26 09 13 ELECTRICAL POWER MONITORING AND CONTROL - SYSTEM

SECTION [26 09 13] [16290]
ELECTRICAL POWER MONITORING AND CONTROL
PART 1 - GENERAL
1.1
SCOPE
A.
This section includes the supply and installation of a complete Enterprise Wide Power
Management and Control System (EPMS) as detailed in the drawings and as described in this
specification.
B.
The contractor shall furnish and install the equipment specified herein. The equipment shall be
as shown in the drawings and outlined below.
C.
System Description Overview
1.
The Power Management and Control System (EPMS) shall be a Web Based Monitoring
& Control system that monitors all specified locations in the distribution system without
any further configuration or setup required after complete installation by the contractor.
The EPMS is defined to include, but not to be limited to, remote devices for monitoring,
control and protection, device communication interface hardware, intercommunication
wiring, monitoring stations, software, software configuration, ancillary equipment, startup
and training services.
2.
The EPMS software shall be designed specifically for Power Monitoring & Control.
D.
Communications Overview
1.
The EPMS system shall be able to utilize the following standard communications
configurations, as a minimum, at the same time:
a.
Direct RS485 serial communications for cable runs of less than 4000ft. Longer
RS-485 runs can be achieved with the use of a RS485 repeater. RS485 supports
communication with up to 32 devices per communications string. Each string shall
consist of good quality 24 AWG (or greater) twisted pair shielded cable for RS485
communications.
b.
Standard Ethernet TCP/IP, 802.3 communications networks. Ethernet
communications of either CAT-5 or Fiber Optic shall be supported at a
100/10BaseT communications speed.
c.
Short haul, Radio Modem and standard Telephone modem communications shall
be supported.
d.
The PMSC system shall be able to utilize the facilities Intranet network and
Internet WAN communications networks.
2.
1.2
Individual equipment line-ups shall be fully wired and tested by the manufacturer such
that the contractor need only provide one connection for communication.
RELATED DOCUMENTS
A.
1.3
[Refer to the following related sections for details on quantities of monitoring points.
1.
[LIST ALL RELATED SECTIONS FOR EQUIPMENT WITH MONITORING DEVICES
INSTALLED] ]
SUBMITTALS
A.
The following information shall be submitted to the Engineer and Owner prior to design or
installation.
1.
System description including an overview of the system provided with detailed description
of suggested communication architecture and the screens to be provided
2.
Bill of Material including a complete listing of all hardware, software, configuration,
training and start-up services being supplied under this contract.
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3.
4.
B.
1.4
Hardware and software description shall be provided in detail for all communications
hardware, software, including sensor devices gathering data to be transmitted over the
network and the Power Management Engineering Station.
Details of the Power Quality analysis or waveform capture features supported in the
software.
Final closeout submittal data shall include a system operation manual which shall include all the
information required by item 1.4.A. In addition, the systems operation manual shall include the
following information:
1.
A system description overview
2.
Descriptive bulletins and/or sales aids covering each of the components in the system.
3.
Manuals for all products used in the system.
4.
The following information shall be provided as a back-up to the information stored on the
computer:
a.
All software programs with original licenses.
b.
Software data files.
c.
All application software screens.
d.
A complete list of all devices in the system with addresses and other
communications related data.
RELATED STANDARDS
A.
1.5
Codes and standards: Provide EPMS components conforming to the following:
1.
ANSI/IEEE C37.90
2.
UL Listed or Recognized
3.
CSA Approved
4.
FCC Emission Standards
QUALITY ASSURANCE
A.
The manufacturer of the equipment shall have been regularly engaged in the manufacture of
the specified remote devices for a period of at least ten (10) years and demonstrate that these
products have been utilized in satisfactory use in functioning systems for similar applications.
The manufacturer shall have at least ten (10) years demonstrated capability in EPMS design,
installation and start-up.
B.
The manufacturer shall submit a list of existing operating installations, including major facilities,
each having a minimum of 50 remote devices communicating with a Power Management
Engineering Station or network.
1.6
DELIVERY, STORAGE AND HANDLING
A.
Deliver material in manufacturer’s original unopened protective packaging unless it is built into
new distribution equipment.
B.
Securely store materials in original packaging in a manner to prevent soiling, physical damage,
incursion of moisture or corrosion prior to installation.
C.
Handle in a manner to prevent damage to finished surfaces.
D.
Maintain protective coverings until installation is complete and remove such covers as part of
final clean-up.
E.
Touch up any damage to finishes to match adjacent surfaces to the satisfaction of the Design
Team.
F.
Where applicable, the EPMS components included with power equipment lineups shall be
factory installed, wired and tested prior to shipment to the job site.
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PART 2 - PRODUCTS
2.1
MANUFACTURERS
A.
2.2
[The low voltage power meter system shall be supplied by Siemens Industry Inc. or preapproved equal. Approved manufacturers are as follows:
1.
Siemens
2.
. ]
EPMS SERVER & CLIENT REQUIRMENTS
A.
The EPMS Server computer shall include [___] factory supplied server computers with at
least the following features:
1.
Server computer with 4 GB RAM,, Dual 2GHz CPU, 146 GB storage on SCSI RAID-1,
CD/DVD RW drive, 21” Flat screen monitor, XGA video card, full-size 101-key enhanced
keyboard and a mouse.
2.
Microsoft Server 2008
3.
Windows XP Professional or Vista operating system.
4.
Microsoft Office recommended for reporting
5.
PDF maker recommended for reporting
6.
A minimum of one (1) parallel port and two (2) serial ports.
7.
Dual NIC Card - 10/100Base T
8.
Auto-reboot capability upon return from power failure. Necessary programs must then
automatically launch without user intervention.
9.
One 400VA, 120VAC, plug-in UPS
B.
The EPMS project shall included [___ ] Web Based Client computers with the following
features:
1.
Minimum computer with 1 GB RAM, 2 GHz, 40 GB hard disk drive, 24 x speed CD
read/write drive, 20” Flat screen monitor, XGA video card, full-size 101-key enhanced
keyboard and a mouse.
2.
Internet Explorer 6.0 or higher.
3.
Windows 2003 Server or Windows XP Professional operating system.
4.
One 400VA, 120VAC, plug-in UPS
2.3
EPMS WEB BASED SOFTWARE OVERVIEW
A.
The EPMS Server software shall be designed on a MICROSOFT WINDOWS-based platform
and have on-line full-screen editing to facilitate the programming and monitoring of the system.
The Power Management Server and Web Based Client locations will allow the monitoring of
vital system parameters and provide a scalable system for future expansions without
replacement of the EPMS system hardware or software.
B.
The EPMS screens shall show all parameters which are available from the individual remote
devices by device, including but not limited to all metered values, load status, alarm status,
energy data, device position and/or status, device data logs, waveform capture, sag/swell
events, etc. In addition, the screens shall be capable (if allowed by the owner) of providing for
suitable tripping, closing and opening of appropriate remote devices.
C.
The EPMS software shall provide, as standard, the following software package to allow for
maximum flexibility and expandability. Additional devices can be added for both Siemens ION
and Modbus devices.
1.
The proposed system will include a EPMS system that supports unlimited Web Based
clients and the following device point level packages:
a.
Five (5) metering device package – Siemens WinPM.Net or equal
b.
Additional (___) Siemens metering devices
c.
Additional (____) Modbus RTU or Ethernet
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D.
The EPMS software Web Bases clients shall require No loading of software to view all the
EPMS screens and data.
E.
The EPMS software shall allow unlimited screens and unlimited screen penetration to lowerlevel detailed screens.
F.
The EPMS software shall provide the following screens as standard in the software:
1.
Real-time Device information like Line to Line and Line to Neutral voltage and current
readings for all Power Meters in a 3-Line diagram format.
2.
Event Logs
3.
Alarm Logs
4.
Historical trend plots
5.
Real-time and historical trend plots
6.
Waveform capture display with zoom in/out capability
7.
Harmonic analysis display
8.
Phasor display
9.
Time-of-use display
10.
Power Quality display
11.
I/O status & control display
12.
Set point and setup display
13.
Device log and setup display
14.
CBEMA curve display
15.
Network diagram display
16.
One-click access to device logs, including long-term min/max, voltage, current, power,
frequency and power factor trending.
17.
Display Flicker data tables
18.
All I/O shall be displayed including current state.
19.
Device "OPEN", "CLOSED", "TRIPPED" and "COMMUNICATION" status.
20.
All measured values supported by the given device as selected by the customer
G.
Customer shall have the ability to remove any non-essential parameters from the real-time list
of each device to minimize searching through non-essential information.
H.
All tables shall be customizable by the customer.
I.
The base EPMS software package shall have as a minimum the following specified features.
1.
System/device alarm logging and reporting: Any changes in any device or the system
itself including log on/off, power on/off at system master computer, shall be identified and
alarmed.
2.
Time/event logging: The time and causes of each event shall be logged directly to the
master control unit file and/or a printer. Time stamping capability in seconds shall be
provided at the system master computer of device on/off, device alarm, device trip and
device no response.
3.
Data Trending: The software shall include the following trending features:
a.
All information monitored by every remote device shall be capable of being
communicated and automatically trended.
b.
Trending time interval and amount of information to be trended shall be userselectable. Trends shall have the ability to combine information from multiple
devices. Time interval selection shall be user-selectable in discrete time blocks
from 1 second to many hours. Additionally, time intervals shall have the capability
of limiting recording to certain time windows of each day or a certain date range.
Automatic start and stop day/times shall be available for unattended recording.
J.
Password Protection: The following password security protection features shall be provided:
1.
The EPMS software shall be capable of having an unlimited number of separate userdefined passwords.
2.
All actions; i.e., log on/off, device control, alarm acknowledgment, etc. shall be time and
date stamped in the event log.
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3.
4.
Password security access shall provide for flexible functional access. Functions such as
alarm acknowledgment, device control, device configuration, etc. shall be individually
customized to each user name assigned.
The EPMS software password security shall be capable of being utilized for both local
and remote computers. Individual operator passwords shall be required at every
computer location. Each operator's capability to interface with the system shall be keyed
to his/her entered password and his/her associated security level at each designated
station.
K.
Diagnostics shall be provided to provide information on device or system malfunction, such as
devices not communicating, watchdog alarms, stale date indication, etc.
L.
The software shall allow the user to set an unlimited number of individual computer alarm levels
for all monitored parameters, such as setting low and high alarm levels for voltage, current,
motor run time, etc. These alarm levels shall be independent of device built-in alarm levels. The
alarm settings shall support signed values (+/-) as well as high and low limits.
M.
The software shall support setting multiple limits, providing additional alarm points above or
below the initial limit.
N.
The software shall display the analog value that caused the alarm on the alarm screen (time
and date stamped) and log same information to the event file.
O.
The software shall be capable of taking the following actions based on any alarm:
1.
Display custom text in a popup screen at the Power Management Engineering Stations
2.
Display any animated diagram based on the activation of the alarm
3.
Play any *.wav file accessible by the Power Management Engineering Station
4.
Loop the playback of the *.wav file until an operator acknowledges the alarm
5.
Activate any output on any power monitoring device in the system, as determined by the
owner.
6.
Email any alarm or event
P.
The software shall have on line, context sensitive help capability included to aid in operating the
software.
Q.
The EPMS system shall communicate to each breaker’s microprocessor based trip units,
protective relay and any digital meters on the electrical distribution system defined in this
specification. Additional analog and discrete statuses required to be monitored by this
specification shall be tied back to I/O units and communicated back to the power monitoring
software.
R.
Ability to perform mathematical operations and alarm on those calculations on the incoming
monitored data.
S.
Display in a real-time trending mode a graphical representation of either monitored or calculated
data.
T.
The system shall have the capability of being programmed and modified on-line. It shall not be
necessary to shut down any part of the system during programming operations.
2.4
EPMS STANDARD REPORTING / BILLING FEATURES
A.
The reporting / billing package shall be built into the EPMS software as standard and allow the
user to run the following standard reports without configuration changes or create new reports
using a built-in report wizard.
B.
The following reports will be available in PDF, TIF, Excel and HTML format.
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C.
2.5
Any computer with Internet Explorer shall be able to view the HTML reports with no special
software besides Internet Explorer 6.0 or later. Standard reports shall include:
1.
Energy Period Over Period Report
2.
Energy by Shift Reports
3.
Energy Cost (Billing) Report
4.
Alarm Report
5.
Event Report
6.
Trending / Load Profile Report
7.
System Configuration Report
8.
and unlimited custom reports
EPMS STANDARD GRAPHIC DISPLAY FEATURES
A.
The EPMS installation shall include as standard a graphical package that allows customdeveloped graphic screens to match customer one-line drawings, customer floor plan or actual
power distribution equipment front elevations, as agreed upon by owner. Owner shall be able to
select colors, numbering scheme and general arrangement of screens.
1.
2.
3.
4.
5.
6.
7.
B.
The EPMS system shall include [___] custom graphical screens.
The Graphical construction utility and any licenses shall be included.
Standard graphical pictures for analog dials, bar charts, hot-link buttons, etc. shall be
included. No additional software will be required to add pictures or links to the software.
The Graphical package shall provide a master overview screen listing all subscreens by
contract designation and from which any subscreen can be selected by mouse click
operation.
The Graphical package shall support breaker position (where supported by the device),
loading levels and links to real-time screens of individual devices represented on the
active screen.
The Graphical package shall allow unlimited users to view and modify the custom
drawings.
The Graphical package shall have the ability to turn logging on and off from the graphical
interface screen with one-click access.
Animation (changing of color) of any object or line on the screen based on a change of incoming
monitored data and/or a software-performed calculation shall be provided. For example,
changing of the single-line bus color based on open or closed status of a circuit breaker or
starter.
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2.6
COMPONENTS [Keep ONLY the appropriate meter specification. Please note the majority
of the remainder of this specification is complete meter specifications. Only select the
meters you need. Delete the other sections. Each meter specification is about 5 pages
long. ]
A.
Advanced Web Enabled Revenue Accurate Power Quality Meter with Sub-Cycle Transient
Detection
1.
Provide a high accuracy power meter meeting the requirements set forth in this
specification. Note any exceptions taken with a detailed description.
a.
Meter shall be Siemens Type 9610 Power Meter with options and features
described in this section.
b.
Provide Power Quality Meter on all incoming switchgear or switchboards mains
and as indicated on the drawings.
B.
1.
2.
3.
4.
Meet the following recognized standards for application in hardened environments
Device must meet all international standards for Safety & Construction applicable to this
type of device:
a.
UL3111-1
b.
CSA C22.2 No 1010-1
c.
IEC1010-1 (EN61010-1)
Device must meet all international standards for Electromagnetic Immunity applicable to
this type of device:
a.
IEEE C.37-90.1-1989 IEEE Standard Surge Withstand Capability (SWC) Tests for
Protective Relays and Relay Systems (ANSI) (All inputs except for the network
communication port)
b.
IEC1000-4-2 (EN61000-4-2/IEC801-2) Electrostatic Discharge (B)
c.
IEC1000-4-3 (EN61000-4-3/IEC801-3) Radiated EM Field Immunity (A)
d.
IEC1000-4-4 (EN61000-4-4/IEC801-4) Electric Fast Transient (B)
e.
IEC1000-4-5 (EN61000-4-5/IEC801-5) Surge Immunity (B)
f.
IEC1000-4-6 (EN61000-4-6/IEC801-6) Conducted Immunity
g.
ANSI C62.41 Surge Immunity
h.
IEC1000-3-2 (EN61000-3-2) Limits for harmonic currents emissions (equipment
input current < 16 amps per phase).
i.
IEC1000-3-3 (EN61000-3-3) Limitation of voltage fluctuations and flicker in low
voltage supply systems for equipment with rated current < 16 amps.
j.
ENV51040 Radiated EM Field Immunity (A)
k.
ENV51041Conducted EM Field Immunity (A)
l.
EN50082-2 Electromagnetic Compatibility, immunity
Device must meet all international standards for Electromagnetic Emissions
a.
FCC Part 15 Subpart B, Class A Class A Digital Device, Radiated Emissions
b.
EN55011 (CISPR 11) Radiated/Conducted Emissions (Group 1, Class A)
c.
EN55022 (CISPR 22) Radiated/Conducted Emissions (Class A)
d.
EN50081-2 Electromagnetic Compatibility, emissions
Device must comply with IEC687 S0.2
C.
Device must provide measurement accuracy that meets or exceeds ANSI C12.20 CA0.2
D.
The power monitoring and control instrument can be used for compliance monitoring to the
following standards:
1.
EN50160 compliance monitoring
2.
IEC 61000-4-7 harmonics and inter-harmonics
3.
IEC 61000-4-15 flicker
4.
CBEMA/ITIC
5.
IEEE 519 and IEEE 1159
E.
Basic hardware requirements of the Power Quality meter are as follows:
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a.
b.
c.
d.
e.
Voltage inputs: The device shall have five voltage inputs (V1, V2, V3, V4, and
Vref). The voltage inputs shall be capable of measuring from 0 to 347 Vrms (lineto-neutral) or from 0 to 600 Vrms (line-to-line). The device shall have provisions
for direct connection (require no PTs) for Wye (Star) systems up to 347 VAC (lineto-neutral) or 600 VAC (line-to-line). The device shall also have provisions for
direct connection to Delta systems (with allowance of accuracy degradation of
0.15%) up to 277 VAC (line-to-neutral) or 480 VAC (line-to-line). All voltage inputs
shall provide:
1.)
Dielectric withstand of 3250 VAC rms, 60 Hz for 1 minute
2.)
Overload protection of 1500 VAC rms continuous
3.)
Fault capture to 1400 V peak at the device terminals
Current inputs: The device shall have five current inputs (I1, I2, I3, I4, and I5). The
current inputs shall be capable of measuring up to 20 A rms (600 V rms maximum
voltage). All current inputs shall provide:
1.)
Dielectric withstand of 3250 VAC rms, 60 Hz for 1 minute
2.)
500 A rms for 1 second, non-recurring
3.)
Fault capture to 50 A rms or 70 A peak at the device terminals
Power supply: The device shall accept power from 85-240 VAC (+/-10%), 47 to 63
Hz or 110-330 VDC (+/-10%) without external converters or separate ordering
options. Maximum burden shall be 20 VA. Ride-through shall be a minimum of
100ms (6 cycles @ 60Hz) for 96 VAC, or 200ms (12 cycles @ 60 Hz) for 120 VAC
or 800ms (48 cycles @ 60 Hz) for 240 VAC. Dielectric withstand shall be 2300
VAC rms, 60 Hz for 1 minute.
On-board I/O: The device supplied shall have the following built-in I/O for this
project.
1.)
Three (3) Form C dry contact relays rated for switching of 2500 VA resistive
2.)
Four (4) Form A solid state outputs
3.)
8 Digital inputs (S1 to S8, SCOM), self-excited dry contact sensing, no
external voltage required, +30VDC differential between SCOM and S1
through S8 inputs
4.)
The following additional I/O may be added through the application of one of
the following I/O cards. Meter must be able to field retrofit to upgrade to
include these cards.
a.)
Four 0 to 1 mA analog inputs and 8 digital inputs
b.)
Four 0 to 20 mA analog inputs and 8 digital inputs
c.)
Four -1 to 1 mA analog outputs and 8 digital inputs
d.)
Four 0 to 20 mA analog outputs and 8 digital inputs
e.)
Four 0 to 20 mA analog inputs, four 0 to 20 mA analog outputs and 8
digital inputs
f.)
Four 0 to 1 mA analog inputs, four -1 to 1 mA analog outputs and 8
digital inputs
Communications
1.)
Provide the following built-in ports in the purchased configuration. All
communication ports shall be standard technology, as defined by the IEEE.
No communication interfaces not defined by the IEEE shall be accepted.
a.)
Standard communications card: includes RS-232/RS-485 (COM1),
RS-485 (COM2), programmable for baud rates from 1200 to 115200
bits per second.
b.)
An IrDA optical port at the face of the meter display for quick
downloading of meter information with the IrDA port on a laptop.
2.)
Meter must be able to field retrofit to upgrade to the following built-in port
options
a.)
10/100 baseT Ethernet connection – with dual master functionality.
b.)
100baseFX Ethernet option– with dual master functionality.
c.)
33.6kbps Modem
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3.)
f.
g.
All communication ports in this section must support all of the following
communication capabilities, independently configurable.
a.)
SEAbus/ION protocol
b.)
Modbus RTU protocol
c.)
DNP 3.0 protocol
d.)
XML
e.)
Independent communications from each port simultaneously with no
noticeable interruption of communications from any of the other
communication ports
f.)
Protocols must be field configurable from the front display or via
communications ports. This must be capable of being accomplished
without resetting the meter, or interrupting its operations in any way.
g.)
Modem and Ethernet port options must support simultaneous
communication to the meter in question and gateway capability to
other RS485 devices on the network via the meter's RS485 ports.
h.)
Support upgrade of the instrumentation firmware.
i.)
Support time synchronization broadcast messages from a host
computer system
j.)
Support time synchronization to GPS time signal
1/4 VGA, bright graphical display (320x240 pixel resolution)
1.)
Ability to display meter data in multiple intuitive formats at the meter display,
with a minimum of the following types of screens.
a.)
3 lines of 1/2" characters for easy viewing of critical power information
b.)
20 real time values on one display for summary overview of currents
and voltages or power readings.
c.)
Display graphical vector representation of all 3 phase voltages and
currents, updated in real time at the meter display, for quick
determination of improper wiring and unusual system conditions
without the need of a computer.
d.)
Display graphical charts of all harmonics (up to the 63rd harmonic) for
each phase voltage and current.
e.)
Display recent events written to the devices event log, including
diagnostic events
f.)
Display information from any measured parameter as a trend
including magnitude and time.
The device shall include 5 MB (optional 10MB) of memory (NVRAM) to store the
following:
1.)
All setup data.
2.)
A time-stamped event log supporting at least 500 events with 1ms resolution
shall record the following information about each event:
a.)
Time of event
b.)
Cause of event
c.)
Effect of event
d.)
Device output reactions
e.)
Priority of event
3.)
Fifty (50) Data Recorder Modules that can each store up to 16 channels of
historical trend data with the following features:
a.)
Each data recorder shall be able to record any high speed (½-cycle)
or high accuracy (1-second) parameter, either measured or derived.
b.)
Each data recorder shall be enabled and triggered manually or
through internal operating conditions, including periodic timer or set
point activity.
c.)
The number of records (depth) of each data recorder and the
overflow conditions (stop-when-full or circular) shall be
programmable.
4.)
Min/Max data for all monitored parameters
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2.
3.
4.
5.
6.
5.)
Waveform recordings as described in the power quality paragraph below.
The devices that are equipped with an Ethernet port are internet enabled and shall
include:
a.
[email protected]®: Automatically e-mail alarm notifications or scheduled system status
updates. E-mail messages sent by the devices can be received like any ordinary
e-mail message. Data logs can also be sent on an event-driven or scheduled
basis.
b.
WebMeter™: Standard built in web pages in the device enable access to real-time
values and basic power quality information using a standard web browser. Basic
configuration of the device can also be performed through the browser. Web pages
must be configurable to allow custom HTML pages to be created. Device must
also support display of downstream devices from the web browser, i.e. feeders and
trip units on customizable web pages within the meter.
c.
XML compatible: Supports easy integration with custom reporting, spreadsheet,
database and other applications.
The device shall accommodate high speed Modbus TCP communications when
connected to Ethernet Port 502.
The device shall support Modbus Master Capability to request data from Modbus
compatible slave devices, and make the data available for display on the front panel,
logging, alarming, for calculations etc.
The PMAC instrument has the ability to perform the following functions without the need
for separate software:
a.
Determine statistical indicators of power quality parameters that include but are not
limited to flicker, dips and swells, harmonics and interharmonics, in accordance
with the EN50160 standards, “Voltage characteristics of electricity supplied by
public distribution systems”.
b.
Evaluate power quality statistically in accordance with IEC 61000-4-7, IEC 610004-15, CBEMA/ITIC, IEEE 1159 and IEEE 519.
c.
Make available the statistical indicators of power quality on the front panel display,
or via communications over any supported protocol (ION, Modbus RTU, Modbus
TCP, DNP 3.0, IEC870-5), or via an analog transducer interface.
d.
Internally record the value of statistical indicators of power quality at regular
intervals and make these data records available through communications or on the
front panel display so that it is easy to determine the trend of these power quality
statistics.
e.
Monitor the value of any statistical indicator of power quality (present, predicted,
average or otherwise manipulated value) with an absolute or relative set point.
When such set point is exceeded, issue an alert via e-mail or pager, or enable
control via a local interface to mitigation equipment or control systems through
relays and analog or digital outputs.
The device shall provide technology and functionality to provide high end Power Quality
monitoring as follows:
a.
Continuously sample at [512 samples per cycle] [1024 samples per cycle] on all
voltage and current inputs to support high-end power quality requirements.
b.
Transient detection with 1024 samples per cycle
c.
High-speed sag/swell detection of voltage disturbances shall be available on a
cycle-by-cycle basis, providing the duration of the disturbance and the minimum,
maximum and average value of the voltage for each phase during the disturbance.
Disturbances less than one cycle in duration shall be detected.
d.
High-speed voltage transient detection, capture and recording: ITIC (CBEMA),
IEEE
e.
Sixteen (16) programmable oscillographic waveform recorders with the following
features:
1.)
Each waveform recorder shall be able to record a digitized representation of
any phase voltage or current signal.
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2.)
7.
Each waveform recorder shall be enabled and triggered manually or through
internal operating conditions, including periodic timer or set point activity.
3.)
High speed triggering shall be supported.
4.)
The number of records (depth) of each data recorder and the overflow
conditions (stop-when-full or circular) shall be programmable.
5.)
The number of cycles and the sampling frequency for the waveform shall be
programmable. The following digitized signal representations shall be
available (at 50Hz or 60Hz):
a.)
[[512 samples per cycle x 4 cycles] [optionally 1024 x 2 cycles]
b.)
256 samples per cycle x 7 cycles
c.)
128 samples per cycle x 14 cycles
d.)
64 samples per cycle x 14 cycles
e.)
64 samples per cycle x 28 cycles
f.)
32 samples per cycle x 12 cycles
g.)
32 samples per cycle x 26 cycles
h.)
32 samples per cycle x 40 cycles
i.)
32 samples per cycle x 54 cycles
j.)
16 samples per cycle x 22 cycles
k.)
16 samples per cycle x 48 cycles
l.)
16 samples per cycle x 72 cycles
m.) 16 samples per cycle x 96 cycles ]
f.
Harmonics Monitoring
1.)
On-board calculation of individual harmonics for all phase currents and
phase to neutral or phase-to-phase voltages, up to the 127th harmonic.
2.)
On-board calculation of total harmonic distortion (up to the 127th harmonic)
for all phase currents and phase to neutral or phase-to-phase voltages.
3.)
Software individual and total harmonic distortion to the 255th
4.)
On-board calculation of k-factors for all phase currents
The device shall provide a User Interface with features as follows:
a.
The device shall be capable of calculating the following information for any reading
at 1-second intervals:
1.)
Thermal demand calculations for any parameter, with user-programmable
length of demand period to match local utility billing method.
2.)
Sliding window demands for any parameter with user-programmable length
of demand period and number of sub-periods to match local utility billing
method.
3.)
Predicted Demand calculations of sliding window demand parameters, with
user-programmable predictive response characteristics.
4.)
Minimum value for any measured parameter.
5.)
Maximum value for any measured parameter.
6.)
Derived values for any combination of measured or calculated parameter,
using the following arithmetic, trigonometric and logic functions (equivalent
PLC capabilities):
a.)
Arithmetic functions: division, multiplication, addition, subtraction,
power, absolute value, square root, average, max, min, RMS, sum,
sum-of-squares, unary minus, integer ceiling, integer floor, modulus,
exponent, PI
b.)
Trigonometric functions: COS, SIN, TAN, ARCCOS, ARCSIN,
ARCTAN, LN, LOG10
c.)
Logic functions: =, =>, <=, <>, <, > and, OR, NOT, IF
d.)
Thermocouple linearization functions: Type J, Type K, Type R, Type
RTD, Type T
e.)
Temperature conversion functions: C to F, F to C
b.
The device shall support direct display of all parameters on the front panel in user
programmable groups, using plain language labels. Simultaneous access to all
parameters shall be available through any communication port.
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c.
8.
The device shall be field programmable as follows:
1.)
Basic parameters: Voltage input scale, voltage mode (wye, delta, and single
phase), current input scale, auxiliary input and output scales and
communications setup parameters are programmable from the front panel.
2.)
All basic parameters described above, plus additional set point/relay and
data log setup parameters may be programmed via the communications
port using a portable or remotely located computer terminal.
3.)
The priority of set point events shall be programmable.
4.)
Using ION modules, support customized configurations of all operating
parameters.
5.)
Provisions shall be made to ensure that programming through a computer
can be secured by user ID and password.
6.)
Provisions shall be made to ensure that programming through the front
panel is secured by password.
d.
The device shall have provisions for creating periodic or non-periodic schedules for
up to two (2) years. These schedules may be used to perform the following
functions:
1.)
Time of Use (TOU)
a.)
The device shall provide extensive Time of Use (TOU) functionality to
store and monitor up to 20 years of seasonal rate schedules. The
TOU feature shall allow four seasons, four-day types (each one
capable of at least eight switch times, with a resolution of one
minute). The TOU feature shall support four rate tariffs and at least
twelve holidays per year and shall allow periodic self-read capability.
2.)
Demand Control
3.)
Load Scheduling
4.)
Logging
5.)
Periodic Resetting
Alarming and set point operations shall be supported. The following features are the
minimum requirements for this function:
a.
The device shall provide set point control of internal recording mechanisms and all
digital output relays as follows:
1.)
24 programmable set points shall be provided, each of which can respond to
out-of-range and alarm conditions for any measured parameter.
a.)
Each set point shall have 1-second minimum response time for high
accuracy operation and ½ cycle typical response time for high-speed
operation.
b.)
Each set point shall have programmable pick-up and dropout levels
(high and low limits) and time delays on operate and release.
c.)
Activity of each set point shall generate an event of a programmable
priority. Priority levels shall support up to 256 levels of alarm severity.
d.)
Any set point shall be programmable to any operating condition and
any number of available set points shall be concurrently
programmable to operate on a particular condition to support multiple
threshold conditions.
e.)
Set points shall be programmable to operate on any over or under
condition for:
(1.) Any voltage or current input or average,
(2.) Voltage or current imbalance,
(3.) Neutral/ground current,
(4.) kW or kVAR forward or reverse,
(5.) kVA,
(6.) Power factor lag or lead,
(7.) Frequency,
(8.) kW or current demand on any phase or total or average,
(9.) Individual harmonic distortion on any phase input,
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2.)
3.)
4.)
5.)
6.)
7.)
(10.) Total harmonic distortion on any phase input,
(11.) Total even or odd harmonic distortion on any phase input,
(12.) Any maximum or minimum value,
(13.) Multiple energy accumulation conditions,
(14.) Phase reversal,
(15.) Pulse counts levels,
(16.) Any digital input conditions
(17.) Any internally derived value
Any set point condition shall be able to control any number of digital output
relays in an AND or an OR configuration, using pulse mode or latch mode
operation, for control and alarm purposes. Digital outputs shall also be
operable remotely via any communications port.
Any set point condition shall be able to provide breaker trip relay operation.
Any set point condition shall be able to trigger an internal data or waveform
recorder.
Consecutive high-speed alarm conditions and triggers shall be supported on
a cycle-by-cycle basis with no “dead” time between events (i.e. there shall
be no need for a rearming delay time between events).
It shall be possible to use any logical combination of any number of
available set point conditions to control any internal or external function or
event.
Digital outputs shall support pulse output relay operation for kWh total, kWh
imported, kWh exported, kVARh total, kVARh imported, kVARh exported
and kVAh values.
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A.
Advanced Web Enabled Power Quality Meter with Utility Billing Grade Measurement
Accuracy
1.
Provide a high accuracy power meter meeting the requirements set forth in this
specification. Note any exceptions taken with a detailed description.
a.
Meter shall be Siemens Type 9510 Power Meter with options and features
described in this section.
b.
Supply this meter at all circuits listed:
1.)
Main Substation
2.)
Critical Load Feeders
3.)
Generator Breakers
4.)
As indicated on the drawings
B.
Meet the following recognized standards for application in hardened environments
1.
Device must meet all international standards for Safety & Construction applicable to this
type of device:
a.
UL3111-1
b.
CSA C22.2 No 1010-1
c.
IEC1010-1 (EN61010-1)
2.
Device must meet all international standards for Electromagnetic Immunity applicable to
this type of device:
a.
IEEE C.37-90.1-1989 IEEE Standard Surge Withstand Capability (SWC) Tests for
Protective Relays and Relay Systems (ANSI) (All inputs except for the network
communication port)
b.
IEC1000-4-2 (EN61000-4-2/IEC801-2) Electrostatic Discharge (B)
c.
IEC1000-4-3 (EN61000-4-3/IEC801-3) Radiated EM Field Immunity (A)
d.
IEC1000-4-4 (EN61000-4-4/IEC801-4) Electric Fast Transient (B)
e.
IEC1000-4-5 (EN61000-4-5/IEC801-5) Surge Immunity (B)
f.
IEC1000-4-6 (EN61000-4-6/IEC801-6) Conducted Immunity
g.
ANSI C62.41 Surge Immunity
h.
IEC1000-3-2 (EN61000-3-2) Limits for harmonic currents emissions (equipment
input current < 16 amps per phase).
i.
IEC1000-3-3 (EN61000-3-3) Limitation of voltage fluctuations and flicker in low
voltage supply systems for equipment with rated current < 16 amps.
j.
ENV51040 Radiated EM Field Immunity (A)
k.
ENV51041Conducted EM Field Immunity (A)
l.
EN50082-2 Electromagnetic Compatibility, immunity
3.
Device must meet all international standards for Electromagnetic Emissions
a.
FCC Part 15 Subpart B, Class A Class A Digital Device, Radiated Emissions
b.
EN55011 (CISPR 11) Radiated/Conducted Emissions (Group 1, Class A)
c.
EN55022 (CISPR 22) Radiated/Conducted Emissions (Class A)
d.
EN50081-2 Electromagnetic Compatibility, emissions
4.
Device must comply with IEC687 S0.2
5.
Device must provide measurement accuracy that meets or exceeds ANSI C12.20 CA0.2
6.
Basic hardware requirements of the Power Quality meter are as follows:
a.
Voltage inputs: The device shall have five voltage inputs (V1, V2, V3, V4, and
Vref). The voltage inputs shall be capable of measuring from 0 to 347 Vrms (lineto-neutral) or from 0 to 600 Vrms (line-to-line). The device shall have provisions
for direct connection (require no PTs) for Wye (Star) systems up to 347 VAC (lineto-neutral) or 600 VAC (line-to-line). The device shall also have provisions for
direct connection to Delta systems (with allowance of accuracy degradation of
0.15%) up to 277 VAC (line-to-neutral) or 480 VAC (line-to-line). All voltage inputs
shall provide:
1.)
Dielectric withstand of 3250 VAC rms, 60 Hz for 1 minute
2.)
Overload protection of 1500 VAC rms continuous
3.)
Fault capture to 1400 V peak at the device terminals
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b.
c.
d.
e.
Current inputs: The device shall have five current inputs (I1, I2, I3, I4, and I5). The
current inputs shall be capable of measuring up to 20 A rms (600 V rms maximum
voltage). All current inputs shall provide:
1.)
Dielectric withstand of 3250 VAC rms, 60 Hz for 1 minute
2.)
500 A rms for 1 second, non-recurring
3.)
Fault capture to 50 A rms or 70 A peak at the device terminals
Power supply: The device shall accept power from 85-240 VAC (+/-10%), 47 to 63
Hz or 110-330 VDC (+/-10%) without external converters or separate ordering
options. Maximum burden shall be 20 VA. Ride-through shall be a minimum of
100ms (6 cycles @ 60Hz) for 96 VAC, or 200ms (12 cycles @ 60 Hz) for 120 VAC
or 800ms (48 cycles @ 60 Hz) for 240 VAC. Dielectric withstand shall be 2300
VAC rms, 60 Hz for 1 minute.
On-board I/O: The device supplied shall have the following built-in I/O for this
project.
1.)
Three (3) Form C dry contact relays rated for switching of 2500 VA resistive
2.)
Four (4) Form A solid state outputs
3.)
8 Digital inputs (S1 to S8, SCOM), self-excited dry contact sensing, no
external voltage required, +30VDC differential between SCOM and S1
through S8 inputs
4.)
[The following additional I/O may be added through the application of
one of the following I/O cards. Meter must be able to field retrofit to
upgrade to include these cards.
a.)
Four 0 to 1 mA analog inputs and 8 digital inputs
b.)
Four 0 to 20 mA analog inputs and 8 digital inputs
c.)
Four -1 to 1 mA analog outputs and 8 digital inputs
d.)
Four 0 to 20 mA analog outputs and 8 digital inputs
e.)
Four 0 to 20 mA analog inputs, four 0 to 20 mA analog outputs
and 8 digital inputs
f.)
Four 0 to 1 mA analog inputs, four -1 to 1 mA analog outputs and
8 digital inputs ]
Communications
1.)
Provide the following built-in ports in the purchased configuration. All
communication ports shall be standard technology, as defined by the IEEE.
No communication interfaces not defined by the IEEE shall be accepted.
a.)
Standard communications card: includes RS-232/RS-485 (COM1),
RS-485 (COM2), programmable for baud rates from 1200 to 115200
bits per second.
b.)
An IrDA optical port at the face of the meter display for quick
downloading of meter information with the IrDA port on a laptop.
2.)
Meter must be able to field retrofit to upgrade to the following built-in port
options
a.)
10/100baseT Ethernet connection –with dual master functionality.
b.)
100baseFX Ethernet option–with dual master functionality.
c.)
33.6kbps Modem
3.)
All communication ports in this section must support all of the following
communication capabilities, independently configurable.
a.)
SEAbus/ION protocol
b.)
Modbus RTU protocol
c.)
DNP 3.0 protocol
d.)
XML
e.)
Independent communications from each port simultaneously with no
noticeable interruption of communications from any of the other
communication ports
f.)
Protocols must be field configurable from the front display or via
communications ports. This must be capable of being accomplished
without resetting the meter, or interrupting its operations in any way.
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g.)
7.
Modem and Ethernet port options must support simultaneous
communication to the meter in question and gateway capability to
other RS485 devices on the network via the meter's RS485 ports.
h.)
Support upgrade of the instrumentation firmware.
i.)
Support time synchronization broadcast messages from a host
computer system
j.)
Support time synchronization to GPS time signal
f.
1/4 VGA, bright graphical display (320x240 pixel resolution)
1.)
Ability to display meter data in multiple intuitive formats at the meter display,
with a minimum of the following types of screens.
a.)
3 lines of 1/2" characters for easy viewing of critical power information
b.)
20 real time values on one display for summary overview of currents
and voltages or power readings.
c.)
Display graphical vector representation of all 3 phase voltages and
currents, updated in real time at the meter display, for quick
determination of improper wiring and unusual system conditions
without the need of a computer.
d.)
Display graphical charts of all harmonics (up to the 63rd harmonic) for
each phase voltage and current.
g.
The device shall include 5 MB (optional 10MB) of memory (NVRAM) to store the
following:
1.)
All setup data.
2.)
A time-stamped event log supporting at least 500 events with 1ms resolution
shall record the following information about each event:
a.)
Time of event
b.)
Cause of event
c.)
Effect of event
d.)
Device output reactions
e.)
Priority of event
3.)
Fifty (50) Data Recorder Modules that can each store up to 16 channels of
historical trend data with the following features:
a.)
Each data recorder shall be able to record any high speed (½-cycle)
or high accuracy (1-second) parameter, either measured or derived.
b.)
Each data recorder shall be enabled and triggered manually or
through internal operating conditions, including periodic timer or set
point activity.
c.)
The number of records (depth) of each data recorder and the
overflow conditions (stop-when-full or circular) shall be
programmable.
4.)
Min/Max data for all monitored parameters
5.)
Waveform recordings as described in the power quality paragraph below.
The devices that are equipped with an Ethernet port are Internet enabled and shall
include:
a.
[email protected]®: Automatically e-mail alarm notifications or scheduled system status
updates. E-mail messages sent by the devices can be received like any ordinary
e-mail message. Data logs can also be sent on an event-driven or scheduled
basis.
b.
WebMeter™: Standard built in web pages in the device enable access to real-time
values and basic power quality information using a standard web browser. Basic
configuration of the device can also be performed through the browser. Web pages
must be configurable to allow custom HTML pages to be created. Device must
also support display of downstream devices from the web browser, i.e. feeders and
trip units on customizable web pages within the meter.
c.
XML compatible: Supports easy integration with custom reporting, spreadsheet,
database and other applications
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8.
9.
10.
11.
The device shall accommodate high speed Modbus TCP communications when
connected to Ethernet Port 502.
The device shall support Modbus Master capability to request data from Modbus
compatible slave devices, and make the data available for display on the front panel,
logging, alarming, for calculations etc
The device shall provide technology and functionality to provide high end Power Quality
monitoring as follows:
a.
Continuously sample at 256 samples per cycle on all voltage and current inputs to
support high-end power quality requirements.
b.
High-speed sag/swell detection of voltage disturbances shall be available on a
cycle-by-cycle basis, providing the duration of the disturbance and the minimum,
maximum and average value of the voltage for each phase during the disturbance.
Disturbances less than one cycle in duration shall be detected.
c.
High-speed voltage transient detection, capture and recording: ITIC (CBEMA),
IEEE
d.
Nine (9) programmable oscillographic waveform recorders with the following
features:
1.)
Each waveform recorder shall be able to record a digitized representation of
any phase voltage or current signal.
2.)
Each waveform recorder shall be enabled and triggered manually or through
internal operating conditions, including periodic timer or set point activity.
3.)
High speed triggering shall be supported.
4.)
The number of records (depth) of each data recorder and the overflow
conditions (stop-when-full or circular) shall be programmable.
5.)
The number of cycles and the sampling frequency for the waveform shall be
programmable. The following digitized signal representations shall be
available (at 50Hz or 60Hz):
a.)
[256 samples per cycle x 7 cycles
b.)
128 samples per cycle x 14 cycles
c.)
64 samples per cycle x 14 cycles
d.)
64 samples per cycle x 28 cycles
e.)
32 samples per cycle x 12 cycles
f.)
32 samples per cycle x 26 cycles
g.)
32 samples per cycle x 40 cycles
h.)
32 samples per cycle x 54 cycles
i.)
16 samples per cycle x 22 cycles
j.)
16 samples per cycle x 48 cycles
k.)
16 samples per cycle x 72 cycles
l.)
16 samples per cycle x 96 cycles ]
e.
Harmonics Monitoring
1.)
On-board calculation of individual harmonics for all phase currents and
phase to neutral or phase-to-phase voltages, up to the 63rd harmonic.
2.)
On-board calculation of total harmonic distortion (up to the 63rd harmonic)
for all phase currents and phase to neutral or phase-to-phase voltages.
3.)
Software individual and total harmonic distortion up to the 127th
4.)
On-board calculation of k-factors for all phase currents
The device shall provide a User Interface with features as follows:
a.
The device shall be capable of calculating the following information for any reading
at 1-second intervals:
1.)
Thermal demand calculations for any parameter, with user-programmable
length of demand period to match local utility billing method.
2.)
Sliding window demands for any parameter with user-programmable length
of demand period and number of sub-periods to match local utility billing
method.
3.)
Predicted Demand calculations of sliding window demand parameters, with
user-programmable predictive response characteristics.
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4.)
5.)
6.)
12.
Minimum value for any measured parameter.
Maximum value for any measured parameter.
Derived values for any combination of measured or calculated parameter,
using the following arithmetic, trigonometric and logic functions (equivalent
PLC capabilities):
a.)
Arithmetic functions: division, multiplication, addition, subtraction,
power, absolute value, square root, average, max, min, RMS, sum,
sum-of-squares, unary minus, integer ceiling, integer floor, modulus,
exponent, PI
b.)
Trigonometric functions: COS, SIN, TAN, ARCCOS, ARCSIN,
ARCTAN, LN, LOG10
c.)
Logic functions: =, =>, <=, <>, <, > and, OR, NOT, IF
d.)
Thermocouple linearization functions: Type J, Type K, Type R, Type
RTD, Type T
e.)
Temperature conversion functions: C to F, F to C
b.
The device shall support direct display of all parameters on the front panel in user
programmable groups, using plain language labels. Simultaneous access to all
parameters shall be available through any communication port.
c.
The device shall be field programmable as follows:
1.)
Basic parameters: Voltage input scale, voltage mode (wye, delta, and single
phase), current input scale, auxiliary input and output scales and
communications setup parameters are programmable from the front panel.
2.)
All basic parameters described above, plus additional set point/relay and
data log setup parameters may be programmed via the communications
port using a portable or remotely located computer terminal.
3.)
The priority of set point events shall be programmable.
4.)
Using ION modules, support customized configurations of all operating
parameters.
5.)
Provisions shall be made to ensure that programming through a computer
can be secured by user ID and password.
6.)
Provisions shall be made to ensure that programming through the front
panel is secured by password.
d.
The device shall have provisions for creating periodic or aperiodic schedules for up
to two (2) years. These schedules may be used to perform the following functions:
1.)
Time of Use (TOU)
a.)
The device shall provide extensive Time of Use (TOU) functionality to
store and monitor up to 20 years of seasonal rate schedules. The
TOU feature shall allow four seasons, four-day types (each one
capable of at least eight switch times, with a resolution of one
minute). The TOU feature shall support four rate tariffs and at least
twelve holidays per year and shall allow periodic self-read capability.
2.)
Demand Control
3.)
Load Scheduling
4.)
Logging
5.)
Periodic Resetting
Alarming and set point operations shall be supported. The following features are the
minimum requirements for this function:
a.
The device shall provide set point control of internal recording mechanisms and all
digital output relays as follows:
1.)
24 programmable set points shall be provided, each of which can respond to
out-of-range and alarm conditions for any measured parameter.
a.)
Each set point shall have 1-second minimum response time for high
accuracy operation and ½ cycle typical response time for high-speed
operation.
b.)
Each set point shall have programmable pick-up and dropout levels
(high and low limits) and time delays on operate and release.
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c.)
2.)
3.)
4.)
5.)
6.)
7.)
Activity of each set point shall generate an event of a programmable
priority. Priority levels shall support up to 256 levels of alarm severity.
d.)
Any set point shall be programmable to any operating condition and
any number of available set points shall be concurrently
programmable to operate on a particular condition to support multiple
threshold conditions.
e.)
Set points shall be programmable to operate on any over or under
condition for:
(1.) Any voltage or current input or average,
(2.) Voltage or current imbalance,
(3.) Neutral/ground current,
(4.) kW or kVAR forward or reverse,
(5.) kVA,
(6.) Power factor lag or lead,
(7.) Frequency,
(8.) kW or current demand on any phase or total or average,
(9.) Individual harmonic distortion on any phase input,
(10.) Total harmonic distortion on any phase input,
(11.) Total even or odd harmonic distortion on any phase input,
(12.) Any maximum or minimum value,
(13.) Multiple energy accumulation conditions,
(14.) Phase reversal,
(15.) Pulse counts levels,
(16.) Any digital input conditions
(17.) Any internally derived value
Any set point condition shall be able to control any number of digital output
relays in an AND or an OR configuration, using pulse mode or latch mode
operation, for control and alarm purposes. Digital outputs shall also be
operable remotely via any communications port.
Any set point condition shall be able to provide breaker trip relay operation.
Any set point condition shall be able to trigger an internal data or waveform
recorder.
Consecutive high-speed alarm conditions and triggers shall be supported on
a cycle-by-cycle basis with no “dead” time between events (i.e. there shall
be no need for a rearming delay time between events).
It shall be possible to use any logical combination of any number of
available set point conditions to control any internal or external function or
event.
Digital outputs shall support pulse output relay operation for kWh total, kWh
imported, kWh exported, kVARh total, kVARh imported, kVARh exported
and kVAh values.
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A.
1.2
Revenue Accurate Multifunction Power Meter with harmonics, waveform recording, data
logging and set point control.
1.
Provide a high accuracy power meter meeting the requirements set forth in this
specification. Note any exceptions taken with a detailed description.
a.
Meter shall be Siemens Type 9360 Power Meter with options and features
described in this section.
RELATED STANDARDS
A.
Meet the following recognized standards for application in hardened environments
1.
Device must meet all international standards for Safety and Construction applicable to
this type of device:
a.
UL 3111
b.
CAN/CSA C22.2 No. 1010-1
c.
IEC 1010-1
d.
CE Marked
2.
Device must meet the following international standard for Electromagnetic Immunity
applicable to this type of device:
a.
IEEE C37.90-1989 IEEE Standard Surge withstand capability Tests for Protective
Relays and Relay Systems (ANSI) (All inputs except for the network
communication port)
3.
Device must meet the following international standard for Electromagnetic Emissions:
a.
FCC: Part 15 of FCC Rules for a Class A digital device
B.
Device must provide measurement accuracy that meets or exceeds ANSI C12.16 Class 10.
1.3
GENERAL PROVISIONS
A.
All setup parameters required by the Power Meter shall be stored in nonvolatile memory and
retained in the event of a control power interruption.
B.
The Power Meter may be applied in 4-wire wye, 3-wire wye, 3-wire delta, direct delta and single
phase systems.
C.
The Power Meter shall be capable of being applied without modification at nominal frequencies
of 50, 60, or 400Hz.
D.
A one-piece and remote display (Tran) design shall be available for the meter.
E.
The Power Meter shall be fully supported by Power Meter Software.
1.4
COMPONENTS
A.
Current/Voltage Inputs
1.
The Power Meter shall have no less than 4 voltage inputs and 3 current inputs.
2.
The Power Meter in its standard configuration shall be able to accept 600VLL/347LN
without using potential transformers.
3.
The Power Meter shall be able to withstand 900 VAC RMS continuously without damage.
4.
The Power Meter shall have nominal current ratings of 5A ac with a current range or 010A ac
5.
The Power Meter shall be able to withstand 15A continuous, 50A for 10s/hour and 500A
1s/hour.
B.
Measured Values
1.
The Power Meter shall provide the following, true RMS metered quantities for voltage:
a.
Voltage L–L Per-Phase
b.
Voltage L-L 3-Phase Avg
c.
Voltage L–N Per-Phase
d.
Voltage 3-Phase Avg
e.
Voltage % unbalanced
f.
Voltage L-L Min/Max
g.
Voltage L-N Min/Max
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2.
3.
4.
5.
h.
Voltage L-L, Unbalanced Min/Max
i.
Voltage L-N, Unbalanced Min/Max
The Power Meter shall provide the following true RMS metered quantities for current:
a.
Current Per-Phase
b.
Current, Neutral (calculated)
c.
Current 3-Phase Avg
d.
Current % Unbalanced
e.
Current Min/Max
The Power Meter shall provide the following true RMS metered quantities for power:
a.
Real Power (Per-Phase, 3-Phase Total)
b.
Reactive Power (Per-Phase, 3-Phase Total)
c.
Apparent Power (Per-Phase, 3-Phase Total)
d.
Power Factor – True (Per-Phase, 3-Phase Total)
e.
Power Factor – Displacement (Per-Phase, 3-Phase Total)
f.
True Power Factor Total – Min/Max
g.
Displacement Power Factor Total – Min/Max
h.
Real Power Factor Total – Min/Max
i.
Reactive Power Total – Min/Max
j.
Apparent Power Total – Min/Max
k.
THD – Voltage, Current (3-Phase, Per-Phase, Neutral)
l.
Fundamental Voltage, Magnitude and Angle (Per-Phase)
m.
Fundamental Current, Magnitude and Angle (Per-Phase)
n.
Fundamental Real Power (Per-Phase, 3-Phase)
o.
Fundamental reactive Power (Per-Phase)
p.
Phase Rotation Unbalance (Current and Voltage)
q.
Harmonic Magnitudes & Angles for Current and Voltage (Per Phase) up to the
63rd Harmonic.
The Power Meter shall provide the following true RMS metered quantities for energy:
a.
Accumulated Energy (Real kWh, Reactive kVARh, Apparent kVAh)
(Signed/Absolute)
b.
Incremental Energy (Real kWh, Reactive kVARh, Apparent kVAh)
(Signed/Absolute)
c.
Conditional Energy (Real kWh, Reactive kVARh, Apparent kVAh)
(Signed/Absolute)
d.
Reactive Energy by Quadrant
The Power Meter shall be able of providing select real-time metering data in floating point
format.
C.
Demand
1.
All power demand calculations shall use any one of the following calculation methods,
selectable by the end user:
a.
Thermal Demand using a sliding window updated every second for the present
demand and at the end of the interval for the last interval. The window length shall
be set by the end user from 1 – 60 minutes in one minute increments.
b.
Block Interval, with optional sub intervals. The window length shall be set by the
end user from 1 – 60 minutes in one minute increments. The following block
methods available are: Sliding Block, Fixed Block and Rolling Block.
c.
The Power Meter shall be able to provide min/max demand, present demand
interval, running average demand and predicted demand on multiple demand
channels including current demand, power demand and user-defined generic
demand channels, which also include demand calculations based on input pulses.
d.
The Power Meter shall be able to perform multiple accepted demand calculation
methods including block, rolling block and thermal demand with userprogrammable length of demand period to match local utility billing method.
D.
Accuracy
1.
The Power Meter shall meet ANSI C12.20 0.5
July 2, 2016
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2.
3.
The Power Meter shall meet IEC 62053-22 class 0.5S (real energy)
The Power Meter shall meet IEC 62053-23 class 2 (reactive energy)
E.
Sampling
1.
The Power Meter shall perform zero-blind metering and sample at a minimum of 128
samples per cycle, simultaneously on all voltage and current channels in the meter.
2.
The Power Meter shall provide 1-second updates in registers and on the display.
3.
The Power Meter shall digitally sample at a rate high enough to provide true RMS
accuracy to the 63rd (PM9360) harmonic for current and voltage.
F.
Logging
1.
The Power Meter shall provide for onboard data logging. The Power Meter shall be able
to log data, alarms, events and waveform captures.
a.
The Power Meter shall support 800kb of logging information.
b.
The Power Meter shall support 3 customizable data logs each capable of capturing
up to 96 user-defined or preset quantities based on an alarm event or a time
interval.
c.
The Power Meter shall support an alarm log which records date/time stamps and
alarm values.
d.
The Power Meter shall support a billing log which records quantities at a userdefined interval.
e.
The Power Meter shall support a Maintenance log which records quantities at a
user-defined interval.
f.
Basic logging shall will be factory set and will startup when power is applied.
G.
Alarming
1.
The Power Meter shall have set point driven alarming capability.
2.
The Power Meter shall be able to generate an email on an alarm condition.
3.
The Power Meter shall support over 50 definable alarm conditions based on pick-up,
drop-out and delay variables.
4.
The Power Meter shall be able to trigger data log captures on an alarm condition.
5.
The Power Meter shall be able to trigger waveform captures on an alarm condition.
6.
The Power Meter shall be able to open or close relays on an alarm condition possibly to
perform load-shedding.
7.
The Power Meter shall be able to combine any logical combination of any number of
available set point conditions to control any internal or external function or event.
8.
The Power Meter shall provide custom Boolean alarms which allow the user to create an
alarm condition with NAND, NOT, OR and XOR on a user-defined register value.
9.
The Power Meter shall have four alarm severity levels for any value.
10.
Indication of an alarm condition shall be given on the front display of the meter.
H.
Communications
1.
The Power Meter shall be capable of the following communications methods:
a.
Ethernet
b.
Serial – RS-232 and RS-485 (2 wire / 4 wire).
2.
The Power Meter shall support the following communications protocols:
a.
Modbus RTU (Serial) built into meter.
b.
Modbus TCP (Ethernet), with optional 10/100Mbaud Ethernet communications
module.
c.
SMTP
d.
SNTP
3.
The Power Meter shall support up to 2 communications port simultaneously.
4.
The Power Meter shall support GPS time synchronization.
I.
I/O Options
1.
The Power Meter shall provide as standard 1 digital input and 1 digital solid state output /
KY pulse output.
2.
The Power Meter shall be capable of supporting 13 digital inputs.
July 2, 2016
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3.
4.
5.
6.
7.
8.
The Power Meter shall be capable of supporting 5 relay outputs which can be configured
for pulse output relay operation for kWh total, kVARh total, kVAh, kWh imported, kVARh
imported, kWh exported, kVARh exported.
The Power Meter shall be capable of supporting 2 energy pulse outputs simultaneously.
The Power Meter shall have relay outputs that can be controlled by communications or
by an alarm.
The Power Meter shall have relay outputs that can be able to be configured for latched
mode or timed mode.
The Power Meter shall be capable of supporting 4 analog inputs
The Power Meter shall be capable of supporting 4 analog outputs.
J.
Display
1.
The Power Meter shall have a 6-line back lit LCD display which provides 4 simultaneous
quantities on-screen.
2.
The Power Meter shall be capable of having an anti-glare backlit white LCD display, both
integrated or in a remote display version.
3.
The Power Meter shall have graphical displays in the form of bar graphs for current and
power values.
4.
The Power Meter shall allow the user to select one of three languages to view on the
screen; English, French, Spanish, German and Russian.
5.
The Power Meter shall provide local access to the following metered values:
a.
Current, per phase rms and 3-phase average.
b.
Voltage, phase-phase, phase to neutral and 3-phase average.
c.
Real Power, per phase and 3-phase total.
d.
Reactive power, per phase and 3-phase total.
e.
Apparent power, per phase and 3-phase total.
f.
Power factor, 3-phase total and per phase.
g.
Frequency
h.
Demand current, per phase and three phase average.
i.
Demand real power and three phase total.
j.
Demand apparent power and three phase total.
k.
Accumulated Energy
l.
THD, current and voltage per phase.
6.
Reset of the following values shall be allowed from the Power Meter display:
a.
Peak demand current.
b.
Peak demand power (kW) and peak demand apparent power (kVA).
c.
Energy (MWh) and reactive energy (MVARh).
7.
Setup requirements shall be allowed at the display. These include:
a.
CT Rating
b.
PT Rating
c.
System Type
d.
Watt-Hour Pulse
e.
Meter ID number
f.
Meter IP Address
K.
Power Quality
1.
The Power Meter shall be IEC 61000-4-30 class B compliant.
2.
The Power Meter shall perform EN50160 power quality evaluations.
3.
The Power Meter shall provide CBEMA/ITIC data.
4.
The Power Meter shall provide harmonic magnitudes and angles up to the 63rd.
L.
Waveform Capture
1.
The Power Meter shall perform 128 samples per cycle waveform capture recording for all
six phases and store it in a non-volatile memory.
2.
The Power Meter shall be able to perform waveform capturing both on-event or manually
triggered.
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3.
4.
5.
6.
7.
8.
The Power Meter shall transmit the waveform samples over the network to the
manufactures PMS software for display, archival and analysis.
Harmonic analysis on the waveform captures will be through the 63rd.
The Power Quality Power Meter shall be able to provide up to 185 cycles of data in a
waveform capture.
The Power Meter shall have configurable waveform capture with flexible resolutions.
The Power Meter shall have Sag / Swell detection for troubleshooting.
All waveforms must reflect the actual circuit performance. Waveforms synthesized or
composed over time shall not be acceptable.
M.
Advanced Features
1.
The Power Meter firmware shall be field upgradeable without any disassembly or
changing of any internal circuit chips. It will also not be required to de-energize the circuit
or equipment to perform the upgrade.
2.
The Power Meter firmware shall be able to trend quantity and provide a prediction of that
quantity over the next 4 intervals with different time resolutions.
3.
The Power Meter firmware shall be able to provide energy used over 3 different userdefined time intervals and also the cost of that energy that has been used over the said
time-interval.
The
time-intervals
shall
have
different
time
resolutions
(daily/weekly/monthly).
4.
The Power Meter shall support five languages without having to upgrade firmware. The
languages are to at minimum include English, French, Spanish, German and Russian.
Other languages such as Turkish are available upon request.
N.
Optional Ethernet Module
1.
The Ethernet communications module shall have an embedded web server capable of
severing HTML pages with dynamic meter data displays.
2.
The HTML web pages shall allow for hyperlinks to other external HTML pages.
3.
The Ethernet module shall connect to the Ethernet LAN via a standard RJ-45 port using
unshielded twisted pair cable or LC fiber optic multimode fiber (100BaseFX).
4.
There shall be indicating LED’s for trouble-shooting that indicate; TRANSMIT, RECEIVE
and LINK status for the Ethernet connection and TRANSMIT, RECEIVE for the RS-485
communications.
5.
The Ethernet card shall be fully compliant with TCP/IP.
6.
The protocol used over Ethernet shall be Modbus TCP.
7.
Setup of the Ethernet card shall be accomplished via the on-board Ethernet port and a
web browser.
8.
It shall be possible to upgrade the Ethernet module via the Ethernet LAN in the field.
9.
The HTML Web pages shall be configurable to display data from all the devices
connected to the Ethernet communications module.
10.
HTML data shall be displayed in a tabular or trended format.
11.
The Ethernet module shall be capable of initiating an e-mail based on the alarms or
custom logic programmed into the meter.
12.
A fixed Ethernet module attached to the meter and deriving power from the meter shall
be used. No external or remote PLC or PC’s shall be used as a gateway.
13.
Ethernet module shall be UL Listed, NOM, CE and CSA certified.
14.
SNMP (Simple Network Management Protocol) shall be supported by the Power Meter
according to the industry standard MIB2.
15.
SNMP (Simple Network Management Protocol) shall be supported to allow date and time
synchronized to within 1 second.
16.
Modifying the HTML pages shall not require any Java scripting.
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A.
1.2
RELATED STANDARDS
A.
1.3
Revenue Accurate Power Meter with Harmonics, Data Logging and Set point Control.
1.
Provide a high accuracy power meter meeting the requirements set forth in this
specification. Note any exceptions taken with a detailed description.
a.
Meter shall be Siemens Type SENTRON PAC4200 Power Meter with options and
features described in this section.
b.
Supply this meter at all circuits listed:
1.)
[Every main on every substation].
2.)
[Every location marked on the attached drawings].
3.)
[Every circuit above 400A].
Meet the following recognized standards for application in hardened environments:
1.
Device must meet all international standards for Safety and Construction applicable to
this type of device:
a.
ANSI C12.20, 0.5% Revenue requirements
b.
IEC61557-12 accuracy certified samples at over 2048 per 10/12 cycles samples
per cycle.
2.
The meter shall also meet the followings standard compliances:
a.
UL, CSA and CE Approvals:
1.)
UL 61010-1, 2nd Ed.
2.)
CAN/CSA-C22.2 NO. 61010-1-04, 2nd Ed.
3.)
CE approved.
4.)
Class 0.2 S acc. to IEC61557-12.( Correlates to IEC62053-22)
3.
The meter shall meet the following Safety / Construction Standards:
a.
IEC1010-1 (EN61010-1): Safety Requirements for Electrical Equipment, Control
and Laboratory Use.
b.
CAN/CSA C22.2 No. 61010-1-04, 2nd Ed.: Safety requirements of Canadian
Standard Association.
c.
Device must meet the following international standard for Electromagnetic
Emissions:
1.)
FCC: Part 15 of FCC Rules for a Class A digital device
THE METER SHALL HAVE THESE STANDARD FEATUERS AT A MINIMUM:
a.
Current inputs: The meter shall accept three 5A nominal current inputs. The
current inputs are capable of measuring up to 5A RMS (300V RMS maximum
voltage). All current inputs provide:
1.)
Dielectric withstand of 3000Vrms 47-63 Hz for 1 minute.
2.)
Surge protection of 120 A RMS for 1 second, non-recurring.
b.
The meter shall have three voltage inputs (V1, V2, and V3). The voltage inputs
can measure from 0 to 400 Vrms (line-to-neutral) or from 0 to 690 Vrms (line-toline).
c.
The meter shall have provisions for direct connection (require no PTs) for Wye
(Star) systems up to 400 VAC (line-to-neutral) or 690 VAC (line-to-line). All
voltage inputs provide:
1.)
Dielectric withstand of 3250 VAC RMS, 60 Hz for 1 minute.
2.)
Overload protection of 1500 VAC RMS continuous.
d.
Power supply:
1.)
[95 - 240 VAC (±10%), 50 to 60 Hz]
2.)
[140 – 340V DC (±10%)]
e.
Typical burden is 6 VA, maximum burden is 8 VA. Dielectric withstand is 2000
VAC RMS, 60 Hz for 1 minute.
f.
The meter shall provide for Screw terminals to meet various regulations.
g.
Operating frequency: 45 to 64 Hz.
h.
Standard Communications port shall be a RJ45 Modbus TCP 10/100BaseT
Copper Ethernet communication with “dual” master functionality. The metering
instrument shall have the following optional communications ports:
July 2, 2016
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i.
j.
k.
l.
m.
n.
o.
p.
q.
r.
s.
t.
u.
v.
1.)
[Profibus DP]
[Profibus DP will programmable to communicate 9600 BPS to 12 MPBS with
supplied .GSD file.]
2.)
[Modbus RTU (RS-485) serial]
[Modbus will be programmable to communicate at speeds from 4800 to 38.4
bits per second]
The meter shall support broadcast messages from up to four master computer
systems through the Ethernet TCP port
The meter shall provide “two” optional ports for future adder options.
The meter shall provide as “standard” the following Inputs/Outputs:
1.)
Two Digital Input – rated at 24 VDC / 0.7mA
2.)
Two Digital Output – rated 12-24 VDC, 0-10mA
A universal counter shall be designed into the meter to count pulses coming into
the digital inputs for measuring variables such as Water, Gas, Air, etc.
Sample Rate shall be at least 2048 samples per cycle.
Meter shall support multiple languages including English, German, French,
Spanish, Italian, Portuguese, Turkish, Chinese and Russian.
Meter design shall be:
1.)
A background-illuminated graphic LCD sized with 128 x 96 pixel resolution.
2.)
An overview size of 3.78”L x 3.78”W (96 x 96mm) and a depth of 2.00”
(51mm), with an optional module added the depth shall be 2.87” (73mm).
Meter base design shall provide for (2) two optional expansion slots.
The meter shall be able to be upgraded in the field without removing the meter.
The meter shall measure the following variables as standard without optional plug
in modules or optional cards;
Basic Measurements
1.)
Voltage (l-n) per phase, Voltage (l-l) per phase, Voltage (l-l) average,
Voltage (l-n) average, Current per phase, Current average total, Active
Power (kW) per phase and total, Apparent Power (kVa) per phase and total,
Reactive Power (kVAR) per phase and total,
Advanced Measurements (Included)
1.)
Power factor (per phase and total), Voltage THD per phase, Current THD
per phase, Frequency, total active power demand import/export; Meter
running counter, universal counter, limit alarming for 6 values
Min/Max Values
1.)
Voltage (l-n) per phase, Voltage (l-l) per phase, Average Voltage (l-l) and (ln) total; Current per phase, Active Power (kW) per phase and total,
Apparent Power (kVa) per phase and total, Reactive Power (kVAR) per
phase and total, Power factor (per phase and total), Voltage THD per phase,
Current THD per phase, Frequency,
Energy Measurements
1.)
Energy (kWh) import/export , high/low tariff; Apparent energy (kVAh),
high/low tariff; Reactive energy (kVARh) import/export, high/low tariff Peak
power demand (kW), Current demand, Peak current demand, Neutral
current, Reactive power (kVAR) peak demand, Apparent power (kVA) peak
demand,.
2.)
3.)
4.)
The meter shall calculate the following information for any reading at 1second intervals:
Sliding window demands for any parameter with user-programmable length
of demand period.
Number of sub-periods to match local utility billing method.
w.
The meter shall display “actual” readings on the display. No manual calculation
shall be required to obtain actual readings.
x.
The meter shall display all measured parameters on the front display.
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1.4
y.
Harmonic Bar Charts shall be available on the display.
z.
Phasor Diagram shall be available on the display to provide fast system
diagnostics.
aa.
Remote access to all metering parameters shall be available through the Ethernet
communications port and Serial port at the same time.
bb.
Meter shall provide as standard the ability to customize up to four screens.
cc.
The meter shall act as a “Gateway” allowing up to 32 Modbus serial to be
connected to the meter and the data passed to the Ethernet LAN.
dd.
An internal Clock shall be provided to allow time and date stamping of data.
ee.
The meter shall have the ability to monitor as least twelve (12) different set points
for alarming. These include: V, I, Power, VAR, VA, Freq, THD and PF.
ff.
Standard logic functionality shall be available in the meter for setting up custom
alarms that can be sent out via the digital output or through the communications
port.
gg.
The meters shall be field programmable as follows:
1.)
Basic parameters: Voltage input scale, voltage mode (Wye, Delta, single
phase), current input scale, auxiliary input and output scales, and
communications setup parameters are programmable from the front panel.
2.)
All basic parameters described above may be programmed via the
communications port using a portable or remotely located computer
terminal.
3.)
Provisions must be made to ensure that programming through a computer
can be secured by user ID and password.
4.)
Provisions must be made to ensure that programming through the front
panel is secured by password.
hh.
The meter shall include flash memory to store in non-volatile memory the following:
1.)
All setup data
2.)
Accumulated energy and demand data.
hh.
The meter shall include data and event logging, as follows:
1.)
Kw, kWd, Min/Max values for up to 40 days at 15 min intervals.
2.)
Event logging for up to 4096 operations.
3.)
Logs shall be first in first out or fixed.
4.)
Date and time synchronization shall be through the digital input,
communication interfaces or internal clock.
II.
Storage of load demand values
1.)
Meter shall have storage capacity of up to 4096 operation, control or
system events
2.)
Power demand values (load profile) for apparent, active and reactive power
for 4 month with minimum & maximum values at a 15min. measuring period
3.)
Total reactive power, fundamental reactive power or distorted reactive
power, selectable
4.)
Arithmetic or cumulated power demand values could be calculated
5.)
Synchronization via digital input, communication interfaces or internal clock
6.)
Supports fixed or rolling block method.
DESIGN
[Select either 2.4.A.1 or 2.4.A.2. For 2.4.A.2, select a, b, c, d, e, f or g]
July 2, 2016
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A.
The SENTRON PAC4200 meter shall be available in the following unit design configurations:
1.
One-piece design that fits into a standard 96mm x 96mm” cutout.
2.
Din Rail Mounting
3.
[Multi Meter Pack Enclosure with the following sizes:
a.
[One meter]
b.
[Up to Two meters]
c.
[Up to Four meters]
d.
[Up to Six meters]
e.
[Up to Eight meters]
f.
[Up to Ten meters]
g.
[Up to Twelve meters] ]
July 2, 2016
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A. Revenue Accurate Multifunction Power Meter with Harmonics.
1.
Provide a high accuracy power meter meeting the requirements set forth in this
specification. Note any exceptions taken with a detailed description.
a.
Meter shall be Siemens Type SENTRON PAC3200 Power Meter with options and
features described in this section.
b.
Supply this meter at all circuits listed:
1.)
2.)
3.)
4.)
5.)
1.2
RELATED STANDARDS
A.
1.3
Section 16145 – Lighting Control Devices
Section 16430 – Low Voltage Switchgear
Section 16441 – Switchboard
Section 16442 – Panelboards
Section 16443 – Motor Control Centers]
a.)
Feeders as shown on the drawings [List all circuits/applications
where this meter will be applied in associated distribution
equipment.]
(1.) [Every main on every substation]
(2.) [Every location marked on the attached drawings]
Meet the following recognized standards for application in hardened environments:
1.
Device must meet all international standards for Safety and Construction applicable to
this type of device:
a.
ANSI C12.20, 0.5% Revenue requirements
b.
IEC 62053-22/23 accuracy certified samples at over 64 samples per cycle
2.
The meter shall also meet the followings standard compliances:
a.
UL, CSA and CE Approvals:
1.)
UL 61010-1, 2nd Ed.
2.)
CAN/CSA-C22.2 NO. 61010-1-04, 2nd Ed.
3.)
CE approved.
b.
Class 0.5 S acc. to IEC62053-22.
3.
The meter shall meet the following Safety / Construction Standards:
a.
IEC1010-1 (EN61010-1): Safety Requirements for Electrical Equipment, Control
and Laboratory Use.
b.
CAN/CSA C22.2 No. 61010-1-04, 2nd Ed.: Safety requirements of Canadian
Standard Association.
THE METER SHALL HAVE THESE STANDARD FEATUERS AT A MINIMUM:
1.
Basic hardware requirements of the Multifunction Power Meter are as follows:
a.
Current inputs: The meter shall accept three 5A nominal current inputs. The
current inputs are capable of measuring up to 5A RMS (300V RMS maximum
voltage). All current inputs provide:
1.)
Dielectric withstand of 3000Vrms 47-63 Hz for 1 minute.
2.)
Surge protection of 120 A RMS for 1 second, non-recurring.
b.
The meter shall have three voltage inputs (V1, V2, and V3). The voltage inputs
can measure from 0 to 400 Vrms (line-to-neutral) or from 0 to 690 Vrms (line-toline).
c.
The meter shall have provisions for direct connection (require no PTs) for Wye
(Star) systems up to 400 VAC (line-to-neutral) or 690 VAC (line-to-line). All
voltage inputs provide:
1.)
Dielectric withstand of 3250 VAC RMS, 60 Hz for 1 minute.
2.)
Overload protection of 1500 VAC RMS continuous.
d.
Power supply:
1.)
[95 - 240 VAC (±10%), 50 to 60 Hz]
2.)
[140 – 340V DC (±10%)]
e.
Typical burden is 6 VA, maximum burden is 8 VA. Dielectric withstand is 2000
VAC RMS, 60 Hz for 1 minute.
July 2, 2016
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f.
g.
h.
i.
j.
k.
l.
m.
Operating frequency: 45 to 64 Hz.
Standard Communications port shall be a RJ45 Modbus TCP 10BaseT Copper
Ethernet communication is standard. The metering instrument shall have the
following optional communications ports:
1.)
[Profibus DP]
2.)
[Profibus DP will programmable to communicate 9600 BPS to 12 MPBS
with supplied .GSD file.]
3.)
[Modbus RTU (RS-485) serial]
4.)
[Modbus will be programmable to communicate at speeds from 4800 to
38.4 bits per second]
The meter shall support broadcast messages from a host computer system.
Inputs/Outputs: The meter shall have:
1.)
One Digital Input – rated at 24 VDC / 0.7mA
2.)
One Digital Output – rated 12-24 VDC, 0-10mA
A universal counter shall be designed into the meter to count pulses coming into
the digital inputs for measuring variables such as Water, Gas, Air, etc.
Sample Rate shall be at least 400 samples per cycle.
Meter shall support multiple languages including English, German, French,
Spanish, Italian, Portuguese, Turkish, Chinese and Russian.
Meter design shall be:
1.)
A background-illuminated graphic LCD with resolutions of 128 x 96 pixels.
2.)
An overview size of 3.78”L x 3.78”W (96 x 96mm) and a depth of 2.00”
(51mm), with an optional module added the depth shall be 2.87” (73mm).
B.
The meter shall be able to be upgraded in the field without removing the meter.
C.
The meter shall measure the following variables as standard without optional plug in modules or
optional cards;
1.
Basic Measurements
a.
Voltage (l-n) per phase, Voltage (l-l) per phase, Voltage (l-l) average, Voltage (l-n)
average, Current per phase, Current average total, Active Power (kW) per phase
and total, Apparent Power (kVa) per phase and total, Reactive Power (kVAR) per
phase and total,
2.
Advanced Measurements (Included)
a.
Power factor (per phase and total), Voltage THD per phase, Current THD per
phase, Frequency, total active power demand import/export; Meter running
counter, universal counter, limit alarming for 6 values
3.
Min/Max Values
a.
Voltage (l-n) per phase, Voltage (l-l) per phase, Average Voltage (l-l) and (l-n) total;
Current per phase, Active Power (kW) per phase and total, Apparent Power (kVa)
per phase and total, Reactive Power (kVAR) per phase and total, Power factor (per
phase and total), Voltage THD per phase, Current THD per phase, Frequency,
4.
Energy Measurements
a.
Energy (kWh) import/export , high/low tariff; Apparent energy (kVAh), high/low
tariff; Reactive energy (kVARh) import/export, high/low tariff Peak power demand
(kW), Current demand, Peak current demand, Neutral current, Reactive power
(kVAR) peak demand, Apparent power (kVA) peak demand,.
D.
The meter shall calculate the following information for any reading at 1-second intervals:
1.
Sliding window demands for any parameter with user-programmable length of demand
period.
2.
Number of sub-periods to match local utility billing method.
E.
The meter shall display “actual” readings on the display. No manual calculation shall be
required to obtain actual readings.
F.
The meter shall display all measured parameters on the front display. Simultaneous access to
all parameters is available through the communications port.
July 2, 2016
Power Monitoring and Control
[Project Name]
[26 09 13] [16290]-30
G.
The meter shall have the ability to monitor as least six (6) different set points for alarming.
These include: V, I, Power, VAR, VA, Freq, THD and PF.
H.
Standard logic functionality shall be available in the meter for setting up custom alarms that can
be sent out via the digital output or through the communications port.
I.
The meters shall be field programmable as follows:
1.
Basic parameters: Voltage input scale, voltage mode (Wye, Delta, single phase), current
input scale, auxiliary input and output scales, and communications setup parameters are
programmable from the front panel.
2.
All basic parameters described above may be programmed via the communications port
using a portable or remotely located computer terminal.
3.
Provisions must be made to ensure that programming through a computer can be
secured by user ID and password.
4.
Provisions must be made to ensure that programming through the front panel is secured
by password.
J.
The meter shall include flash memory to store in non-volatile memory the following:
1.
All setup data
2.
Accumulated energy and demand data.
K.
The SENTRON PAC3200 meter shall be available in the following unit design configurations:
1.
[One-piece design that fits into an 96mmx96mm cutout.]
2.
Din Rail Mountable version
3.
[Multi Meter Pack Enclosure (NEMA 1) with the following sizes:
a.
[One meter]
b.
[Up to Two meters]
c.
[Up to Four meters]
d.
[Up to Six meters]
e.
[Up to Eight meters]
f.
[Up to Ten meters]
g.
[Up to Twelve meters] ]
July 2, 2016
Power Monitoring and Control
[Project Name]
[26 09 13] [16290]-31
A. Revenue Accurate Multifunction Basic Power Meter.
1.
Provide a high accuracy power meter meeting the requirements set forth in this
specification. Note any exceptions taken with a detailed description.
a.
Meter shall be Siemens Type SENTRON PAC3100 Power Meter with features
described in this section.
b.
Supply this meter at all circuits listed:
1.)
Section 16145 – Lighting Control Devices
2.)
Section 16430 – Low Voltage Switchgear
3.)
Section 16441 – Switchboard
4.)
Section 16442 – Panelboards
5.)
Section 16443 – Motor Control Centers]
1.2
RELATED STANDARDS
A.
1.3
Meet the following recognized standards for application in hardened environments:
1.
Device must meet all international standards for Safety and Construction applicable to
this type of device:
a.
ANSI C12.16, 1% Revenue requirements
b.
IEC 62053-22/23 accuracy certified samples at over 64 samples per cycle
2.
The meter shall also meet the followings standard compliances:
a.
UL, CSA and CE Approvals:
1.)
UL 61010-1, 2nd Ed.
2.)
CAN/CSA-C22.2 NO. 61010-1, 2nd Ed.
3.)
CE approved.
b.
Class 1 acc. to IEC62053-22.
3.
The meter shall meet the following Safety / Construction Standards:
a.
IEC1010-1 (EN61010-1): Safety Requirements for Electrical Equipment, Control
and Laboratory Use.
b.
CAN/CSA C22.2 No. 61010-1-04, 2nd Ed.: Safety requirements of Canadian
Standard Association.
THE METER SHALL HAVE THESE STANDARD FEATUERS AT A MINIMUM:
a.
Current inputs: The meter shall accept three 5A nominal current inputs. The
current inputs are capable of measuring up to 5A RMS (300V RMS maximum
voltage). All current inputs provide:
1.)
Dielectric withstand of 3000Vrms 47-63 Hz for 1 minute.
2.)
Surge protection of 120 A RMS for 1 second, non-recurring.
b.
The meter shall have three voltage inputs (V1, V2 and V3). The voltage inputs can
measure from 0 to 480 Vrms (line-to-line).
c.
The meter shall have provisions for direct connection (require no PTs) for Wye
(Star) systems up to 277 VAC (line-to-neutral). All voltage inputs provide:
1.)
Dielectric withstand of 3250 VAC RMS, 60 Hz for 1 minute.
2.)
Overload protection of 1500 VAC RMS continuous.
d.
Power supply:
1.)
[100 - 240 VAC (±10%), 50 to 60 Hz]
2.)
[110 – 250V DC (±10%)]
e.
Typical burden is 6 VA, maximum burden is 8 VA. Dielectric withstand is 2000
VAC RMS, 60 Hz for 1 minute.
f.
Operating frequency: 45 to 64 Hz.
g.
Standard Communications port shall be a Modbus RS485 as standard.
h.
The meter shall support broadcast messages from a host computer system.
i.
Inputs/Outputs: The meter shall have:
1.)
Two Wet Digital Inputs – rated at 24 VDC / 0.7mA
2.)
Two Wet Digital Outputs – rated 0-30 VDC, 0-10mA
j.
A universal counter shall be designed into the meter to count pulses coming into
the digital inputs for measuring variables such as Water, Gas, Air, etc.
July 2, 2016
Power Monitoring and Control
[Project Name]
[26 09 13] [16290]-32
k.
l.
m.
1.4
Sample Rate shall be at least 64 samples per cycle.
Meter shall support multiple languages including English, German, French,
Spanish, Italian, Portuguese, Turkish, Chinese and Russian.
Meter design shall be:
1.)
A background-illuminated graphic LCD sized 128 x 96mm.
2.)
An overview size of 3.78”L x 3.78”W (96 x 96mm) and a depth of 2.00”
(51mm), with an optional module added the depth shall be 2.87” (73mm).
OVERVIEW
A.
The meter shall be able to be upgraded in the field without removing the meter.
B.
The meter shall measure the following variables as standard without optional plug in modules or
optional cards:
1.
Basic Measurements
a.
Voltage (l-n) per phase, Voltage (l-l) per phase, Voltage (l-l) average, Voltage (l-n)
average, Current per phase, Current average total, Active Power (kW) per phase
and total, Apparent Power (kVa) per phase and total, Reactive Power (kVAR) per
phase and total.
2.
Advanced Measurements (Included)
a.
Total Power factor, frequency, total active power demand import/export, Min/Max
Values
b.
Voltage (l-n) per phase, Voltage (l-l) per phase, Average Voltage (l-l) and (l-n) total;
Current per phase, Active Power (kW) per phase and total, Apparent Power (kVa)
per phase and total, Reactive Power (kVAR) per phase and total, total Power
factor, Frequency.
3.
Energy Measurements
a.
Active
Energy
(kWh)
import/export/net,
Reactive
energy
(kVARh)
import/export/net, Peak power demand (kW), Current demand, Peak current
demand, Neutral current, Reactive power (kVAR) peak demand, Apparent power
(kVA) peak demand.
C.
The meter shall calculate the following information for any reading at 1-second intervals:
1.
Sliding window demands for any parameter with user-programmable length of demand
period.
2.
Number of sub-periods to match local utility billing method.
D.
The meter shall display “actual” readings on the display. No manual calculation shall be
required to obtain actual readings.
E.
The meter shall display all measured parameters on the front display. Simultaneous access to
all parameters is available through the communications port.
F.
Standard logic functionality shall be available in the meter for setting up custom alarms that can
be sent out via the digital output or through the communications port.
G.
The meters shall be field programmable as follows:
1.
Basic parameters: Voltage input scale, voltage mode (Wye, Delta, single phase), current
input scale, auxiliary input and output scales and communications setup parameters are
programmable from the front panel.
2.
All basic parameters described above may be programmed via the communications port
using a portable or remotely located computer terminal.
3.
Provisions must be made to ensure that programming through a computer can be
secured by user ID and password.
4.
Provisions must be made to ensure that programming through the front panel is secured
by password.
H.
The meter shall include flash memory to store in non-volatile memory the following:
1.
All setup data
2.
Accumulated energy and demand data.
July 2, 2016
Power Monitoring and Control
[Project Name]
[26 09 13] [16290]-33
1.5
DESIGN [Select either 2.4.A.1 or 2.4.A.2. For 2.4.A.2, select a, b, c, d, e, f or g]
A.
The SENTRON PAC3100 meter shall be available in the following unit design
configurations:
1.
[One-piece design that fits into an 96mmx96mm cutout.]
2.
Din Rail Mountable Version
3.
[Multi Meter Pack Enclosure (NEMA 1) with the following sizes:
a.
[One meter]
b.
[Up to Two meters]
c.
[Up to Four meters]
d.
[Up to Six meters]
e.
[Up to Eight meters]
f.
[Up to Ten meters]
g.
[Up to Twelve meters] ]
PART 2 - EXECUTION
2.1
INSTALLATION
A.
The Contractor shall furnish, install and terminate all communication conductors and associated
conduits external to any factory supplied equipment.
B.
All communication conductor wiring and routing shall
recommendations and as shown on the contract drawings.
C.
Install Power Management Engineering Station in a secure location and connect all appropriate
communication cables.
2.2
be
per
the
manufacturer's
ADJUSTMENTS AND CLEANING
A.
2.3
Clean exposed surfaces using manufacturer recommended materials and methods.
TESTING
A.
The following standard factory procedures and tests shall be performed on the equipment
provided under this section.
1.
Configure and load all software on Power Management Engineering Station at the
manufacturer's factory.
2.
Test and operate computer and software in a simulated system mode for minimum of 24
hours.
B.
Furnish the services of a manufacturer's representative to assist the owner in starting-up and
training the system for [____days] [the number of days specified in section 3.6.F below].
The manufacturer's representative shall be factory-trained and shall have a thorough knowledge
of the software, hardware and system programming. The manufacturer's representative shall
provide the following services:
1.
Setting all the addresses of all devices in the equipment.
2.
Verifying and troubleshooting the integrity of the data lines (run by the contractor).
3.
Assisting the contractor and owner in correcting any data line problems.
4.
Coordinating any possible warranty problems.
5.
Verify the EPMS screens match the field device readings.
C.
Verify complete system operation including all hardware, software and communication devices.
D.
Verify networking performance with all interfacing systems by other manufacturers.
July 2, 2016
Power Monitoring and Control
[Project Name]
[26 09 13] [16290]-34
2.4
WARRANTY
A.
2.5
Equipment manufacturer warrants that all goods supplied are free of non-conformities in
workmanship and materials for one year from date of initial operation, but not more than
eighteen months from date of shipment.
SOFTWARE SERVICE AGREEMENT
A.
2.6
[The electrical equipment manufacturer shall include [a 1 year] [2 years] [3 years] of
Software Service Agreement which provides customer with software upgrades for the
software specified above as they are available. ]
SYSTEM START-UP AND TRAINING
A.
Project management shall be provided for the entire project through a single source of contact.
The end-user shall also provide a single source of contract with authority over the project to
make decisions on timely bases.
B.
On-Site start-up and training of the Owners personnel on the EPMS shall be included in the
project bid.
C.
Start-Up shall consist of complete configuration and in-service testing of the system, to confirm
proper operation of the EPMS.
D.
Training shall include any documentation and hands-on exercises needed by the owner’s
personnel, to assume full responsibility for the EPMS.
E.
Supplier shall have a remote fully functional training facility for advanced EPMS training
classes.
F.
The project bid shall include a minimum of:
1.
[___] trips for pre-startup review meetings.
2.
[___] days for on-site start-up services which includes installing the EPMS
software at the server location and configuring the software & metering devices.
3.
[___] days of on-site EPMS training will be provided that includes hands-on and
written material.
4.
The bid shall include [___] follow-up days for completion/modification of work as
needed.
END OF SECTION
July 2, 2016
Power Monitoring and Control
[Project Name]
[26 09 13] [16290]-35
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