains  
more lagging long enough to satisfy the pickup delay period. When the value  
becomes equal to or less lagging than the dropout setpoint and remains less  
055 Lagging Power Factor lagging for the dropout delay period, the alarm will drop out. Both the pickup  
setpoint and the dropout setpoint must be positive values representing lagging  
power factor. Enter setpoints as integer values representing power factor in  
thousandths. For example, to define a dropout setpoint of –0.5, enter 500. Delays  
are in seconds.  
Digital  
The digital input transition alarms will occur whenever the digital input changes  
from off to on. The alarm will dropout when the digital input changes back to on  
from off. The pickup and dropout setpoints and delays do not apply.  
060 Digital Input On  
061 Digital Input Off  
070 Unary  
The digital input transition alarms will occur whenever the digital input changes  
from on to off.The alarm will dropout when the digital input changes back to off  
from on. The pickup and dropout setpoints and delays do not apply.  
This is a internal signal from the power meter and can be used, for example, to  
alarm at the end of an interval or when the power meter is reset. Neither the  
pickup and dropout delays nor the setpoints apply.  
52  
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63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
Advanced Alarms  
This section describes the advanced alarm features found on the PM850 and the PM870.  
For information about basic alarm features, see “Basic Alarms” on page 45.  
Table 6 – 7: Advanced alarm features by model  
Advanced Alarm Feature  
PM850  
PM870  
Boolean alarms  
Disturbance alarms  
Alarm levels  
10  
10  
12  
Yes  
Yes  
Yes  
Yes  
Custom alarms  
Advanced Alarm Groups  
In addition to the basic alarm groups (see “Basic Alarm Groups” on page 45), the  
following advanced alarm groups are available.  
Boolean—Boolean alarms use Boolean logic to combine up to four enabled alarms.  
You can choose from the Boolean logic operands: AND, NAND, OR, NOR, or XOR to  
combine your alarms. Up to 10 alarms can be set up in this group.  
Disturbance (PM870)—Disturbance alarms have a detection rate of half a cycle and  
are useful for detecting voltage sags and swells. The Power Meter comes configured  
with 12 default voltage sag and swell alarms; current sag and swell alarms are available  
by configuring custom alarms. Up to 12 disturbance alarms can be set up in this group.  
For more information about disturbance monitoring, see Chapter 9—Disturbance  
Custom—The power meter has many pre-defined alarms, but you can also set up your  
own custom alarms using PowerLogic software. For example, you may need to alarm  
on a sag condition for current A. To create this type of custom alarm:  
1. Select the appropriate alarm group (Disturbance in this case).  
2. Delete any of the default alarms you are not using from the disturbance alarms  
group (for example, Sag Vbc). The Add button should be available now.  
3. Click Add, then select Disturbance, Sag, and Current A.  
4. Give the alarm a name.  
5. Save the custom alarm.  
After creating a custom alarm, you can configure it by applying priorities, setting pickups  
and dropouts (if applicable), and so forth.  
PowerLogic software can be used to configure any of the advanced alarm types, but the  
power meter display cannot be used. Also, use PowerLogic software to delete an alarm  
and create a new alarm for evaluating other metered quantities.  
53  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
63230-500-225A2  
3/2011  
Alarm Levels  
Using PowerLogic software with a PM850 or PM870, multiple alarms can be set up for one  
particular quantity (parameter) to create alarm “levels”. You can take different actions  
depending on the severity of the alarm.  
For example, you could set up two alarms for kW Demand. A default alarm already exists  
for kW Demand, but you could create another custom alarm for kW Demand, selecting  
different pickup points for it. The custom kW Demand alarm, once created, will appear in  
the standard alarm list. For illustration purposes, let’s set the default kW Demand alarm to  
120 kW and the new custom alarm to 150 kW. One alarm named kW Demand ; the other  
kW Demand 150kW as shown in Figure 6–3. If you choose to set up two alarms for the  
same quantity, use slightly different names to distinguish which alarm is active. The display  
can hold up to 15 characters for each name. You can create up to 10 alarm levels for each  
quantity.  
Figure 6–3:Two alarms set up for the same quantity with different pickup and dropout set  
points  
kW Demand  
Alarm #43 Pick Up  
150  
140  
130  
120  
100  
Alarm #43 Drop Out  
Alarm #26 Pick Up  
Alarm #26 Drop Out  
Time  
Demand OK Approaching  
Peak Demand  
Below Peak Demand OK  
Demand  
Peak Demand Exceeded  
kW Demand (default)  
Alarm #26 kW Demand with pickup  
of 120 kWd, medium priority  
kW Demand 150 kW (custom)  
Alarm #43 kW Demand with pickup  
of 150 kWd, high priority  
Viewing Alarm Activity and History  
1. Press ###:until ALARM is visible.  
2. Press ALARM.  
ꢝꢬꢄꢇꢆꢬꢔꢕ  
ꢌꢍꢇꢆꢉ  
ꢉꢀꢁ  
ꢂꢅꢆ  
ꢆꢄꢇꢀꢁꢇꢆꢄ  
ꢑꢆ  
3. View the active alarm listed on the power  
meter display. If there are no active  
alarms, the screen reads, “NO ACTIVE  
ALARMS.”  
ꢁꢊꢃꢚꢌ  
4. If there are active alarms, press <--or --  
ꢋꢫꢰꢻ  
>to view a different alarm.  
5. Press HIST.  
ꢳꢖ  
6. Press <--or -->to view a different  
ꢈꢉ  
ꢙꢍꢍ  
ꢍꢍꣅ  
ꢂꢔꢚꢊꢬ  
alarm’s history.  
7. Press 1;to return to the SUMMARY  
screen.  
54  
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63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
Alarm Conditions and Alarm Numbers  
This section lists the power meter’s predefined alarm conditions. For each alarm condition,  
the following information is provided.  
Alarm No.—a position number indicating where an alarm falls in the list.  
Alarm Description—a brief description of the alarm condition  
Abbreviated Display Name—an abbreviated name that describes the alarm condition,  
but is limited to 15 characters that fit in the window of the power meter’s display.  
Test Register—the register number that contains the value (where applicable) that is  
used as the basis for a comparison to alarm pickup and dropout settings.  
Units—the unit that applies to the pickup and dropout settings.  
Scale Group—the scale group that applies to the test register’s metering value (A–F).  
For a description of scale groups, see “Scale Factors” on page 49.  
Alarm Type—a reference to a definition that provides details on the operation and  
configuration of the alarm. For a description of advanced alarm types, refer to  
Table 6–8 lists the preconfigured alarms by alarm number.  
Table 6–8: List of Default Disturbance Alarms by Alarm Number  
Alarm  
Number  
Abbreviated  
Display Name Register  
Test  
Scale Alarm  
Alarm Description  
Units  
Group  
Type  
Disturbance Monitoring (1/2 Cycle) (PM870)  
41  
42  
43  
44  
45  
46  
47  
48  
49  
50  
51  
52  
Voltage Swell A  
Voltage Swell B  
Voltage Swell C  
Voltage Swell A–B  
Voltage Swell B–C  
Voltage Swell C–A  
Voltage Sag A–N  
Voltage Sag B–N  
Voltage Sag C–N  
Voltage Sag A–B  
Voltage Sag B–C  
Voltage Sag C–A  
Swell Van  
Swell Vbn  
Swell Vcn  
Swell Vab  
Swell Vbc  
Swell Vca  
Sag Van  
Sag Vbn  
Sag Vcn  
Sag Vab  
Sag Vbc  
Sag Vca  
Volts  
Volts  
Volts  
Volts  
Volts  
Volts  
Volts  
Volts  
Volts  
Volts  
Volts  
Volts  
D
D
D
D
D
D
D
D
D
D
D
D
080  
080  
080  
080  
080  
080  
080  
080  
080  
080  
080  
080  
Scale groups are described in Table 6–2 on page 49.  
Advanced Alarm types are described in Table 6–9 on page 56.  
NOTE: Current sag and swell alarms are enabled using PowerLogic software or by setting  
up custom alarms. To do this, delete any of the above default disturbance alarms, and then  
create a new current sag or swell alarm (see the example under the “Advanced Alarm  
Groups” on page 53.). Sag and swell alarms are available for all channels.  
55  
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PowerLogicTM Series 800 Power Meter  
Chapter 6—Alarms  
63230-500-225A2  
3/2011  
Table 6–9: Advanced Alarm Types  
Type  
Description  
Operation  
Boolean  
Logic  
AND  
The AND alarm will occur when all of the combined enabled alarms are  
true (up to 4). The alarm will drop out when any of the enabled alarms  
drops out.  
100  
101  
102  
103  
104  
Logic  
NAND  
The NAND alarm will occur when any, but not all, or none of the  
combined enabled alarms are true. The alarm will drop out when all of  
the enabled alarms drop out, or all are true.  
Logic  
OR  
The OR alarm will occur when any of the combined enabled alarms are  
true (up to 4). The alarm will drop out when all of the enabled alarms  
are false.  
Logic  
NOR  
The NOR alarm will occur when none of the combined enabled alarms  
are true (up to 4). The alarm will drop out when any of the enabled  
alarms are true.  
Logic  
XOR  
The XOR alarm will occur when only one of the combined enabled  
alarms is true (up to 4). The alarm will drop out when the enabled alarm  
drops out or when more than one alarm becomes true.  
Disturbance (PM870)  
The voltage swell alarms will occur whenever the continuous rms  
calculation is above the pickup setpoint and remains above the pickup  
setpoint for the specified number of cycles. When the continuous rms  
calculations fall below the dropout setpoint and remain below the  
setpoint for the specified number of cycles, the alarm will drop out.  
Pickup and dropout setpoints are positive and delays are in cycles.  
080  
080  
Voltage Swell  
Voltage Sag  
The voltage sag alarms will occur whenever the continuous rms  
calculation is below the pickup setpoint and remains below the pickup  
setpoint for the specified number of cycles. When the continuous rms  
calculations rise above the dropout setpoint and remain above the  
setpoint for the specified number of cycles, the alarm will drop out.  
Pickup and dropout setpoints are positive and delays are in cycles.  
56  
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63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 7—Logging  
Chapter 7—Logging  
Introduction  
This chapter briefly describes the following logs of the power meter:  
Alarm log  
Maintenance log  
Billing log  
User-defined data logs  
See the table below for a summary of logs supported by each power meter model.  
Table 7–1: Number of Logs Supported by Model  
Number of Logs per Model  
Log Type  
PM810 with  
PM810LOG  
PM810  
PM820  
PM850  
PM870  
Alarm Log  
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
Maintenance Log  
Billing Log  
1
Data Log 1  
Data Log 2  
Data Log 3  
Data Log 4  
1
Logs are files stored in the non-volatile memory of the power meter and are referred to as  
“on-board logs.” The amount of memory available depends on the model (see Table 7–2).  
Data and billing log files are preconfigured at the factory. You can accept the preconfigured  
logs or change them to meet your specific needs. Use PowerLogic software to set up and  
view all the logs. See your software’s online help or documentation for information about  
working with the power meter’s on-board logs.  
Table 7–2: Available Memory for On-board Logs  
Power Meter Model  
Total Memory Available  
PM810  
PM810 with PM810LOG  
PM820  
0 KB  
80 KB  
80 KB  
800 KB  
800 KB  
PM850  
PM870  
Waveform captures are stored in the power meter’s memory, but they are not considered  
Log Files”on the next page for information about memory allocation in the power meter.  
57  
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PowerLogicTM Series 800 Power Meter  
Chapter 7—Logging  
63230-500-225A2  
3/2011  
Memory Allocation for Log Files  
Each file in the power meter has a maximum memory size. Memory is not shared between  
the different logs, so reducing the number of values recorded in one log will not allow more  
values to be stored in a different log. The following table lists the memory allocated to each  
log:  
Table 7–3: Memory Allocation for Each Log  
Max. Records  
Stored  
Max. Register  
Values Recorded  
Storage  
(Bytes)  
Power Meter  
Model  
Log Type  
Alarm Log  
100  
40  
11  
4
2,200  
320  
All models  
Maintenance Log  
All models  
PM810 with  
PM810LOGPM820  
Billing Log  
5000  
1851  
96 + 3 D/T  
96 + 3 D/T  
65,536  
14,808  
PM850  
PM870  
PM810 with  
PM810LOGPM820  
Data Log 1  
PM850  
PM870  
PM850  
PM870  
PM850  
PM870  
PM850  
PM870  
Data Log 2  
Data Log 3  
Data Log 4  
5000  
5000  
96 + 3 D/T  
96 + 3 D/T  
96 + 3 D/T  
393,216  
393,216  
393,216  
32,000  
Alarm Log  
By default, the power meter can log the occurrence of any alarm condition. Each time an  
alarm occurs it is entered into the alarm log. The alarm log in the power meter stores the  
pickup and dropout points of alarms along with the date and time associated with these  
alarms. You select whether the alarm log saves data as first-in-first-out (FIFO) or fill and  
hold. With PowerLogic software, you can view and save the alarm log to disk, and reset the  
alarm log to clear the data out of the power meter’s memory.  
Alarm Log Storage  
Maintenance Log  
The power meter stores alarm log data in non-volatile memory. The size of the alarm log is  
fixed at 100 records.  
The power meter stores a maintenance log in non-volatile memory. The file has a fixed  
record length of four registers and a total of 40 records. The first register is a cumulative  
counter over the life of the power meter. The last three registers contain the date/time of  
when the log was updated. Table 7–4 describes the values stored in the maintenance log.  
These values are cumulative over the life of the power meter and cannot be reset.  
NOTE: Use PowerLogic software to view the maintenance log.  
58  
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63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Chapter 7—Logging  
Table 7–4: Values Stored in the Maintenance Log  
Record  
Value Stored  
Number  
1
2
3
4
Time stamp of the last change  
Date and time of the last power failure  
Date and time of the last firmware download  
Date and time of the last option module change  
Date and time of the latest LVC update due to configuration errors  
detected during meter initialization  
5
6–11  
12  
13  
14  
15  
16  
17  
18  
19  
20  
21  
22  
23  
24  
25  
26  
27  
28  
29  
30  
31  
32  
33  
34  
35  
36  
37  
38  
39  
40  
Reserved  
Date and time the Present Month Min/Max was last reset  
Date and time the Previous Month Min/Max was last reset  
Date and time the Energy Pulse Output was overdriven  
Date and time the Power Demand Min/Max was last reset  
Date and time the Current Demand Min/Max was last reset  
Date and time the Generic Demand Min/Max was last reset  
Date and time the Input Demand Min/Max was last reset  
Reserved  
Date and time the Accumulated Energy value was last reset  
Date and time the Conditional Energy value was last reset  
Date and time the Incremental Energy value was last reset  
Reserved  
Date and time of the last Standard KY Output operation  
Date and time of the last Discrete Output @A01 operation➀  
Date and time of the last Discrete Output @A02 operation➀  
Date and time of the last Discrete Output @A03 operation➀  
Date and time of the last Discrete Output @A04 operation➀  
Date and time of the last Discrete Output @A05 operation➀  
Date and time of the last Discrete Output @A06 operation➀  
Date and time of the last Discrete Output @A07 operation➀  
Date and time of the last Discrete Output @A08 operation➀  
Date and time of the last Discrete Output @B01 operation➀  
Date and time of the last Discrete Output @B02 operation➀  
Date and time of the last Discrete Output @B03 operation➀  
Date and time of the last Discrete Output @B04 operation➀  
Date and time of the last Discrete Output @B05 operation➀  
Date and time of the last Discrete Output @B06 operation➀  
Date and time of the last Discrete Output @B07 operation➀  
Date and time of the last Discrete Output @B08 operation➀  
Additional outputs require option modules and are based on the I/O  
configuration of that particular module.  
59  
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PowerLogicTM Series 800 Power Meter  
Chapter 7—Logging  
63230-500-225A2  
3/2011  
Data Logs  
The PM810 with a PM810LOG records and stores readings at regularly scheduled intervals  
in one independent data log. This log is preconfigured at the factory. You can accept the  
preconfigured data log or change it to meet your specific needs. You can set up the data  
log to store the following information:  
The PM820 records and stores readings at regularly scheduled intervals in one  
independent data log. The PM850 and PM870 record and store meter readings at regularly  
scheduled intervals in up to three independent data logs. Some data log files are  
preconfigured at the factory. You can accept the preconfigured data logs or change them to  
meet your specific needs. You can set up each data log to store the following information:  
Timed Interval—1 second to 24 hours for Data Log 1  
Timed Interval—1 second to 24 hours for Data Log 1, and 1 minute to 24 hours for Data  
Logs 2, 3 and 4 (how often the values are logged)  
First-In-First-Out (FIFO) or Fill and Hold  
Values to be logged—up to 96 registers along with the date and time of each log entry  
START/STOP Time—each log has the ability to start and stop at a certain time during  
the day  
The default registers for Data Log 1 are listed in Table 7–5 below.  
Table 7–5: Default Data Log 1 Register List  
Number of  
Description  
Data TypeRegister Number  
Registers  
Start Date/Time  
3
1
1
1
1
1
1
1
1
1
1
1
1
1
1
D/T  
integer  
Current D/T  
1100  
1101  
1102  
1103  
1120  
1121  
1122  
1124  
1125  
1126  
1160  
1161  
1162  
1163  
Current, Phase A  
Current, Phase B  
Current, Phase C  
Current, Neutral  
integer  
integer  
integer  
Voltage A-B  
integer  
Voltage B-C  
integer  
Voltage C-A  
integer  
Voltage A-N  
integer  
Voltage B-N  
integer  
Voltage C-N  
integer  
True Power Factor, Phase A  
True Power Factor, Phase B  
True Power Factor, Phase C  
True Power Factor, Total  
signed integer  
signed integer  
signed integer  
signed integer  
Last Demand, Current,  
3-Phase Average  
1
1
1
1
integer  
integer  
integer  
integer  
2000  
2150  
2165  
2180  
Last Demand, Real Power,  
3-Phase Total  
Last Demand, Reactive  
Power, 3-Phase Total  
Last Demand, Apparent  
Power 3-Phase Total  
Refer to Appendix A for more information about data types.  
Use PowerLogic software to clear each data log file, independently of the others, from the  
power meter’s memory. For instructions on setting up and clearing data log files, refer to  
the PowerLogic software online help or documentation.  
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Chapter 7—Logging  
Alarm-driven Data Log Entries  
The PM810 with a PM810LOG can detect over 50 alarm conditions, including over/under  
conditions, digital input changes, phase unbalance conditions, and more. (See Chapter  
6—Alarms on page 45 for more information.) Use PowerLogic software to assign each  
alarm condition one or more tasks, including forcing data log entries into Data Log 1.  
The PM820, PM850, and PM870 can detect over 50 alarm conditions, including over/under  
conditions, digital input changes, phase unbalance conditions, and more. (See Chapter  
6—Alarms on page 45 for more information.) Use PowerLogic software to assign each  
alarm condition one or more tasks, including forcing data log entries into one or more data  
log files.  
For example, assume you have defined three data log files. Using PowerLogic software,  
you could select an alarm condition such as “Overcurrent Phase A” and set up the power  
meter to force data log entries into any of the three log files each time the alarm condition  
occurs.  
Organizing Data Log Files (PM850, PM870)  
You can organize data log files in many ways. One possible way is to organize log files  
according to the logging interval. You might also define a log file for entries forced by alarm  
conditions. For example, you could set up three data log files as follows:  
Data Log 1:  
Data Log 2:  
Data Log 3:  
Log voltage every minute. Make the file large  
enough to hold 60 entries so that you could look  
back over the last hour’s voltage readings.  
Log energy once every day. Make the file large  
enough to hold 31 entries so that you could look  
back over the last month and see daily energy use.  
Report by exception. The report by exception file  
contains data log entries that are forced by the  
occurrence of an alarm condition. See the topic  
information.  
NOTE: The same data log file can support both scheduled and alarm-driven entries.  
Billing Log  
The PM810 with a PM810LOG, PM820, PM850 and PM870 Power Meters store a  
configurable billing log that updates every 10 to 1,440 minutes (the default interval 60  
minutes). Data is stored by month, day, and the specified interval in minutes. The log  
contains 24 months of monthly data and 32 days of daily data, but because the maximum  
amount of memory for the billing log is 64 KB, the number of recorded intervals varies  
based on the number of registers recorded in the billing log. For example, using all of the  
registers listed in Table 7–6, the billing log holds 12 days of data at 60-minute intervals.  
This value is calculated by doing the following:  
1. Calculate the total number of registers used (see Table 7–6 on page 63 for the number  
of registers). In this example, all 26 registers are used.  
2. Calculate the number of bytes used for the 24 monthly records.  
24 records (26 registers x 2 bytes/register) = 1,248  
3. Calculate the number of bytes used for the 32 daily records.  
32 (26 x 2) = 1,664  
4. Calculate the number of bytes used each day (based on 15 minute intervals).  
96 (26 x 2) = 4,992  
5. Calculate the number of days of 60-minute interval data recorded by subtracting the  
values from steps 2 and 3 from the total log file size of 65,536 bytes and then dividing  
by the value in step 4.  
(65,536 – 1,248 – 1,664) 4,992 = 12 days  
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Chapter 7—Logging  
Table 7–6: Billing Log Register List  
Number of  
Description  
Data TypeRegister Number  
Registers  
Start Date/Time  
3
4
4
4
4
4
1
1
1
D/T  
Current D/T  
1700  
Real Energy In  
MOD10L4  
MOD10L4  
MOD10L4  
MOD10L4  
MOD10L4  
INT16  
Reactive Energy In  
Real Energy Out  
1704  
1708  
Reactive Energy Out  
Apparent Energy Total  
Total PF  
1712  
1724  
1163  
3P Real Power Demand  
3P Apparent Power Demand  
INT16  
2151  
INT16  
2181  
Refer to Appendix A for more information about data types.  
Configure the Billing Log Logging Interval  
The billing log can be configured to update every 10 to 1,440 minutes. The default logging  
interval is 60 minutes. To set the logging interval you can use PowerLogic software, or you  
can use the power meter to write the logging interval to register 3085 (see “Read and  
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PowerLogicTM Series 800 Power Meter  
Chapter 8—Waveform Capture  
Chapter 8—Waveform Capture  
Introduction  
This section explains the waveform capture capabilities of the following Power Meter  
models:  
PM850  
PM870  
See Table 8–1 for a summary of waveform capture features.  
Table 8–1: Waveform capture summary by model  
Waveform Capture Feature  
PM850  
PM870  
Number of waveform captures  
Waveform initiated:  
Manually  
5
5
By alarm  
Samples per cycle  
Channels (1 to 6)  
Cycles  
128  
Configurable*  
Configurable*  
Configurable*  
Configurable*  
Configurable  
3
1
Precycles  
* See Figure 8–1.  
Waveform Capture  
A waveform capture can be initiated manually or by an alarm trigger to analyze steady-  
state or disturbance events. This waveform provides information about individual  
harmonics, which PowerLogic software calculates through the 63rd harmonic. It also  
calculates total harmonic distortion (THD) and other power quality parameters.  
NOTE: Disturbance waveform captures are available in the PM870 only.  
In the PM850, the waveform capture records five individual three-cycle captures at 128  
samples per cycle simultaneously on all six metered channels. In the PM870, there is a  
range of one to five waveform captures, but the number of cycles captured varies based on  
the number of samples per cycle and the number of channels selected in your software.  
Use Figure 8–1 to determine the number of cycles captured.  
Figure 8–1: PM870 Number of Cycles Captured  
6
5
4
3
2
1
30  
35  
45  
60  
90  
15  
15  
20  
30  
45  
7
3
9
4
10  
15  
20  
5
Number  
of  
Channels  
7
10  
185  
16  
90  
32  
45  
64  
20  
128  
Number of Samples per Cycle  
NOTE: The number of cycles shown above are the total number of cycles allowed (pre-  
event cycles + event cycles = total cycles).  
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Initiating a Waveform  
Using PowerLogic software from a remote PC, initiate a waveform capture manually by  
selecting the power meter and issuing the acquire command. The software will  
automatically retrieve the waveform capture from the power meter. You can display the  
waveform for all three phases, or zoom in on a single waveform, which includes a data  
block with extensive harmonic data. See your software’s online help or documentation for  
instructions.  
Waveform Storage  
The power meter can store multiple captured waveforms in its non-volatile memory. The  
number of waveforms stored is based on the number selected. There are a maximum of  
five stored waveforms. All stored waveform data is retained on power loss.  
Waveform Storage Modes  
There are two ways to store waveform captures: “FIFO” and “Fill and Hold.” FIFO mode  
allows the file to fill up the waveform capture file. After the file is full, the oldest waveform  
capture is removed, and the most recent waveform capture is added to the file. The Fill and  
Hold mode fills the file until the configured number of waveform captures is reached. New  
waveform captures cannot be added until the file is cleared.  
How the Power Meter Captures an Event  
When the power meter senses the trigger—that is, when the digital input transitions from  
OFF to ON, or an alarm condition is met—the power meter transfers the cycle data from its  
data buffer into the memory allocated for event captures.  
Channel Selection in PowerLogic Software  
Using PowerLogic software, you can select up to six channels to include in the waveform  
capture. See your software’s online help or documentation for instructions.  
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PowerLogicTM Series 800 Power Meter  
Chapter 9—Disturbance Monitoring (PM870)  
Chapter 9—Disturbance Monitoring (PM870)  
This chapter provides background information about disturbance monitoring and describes  
how to use the PM870 to continuously monitor for disturbances on the current and voltage  
inputs.  
About Disturbance Monitoring  
Momentary voltage disturbances are an increasing concern for industrial plants, hospitals,  
data centers, and other commercial facilities because modern equipment used in those  
facilities tends to be more sensitive to voltage sags, swells, and momentary interruptions.  
The power meter can detect these events by continuously monitoring and recording current  
and voltage information on all metered channels. Using this information, you can diagnose  
equipment problems resulting from voltage sags or swells and identify areas of  
vulnerability, enabling you to take corrective action.  
The interruption of an industrial process because of an abnormal voltage condition can  
result in substantial costs, which manifest themselves in many ways:  
labor costs for cleanup and restart  
lost productivity  
damaged product or reduced product quality  
delivery delays and user dissatisfaction  
The entire process can depend on the sensitivity of a single piece of equipment. Relays,  
contactors, adjustable speed drives, programmable controllers, PCs, and data  
communication networks are all susceptible to power quality problems. After the electrical  
system is interrupted or shut down, determining the cause may be difficult.  
Several types of voltage disturbances are possible, each potentially having a different  
origin and requiring a separate solution. A momentary interruption occurs when a protective  
device interrupts the circuit that feeds a facility. Swells and over-voltages can damage  
equipment or cause motors to overheat. Perhaps the biggest power quality problem is the  
momentary voltage sag caused by faults on remote circuits.  
A voltage sag is a brief (1/2 cycle to 1 minute) decrease in rms voltage magnitude. A sag is  
typically caused by a remote fault somewhere on the power system, often initiated by a  
lightning strike. In Figure 9–1, the utility circuit breaker cleared the fault near plant D. The  
fault not only caused an interruption to plant D, but also resulted in voltage sags to plants A,  
B, and C.  
NOTE: The PM870 is able to detect sag and swell events less than 1/2 cycle duration.  
However, it may be impractical to have setpoints more sensitive than 10% for voltage and  
current fluctuations.  
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Chapter 9—Disturbance Monitoring (PM870)  
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Figure 9–1: A fault can cause a voltage sag on the whole system  
Utility Circuit  
Breakers with  
Reclosers  
1
Plant A  
Plant B  
Plant C  
Utility  
Transformer  
2
3
4
Plant D  
X
Fault  
A fault near plant D, cleared by the utility circuit  
breaker, can still affect plants A, B, and C,  
resulting in a voltage sag.  
System voltage sags are much more numerous than interruptions, since a wider part of the  
distribution system is affected. And, if reclosers are operating, they may cause repeated  
sags. The PM870 can record recloser sequences, too. The waveform in Figure 9–2 shows  
the magnitude of a voltage sag, which persists until the remote fault is cleared.  
Figure 9–2: Waveform showing voltage sag caused by a remote fault and lasting five cycles  
With the information obtained from the PM870 during a disturbance, you can solve  
disturbance-related problems, including the following:  
Obtain accurate measurement from your power system  
— Identify the number of sags, swells, or interruptions for evaluation  
— Accurately distinguish between sags and interruptions, with accurate recording of  
the time and date of the occurrence  
— Provide accurate data in equipment specification (ride-through, etc.)  
Determine equipment sensitivity  
— Compare equipment sensitivity of different brands (contactor dropout, drive  
sensitivity, etc.)  
— Diagnose mysterious events such as equipment malfunctions, contactor dropout,  
computer glitches, etc.  
— Compare actual sensitivity of equipment to published standards  
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— Use waveform capture to determine exact disturbance characteristics to compare  
with equipment sensitivity  
— Justify purchase of power conditioning equipment  
— Distinguish between equipment malfunctions and power system related problems  
Develop disturbance prevention methods  
— Develop solutions to voltage sensitivity-based problems using actual data  
Work with the utility  
— Discuss protection practices with the serving utility and negotiate suitable changes  
to shorten the duration of potential sags (reduce interruption time delays on  
protective devices)  
— Work with the utility to provide alternate “stiffer” services (alternate design practices)  
Capabilities of the PM870 During an Event  
The PM870 calculates rms magnitudes, based on 128 data points per cycle, every 1/2  
cycle. This ensures that even sub-cycle duration rms variations are not missed.  
The power meter is configured with 12 default voltage disturbance alarms for all voltage  
channels. Current sag and swell alarms are available by configuring custom alarms. A  
maximum of 12 disturbance alarms are available. When the PM870 detects a sag or swell,  
it can perform the following actions:  
Perform a waveform capture with a resolution from 185 cycles at 16 samples per  
cycle on one channel down to 3 cycles at 128 samples per cycle on all six channels of  
the metered current and voltage inputs (see Figure 8–1 on page 63). Use PowerLogic  
software to set up the event capture and retrieve the waveform.  
Record the event in the alarm log. When an event occurs, the PM870 updates the  
alarm log with an event date and time stamp with 1 millisecond resolution for a sag or  
swell pickup, and an rms magnitude corresponding to the most extreme value of the  
sag or swell during the event pickup delay. Also, the PM870 can record the sag or swell  
dropout in the alarm log at the end of the disturbance. Information stored includes: a  
dropout time stamp with 1 millisecond resolution and a second rms magnitude  
corresponding to the most extreme value of the sag or swell. Use PowerLogic software  
to view the alarm log.  
NOTE: The Power Meter display has a 1 second resolution.  
Force a data log entry in up to 3 independent data logs. Use PowerLogic software to  
set up and view the data logs.  
Operate any output relays when the event is detected.  
Indicate the alarm on the display by flashing the maintenance icon to show that a sag  
or swell event has occurred.  
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PowerLogicTM Series 800 Power Meter  
Chapter 10—Maintenance and Troubleshooting  
Chapter 10—Maintenance and Troubleshooting  
Introduction  
This chapter describes information related to maintenance of your power meter.  
The power meter does not contain any user-serviceable parts. If the power meter requires  
service, contact your local sales representative. Do not open the power meter. Opening the  
power meter voids the warranty.  
DANGER  
HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH  
• Do not attempt to service the power meter. CT and PT inputs may contain  
hazardous currents and voltages.  
• Only authorized service personnel from the manufacturer should service the  
power meter.  
Failure to follow these instructions will result in death or serious injury.  
CAUTION  
HAZARD OF EQUIPMENT DAMAGE  
• Do not perform a Dielectric (Hi-Pot) or Megger test on the power meter. High  
voltage testing of the power meter may damage the unit.  
• Before performing Hi-Pot or Megger testing on any equipment in which the power  
meter is installed, disconnect all input and output wires to the power meter.  
Failure to follow these instructions can result in injury or equipment damage.  
Power Meter Memory  
The power meter uses its non-volatile memory (RAM) to retain all data and metering  
configuration values. Under the operating temperature range specified for the power meter,  
this non-volatile memory has an expected life of up to 100 years. The power meter stores  
its data logs on a memory chip, which has a life expectancy of up to 20 years under the  
operating temperature range specified for the power meter. The life of the internal battery-  
backed clock is over 10 years at 25°C.  
NOTE: Life expectancy is a function of operating conditions; this does not constitute any  
expressed or implied warranty.  
Date and Time Settings  
The clock in the PM810 is volatile. Therefore, the PM810 returns to the default clock  
date/time of 12:00 AM 01-01-1980 each time the meter resets. Reset occurs when the  
meter loses control power or you change meter configuration parameters including  
selecting the time format (24-hr or AM/PM) or date format. To avoid resetting clock time  
more than once, always set the clock date and time last. The PM810LOG (optional module)  
provides a non-volatile clock in addition to on-board logging and individual harmonics  
readings for the PM810.  
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Chapter 10—Maintenance and Troubleshooting  
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Identifying the Firmware Version, Model, and Serial Number  
1. From the first menu level, press ###:until  
MAINT is visible.  
ꢅꢄꢚꢄꢇꢆꢊꢕꢮꢝ  
ꢈꢂꢆ  
ꢉꢀꢅꢉꢆꢆ  
ꢉꢆꢅꢋꢆꢆ  
ꢀꢂꢆꢆꢆꢉꢊꢁ  
2. Press DIAG.  
3. Press METER.  
ꢀꢆꢅ  
ꢅꢝꢋꢄꢨ  
ꢌ  
4. View the model, firmware (OS) version,  
and serial number.  
ꢆꢆꢬ  
ꢆꢆꢬ  
5. Press 1;to return to the MAINTENANCE  
screen.  
ꢇꢄꢃꢄꢚ  
ꢃꢌꢕꢌ  
ꢈꢉ  
ꢙꢍ  
ꢍꣅ  
Viewing the Display in Different Languages  
The power meter can be set to use one of five different languages: English, French, and  
Spanish. Other languages are available. Please contact your local sales representative for  
more information about other language options.  
The power meter language can be selected by doing the following:  
1. From the first menu level, press ###:until  
MAINT is visible.  
ꢨꢂꢕꢩꢛꢂꢩꢄ  
2. Press MAINT.  
3. Press SETUP.  
ꢄꢕꢩꢨꢌ  
4. Enter your password, then press OK.  
5. Press ###:until LANG is visible.  
6. Press LANG.  
7. Select the language: ENGL (English),  
FREN (French), SPAN (Spanish), GERMN  
(German), or RUSSN (Russian).  
ꢈꢉ  
ꢙꢍ  
ꢝꢞ  
8. Press OK.  
9. Press1;.  
10. Press YES to save your changes.  
Technical Support  
For assistance with technical issues, contact your local Schneider Electric representative.  
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Chapter 10—Maintenance and Troubleshooting  
Troubleshooting  
The information in Table 10–1 on page 72 describes potential problems and their possible  
causes. It also describes checks you can perform or possible solutions for each. If you still  
cannot resolve the problem after referring to this table, contact the your local Schneider  
Electric sales representative for assistance.  
DANGER  
HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH  
• Apply appropriate personal protective equipment (PPE) and follow safe  
electrical practices. For example, in the United States, see NFPA 70E.  
• This equipment must be installed and serviced only by qualified personnel.  
• Turn off all power supplying this equipment before working on or inside.  
• Always use a properly rated voltage sensing device to confirm that all power is  
off.  
• Carefully inspect the work area for tools and objects that may have been left  
inside the equipment.  
• Use caution while removing or installing panels so that they do not extend into  
the energized bus; avoid handling the panels which could cause personal injury.  
Failure to follow these instructions will result in death or serious injury.  
Heartbeat LED  
The heartbeat LED helps to troubleshoot the power meter. The LED works as follows:  
Normal operation — the LED flashes at a steady rate during normal operation.  
Communications — the LED flash rate changes as the communications port transmits  
and receives data. If the LED flash rate does not change when data is sent from the  
host computer, the power meter is not receiving requests from the host computer.  
Hardware — if the heartbeat LED remains lit and does not flash ON and OFF, there is  
a hardware problem. Do a hard reset of the power meter (turn OFF power to the power  
meter, then restore power to the power meter). If the heartbeat LED remains lit, contact  
your local sales representative.  
Control power and display — if the heartbeat LED flashes, but the display is blank,  
the display is not functioning properly. If the display is blank and the LED is not lit, verify  
that control power is connected to the power meter.  
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Chapter 10—Maintenance and Troubleshooting  
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Table 10–1: Troubleshooting  
Potential Problem  
Possible Cause  
Possible Solution  
Go to DIAGNOSTICS > MAINTENANCE.  
Error messages display to indicate the  
reason the icon is illuminated. Note these  
When the maintenance icon is  
illuminated, it indicates a potential  
The maintenance icon is  
illuminated on the power  
meter display.  
hardware or firmware problem in the error messages and call Technical  
power meter.  
Support, or contact your local sales  
representative for assistance.  
The display shows error  
code 3.  
Loss of control power or meter  
configuration has changed.  
Set date and time.  
Verify that the power meter line (L) and  
neutral (N) terminals (terminals 25 and  
27) are receiving the necessary power.  
Verify that the heartbeat LED is  
blinking.  
The display is blank after  
applying control power to  
the power meter.  
The power meter may not be  
receiving the necessary power.  
Verify that the power meter is grounded as  
Power meter is grounded incorrectly. described in “Grounding the Power Meter”  
in the installation manual.  
Check that the correct values have been  
entered for power meter setup parameters  
Incorrect setup values.  
Incorrect voltage inputs.  
(CT and PT ratings, System Type, Nominal  
Frequency, and so on). See “Power Meter  
Setup” on page 13 for setup instructions.  
The data being displayed is  
inaccurate or not what you  
expect.  
Check power meter voltage input terminals  
L (8, 9, 10, 11) to verify that adequate  
voltage is present.  
Check that all CTs and PTs are connected  
correctly (proper polarity is observed) and  
that they are energized. Check shorting  
page 73. Initiate a wiring check using  
PowerLogic software.  
Power meter is wired improperly.  
Check to see that the power meter is  
correctly addressed. See “COMMS  
instructions.  
Power meter address is incorrect.  
Power meter baud rate is incorrect.  
Verify that the baud rate of the power  
meter matches the baud rate of all other  
devices on its communications link. See  
page 15 for instructions.  
Cannot communicate with  
power meter from a remote  
personal computer.  
Verify the power meter communications  
connections. Refer to the PM800-Series  
Installation Guide.  
Communications lines are improperly  
connected.  
Check to see that a multipoint  
Communications lines are improperly communications terminator is properly  
terminated.  
installed. Refer to the PM800-Series  
Installation Guide.  
Check the route statement. Refer to your  
software online help or documentation for  
instructions on defining route statements.  
Incorrect route statement to power  
meter.  
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PowerLogicTM Series 800 Power Meter  
Appendix A—Instrument Transformer Wiring: Troubleshooting Tables  
Appendix A—Instrument Transformer Wiring: Troubleshooting Tables  
Abnormal readings in an installed meter can sometimes signify improper wiring. This  
appendix is provided as an aid in troubleshooting potential wiring problems.  
Using This Appendix  
The following pages contain “Case” tables arranged in sections. These tables show a  
variety of symptoms and probable causes.  
Section I: Check these tables first. These are common problems for 3-wire and 4-wire  
systems that can occur regardless of system type.  
Section II: Check these tables if troubleshooting more complex 3-wire systems.  
Section III: Check these tables if troubleshooting more complex 4-wire systems.  
The symptoms listed are “ideal,” and some judgment should be exercised when  
troubleshooting. For example, if the kW reading is 25, but you know that it should be about  
300 kW, go to a table where “kW = 0” is listed as one of the symptoms.  
Because it is nearly impossible to address all combinations of multiple wiring mistakes or  
other problems that can occur (e.g., blown PT fuses, missing PT neutral ground  
connection), this guide generally addresses only one wiring problem at a time.  
Before trying to troubleshoot wiring problems, it is imperative that all instantaneous  
readings be available for reference. Specifically, those readings should include the  
following:  
line-to-line voltages  
line-to-neutral voltages  
phase currents  
power factor  
kW  
kVAR  
kVA  
What is Normal?  
Most power systems have a lagging (inductive) power factor. The only time a leading power  
factor is expected is if power factor correction capacitors are switched in or over-excited  
synchronous motors with enough capacitive kVARS are on-line to overcorrect the power  
factor to leading. Some uninterruptable power supplies (UPS) also produce a leading  
power factor.  
"Normal" lagging power system readings are as follows:  
Positive kW = 3 VAB I3Avg PF3Avg   1000  
Negative kVAR =  kVA2 kW2   1000  
kVA (always positive) = 3 VAB I3Avg   1000  
PF3Avg = lagging in the range 0.70 to 1.00 (for 4-wire systems, all phase PFs are  
about the same)  
Phase currents approximately equal  
Phase voltages approximately equal  
A quick check for proper readings consists of kW comparisons (calculated using the  
previous equation and compared to the meter reading) and a reasonable lagging 3-phase  
average power factor reading. If these checks are okay, there is little reason to continue to  
check for wiring problems.  
© 2011 Schneider Electric All Rights Reserved  
 
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PowerLogicTM Series 800 Power Meter  
Appendix A—Instrument Transformer Wiring: Troubleshooting Tables  
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3/2011  
Section I: Common Problems for 3-Wire and 4-Wire Systems  
Section I—Case A  
Symptoms: 3-Wire and 4-Wire  
Possible Causes  
CT secondaries shorted.  
Zero amps  
Less than 2% load on power meter based on CT ratio.  
Zero kW, kVAR, kVA  
Example: with 100/5 CT's, at least 2A must flow through CT window for power  
meter to “wake up.”  
Section I—Case B  
Symptoms: 3-Wire and 4-Wire  
Possible Causes  
All three CT polarities backwards; could be CTs are physically mounted  
with primary polarity mark toward the load instead of toward source or  
secondary leads swapped.  
Negative kW of expected magnitude  
Positive kVAR  
All three PT polarities backwards; again, could be on primary or secondary.  
Normal lagging power factor  
NOTE: Experience shows CTs are usually the problem.  
Section I—Case C  
Symptoms: 3-Wire and 4-Wire  
Possible Causes  
PTs primary and/or secondary neutral common not grounded (values as  
high as 275 Hz and as low as 10 Hz have been seen).  
Frequency is an abnormal value; may or may  
not be a multiple of 50/60 Hz.  
System grounding problem at the power distribution transformer (such as  
utility transformer), though this is not likely.  
74  
© 2011 Schneider Electric All Rights Reserved  
 
 
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PowerLogicTM Series 800 Power Meter  
Appendix A—Instrument Transformer Wiring: Troubleshooting Tables  
Section II: 3-Wire System Troubleshooting  
Section II—Case A  
Symptoms: 3-Wire  
Possible Causes  
Currents and voltages approximately balanced  
kW = near 0  
CT secondary leads are swapped (A-phase lead on C-phase terminal and  
vice versa).  
kVAR = near 0  
PT secondary leads are swapped (A-phase lead on C-phase terminal and  
vice versa).  
PF can be any value, probably fluctuating  
Section II—Case B  
Symptoms: 3-Wire  
Possible Causes  
Phase B current is 3 higher than A and C  
(except in System Type 31).  
kVA = about half of the expected magnitude  
One CT polarity is backwards.  
kW and kVAR can be positive or negative, less  
than about half of the expected magnitude.  
PF can be any value, probably a low leading  
value.  
Section II—Case C  
Symptoms: 3-Wire  
Possible Causes  
VCA is 3 higher than VAB and VBC  
kVA = about half of the expected magnitude  
kW and kVAR can be positive or negative, less  
than about half of the expected magnitude  
One PT polarity is backwards.  
PF can be any value, probably a low leading  
value  
Section II—Case D  
Symptoms: 3-Wire  
Possible Causes  
kW = 0 or low, with magnitude less than kVAR  
Either the two voltage leads are swapped OR the two current leads are  
swapped AND one instrument transformer has backwards polarity.  
kVAR = positive or negative with magnitude of  
close to what is expected for kW  
(look for VCA  
=
3 high or phase B current = 3 high)  
kVA = expected magnitude  
The power meter is metering a purely capacitive load (this is unusual); in  
this case kW and kVAR will be positive and PF will be near 0 lead.  
PF = near 0 up to about 0.7 lead  
Section II—Case E  
Symptoms: 3-Wire  
Possible Causes  
One phase current reads 0  
The CT on the phase that reads 0 is short-circuited.  
kVA = about 1/2 of the expected value  
Less than 2% current (based on CT ratio) flowing through the CT on the  
phase that reads 0.  
kW, kVAR, and power factor can be positive or  
negative of any value  
© 2011 Schneider Electric All Rights Reserved  
 
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Appendix A—Instrument Transformer Wiring: Troubleshooting Tables  
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Section III: 4-Wire System Troubleshooting  
Section III—Case A  
Symptoms: 4-Wire  
Possible Causes  
kW = 1/3 of the expected value  
kVAR = 1/3 of the expected value  
power factor = 1/3 of the expected value  
All else is normal  
One CT polarity is backwards.  
NOTE: The only way this problem will usually be detected is by the Quick Check  
procedure. It is very important to always calculate kW. In this case, it is the only symptom  
and will go unnoticed unless the calculation is done or someone notices backwards CT on  
a waveform capture.  
Section III—Case B  
Symptoms: 4-Wire  
Possible Causes  
One PT polarity is backwards.  
kW = 1/3 of the expected value  
kVAR = 1/3 of the expected value  
2 of the 3 line-to-line voltages are 3 low  
power factor = 1/3 of the expected value  
All else is normal  
NOTE: The line-to-line voltage reading that does not reference the PT with backwards  
polarity will be the only correct reading.  
Example: VAB= 277, VBC= 480, VCA= 277  
In this case, the A-phase PT polarity is backwards. VBC is correct because it does not  
reference VA  
.
Section III—Case C  
Symptoms: 4-Wire  
Possible Causes  
One line-to-neutral voltage is zero  
2 of the 3 line-to-line voltages are 3 low  
kW = 2/3 of the expected value  
kVAR = 2/3 of the expected value  
kVA = 2/3 of the expected value  
Power factor may look abnormal  
PT metering input missing (blown fuse, open phase disconnect, etc.) on the  
phase that reads zero.  
NOTE: The line-to-line voltage reading that does not reference the missing PT input will be  
the only correct reading.  
Example: VAB= 277, VBC= 277, VCA= 480  
In this case, the B-phase PT input is missing. VCA is correct because it does not  
reference VB  
.
Section III—Case D  
Symptoms: 4-Wire  
Possible Causes  
3-phase kW = 2/3 of the expected value  
3-phase kVAR = 2/3 of the expected value  
3-phase kVA = 2/3 of the expected value  
One phase current reads 0  
The CT on the phase that reads 0 is short-circuited.  
Less than 2% current (based on CT ratio) flowing through the CT on the  
phase that reads 0.  
All else is normal  
76  
© 2011 Schneider Electric All Rights Reserved  
 
 
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PowerLogicTM Series 800 Power Meter  
Appendix A—Instrument Transformer Wiring: Troubleshooting Tables  
Section III—Case E  
Symptoms: 4-Wire  
Possible Causes  
kW = near 0  
kVA = near 0  
Two CT secondary leads are swapped (A-phase on B-phase terminal, for  
example).  
Two PT secondary leads are swapped (A-phase on B-phase terminal, for  
example).  
3-phase average power factor flip-flopping lead  
and lag  
NOTE: In either case, the phase input that is not swapped will read normal lagging power  
factor.  
Voltages, currents, and kVA are normal  
Section III—Case F  
Symptoms: 4-Wire  
Possible Causes  
kW = negative and less than kVAR  
All three PT lead connections “rotated” counterclockwise: A-phase wire on  
C-phase terminal, B-phase wire on A-phase terminal, C-phase wire on B-  
phase terminal.  
KVAR = negative and close to value expected  
for kW  
kVA = expected value  
All three CT lead connections “rotated” clockwise: A-phase wire on B-phase  
terminal, B-phase wire on C-phase terminal, C-phase wire on A-phase  
terminal.  
Power factor low and leading  
Voltages and currents are normal  
Section III—Case G  
Symptoms: 4-Wire  
Possible Causes  
kW = negative and less than kVAR  
All three PT lead connections “rotated” clockwise: A-phase wire on B-phase  
terminal, B-phase wire on C-phase terminal, C-phase wire on A-phase  
terminal.  
kVAR = positive and close to the value for kW  
NOTE: looks like kW and kVAR swapped places  
All three CT lead connections “rotated” counterclockwise: A-phase wire on  
C-phase terminal, B-phase wire on A-phase terminal, C-phase wire on B-  
phase terminal.  
kVA = expected value  
Power factor low and lagging  
Voltages and currents are normal  
© 2011 Schneider Electric All Rights Reserved  
 
77  
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Appendix A—Instrument Transformer Wiring: Troubleshooting Tables  
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Field Example  
Readings from a 4-wire system  
kW= 25  
kVAR= –15  
kVA= 27  
IA= 904A  
IB= 910A  
IC= 931A  
I3Avg= 908A  
VAB= 495V  
VBC= 491V  
VCA= 491V  
VAN= 287V  
VBN= 287V  
VCN= 284V  
PF3Avg= 0.75 lag to 0.22 lead fluctuating  
Troubleshooting Diagnosis  
Power factors cannot be correct .  
None of the “Section II” symptoms exist, so proceed to the 4-wire troubleshooting  
(“Section IV”).  
Cannot calculate kW because 3-phase power factor cannot be right, so calculate kVA  
instead.  
Calculated kVA = 3 Vab I3Avg   1000  
= 1.732 495 908  1000  
= 778 kVA  
Power meter reading is essentially zero compared to this value.  
4-wire Case E looks similar.  
Since the PTs were connected to other power meters which were reading correctly,  
suspect two CT leads swapped.  
Since A-phase power factor is the only one that has a normal looking lagging value,  
suspect B and C-phase CT leads may be swapped.  
After swapping B and C-phase CT leads, all readings went to the expected values;  
problem solved.  
78  
© 2011 Schneider Electric All Rights Reserved  
 
 
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PowerLogicTM Series 800 Power Meter  
Appendix B—Register List  
Appendix B—Register List  
Register List Access  
The register list corresponding to the latest firmware version can be found on line at the  
Schneider Electric website.  
1. Using a web browser, go to: www.Schneider-Electric.com.  
2. Locate the Search box in the upper right corner of the home page.  
3. In the Search box enter “PM8”.  
4. In the drop-down box click on the selection “PM800 series”.  
5. Locate the downloads area on the right side of the page and click on  
“Software/Firmware”.  
6. Click on the applicable register list then download the document file indicated.  
In addition you will find the latest firmware files and a firmware history file that describes the  
enhancements for each of the different firmware releases.  
About Registers  
For registers defined in bits, the rightmost bit is referred to as bit 00. Figure B–1 shows how  
bits are organized in a register.  
Figure B–1: Bits in a register  
High Byte  
Low Byte  
0
0
0
0
0
0
1
0
0
0
1
0
0
1
0
0
Bit No.  
15 14 13 12 11 10 09 08 07 06 05 04 03 02 01  
00  
The power meter registers can be used with MODBUS or JBUS protocols. Although the  
MODBUS protocol uses a zero-based register addressing convention and JBUS protocol  
uses a one-based register addressing convention, the power meter automatically  
compensates for the MODBUS offset of one. Regard all registers as holding registers  
where a 30,000 or 40,000 offset can be used. For example, Current Phase A will reside in  
register 31,100 or 41,100 instead of 1,100.  
Floating-point Registers  
Floating-point registers are also available. To enable floating-point registers, see “Enabling  
© 2011 Schneider Electric All Rights Reserved  
 
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Appendix B—Register List  
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How Date and Time are Stored in Registers  
The date and time are stored in a three-register compressed format. Each of the three  
registers, such as registers 1810 to 1812, contain a high and low byte value to represent  
the date and time in hexadecimal. Table B–1 lists the register and the portion of the date or  
time it represents.  
Table B–1: Date and Time Format  
Register  
Hi Byte  
Lo Byte  
Register 0  
Month (1-12)  
Day (1-31)  
Register 1  
Register 2  
Year (0-199)  
Minute (0-59)  
Hour (0-23)  
Second (0-59)  
Table B–2 provides an example of the date and time. If the date was 01/25/00 at 11:06:59,  
the Hex value would be 0119, 640B, 063B. Breaking it down into bytes we have the  
following:  
Table B–2: Date and Time Byte Example  
Hexadecimal Value  
Hi Byte  
Lo Byte  
0119  
01 = month  
19 = day  
640B  
063B  
64 = year  
0B = hour  
06 = minute  
3B = seconds  
NOTE: Date format is a 3 (6-byte) register compressed format. (Year 2001 is represented  
as 101 in the year byte.)  
How Signed Power Factor is Stored in the Register  
Each power factor value occupies one register. Power factor values are stored using  
signed magnitude notation (see Figure B–2). Bit number 15, the sign bit, indicates  
leading/lagging. A positive value (bit 15=0) always indicates leading. A negative value (bit  
15=1) always indicates lagging. Bits 0–9 store a value in the range 0–1,000 decimal. For  
example the power meter would return a leading power factor of 0.5 as 500. Divide by  
1,000 to get a power factor in the range 0 to 1.000.  
Figure B–2: Power Factor Register Format  
15 14 13 12 11 10  
9
8
7
6
5
4
3
2
1
0
0
0
0
0
0
Unused Bits  
Set to 0  
Power Factor  
in the range 100-1000 (thousandths)  
Sign Bit  
0=Leading  
1=Lagging  
When the power factor is lagging, the power meter returns a high negative value—for  
example, -31,794. This happens because bit 15=1 (for example, the binary equivalent of -  
31,794 is 1000001111001110). To get a value in the range 0 to 1,000, you need to mask bit  
15. You do this by adding 32,768 to the value. An example will help clarify.  
Assume that you read a power factor value of -31,794. Convert this to a power factor in the  
range 0 to 1.000, as follows:  
-31,794 + 32,768 = 974  
974/1,000 = .974 lagging power factor  
80  
© 2011 Schneider Electric All Rights Reserved  
 
               
63230-500-225A2  
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PowerLogicTM Series 800 Power Meter  
Appendix B—Register List  
Supported Modbus Commands  
Table B–3 provides the Modbus commands that the PM800 Series meters support. For an  
up-to-date register list, see ““Register List Access”” at the start of this chapter.  
Table B–3: Modbus Commands  
Command  
Description  
0x03  
0x04  
0x06  
0x10  
Read holding registers  
Read input registers  
Preset single registers  
Preset multiple registers  
Report ID  
Return String  
byte 1: 0x11  
byte 2: number of bytes following without crc  
byte 3: ID byte = 250  
0x11  
byte 4: status = 0xFF  
bytes 5+: ID string = PM8xx Power Meter  
last 2 bytes: CRC  
Read device identification, BASIC implementation (0x00, 0x01, 0x02 data),  
conformity level 1,  
Object Values  
0x01: If register 4128 is 0, then “Schneider Electric. If register 4128 is 1,  
then “Square D”  
0x2B  
0x02: “PM8xx”  
0x03: “Vxx.yyy” where xx.yyy is the OS version number. This is the  
reformatted version of register 7001. If the value for register 7001 is 11900,  
then the 0x03 data would be “V11.900”  
Resetting Registers  
Table B–4 provides the commands needed to reset many of the power meter features. You  
can perform these resets simply by writing the commands into register 4126.  
Table B–4: Register Listing—Reset Commands  
Reset Commands—Write commands to Register 4126.  
Command  
666  
Parameters  
Notes  
Restart demand metering  
1115  
Reset Meter  
3211  
Reset all alarms to default values  
De-energize digital output  
Energize digital output  
3320  
3321  
3361  
Reset digital output counter  
Reset digital input counters  
3365  
Register Energy value to  
7016  
7017  
7018  
7019  
7020  
7021  
4000  
4001  
4002  
4003  
4004  
4005  
6209  
Preset Energy Values  
10001  
14255  
21212  
30078  
Clear the Usage Timers. (Set to 0)  
Reset all Min/Max Values. (Sets values to defaults)  
Reset Peak Demand values. (Set to 0)  
Clear all Energy Accumulators. (Set to 0)  
© 2011 Schneider Electric All Rights Reserved  
 
81  
       
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Appendix B—Register List  
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© 2011 Schneider Electric All Rights Reserved  
 
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Appendix C—Using the Command Interface  
Appendix C—Using the Command Interface  
Overview of the Command Interface  
The power meter provides a command interface, which can be used to issue commands  
that perform various operations such as controlling relays. Table C–1 lists the definitions for  
the registers.Table C–2 lists the available commands. The command interface is located in  
memory at registers 8000–8149.  
Table C–1: Location of the command interface  
Register  
Description  
8000  
This is the register where you write the commands.  
These are the registers where you write the parameters for a  
command. Commands can have up to 15 parameters associated with  
them.  
8001–8015  
Command pointer. This register holds the register number where the  
most recently entered command is stored.  
8017  
8018  
8019  
Results pointer. This register holds the register number where the  
results of the most recently entered command are stored.  
I/O data pointer. Use this register to point to data buffer registers  
where you can send additional data or return data.  
These registers are for you (the user) to write information. Depending  
on which pointer places the information in the register, the register can  
contain status (from pointer 8017), results (from pointer 8018), or data  
(from pointer 8019). The registers will contain information such as  
whether the function is enabled or disabled, set to fill and hold, start  
and stop times, logging intervals, and so forth.  
8020–8149  
By default, return data will start at 8020 unless you specify otherwise.  
When registers 8017 through 8019 are set to zero, no values are returned. When any or all  
of these registers contain a value, the value in the register “points” to a target register,  
which contains the status, error code, or I/O data (depending on the command) when the  
command is executed. Figure C–1 shows how these registers work.  
NOTE: You determine the register location where results will be written. Therefore, take  
care when assigning register values in the pointer registers; values may be corrupted when  
two commands use the same register.  
Figure C–1: Command interface pointer registers  
Register 8017 8020  
(status of the  
last command)  
1
Register 8020  
Register 8021  
Register 8022  
Register 8018 8021  
Register 8019 8022  
(error code caused by  
the last command)  
51  
0
(data returned by the  
last command)  
Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.  
83  
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PowerLogicTM Series 800 Power Meter  
Appendix C—Using the Command Interface  
63230-500-225A2  
3/2011  
Issuing Commands  
To issue commands using the command interface, follow these general steps:  
1. Write the related parameter(s) to the command parameter registers 8001–15.  
2. Write the command code to command interface register 8000.  
If no parameters are associated with the command, then you need only to write the  
command code to register 8000. Table C–2 lists the command codes that can be written to  
the command interface into register 8000. Some commands have an associated register  
where you write parameters for that command. For example, when you write the parameter  
9999 to register 8001 and issue command code 3351, all relays will be energized if they are  
set up for external control.  
Table C–2: Command Codes  
Command  
Command  
Code  
Parameter  
Register  
Parameters  
Description  
Causes soft reset of the unit (re-initializes the  
power meter).  
1110  
1210  
1310  
None  
None  
None  
None  
Clears the communications counters.  
Sets the system date and time. Values for the  
registers are:  
8001  
8002  
8003  
8004  
8005  
8006  
Month  
Day  
Month (1–12)  
Day (1–31)  
Year  
Year (4-digit, for example 2000)  
Hour (Military time, for example 14 = 2:00pm)  
Minute (1–59)  
Hour  
Minute  
Second  
Second (1–59)  
1410  
1411  
None  
None  
None  
None  
Disables the revenue security switch  
Enables the revenue security switch  
Relay Outputs  
3310  
3311  
3320  
3321  
8001  
8001  
8001  
8001  
Relay Output Number Configures relay for external control.  
Relay Output Number Configures relay for internal control.  
Relay Output Number De-energizes designated relay.  
Relay Output Number Energizes designated relay.  
Releases specified relay from latched  
condition.  
3330  
8001  
Relay Output Number ➀  
3340  
3341  
3350  
3351  
3361  
3362  
3363  
3364  
8001  
8001  
8001  
8001  
8001  
8001  
8001  
8001  
Relay Output Number Releases specified relay from override control.  
Relay Output Number Places specified relay under override control.  
9999  
9999  
De-energizes all relays.  
Energizes all relays.  
Relay Output Number Resets operation counter for specified relay.  
Relay Output Number Resets the turn-on time for specified relay.  
None  
None  
Resets the operation counter for all relays.  
Resets the turn-on time for all relays.  
Resets the operation counter for specified  
input.  
3365  
8001  
Input Number ➀  
3366  
3367  
3368  
3369  
3370  
3371  
3380  
3381  
8001  
8001  
8001  
8001  
8001  
8001  
8001  
8002  
Input Number ➀  
None  
Resets turn-on time for specified input.  
Resets the operation counter for all inputs.  
Resets turn-on time for all inputs.  
None  
None  
Resets all counters and timers for all I/Os.  
Analog Output Number Disables specified analog output.  
Analog Output Number Enables specified analog output.  
9999  
9999  
Disables all analog outputs.  
Enables all analog outputs.  
You must write to register 8001 the number that identifies which output you would like to use. To determine  
the identifying number, refer to“I/O Point Numbers” on page 86 for instructions.  
Data buffer location (register 8019) is the pointer to the first register where data will be stored. By default,  
return data begins at register 8020, although you can use any of the registers from 8020–8149. Take care when  
assigning pointers. Values may be corrupted if two commands are using the same register.  
Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.  
84  
© 2011 Schneider Electric. All Rights Reserved.  
 
       
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Appendix C—Using the Command Interface  
Table C–2: Command Codes  
Command  
Command  
Parameter  
Parameters  
Description  
Code  
Register  
Resets  
1522  
None  
8001  
None  
Resets the alarm history log.  
Resets min/max.  
0 = Present and previous  
months  
4110  
1 = Present month  
2 = Previous month  
None  
5110  
5111  
5113  
5114  
None  
None  
None  
None  
Resets all demand registers.  
Resets current demand.  
Resets power demand.  
Resets input demand.  
None  
None  
None  
Resets generic demand for first group of 10  
quantities.  
5115  
None  
None  
5210  
5211  
5213  
5214  
5215  
None  
None  
None  
None  
None  
None  
None  
None  
None  
None  
Resets all min/max demand.  
Resets current min/max demand.  
Resets power min/max demand.  
Resets input min/max demand.  
Resets generic 1 min/max demand.  
Start new demand interval.  
Bit 0 = Power Demand  
5910  
6209  
8001  
8019  
Bitmap  
1 = Current Demand  
2 = Input Metering Demand  
3 = Generic Demand Profile  
Preset Accumulated Energies  
Requires the IO Data Pointer to point to  
registers where energy preset values are  
entered. All Accumulated energy values must  
be entered in the order in which they occur in  
registers 1700 to 1727.  
I/O Data Pointer ➁  
6210  
6211  
6212  
6213  
6214  
None  
None  
None  
None  
None  
None  
None  
None  
None  
None  
Clears all energies.  
Clears all accumulated energy values.  
Clears conditional energy values.  
Clears incremental energy values.  
Clears input metering accumulation.  
Resets the following parameters to IEEE or  
IEC defaults:  
1. Phase labels  
2. Menu labels  
3. Harmonic units  
4. PF sign  
1 = IEEE  
2 = IEC  
6215  
None  
5. THD denominator  
6. Date Format  
6320  
6321  
6910  
None  
None  
None  
None  
None  
None  
Disables conditional energy accumulation.  
Enables conditional energy accumulation.  
Starts a new incremental energy interval.  
Files  
Triggers data log entry. Bitmap where Bit 0 =  
Data Log 1, Bit 1 = Data Log 2, Bit 2 = Data  
Log 3, etc.  
7510  
7511  
8001  
8001  
1–3  
File Number  
Triggers single data log entry.  
You must write to register 8001 the number that identifies which output you would like to use. To determine  
the identifying number, refer to“I/O Point Numbers” on page 86 for instructions.  
Data buffer location (register 8019) is the pointer to the first register where data will be stored. By default,  
return data begins at register 8020, although you can use any of the registers from 8020–8149. Take care when  
assigning pointers. Values may be corrupted if two commands are using the same register.  
Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.  
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Appendix C—Using the Command Interface  
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Table C–2: Command Codes  
Command  
Parameter  
Register  
Command  
Code  
Parameters  
Description  
Setup  
9020  
None  
8001  
None  
Enter into setup mode.  
Exit setup mode and save all changes.  
1 = Save  
9021  
2 = Do not save  
You must write to register 8001 the number that identifies which output you would like to use. To determine  
the identifying number, refer to“I/O Point Numbers” on page 86 for instructions.  
Data buffer location (register 8019) is the pointer to the first register where data will be stored. By default,  
return data begins at register 8020, although you can use any of the registers from 8020–8149. Take care when  
assigning pointers. Values may be corrupted if two commands are using the same register.  
Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.  
I/O Point Numbers  
All inputs and outputs of the power meter have a reference number and a label that  
correspond to the position of that particular input or output.  
The reference number is used to manually control the input or output with the command  
interface.  
The label is the default identifier that identifies that same input or output. The label  
appears on the display, in PowerLogic software, and on the option card.  
See Table C–3 for a complete list of I/O Point Numbers  
Table C–3: I/O Point Numbers  
Module  
Standard I/O  
PM8M22 PM8M26 PM8M2222  
I/O Point Number  
KY  
S1  
1
2
A-R1  
A-R2  
A-S1  
A-S2  
A-S3  
A-S4  
A-S5  
A-S6  
A-R1  
A-R2  
A-S1  
3
4
5
6
7
8
9
10  
A-R1  
A-R2  
A-S1  
A-S2  
A-S2  
A
B
A-AI1  
A-AI2  
A-AO1  
A-AO2  
B-R1  
B-R2  
B-S1  
B-S2  
B-S3  
B-S4  
B-S5  
B-S6  
B-R1  
B-R2  
B-S1  
11  
12  
13  
14  
15  
16  
17  
18  
B-R1  
B-R2  
B-S1  
B-S2  
B-S2  
B-AI1  
B-AI2  
B-AO1  
B-AO2  
Operating Outputs from the Command Interface  
To operate an output from the command interface, first identify the relay using the I/O point  
number. Then, set the output to external control. For example, to energize output 1, write  
the commands as follows:  
1. Write number 1 to register 8001.  
2. Write command code 3310 to register 8000 to set the relay to external control.  
3. Write command code 3321 to register 8000.  
If you look in the “Relay Outputs” section of Table C–2 on page 84, you’ll see that  
command code 3310 sets the relay to external control and command code 3321 is listed as  
the command used to energize a relay. Command codes 3310–3381 are for use with inputs  
and outputs.  
Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.  
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Appendix C—Using the Command Interface  
Using the Command Interface to Change Configuration Registers  
You can also use the command interface to change values in selected metering-related  
registers, such as setting the time of day of the clock or resetting generic demand.  
Two commands, 9020 and 9021, work together as part of the command interface  
procedure when you use it to change power meter configuration. You must first issue  
command 9020 to enter into setup mode, change the register, and then issue 9021 to save  
your changes and exit setup mode.  
Only one setup session is allowed at a time. While in this mode, if the power meter detects  
more than two minutes of inactivity, that is, if you do not write any register values or press  
any buttons on the display, the power meter will time out and restore the original  
configuration values. All changes will be lost. Also, if the power meter loses power or  
communications while in setup mode, your changes will be lost.  
The general procedure for changing configuration registers using the command interface is  
as follows:  
1. Issue command 9020 in register 8000 to enter into setup mode.  
2. Make changes to the appropriate register by writing the new value to that register.  
Perform register writes to all registers that you want to change. For instructions on  
reading and writing registers, see “Read and Write Registers” on page 26.  
3. To save the changes, write the value 1 to register 8001.  
NOTE: Writing any other value except 1 to register 8001 lets you exit setup mode  
without saving your changes.  
4. Issue command 9021 in register 8000 to initiate the save and reset the power meter.  
For example, the procedure to change the demand interval for current is as follows:  
1. Issue command code 9020 in register 8000.  
2. Write the new demand interval to register 1801.  
3. Write 1 to register 8001.  
4. Issue command code 9021 in register 8000.  
Refer to “Register List Access” on page 79 for instructions on accessing the complete  
register list.  
Conditional Energy  
Power meter registers 1728–1744 are conditional energy registers.  
Conditional energy can be controlled in one of two ways:  
Over the communications link, by writing commands to the power meter’s command  
interface, or  
By a digital input—for example, conditional energy accumulates when the assigned  
digital input is on, but does not accumulate when the digital input is off.  
The following procedures explain how to set up conditional energy for command interface  
control and for digital input control. The procedures refer to register numbers and command  
codes. For a listing of command codes, see Table C–2 on page 84.  
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Command Interface Control  
Set Control—To set control of conditional energy to the command interface:  
1. Write command code 9020 to register 8000.  
2. In register 3227, set bit 6 to 1 (preserve other bits that are ON).  
3. Write 1 to register 8001.  
4. Write command code 9021 to register 8000.  
Start— To start conditional energy accumulation, write command code 6321 to register  
8000.  
Verify Setup—To verify proper setup, read register 1794. The register should read 1,  
indicating conditional energy accumulation is ON.  
Stop—To stop conditional energy accumulation, write command code 6320 to register  
8000.  
Clear—To clear all conditional energy registers (1728-1747), write command code  
6212 to register 8000.  
Digital Input Control  
Set Control—To configure conditional energy for digital input control:  
1. Write command code 9020 to register 8000.  
2. In register 3227, set bit 6 to 0 (preserve other bits that are ON).  
3. Configure the digital input that will drive conditional energy accumulation. For the  
appropriate digital input, write 3 to the Base +9 register.  
4. Write 1 to register 8001.  
5. Write command code 9021 to register 8000.  
Clear—To clear all conditional energy registers (1728–1747), write command code  
6212 to register 8000.  
Verify Setup—To verify proper setup, read register 1794. The register should read 0  
when the digital input is off, indicating that conditional energy accumulation is off. The  
register should read 1 when conditional energy accumulation is on.  
Incremental Energy  
The power meter’s incremental energy feature allows you to define a start time, end time,  
and time interval for incremental energy accumulation. At the end of each incremental  
energy period, the following information is available:  
Wh IN during the last completed interval (reg. 1748–1750)  
VARh IN during the last completed interval (reg. 1751–1753)  
Wh OUT during the last completed interval (reg. 1754–1756)  
VARh OUT during the last completed interval (reg. 1757–1759)  
VAh during the last completed interval (reg. 1760–1762)  
Date/time of the last completed interval (reg. 1763–1765)  
Peak kW demand during the last completed interval (reg. 1940)  
Date/Time of Peak kW during the last completed interval (reg. 1941–1943)  
Peak kVAR demand during the last completed interval (reg. 1945)  
Date/Time of Peak kVAR during the last completed interval (reg. 1946–1948)  
Peak kVA demand during the last completed interval (reg. 1950)  
Date/Time of Peak kVA during the last completed interval (reg. 1951–1953)  
The power meter can log the incremental energy data listed above. This logged data  
provides all the information needed to analyze energy and power usage against present or  
future utility rates. The information is especially useful for comparing different time-of-use  
rate structures.  
When using the incremental energy feature, remember that peak demands help minimize  
the size of the data log in cases of sliding or rolling demand. Shorter incremental energy  
periods make it easier to reconstruct a load profile analysis.  
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Appendix C—Using the Command Interface  
Using Incremental Energy  
Incremental energy accumulation begins at the specified start time and ends at the  
specified end time. When the start time arrives, a new incremental energy period begins.  
The start and end time are specified in minutes from midnight. For example:  
Interval: 420 minutes (7 hours)  
Start time: 480 minutes (8:00 a.m.)  
End time = 1440 minutes (12:00 p.m.)  
The first incremental energy calculation will be from 8:00 a.m. to 3:00 p.m. (7 hours) as  
illustrated in Figure C–2. The next interval will be from 3:00 p.m. to 10:00 p.m., and the  
third interval will be from 10 p.m. to 12:00 p.m. because 12:00 p.m. is the specified end  
time. A new interval will begin on the next day at 8:00 a.m. Incremental energy  
accumulation will continue in this manner until the configuration is changed or a new  
interval is started by a remote master.  
Figure C–2: Incremental energy example  
End Time  
12  
11  
1
10  
2
4
9
3
8
Start Time  
r
7
5
6
1st Interval (7 hours) = 8:00 a.m. to 3:00 p.m  
2nd Interval (7 hours) = 3:00 p.m. to 10:00 p.m  
3rd Interval (2 hours) = 10:00 p.m. to 12:00 p.m  
Set up—To set up incremental energy:  
1. Write command code 9020 to register 8000.  
2. In register 3230, write a start time (in minutes-from-midnight).  
3. For example, 8:00 am is 480 minutes.  
4. In register 3231, write an end time (in minutes-from-midnight).  
5. Write the desired interval length, from 0–1440 minutes, to register 3229.  
6. If incremental energy will be controlled from a remote master, such as a  
programmable controller, write 0 to the register.  
7. Write 1 to register 8001.  
8. Write command code 9021 to register 8000.  
Start—To start a new incremental energy interval from a remote master, write  
command code 6910 to register 8000.  
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Appendix C—Using the Command Interface  
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Setting Up Individual Harmonic Calculations  
The PM810 with a PM810LOG can perform up to the 31st harmonic magnitude and angle  
calculations for each metered value and for each residual value. The Power Meter can  
perform harmonic magnitude and angle calculations for each metered value and for each  
residual value. The harmonic magnitude for current and voltage can be formatted as either  
a percentage of the fundamental (THD), as a percentage of the rms values (thd), or rms.  
The harmonic magnitude and angles are stored in a set of registers: 13,200–14,608. During  
the time that the power meter is refreshing harmonic data, the power meter posts a value of  
0 in register 3246. When the set of harmonic registers is updated with new data, the power  
meter posts a value of 1 in register 3246. The power meter can be configured to hold the  
values in these registers for up to 60 metering update cycles once the data processing is  
complete.  
The power meter has three operating modes for harmonic data processing: disabled,  
magnitude only, and magnitude and angles. Because of the extra processing time  
necessary to perform these calculations, the factory default operating mode is magnitudes  
only.  
To configure the harmonic data processing, write to the registers described in Table C–4:  
Table C–4: Registers for Harmonic Calculations  
Reg No.  
Value  
Description  
Harmonic processing;  
0 = disabled  
3240  
0, 1, 2  
1 = magnitudes only enabled  
2 = magnitudes and angles enabled  
Harmonic magnitude formatting for voltage;  
0 = % of fundamental (default)  
1 = % of rms  
3241  
3242  
0, 1, 2  
0, 1, 2  
2 = rms  
Harmonic magnitude formatting for current;  
0 = % of fundamental (default)  
1 = % of rms  
2 = rms  
This register shows the harmonics refresh interval  
(default is 30 seconds).  
3243  
3244  
10–60 seconds  
0–60 seconds  
This register shows the time remaining before the  
next harmonic data update.  
This register indicates whether harmonic data  
processing is complete:  
3245  
0,1  
0 = processing incomplete  
1 = processing complete  
Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.  
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Appendix C—Using the Command Interface  
Changing Scale Factors  
The power meter stores instantaneous metering data in 16-bit single registers. A value held  
in each register must be an integer between –32,767 and +32,767. Because some values  
for metered current, voltage, and power readings fall outside this range, the power meter  
uses multipliers, or scale factors. This enables the power meter to extend the range of  
metered values that it can record.  
The power meter stores these multipliers as scale factors. A scale factor is the multiplier  
expressed as a power of 10. For example, a multiplier of 10 is represented as a scale factor  
1
2
of 1, since 10 =10; a multiplier of 100 is represented as a scale factor of 2, since 10 =100.  
You can change the default value of 1 to other values such as 10, 100, or 1,000. However,  
these scale factors are automatically selected when you set up the power meter, either  
from the display or by using PowerLogic software.  
If the power meter displays “overflow” for any reading, change the scale factor to bring the  
reading back into a range that fits in the register. For example, because the register cannot  
store a number as large as 138,000, a 138 kV system requires a multiplier of 10. 138,000 is  
converted to 13,800 x 10. The power meter stores this value as 13,800 with a scale factor  
1
of 1 (because 10 =10).  
Scale factors are arranged in scale groups. You can use the command interface to change  
scale factors on a group of metered values. However, be aware of these important points if  
you choose to change scale factors:  
We strongly recommend that you do not change the default scale factors, which are  
automatically selected by PowerLogic hardware and software.  
When using custom software to read power meter data over the communications link,  
you must account for these scale factors. To correctly read any metered value with a  
scale factor other than 0, multiply the register value read by the appropriate power of 10.  
As with any change to basic meter setup, when you change a scale factor, all min/max  
and peak demand values should be reset.  
Enabling Floating-point Registers  
For each register in integer format, the power meter includes a duplicate set of registers in  
floating-point format. The floating point registers are disabled by default, but they can be  
turned ON by doing the following:  
NOTE: See “Read and Write Registers” on page 26 for instructions on how to read and  
write registers.  
1. Read register 11700 (Current Phase A in floating-point format). If floating-point registers  
are OFF, you will see -32,768.  
2. Write command code 9020 to register 8000.  
3. Write 1 to register 3248.  
4. Write 1 to register 8001.  
5. Write command code 9021 to register 8000.  
6. Read register 11700. You will see a value of 1, which indicates floating-point registers  
are ON.  
NOTE: Values such as current phase A are not shown in floating-point format on the  
display even though floating-point registers are ON. To view floating-point values, read the  
floating-point registers using the display or PowerLogic software.  
Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.  
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Appendix C—Using the Command Interface  
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Appendix D—Advanced Power Quality Evaluations  
Appendix D—Advanced Power Quality Evaluations  
The information in this appendix applies to the following models:  
PM850—EN50160 (evaluation only)  
PM870—EN50160, ITI (CBEMA), and SEMI-F47  
Power Quality Standards  
The Advanced Power Quality feature includes power quality (PQ) evaluations according to  
the European standard EN50160 and the SEMI-F47/ITI (CBEMA) specifications. The  
PM870 registers data under both standards. The PM850 can report data under the  
EN50160 standard only. For instructions on how to enable these evaluation features, see  
SEMI-F47/ITI (CBEMA) Specification  
The SEMI-F47-200 Specification for Semiconductor Processing Equipment Voltage Sag  
Immunity was approved by the Global Facilities Committee and is the direct responsibility  
of the North American Facilities Committee. This standard is very similar to the Information  
Technical Industry (ITI) Council standard.  
Semiconductor factories require high levels of power quality due to the sensitivity of  
equipment and process controls. Semiconductor processing equipment is especially  
vulnerable to voltage sags.  
The SEMI-F47 standard addresses specifications for semiconductor processing equipment  
voltage sag immunity. It does not include over-voltage conditions, voltage sag durations  
less than 0.05 seconds (50 milliseconds), or voltage sag duration greater than 1.0 seconds.  
If necessary, the ITI CBEMA-curve can be used to specify additional requirements.  
Refer to the Schneider Electric POWERLOGIC Web Pages Instruction Bulletin (document  
# 63230-304-207) for more information on using the web pages on the ECC to view  
SEMI-47 and ITI(CBEMA) data.  
Table D–1: Categorized disturbance levels (% of nominal)  
Sag levels  
Swell levels  
80% — 90%  
70% — 80%  
40% — 70%  
0% — 40%  
110% — 120%  
120% — 140%  
140% — 200%  
200% — 500%  
Table D–2: Duration categories  
Duration  
< 20 msec  
20 msec — 500 msec  
500 msec — 10 sec  
>10 sec  
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Appendix D—Advanced Power Quality Evaluations  
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Figure D–1: ITI (CBEMA) Curve  
ITI (CBEMA) Curve  
500  
400  
300  
Prohibited Region  
Voltage Tolerance Envelope  
Applicable to 120, 120/208,  
and 120/240 Nominal Voltages  
200  
140  
120  
100  
110  
90  
No Interruption In Function Region  
80  
70  
40  
0
No Damage Region  
Steady  
State  
0.5 s  
20 ms  
10 s  
Duration in Seconds (s)  
Table D–3: Categorized disturbance levels (F-47)  
Sag levels  
80% — 90%  
70% — 80%  
50% — 70%  
0% — 50%  
Table D–4: Duration categories  
Duration  
< 50 msec  
50 msec — 200 msec  
200 msec — 500 msec  
500 msec — 1000 msec  
>1000 msec  
Figure D–2: Voltage Sag ride-through capability  
Duration of Voltage Sag in Seconds  
0.05  
100  
0.10  
0.20  
0.50  
1.00  
90  
80  
70  
60  
50  
40  
30  
20  
10  
0
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Appendix D—Advanced Power Quality Evaluations  
EN50160:2000 Specification  
EN50160:2000 “Voltage characteristics of electricity supplied by public distribution systems”  
is a European standard that defines the quality of the voltage a customer can expect from  
the electric utility. Although this is a European standard, it can be applied globally.  
The PM850 and the PM870 evaluates the following electrical characteristics in accordance  
with EN50160:  
Table D–5: EN50160 Evaluation for the PM850 and PM870  
Feature  
PM850  
PM870  
Evaluation During Normal Operation (Meter-based Data)  
Frequency  
3
3
3
3
3
3
Supply voltage variations  
Supply voltage unbalance  
Harmonic voltage  
3
3
3
3
Total Harmonic Distortion  
Evaluations During Abnormal Operations (Alarm-based Data)  
Magnitude of rapid voltage changes  
Supply voltage dips  
3
3
3
3
3
3
3
Short interruptions of the supply voltage  
Long interruptions of the supply voltage  
Temporary power frequency over-voltages  
3
3
3
The PM850 performs EN50160 evaluations based on standard alarms, while the  
PM870 performs EN50160 evaluations on disturbance alarms.  
These features must be configured using register writes. See Table D–11 on page 99  
for a list of configuration and status registers.  
As illustrated in Table D–5, the EN50160 evaluations performed by the PM850 and the  
PM870 can be divided into two categories. The first category performs evaluations during  
normal operation utilizing meter data. The second category performs evaluations during  
abnormal operation utilizing either standard alarms (PM850) or disturbance alarms (PM870).  
The EN50160:2000 Specification sets limits for most of the evaluations. These limits are  
built into the PM850 and the PM870 firmware. You can configure registers for other  
evaluations and change them from the default values.  
How Evaluation Results Are Reported  
The PM850 and the PM870 reports evaluation data in register entries and alarm log  
entries. Table D–6 describes the register entries for the evaluation data.  
Table D–6: Register Entries  
Register  
Description  
Number  
Summary bitmap of active evaluations that reports which areas  
of evaluation are active in the PM850 and the PM870.  
3910  
Summary bitmap of evaluation status that reports the pass/fail  
status of each area of evaluation.  
3911  
Detail bitmap of evaluation status that reports the pass/fail status  
of the evaluation of each individual data item. Detailed data  
summary information is also available for each of the evaluations  
Portal registers  
for the present interval and for the previous interval. You can  
access this data over a communications link using Modbus block  
reads of “portal” registers. Refer to “Evaluation During Normal  
Operation” on page 96 for additional information.  
Log entries for the evaluation data include:  
On-board alarm log entry for diagnostic alarms: When the status of an area of  
evaluation is outside the range of acceptable values, an entry is made in the on-board  
alarm log. This entry provides notification of the exception for a specific area of  
evaluation. This notification is reported only in PowerLogic software and does not  
appear on the local display.  
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On-board alarm log entry for alarms: PM850 and the PM870 alarms are used to  
perform some of the evaluations. If an on-board alarm log is enabled, an entry will be  
made in the on-board alarm log when any of these alarms pick up or drop out.  
NOTE: Enabling PQ Advanced evaluation does not guarantee that the on-board alarm log  
or waveform files are enabled or properly configured to record these events. You should  
consider your requirements and configure these files and the event captures triggered by  
the various alarms to provide any additional data that would be helpful to diagnose or  
document an exception to this standard.  
Possible Configurations Through Register Writes  
This section describes the changes you can make to configurations for the EN50160  
evaluation through register writes in the PM850 and the PM870. Refer to “Advanced  
SEMI-F47/ITI (CBEMA)]” on page 99 for register assignments.  
Select the first day of the week for evaluations. You can define the first day of the  
week to be used for the EN50160 evaluations in register 3905.  
Define the voltage interruption. The standard defines an interruption as voltage less  
than 1% of nominal voltage. Because some locations require a different definition, you  
can configure this value in register 3906.  
Define allowable range of slow voltage variations. The standard defines the allowable  
range of slow voltage variations to be ±10% of nominal voltage. Because some locations  
require a different definition, you can configure this value in register 3907.  
1
Evaluation During Normal Operation  
When the EN50160 evaluation is enabled, the PM850 and the PM870 evaluates metered  
data under normal operating conditions, “excluding situations arising from faults or voltage  
interruptions.” For this evaluation, normal operating conditions are defined as all phase  
voltages greater than the definition of interruption. The standard specifies acceptable  
ranges of operation for these data items.  
This section describes how the EN50160 standard addresses metered data.  
Power Frequency  
EN50160 states that the nominal frequency of the supply voltage shall be 50 Hz. Under  
normal operating conditions, the power meter will perform the valuation based on the  
nominal frequency set on the meter.  
for systems with synchronous connection to an interconnected system:  
— 50 Hz 1% during 99.5% of a year  
— 50 Hz + 4 to -6% for 100% of the time  
for systems with no synchronous connection to an interconnected system (for example,  
power systems on some islands):  
— 50 Hz 2% during 95% of a week  
— 50 Hz 15% for 100% of the time  
NOTE: The same range of percentages are used for 60 Hz systems.  
Supply Voltage Variations  
EN50160 states that, under normal operating conditions, excluding situations arising from  
faults or voltage interruptions:  
during each period of one week 95% of the ten minute mean rms values of the supply  
voltage shall be within the range of U 10%.  
n
all ten minute mean rms values of the supply voltage shall be within the range of U  
+10% to -15%.  
n
1
EN 50160:2000, Voltage characteristics of electricity supplied by public distribution systems.  
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Appendix D—Advanced Power Quality Evaluations  
Supply Voltage Unbalance  
EN50160 states that, under normal operating conditions, during each period of one week,  
95% of the ten minute mean rms values of the negative phase sequence component of the  
supply voltage shall be within the range 0–2% of the positive phase sequence component.  
Harmonic Voltage  
EN50160 states that, under normal operating conditions, during each period of one week,  
95% of the ten minute mean rms values of each individual harmonic voltage shall be less  
than or equal to the value given in Table D–7. Additionally, the THD of the supply voltage  
shall be less than 8%.  
Table D–7: Values of individual harmonic voltages at the supply terminals for orders up  
to 25 in % of nominal voltage  
Odd Harmonics  
Even Harmonics  
Not Multiples of 3  
Multiples of 3  
Relative  
Relative  
Relative  
Voltage  
Order h  
Order h  
Order h  
Voltage  
6%  
Voltage  
5%  
5
3
9
2
4
2%  
1%  
7
5%  
1.5%  
0.5%  
0.5%  
11  
13  
17  
19  
23  
25  
3.5%  
3%  
15  
21  
6...24  
0.5%  
2%  
1.5%  
1.5%  
NOTE: No values are given for harmonics of order higher than 25, as they are usually small, but largely  
unpredictable because of resonance effects.  
Evaluations During Abnormal Operation  
Count of Magnitude of Rapid Voltage Changes  
The standard does not specify the rate of change of the voltage for this evaluation. For this  
evaluation, the PM850 and the PM870 counts a change of 5% nominal and 10%  
nominal from one one-second meter cycle to the next one-second meter cycle. It counts  
rapid voltage decreases and increases separately. The interval for accumulation of these  
events is one week.  
You can configure the number of allowable events per week in register 3917.  
(Default = -32768 = Pass/Fail evaluation disabled.)  
Detection and Classification of Supply Voltage Dips  
According to EN50160, voltage dips are generally caused by faults in installations or the  
electrical utility distribution system. The faults are unpredictable and frequency varies  
depending on the type of power system and where events are monitored.  
Under normal operating conditions, the number of voltage dips expected may be anywhere  
from less than a hundred to nearly a thousand. The majority of voltage dips last less than  
one second with a depth less than 60%. However, voltage dips of greater depth and  
duration can occasionally occur. In some regions, voltage dips with depths between 10%  
and 15% of the nominal voltage are common because of the switching of loads at a  
customer’s installation.  
Supply voltage dips are under-voltage events that last from 10 ms to 1 minute. Magnitudes  
are the minimum rms values during the event. Disturbance alarms are used to detect these  
events in the PM870. Standard speed under-voltage alarms are used to detect these  
events in the PM850. The standard does not specifically address how to classify supply  
voltage dips or how many are allowable. Table D–8 shows how the PM850 and the PM870  
detect and classify the dips for each phase voltage.  
97  
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PowerLogicTM Series 800 Power Meter  
Appendix D—Advanced Power Quality Evaluations  
63230-500-225A2  
3/2011  
Table D–8: Voltage dip classifications  
Duration (t) seconds  
1 t < 3  
3 t < 10 10 t < 20 20 t < 60 60  t < 180  
Total  
Depth (D) % Nominal  
10 D < 15  
15 D < 30  
30 D < 45  
45 D < 60  
60 D < 75  
75 D < 90  
90 D < 99  
Total  
You can configure the number of allowable events per week for each range of Depth in  
registers 3920 – 3927. (Default = -32768 = Pass/Fail evaluation disabled.)  
Detection of Interruptions of the Supply Voltage  
The standard defines an interruption as voltage less than 1% of nominal voltage. Because  
some locations require a different definition, you can configure this value in register 3906.  
Interruptions are classified as “short” if duration 3 minutes or “long” otherwise. The  
PM850 and the PM870 classifies interruptions as shown in Table D–9.  
Table D–9: Voltage interruptions  
Duration (t) seconds  
5 t < 10  t < 20 t < 60 t < 180 t < 600 t <  
t < 1  
1 t < 2 2 t < 5  
1200 t  
10  
20  
60  
180  
600  
1200  
Total  
You can configure the number of allowable short interruptions per year in register 3918  
(Default = -32768 = Pass/Fail evaluation disabled). You can configure the number of  
allowable long interruptions per year in register 3919. (Default = -32768 = Pass/Fail  
evaluation disabled.)  
Detecting and Classifying Temporary Power Frequency Over-voltages  
As stated in EN50160, a temporary power frequency over-voltage generally appears during  
a fault in the electrical utility power distribution system or in a customer’s installation, and  
disappears when the fault is cleared. Usually, the over-voltage may reach the value of  
phase-to-phase voltage because of a shift of the neutral point of the three-phase voltage  
system.  
Under certain circumstances, a fault occurring upstream from a transformer will produce  
temporary over-voltages on the low voltage side for the time during which the fault current  
flows. Such over-voltages will generally not exceed 1.5 kV rms.  
Table D–10 shows how the PM850 and the PM870 detect and classify the over-voltages for  
each phase voltage.  
NOTE: Disturbance alarms are used to detect these events in the PM870. In the PM850,  
standard speed over-voltage alarms are used to detect these events.  
Table D–10: Over-voltages  
Duration (t) seconds  
Magnitude (M) %  
1  t < 3 3  t < 10 10  t < 20 20  t < 60 60  t < 180  
Total  
Nominal  
110 < M 115  
115 < M 130  
130 < M 145  
145 < M 160  
160 < M 175  
175 < M 200  
M > 200  
Total  
You can configure the number of allowable events per week for each range of magnitude in  
registers 3930 – 3937. (Default = -32768 = Pass/Fail evaluation disabled.)  
98  
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63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Appendix D—Advanced Power Quality Evaluations  
Operation with PQ Advanced Enabled  
This section describes how PM850 and PM870 EN50160 evaluation operation is affected  
when PQ Advanced evaluation is enabled.  
Resetting Statistics  
You can reset statistics for the EN50160 evaluations with the command 11100. A  
parameter value of 9999 will reset all items. A timestamp is provided in registers for each  
item indicating when the last reset was performed. This command is disabled when  
revenue security is active.  
NOTE: You should reset statistics when you enable EN50160 for the first time and also  
whenever you make any changes to the basic meter setup such as changing the nominal  
Harmonic Calculations  
When PQ Advanced evaluation is enabled, the harmonic calculations will be set to update  
every 10 seconds. You can select the format of the harmonic calculations to be %Nominal,  
%Fundamental, or %RMS.  
Time Intervals  
Time intervals are synchronized with the Trending and Forecasting feature. For additional  
information, refer to the Schneider Electric POWERLOGIC Web Pages Instruction Bulletin  
(document # 63230-304-207). Weekly values will be posted at midnight of the morning of  
the “First Day of Week” configured in register 3905. Yearly values will be based on the  
calendar year.  
All of the EN50160 data is stored in non-volatile memory once per hour or when an event  
occurs. In the event of a meter reset, up to one hour of routine meter evaluation data will be  
lost.  
Advanced Power Quality Evaluation System Configuration  
and Status Registers [EN50160 and SEMI-F47/ITI (CBEMA)]  
Table D–11 lists registers for system configuration and status evaluation.  
Table D–11: PQ Advanced Evaluation System Configuration and Status Registers  
Register Number Description  
Enable/Disable PQ Advanced Evaluation  
3900  
3901  
3902  
3903  
3904  
1
1
1
1
1
0 = Disable (default)  
1 = Enable  
Nominal Voltage, (copied from register 3234 for reference)  
Default = 230  
Voltage Selection for 4-Wire Systems  
0 = Line-to-Neutral (default)  
1 = Line-to-Line  
Nominal Frequency, Hz (copied from register 3208 for reference)  
Default = 60  
Frequency configuration  
0 = system with synchronous connection to interconnected system (default)  
1 = system without synchronous connection to interconnected system  
First Day of Week (EN50160 only)  
1 = Sunday  
2 = Monday (default)  
3 = Tuesday  
3905  
1
4 = Wednesday  
5 = Thursday  
6 = Friday  
7 = Saturday  
99  
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PowerLogicTM Series 800 Power Meter  
Appendix D—Advanced Power Quality Evaluations  
63230-500-225A2  
3/2011  
Table D–11: PQ Advanced Evaluation System Configuration and Status Registers  
Register Number Description  
Definition of Interruption (EN50160 only)  
3906  
3907  
1
1
0 – 10% Nominal (default = 1)  
Allowable Range of Slow Voltage Variations (EN50160 only)  
1 – 20% Nominal (default = 10)  
3908  
3909  
1
1
Reserved  
Reserved  
Bitmap of active evaluations  
Bit 00 – Summary bit – at least one EN50160 evaluation is active  
Bit 01 – Frequency  
Bit 02 – Supply voltage variations  
Bit 03 – Magnitude of rapid voltage changes  
Bit 04 – Not used  
Bit 05 – Supply voltage dips  
Bit 06 – Short interruptions of the supply voltage  
Bit 07 – Long interruptions of the supply voltage  
Bit 08 – Temporary power frequency over-voltages  
Bit 09 – Not used  
3910  
1
Bit 10 – Supply voltage unbalance  
Bit 11 – Harmonic voltage  
Bit 12 – THD  
Bit 13 – Not used  
Bit 14 – Not used  
Bit 15 – Not used  
Bitmap of evaluation status summary  
Bit 00 – Summary bit – at least one EN50160 evaluation has failed.  
Bit 01 – Frequency  
Bit 02 – Supply voltage variations  
Bit 03 – Magnitude of rapid voltage changes  
Bit 04 – Not used  
Bit 05 – Supply voltage dips  
Bit 06 – Short interruptions of the supply voltage  
Bit 07 – Long interruptions of the supply voltage  
Bit 08 – Temporary power frequency over-voltages  
Bit 09 – Not used  
3911  
1
Bit 10 – Supply voltage unbalance  
Bit 11 – Harmonic voltage  
Bit 12 – THD  
Bit 13 – Not used  
Bit 14 – Not used  
Bit 15 – Not used  
3912  
3914  
3916  
2
2
1
Count of 10-second intervals present year  
Count of 10-second intervals this week  
Count of 10-minute intervals this week  
Number of allowable rapid voltage changes per week  
Default = -32768 = Pass/Fail evaluation disabled  
Number of allowable short interruptions per year  
Default = -32768 = Pass/Fail evaluation disabled  
Number of allowable long interruptions per year  
Default = -32768 = Pass/Fail evaluation disabled  
Number of allowable voltage dips per week for each range of Depth  
Default = -32768 = Pass/Fail evaluation disabled  
3917  
3918  
3919  
3920  
3930  
1
1
1
8
8
Number of allowable over-voltages per week for each range of Magnitude  
Default = -32768 = Pass/Fail evaluation disabled  
100  
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63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Appendix D—Advanced Power Quality Evaluations  
EN50160 Evaluation Data Available Over a Communications Link  
Portal Registers  
Evaluation data is available over communications via “portal” register reads. Each data  
item is assigned a portal register number. A block read of the specified size at that address  
will return the data for that item. In general, if the block size is smaller than specified, the  
data returned will be 0x8000 (-32768) to indicate the data is invalid. If the block size is  
larger than specified, the data for the item will be returned and the remaining registers will  
be padded with 0x8000. Refer to Table D–12 for portal register descriptions.  
Table D–12: Portal Register Descriptions  
Portal  
Description Size  
Data  
Register number of Metered Quantity (can be used to confirm data item  
being reported)  
Register value (present metered value)  
Average value (at end of last completed averaging time period)  
Minimum value during the last completed averaging time period  
Maximum value during the last completed averaging time period  
Minimum value during this interval  
Maximum value during this interval  
Minimum value during the last interval  
Maximum value during the last interval  
Summary of  
53432 –  
53434  
Meter Data  
Evaluations by  
Item  
Percent in Evaluation Range 1 this interval  
33  
Percent in Evaluation Range 2 this interval (when applicable)  
Percent in Evaluation Range 1 last interval  
Percent in Evaluation Range 2 last interval (when applicable)  
Count of average values in Evaluation Range 1 (MOD10L2)  
Count of average values in Evaluation Range 2 (MOD10L2)  
Count of total valid averages for Evaluation of Range 1 (MOD10L2)  
Count of total valid averages for Evaluation of Range 2 (MOD10L2)  
Date/Time Last Excursion Range 1 (4-register format)  
Date/Time Last Excursion Range 2 (4-register format)  
Date/Time Last Reset (4-register format)  
Count of rapid voltage increases this week  
Count of rapid voltage decreases this week  
Summary of  
Rapid Voltage  
Changes by  
Phase  
Count of rapid voltage increases last week  
53435 –  
53437  
12  
Count of rapid voltage decreases last week  
Date/Time last rapid voltage change (4-register format)  
Date/Time last reset (4-register format)  
Count of dips by magnitude & duration this week (96 values) [See  
Summary of  
Voltage Dips  
by Phase This  
Week  
53438 –  
53440  
104  
Date/Time last voltage dip (4-register format)  
Date/Time last reset (4-register format)  
Count of dips by magnitude & duration last week (96 values) [See  
Summary of  
Voltage Dips  
by Phase Last  
Week  
53441 –  
53443  
104  
Date/Time last voltage dip (4-register format)  
Date/Time last reset (4-register format)  
Flag indicating interruption is active  
Elapsed seconds for interruption in progress  
Count of short interruptions this year  
Count of long interruption this year  
Summary of  
Supply  
Voltage  
Interruptions  
3-Phase and  
by Phase  
Count of short interruptions last year  
Count of long interruptions last year  
53444 –  
53447  
34  
Count of interruptions by duration this year (10 values) [See “Detection of  
Count of interruptions by duration last year (10 values) [See “Detection of  
Date/Time of last interruption (4-register format)  
Date/Time of last reset (4-register format)  
101  
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PowerLogicTM Series 800 Power Meter  
Appendix D—Advanced Power Quality Evaluations  
63230-500-225A2  
3/2011  
Table D–12: Portal Register Descriptions  
Portal  
Description Size  
Data  
Temporary  
Power  
Frequency  
Over-voltages  
by Phase This  
Week  
Count of over-voltages by magnitude & duration this week (96 values) [See  
53448 –  
53449  
104  
Date/Time last over-voltage (4-register format)  
Date/Time last reset (4-register format)  
Temporary  
Power  
Frequency  
Over-voltages  
by Phase Last  
Week  
Count of over-voltages by magnitude & duration last week (96 values) [See  
53450 –  
53452  
104  
Date/Time last over-voltage (4-register format)  
Date/Time last reset (4-register format)  
Register 2 – Bitmap of evaluation  
Register 1 – Bitmap of active  
status summary (same as register  
evaluations (same as register 3910)  
3911)  
Bit set when evaluation is active  
Bit set when evaluation fails  
Bit 00 – Summary bit – at least one  
Bit 00 – Summary bit – at least one  
EN50160 evaluation is active  
EN50160 evaluation has failed  
Bit 01 – Frequency  
Bit 01 – Frequency  
Bit 02 – Supply voltage variations  
Bit 02 – Supply voltage variations  
Bit 03 – Magnitude of rapid voltage  
Bit 03 – Magnitude of rapid voltage  
changes  
changes  
Bit 04 – Not used  
Bit 04 – Not used  
Bit 05 – Supply voltage dips  
Bit 05 – Supply voltage dips  
Evaluation  
Summary  
Bitmap  
Bit 06 – Short interruptions of the  
Bit 06 – Short interruptions of the  
supply voltage  
53312  
18  
supply voltage  
Bit 07 – Long interruptions of the  
Bit 07 – Long interruptions of the  
supply voltage  
supply voltage  
Bit 08 – Temporary power frequency  
Bit 08 – Temporary power frequency  
over-voltages  
over-voltages  
Bit 09 – Not used  
Bit 09 – Not used  
Bit 10 – Supply voltage unbalance  
Bit 10 – Supply voltage unbalance  
Bit 11 – Harmonic voltage  
Bit 11 – Harmonic voltage  
Bit 12 – THD  
Bit 12 – THD  
Bit 13 – Not used  
Bit 13 – Not used  
Bit 14 – Not used  
Bit 14 – Not used  
Bit 15 – Not used  
Bit 15 – Not used  
Register 3 (Range 1)/Register 11  
(Range 2) – Bitmap of evaluation  
status of individual evaluations  
Register 4 (Range 1)/Register 12  
(Range 2) – Bitmap of evaluation  
status of individual evaluations  
Bit 00 – Frequency  
Bit 01 – Va  
Bit 00 – Va H7  
Bit 01 – Va H8  
Bit 02 – Va H9  
Bit 03 – Va H10  
Bit 04 – Va H11  
Bit 05 – Va H12  
Bit 06 – Va H13  
Bit 07 – Va H14  
Bit 08 – Va H15  
Bit 09 – Va H16  
Bit 10 – Va H17  
Bit 11 – Va H18  
Bit 12 – Va H19  
Bit 13 – Va H20  
Bit 14 – Va H21  
Bit 15 – Va H22  
Bit 02 – Vb  
Bit 03 – Vc  
Bit 04 – Not used  
Bit 05 – Not used  
Bit 06 – Not used  
Bit 07 – Voltage Unbalance  
Bit 08 – THD Va  
Bit 09 – THD Vb  
Bit 10 – THD Vc  
Bit 11 – Va H2  
Bit 12 – Va H3  
Bit 13 – Va H4  
Bit 14 – Va H5  
Bit 15 – Va H6  
102  
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3/2011  
PowerLogicTM Series 800 Power Meter  
Appendix D—Advanced Power Quality Evaluations  
Table D–12: Portal Register Descriptions  
Portal Description Size  
Data  
Register 5 (Range 1)/Register 13  
(Range 2) – Bitmap of evaluation  
status of individual evaluations  
Register 6 (Range 1)/Register 14  
(Range 2) – Bitmap of evaluation  
status of individual evaluations  
Bit 00 – Va H23  
Bit 01 – Va H24  
Bit 02 – Va H25  
Bit 03 – Vb H2  
Bit 04 – Vb H3  
Bit 05 – Vb H4  
Bit 06 – Vb H5  
Bit 07 – Vb H6  
Bit 08 – Vb H7  
Bit 09 – Vb H8  
Bit 10 – Vb H9  
Bit 11 – Vb H10  
Bit 12 – Vb H11  
Bit 13 – Vb H12  
Bit 14 – Vb H13  
Bit 15 – Vb H14  
Bit 00 – Vb H15  
Bit 01 – Vb H16  
Bit 02 – Vb H17  
Bit 03 – Vb H18  
Bit 04 – Vb H19  
Bit 05 – Vb H20  
Bit 06 – Vb H21  
Bit 07 – Vb H22  
Bit 08 – Vb H23  
Bit 09 – Vb H24  
Bit 10 – Vb H25  
Bit 11 – Vc H2  
Bit 12 – Vc H3  
Bit 13 – Vc H4  
Bit 14 – Vc H5  
Bit 15 – Vc H6  
Register 7 (Range 1)/Register 15  
(Range 2) – Bitmap of evaluation  
status of individual evaluations  
Register 8 (Range 1)/Register 16  
(Range 2) – Bitmap of evaluation  
status of individual evaluations  
Bit 00 – Vc H7  
Bit 01 – Vc H8  
Bit 02 – Vc H9  
Bit 03 – Vc H10  
Bit 04 – Vc H11  
Bit 05 – Vc H12  
Bit 06 – Vc H13  
Bit 07 – Vc H14  
Bit 08 – Vc H15  
Bit 09 – Vc H16  
Bit 10 – Vc H17  
Bit 11 – Vc H18  
Bit 12 – Vc H19  
Bit 13 – Vc H20  
Bit 14 – Vc H21  
Bit 15 – Vc H22  
Bit 00 – Vc H23  
Bit 01 – Vc H24  
Bit 02 – Vc H25  
Bit 03 – V 3PH  
Bit 04 – KW 3PH  
Bit 05 – KVAR 3PH  
Bit 06 – Ia  
Bit 07 – Ib  
Bit 08 – Ic  
Bit 09 – Ia H3  
Bit 10 – Ib H3  
Bit 11 – Ic H3  
Bit 12 – Ia H5  
Bit 13 – Ib H5  
Bit 14 – Ic H5  
Bit 15 – Ia H7  
Register 9 (Range 1)/Register 17  
(Range 2) – Bitmap of evaluation  
status of individual evaluations  
Register 10 (Range 1)/Register 18  
(Range 2) – Bitmap of evaluation  
status of individual evaluations  
Bit 00 – Ib H7  
Bit 00 – Reserved  
Bit 01 – Reserved  
Bit 02 – Reserved  
Bit 03 – Reserved  
Bit 04 – Reserved  
Bit 05 – Reserved  
Bit 06 – Reserved  
Bit 07 – Reserved  
Bit 08 – Not used  
Bit 09 – Not used  
Bit 10 – Not used  
Bit 11 – Not used  
Bit 12 – Not used  
Bit 13 – Not used  
Bit 14 – Not used  
Bit 15 – Not used  
Bit 01 – Ic H7  
Bit 02 – Ia H9  
Bit 03 – Ib H9  
Bit 04 – Ic H9  
Bit 05 – Ia H11  
Bit 06 – Ib H11  
Bit 07 – Ic H11  
Bit 08 – Ia H13  
Bit 09 – Ib H13  
Bit 10 – Ic H13  
Bit 11 – Reserved  
Bit 12 – Reserved  
Bit 13 – Reserved  
Bit 14 – Reserved  
Bit 15 – Reserved  
103  
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PowerLogicTM Series 800 Power Meter  
Appendix D—Advanced Power Quality Evaluations  
63230-500-225A2  
3/2011  
Alarms Allocated for PQ Advanced Evaluations  
To accomplish some of the evaluations required and to provide a record of events in the  
on-board alarm log, the PM850 uses standard alarms, and the PM870 uses disturbance  
alarms. When the evaluation is enabled, certain alarm positions will be claimed and  
automatically configured for use in the evaluation. You cannot use these alarms for other  
purposes while the evaluation is enabled. These alarms include:  
Over Voltage (PM850): Standard speed alarm positions 35-37  
Under Voltage (PM850): Standard speed alarm positions 38-40  
Disturbance for Voltage Swells and Sags (PM870): Disturbance alarm positions 1-3 and 7-9  
NOTE: The position depends on the system type (register 3902).  
“PQ Advanced” is included in the alarm label for alarms being used by this evaluation.  
Setting Up PQ Advanced Evaluation from the Display  
To set up the PQ Advanced evaluation in the power meter, you need to perform these  
steps using the meter set-up procedure:  
1. Enable the PQ Advanced evaluation.  
By default, the PQ Advanced evaluation is disabled. To enable the evaluation, use the  
2. Select the nominal voltage of your system.  
NOTE: The EN50160 standard defines nominal voltage for low-voltage systems to be  
230V line-to-line for 3-wire systems or 230V line-to-neutral for 4-wire systems.  
Therefore, the default value for Nominal Voltage is 230.  
If the application is a medium-voltage system, or if you want the evaluations to be  
based on some other nominal voltage, you can configure this value using the display  
only. PowerLogic software does not allow configuration of nominal voltage  
3. Select the nominal frequency of your system.  
NOTE: The EN50160 standard defines nominal frequency as 50 Hz, but the PM850 and  
the PM870 can also evaluate 60 Hz systems. They cannot evaluate nominal frequency  
for 400 Hz systems.  
The default nominal frequency in the PM850 and the PM870 is 60 Hz. To change the  
default, from the display Main Menu, select Setup > Meter > Frequency. From  
PowerLogic software, see the online help file.  
4. Reset the PQ Advanced Statistics.  
a. Write 9999 in register 8001.  
b. Write 11100 in register 8000.  
5. Reset the ITI (CBEMA) and SEMI F-47 Statistics.  
a. Write 9999 in register 8001.  
b. Write 11200 in register 8000.  
104  
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PowerLogicTM Series 800 Power Meter  
Glossary  
Glossary  
Terms  
accumulated energy—energy can  
event—the occurrence of an alarm  
accumulate in either signed or unsigned condition, such as Under-voltage Phase  
(absolute) mode. In signed mode, the  
direction of power flow is considered,  
and the accumulated energy magnitude  
may increase and decrease. In absolute  
mode, energy accumulates as a  
positive, regardless of the power flow  
direction.  
A, configured in the power meter.  
firmware—operating system within the  
power meter.  
fixed block—an interval selected from  
1 to 60 minutes (in 1-minute  
increments). The power meter  
calculates and updates the demand at  
the end of each interval.  
active alarm—an alarm that has been  
set up to trigger, when certain  
conditions are met, the execution of a  
task or notification. An icon in the  
upper-right corner of the meter  
indicates that an alarm is active (!).  
See also enabled alarm and disabled  
alarm.  
float—a 32-bit floating point value  
returned by a register (see Register List  
on page 79). The upper 16-bits are in  
the lowest-numbered register pair. For  
example, in the register 4010/11, 4010  
contains the upper 16-bits while 4011  
contains the lower 16-bits.  
baud rate—specifies how fast data is  
transmitted across a network port.  
frequency—number of cycles in one  
second.  
block interval demand— power  
demand calculation method for a block line-to-line voltages—measurement of  
of time. Includes three ways to apply  
calculating to that block of time; sliding  
block, fixed block, or rolling block  
methods.  
the rms line-to-line voltages of the circuit.  
line-to-neutral voltages  
—measurement of the rms line-to-  
neutral voltages of the circuit.  
communications link—a chain of  
devices connected by a  
communications cable to a  
communications port.  
maximum demand current—highest  
demand current measured in amperes  
since the last reset of demand.  
maximum demand real power  
—highest demand real power  
measured since the last rest of  
current transformer (CT)—current  
transformer for current inputs.  
demand—average value of a quantity, demand.  
such as power, over a specified interval  
of time.  
maximum demand voltage—highest  
demand voltage measured since the  
last reset of demand voltage.  
device address—defines where the  
power meter resides in the power  
monitoring system.  
maximum demand (peak demand)  
—highest average load during a  
specific time interval.  
disabled alarm—an alarm which has  
been configured but which is currently  
“turned off”; i.e, the alarm will not  
execute its associated task even when  
its conditions are met. See also enabled  
alarm and active alarm.  
maximum value—highest value  
recorded of the instantaneous quantity  
such as Phase A Current, Phase A  
Voltage, etc., since the last reset of the  
minimums and maximums.  
enabled alarm—an alarm that has  
been configured and “turned on” and  
will execute its associated task when its  
conditions are met. See also disabled  
alarm and active alarm.  
minimum value—lowest value  
recorded of the instantaneous quantity  
such as Phase A Current, Phase A  
Voltage, etc., since the last reset of the  
minimums and maximums.  
105  
© 2011 Schneider Electric. All Rights Reserved.  
 
     
PowerLogicTM Series 800 Power Meter  
Glossary  
63230-500-225A2  
3/2011  
nominal—typical or average.  
sag/swell—fluctuation (decreasing or  
increasing) in voltage or current in the  
electrical system being monitored. See  
also, voltage sag and voltage swell.  
parity—refers to binary numbers sent  
over the communications link. An extra  
bit is added so that the number of ones  
in the binary number is either even or  
odd, depending on your configuration.  
Used to detect errors in the  
scale factor—multipliers that the power  
meter uses to make values fit into the  
register where information is stored.  
transmission of data.  
safety extra low voltage (SELV)  
partial interval demand—calculation  
circuit—a SELV circuit is expected to  
of energy thus far in a present interval. always be below a hazardous voltage  
Equal to energy accumulated thus far in level.  
the interval divided by the length of the  
short integer—a signed 16-bit integer  
complete interval.  
phase currents (rms)—measurement  
sliding block—an interval selected  
in amperes of the rms current for each  
from 1 to 60 minutes (in 1-minute  
of the three phases of the circuit. See  
increments). If the interval is between 1  
also maximum value.  
and 15 minutes, the demand calculation  
phase rotation—phase rotations refers updates every 15 seconds. If the  
to the order in which the instantaneous interval is between 16 and 60 minutes,  
values of the voltages or currents of the the demand calculation updates every  
system reach their maximum positive  
values. Two phase rotations are  
possible: A-B-C or A-C-B.  
60 seconds. The power meter displays  
the demand value for the last  
completed interval.  
potential transformer (PT)—also  
known as a voltage transformer  
system type—a unique code assigned  
to each type of system wiring  
configuration of the power meter.  
power factor (PF)—true power factor is  
the ratio of real power to apparent  
power using the complete harmonic  
content of real and apparent power.  
Calculated by dividing watts by volt  
amperes. Power factor is the difference  
between the total power your utility  
delivers and the portion of total power  
that does useful work. Power factor is  
the degree to which voltage and current  
to a load are out of phase.  
thermal demand—demand calculation  
based on thermal response.  
Total Harmonic Distortion (THD or  
thd)—indicates the degree to which the  
volt-age or current signal is distorted in  
a circuit.  
total power factorsee power factor.  
true power factor—see power factor.  
unsigned integer—an unsigned 16-bit  
page 79).  
real power—calculation of the real  
power (3-phase total and per-phase  
real power calculated) to obtain  
kilowatts.  
unsigned long integer—an unsigned  
32-bit value returned by a register  
upper 16-bits are in the lowest-  
rms—root mean square. Power meters  
are true rms sensing devices.  
rolling block—a selected interval and  
numbered register pair. For example, in  
sub-interval that the power meter uses the register pair 4010 and 4011, 4010  
for demand calculation. The sub-  
interval must divide evenly into the  
interval. Demand is updated at each  
sub-interval, and the power meter  
displays the demand value for the last  
completed interval.  
contains the upper 16-bits while 4011  
contains the lower 16-bits.  
VAR—volt ampere reactive.  
voltage sag—a brief decrease in  
effective voltage for up to one minute in  
duration.  
voltage swell—increase in effective  
voltage for up to one minute in duration.  
106  
© 2011 Schneider Electric. All Rights Reserved.  
 
   
63230-500-225A2  
3/2011  
PowerLogicTM Series 800 Power Meter  
Glossary  
Abbreviations and Symbols  
kVA—Kilovolt-Ampere  
A—Ampere  
kVAD—Kilovolt-Ampere demand  
A IN—Analog Input  
kVAR—Kilovolt-Ampere reactive  
A OUT—Analog Output  
ABSOL—Absolute Value  
ACCUM—Accumulated  
ACTIV—Active  
kVARD—Kilovolt-Ampere reactive  
demand  
kVARH—Kilovolt-Ampere reactive hour  
kW—Kilowatt  
ADDR—Power meter address  
ADVAN—Advanced screen  
AMPS—Amperes  
kWD—Kilowatt demand  
kWH—Kilowatthours  
kWH/P—Kilowatthours per pulse  
kWMAX—Kilowatt maximum demand  
LANG—Language  
BARGR—Bargraph  
COINC—Demand values occurring at  
the same time as a peak demand value  
LOWER—Lower Limit  
COMMS—Communications  
COND—Conditional Energy Control  
CONTR—Contrast  
MAG—Magnitude  
MAINT—Maintenance screen  
MAMP—Milliamperes  
CPT—Control Power Transformer  
MB A7—MODBUS ASCII 7 Bits  
MB A8—MODBUS ASCII 8 Bits  
MBRTU—MODBUS RTU  
MIN—Minimum  
CT—see current transformer on  
DEC—Decimal  
D IN—Digital Input  
DIAG—Diagnostic  
DISAB—Disabled  
DISPL—Displacement  
D OUT—Digital Output  
DMD—Demand  
MINS—Minutes  
MINMX—Minimum and maximum  
values  
MSEC—Milliseconds  
MVAh—Megavolt ampere hour  
MVARh—Megavolt ampere reactive  
hour  
DO—Drop Out Limit  
ENABL—Enabled  
ENDOF—End of demand interval  
ENERG—Energy  
F—Frequency  
MWh—Megawatt hour  
NORM—Normal mode  
O.S.—Operating System (firmware  
version)  
HARM—Harmonics  
HEX—Hexadecimal  
HIST—History  
P—Real power  
PAR—Parity  
PASSW—Password  
Pd—Real power demand  
PF—Power factor  
Ph—Real energy  
PM—Power meter  
HZ—Hertz  
I—Current  
I/O—Input/Output  
IMAX—Current maximum demand  
107  
© 2011 Schneider Electric. All Rights Reserved.  
 
 
PowerLogicTM Series 800 Power Meter  
Glossary  
63230-500-225A2  
3/2011  
PQS—Real, reactive, apparent power  
PQSd—Real, reactive, apparent power  
demand  
PR—Alarm Priority  
PRIM—Primary  
PT—Number of voltage connections  
(see potential transformer on page 106)  
PU—Pick Up Limit  
PULSE—Pulse output mode  
PWR—Power  
Q—Reactive power  
Qd—Reactive power demand  
Qh—Reactive energy  
R.S.—Firmware reset system version  
RELAT—Relative value in %  
REG—Register Number  
S—Apparent power  
S.N.—Power meter serial number  
SCALE—see scale factor on page 106  
Sd—Apparent power demand  
SECON—Secondary  
SEC—Seconds  
Sh—Apparent Energy  
SUB-I—Sub-interval  
THD—Total Harmonic Distortion  
U—Voltage line to line  
UNBAL—Unbalance  
UPPER—Upper limit  
V—Voltage  
VAh—Volt amp hour  
VARh—Volt amp reactive hour  
VMAX—Maximum voltage  
VMIN—Minimum voltage  
Wh—Watthour  
108  
© 2011 Schneider Electric. All Rights Reserved.  
 
TM  
63230-500-225A2  
3/2011  
PowerLogic Series 800 Power Meter  
Index  
Index  
clock  
Numerics  
A
command interface  
communications  
accumulate energy  
address  
alarm  
alarm backlight  
alarm levels  
alarm log  
conditional energy  
CT  
custom  
alarms  
D
date  
EN50160 Evaluation  
demand  
demand power  
analog input  
diagnostic alarms  
diagnostics  
B
bar graph  
C
calculating  
changing  
© 2011 Schneider Electric All Rights Reserved  
109  
 
TM  
63230-500-225A2  
3/2011  
PowerLogic Series 800 Power Meter  
Index  
display  
F
disturbance monitoring  
floating-point registers  
E
G
EN50160 Evaluation  
accumulation  
H
harmonic  
calculations  
I
depth  
I/O  
incremental energy interval  
initialize  
statistics  
system configuration  
input  
input/output  
inputs  
K
L
labels  
language  
lock resets  
M
maintenance  
energy  
equipment sensitivity  
event log  
© 2011 Schneider Electric All Rights Reserved  
110  
 
TM  
63230-500-225A2  
3/2011  
PowerLogic Series 800 Power Meter  
Index  
memory  
power meter  
metered values  
minimum/maximum  
minimum/maximum values  
with display  
mode  
monitoring  
problems  
protocols  
PT  
N
nominal frequency  
nominal voltage  
O
Q
quantities  
R
readings  
recording  
operating time  
operating time threshold  
outputs  
register writes  
registers  
P
password  
phase loss  
relay operating modes  
phase rotation  
pickups and dropouts  
PLC  
power demand configuration  
© 2011 Schneider Electric All Rights Reserved  
111  
 
TM  
63230-500-225A2  
3/2011  
PowerLogic Series 800 Power Meter  
Index  
relays  
reset  
T
testing  
time  
resets  
time intervals  
S
sag/swell  
trending and forecasting  
troubleshooting  
U
V
set up  
VAR  
VAR/PF convention  
voltage swell  
W
watthours  
waveform captures  
wiring  
synchronized demand  
synchronizing  
system type  
© 2011 Schneider Electric All Rights Reserved  
112  
 
 
PowerLogic™ Power Meter 800 User Guide  
PowerLogic is a trademark of Schneider Electric, Other trademarks are the property of their  
respective owners.  
Schneider Electric  
295 Tech Park Drive, Suite 100  
Lavergne, TN 37086 USA  
Electrical equipment should be installed, operated, serviced, and maintained only by qualified  
personnel. No responsibility is assumed by Schneider Electric for any consequences arising out of  
the use of this material.  
For technical support:  
Global-PMC-Tech-support@schneider-electric.com  
(00) + 1 250 544 3010  
63230-500-225A2  
Replaces 63230-500-225A1, dated  
© 2006 - 2011 Schneider Electric All Rights Reserved  
3/2011  
6/2006  
Contact your local Schneider Electric sales  
representative for assistance or go to  
www.schneider-electric.com  
 

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