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SECTION 26 09 13.11 [16295]
ADVANCED METERING WITH POWER CONTROL
Square DTM by Schneider Electric
PowerLogic ION7650 Meter Specifications
Advanced Metering with Power Quality
PART 1
GENERAL
1.1
SUMMARY
A.
1.2
Provide labor, material, equipment, related services, and supervision required, including, but not limited
to, manufacturing, fabrication, erection, and installation for advanced metering with power control as
required for the complete performance of the work, and as shown on the Drawings and as herein
specified.
REFERENCES
A.
General: The publications listed below form a part of this Specification to the extent referenced. The
publications are referred to in the text by the basic designation only. The edition/revision of the referenced
publications shall be the latest date as of the date of the Contract Documents, unless otherwise specified.
B.
American National Standards Institute (ANSI):
1.
C.
Canadian Standards Association (CSA):
1.
D.
E.
CAN/CSA C22.2 No. 1010-1, “Safety Requirements for Electrical Equipment for Measurement,
Control, and Laboratory Use - Part 1: General Requirements.”
European Standards (EN):
1.
EN 50160, “Voltage Characteristics of Electricity Supplied by Public Distribution Systems.”
2.
EN 55011, “Limits and Methods of Measurement of Radio Interference Characteristics of
Industrial, Scientific, and Medical Equipment.”
3.
EN 55022, “Information Technology Equipment - Radio Disturbance Characteristics - Limits and
Methods of Measurement.”
Federal Communications Commission (FCC):
1.
F.
ANSI C12.20, "Electricity Meters - 0.2 and 0.5 Accuracy Classes.”
FCC 47 CFR Part 15, "Radio Frequency Devices."
Institute of Electrical and Electronics Engineers, Inc. (IEEE):
1.
ANSI/IEEE C37.90.1, "Surge Withstanding Capability (SWC) Tests for Protective Relays and
Relay Systems."
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G.
Interference Causing Equipment Standard (ICES):
1.
H.
I.
ICES 003, “Information Technology Equipment (ITE) - Limits and Methods of Measurement.”
International Electrotechnical Commission (IEC):
1.
IEC 1000-3-2, “Part 3: Limits - Section 2: Limits for Harmonic Current Emissions (Equipment
Input Current ≤16 Amperes per Phase).”
2.
IEC 1000-3-3, “Part 3: Limits - Section 3: Limitation of Voltage Fluctuations and flicker in LowVoltage Supply Systems for Equipment with Rated Current ≤16 Amperes.”
3.
IEC 1000-4-2, “Electrostatic Discharge Requirements.”
4.
IEC 1000-4-3, “Radiated Electromagnetic Field Requirements.”
5.
IEC 1000-4-4, “Electrical Fast Transient (Burst) Requirements.”
6.
IEC 1000-4-5, “Surge Voltage Immunity Requirements.”
7.
IEC 1000-4-6, “Immunity to Conducted Disturbances Induced by Radio Frequency Fields above
9 kHz.”
8.
IEC 1000-4-12, “Oscillatory Waves Immunity Test.”
9.
IEC 61000-4-7, “Electromagnetic Compatibility (EMC) - Part 4-7: Testing and Measurement
Techniques; General Guide on Harmonics and Interharmonics Measurements and
Instrumentation, for Power Supply Systems and Equipment Connected Thereto.”
10.
IEC 61000-4-15, “Electromagnetic Compatibility (EMC) - Part 4-15: Testing and Measurement
Techniques; Flickermeter Functional and Design Specifications.”
11.
IEC 61000-4-30, “Electromagnetic Compatibility (EMC) - Part 4-30: Testing and Measurement
Techniques; Power Quality Measurements Methods.”
12.
IEC 61010-1, “Safety Requirements for Electrical Equipment for Measurement, Control and
Laboratory Use - Part 1: General Requirements.”
13.
IEC 61850, “Communication Networks and Systems in Substations Series.”
14.
IEC 61850-8-1, “Communication Networks and Systems for Power Utility Automation - Part 8-1:
Specific Communication Service Mapping (SCSM) - Mappings to MMS (ISO 9506-1 and ISO
9506-2) and to ISO/IEC 8802-3.”
15.
IEC 62052-11, “Electricity Metering Equipment (AC) - General Requirements, Tests and Test
Conditions - Part 11: Metering Equipment.”
16.
IEC 62053-22, “Electricity Metering Equipment (AC) - Particular Requirements - Part 22: Static
Meters for Active Energy (Classes 0,2 S and 0,5 S).”
17.
IEC 62053-23, “Electricity Metering Equipment (AC) - Particular Requirements - Part 23: Static
Meters for Reactive Energy (Classes 2 and 3).”
International Organization for Standardization (ISO):
1.
ISO 9001, "Quality Management Systems - Requirements."
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J.
Underwriters Laboratories, Inc. (UL):
1.
1.3
UL 61010B-1, “Electrical Measuring and Test Equipment; Part 1: General Requirements.”
SUBMITTALS
A.
General: Submit the following in accordance with Conditions of the Contract and Division 01 - General
Requirements.
B.
Product Data: Submit product data showing material proposed. Submit sufficient information to determine
compliance with the Drawings and Specifications.
C.
Shop Drawings: Submit shop drawings for each product and accessory required. Include information not
fully detailed in manufacturer’s standard product data.
D.
Wiring Diagrams: Submit wiring diagrams detailing power, signal, and control systems, clearly
differentiating between manufacturer-installed wiring and field-installed wiring, and between
components provided by the manufacturer and those provided by others.
E.
Operation and Maintenance Data: Submit operation and maintenance data for advanced metering with
power control to include in operation and maintenance manuals specified in Division 01 - General
Requirements.
1.4
QUALITY ASSURANCE
A.
Qualifications:
1.
Manufacturer Qualifications: Manufacturer shall be a firm engaged in the manufacture of advanced
metering with power control of types and sizes required, and whose products have been in
satisfactory use in similar service for a minimum of five years.
a.
2.
The product test and calibration process shall be part of a quality program that shall be
registered with UL to ISO 9001.
Installer Qualifications: Installer shall be a firm that shall have a minimum of five years of successful
installation experience with projects utilizing advanced metering with power control similar in type
and scope to that required for this Project and shall be approved by the manufacturer.
B.
Regulatory Requirements: Comply with applicable requirements of the laws, codes, ordinances, and
regulations of Federal, State, and local authorities having jurisdiction. Obtain necessary approvals from
such authorities.
C.
Pre-Installation Conference: Prior to commencing the installation, meet at the Project site to review the
material selections, installation procedures, and coordination with other trades. Pre-installation conference
shall include, but shall not be limited to, the Contractor, the Installer, manufacturer’s representatives, and
any trade that requires coordination with the work. Date and time of the pre-installation conference shall
be acceptable to the Owner and the Architect.
D.
Single Source Responsibility: Obtain advanced metering with power control and required accessories
from a single source with resources to produce products of consistent quality in appearance and
physical properties without delaying the work. Any materials which are not produced by the
manufacturer shall be acceptable to and approved by the manufacturer.
1.5
DELIVERY, STORAGE, AND HANDLING
A.
Deliver materials to the Project site in supplier’s or manufacturer’s original wrappings and containers,
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labeled with supplier’s or manufacturer’s name, material or product brand name, and lot number, if any.
B.
Store materials in their original, undamaged packages and containers, inside a well-ventilated area
protected from weather, moisture, soiling, extreme temperatures, and humidity.
PART 2
PRODUCTS
2.1
MANUFACTURERS
A.
2.2
The PMS instrument shall be a “PowerLogic ION7650” manufactured by Schneider Electric or
equivalent.
ADVANCED REVENUE METER WITH POWER QUALITY ANALYSIS
A.
B.
C.
General Provisions:
1.
Setup parameters required by the PMS shall be stored in nonvolatile memory and retained in the
event of a control power interruption.
2.
The PMS instrument may be applied in four-wire wye, three-wire wye, three-wire delta, direct
delta, and single-phase systems.
3.
The PMS instrument shall be fully supported by PMS software.
Markings:
1.
The PMS instrument shall be marked and comply with CE directives.
2.
The PMS instrument shall be marked and comply with the CSA:
3.
The PMS instrument shall be marked with UL.
Standards Compliance:
1.
2.
The PMS instrument shall comply to the following safety/construction standards:
a.
CAN/CSA C22.2 No. 1010-1.
b.
IEC 61010-1.
c.
IEC 62052-11.
d.
UL 61010B-1.
The PMS instrument shall comply to the following electromagnetic immunity standards:
a.
ANSI/IEEE C37.90.1 (all inputs tested, except for the network communications port).
b.
IEC 1000-3-2 (limits for harmonic currents emissions; equipment input current less than 16
amperes per phase).
c.
IEC 1000-3-3 (limitation of voltage fluctuations and flicker in low voltage supply systems for
equipment with rated current less than 16 amperes).
d.
IEC 1000-4-2 (electrostatic discharge [B]).
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3.
4.
5.
e.
IEC 1000-4-3 (radiated EM field immunity [A]).
f.
IEC 1000-4-4 (electric fast transient [B]).
g.
IEC 1000-4-5 (surge immunity [B]).
h.
IEC 1000-4-6 (conducted immunity).
i.
IEC 1000-4-12 (immunity to damped oscillatory waves).
The PMS instrument shall have a third party certification proving compliance to the following
electromagnetic emission standards:
a.
FCC 47 CFR Part 15 (Subpart B, Class A: Class A digital device, radiated emissions).
b.
EN 55011 (radiated/conducted emissions, Group 1, Class A).
c.
EN 55022 (radiated/conducted emissions, Class A).
d.
ICES 003 (industry Canada, ICES Class A digital device, radiated/conducted emissions).
The PMS instrument shall comply to the following measurement standards with third party
compliance certification:
a.
IEC 61000-4-7 (interharmonics).
b.
IEC 61000-4-15 (flicker, accurate to PST of 20).
c.
IEC 61000-4-30 (Class A Edition 2).
The PMS instrument shall have a third party compliance certification to the following
communications standards:
a.
D.
E.
IEC 61850-8-1 (Edition 1).
Current/Voltage Inputs:
1.
The PMS instrument shall have no less then four voltage inputs and five current inputs.
2.
The PMS instrument in its standard configuration shall be able to accept 600 volts AC LL / 347
volts AC LN without using potential transformers.
3.
The PMS instrument shall be able to withstand 1500 volts AC RMS continuously without
damaging the device.
4.
The PMS instrument shall support nominal current ratings of 1 ampere, 2 amperes, 5 amperes,
10 amperes, or 20 amperes and an overcurrent rating of 500 amperes for 1 second (5 amperes
nominal model) or 200 amperes for 1 second (1 ampere nominal model).
Measured Values:
1.
The PMS instrument shall provide at a minimum the following voltage values:
a.
Voltage L–L per-phase.
b.
Voltage L-L three-phase average.
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2.
3.
4.
c.
Voltage L–N per-phase.
d.
Voltage three-phase average.
e.
Voltage percent unbalanced.
The PMS instrument shall provide at a minimum the following current values:
a.
Current per phase.
b.
Current neutral (measured).
c.
Current three-phase average.
d.
Current percent Unbalanced.
The PMS instrument shall provide at a minimum the following power values:
a.
Real power (per phase, three-phase total).
b.
Reactive power (per phase, three-phase total).
c.
Apparent power (per phase, three-phase total).
d.
Power factor - true (per phase, three-phase total).
e.
Power factor - displacement (per phase, three-phase total).
The PMS instrument shall provide at a minimum the following energy values:
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.
5.
The PMS instrument shall be able to provide a minimum/maximum value for any measured
parameter.
6.
The PMS instrument shall be capable of deriving values for any combination of measured or
calculated parameter, using the following arithmetic, trigonometric, and logic functions (or
equivalent PLC capabilities):
a.
Arithmetic functions; division, multiplication, addition, subtraction, power, absolute value,
square root, average, maximum, minimum, 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.
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F.
G.
H.
I.
Demand:
1.
The PMS instrument shall be able to provide minimum/maximum demand, present demand
interval, running average demand, and predicted demand on multiple demand channels.
2.
The PMS instrument shall be able to perform multiple accepted demand calculation methods,
including, but not limited to, block, rolling block, and thermal demand with user-programmable
demand period lengths.
Accuracy:
1.
The PMS instrument shall meet ANSI C12.20 accuracy Class 0.2.
2.
The PMS instrument shall meet IEC 62053-22.
3.
The PMS instrument shall meet IEC 62053-23.
4.
The PMS instrument shall provide four-quadrant metering.
Sampling:
1.
The PMS instrument shall sample at 1024 OR 512 samples per cycle.
2.
The PMS Instrument shall be able to perform high speed sag/swell detection of voltage
disturbances on a cycle-by-cycle basis, providing the duration of the disturbance, the minimum,
maximum, and average value of the voltage for each phase during the disturbance. Disturbances
less than one cycle in duration can be detected.
Logging:
1.
The PMS instrument shall have at least 5 MB of user-programmable onboard data logging.
2.
The PMS instrument shall store critical internal and revenue data upon sudden power loss.
3.
The PMS instrument shall have non-volatile memory.
4.
The PMS instrument shall have a time-stamped event log with the following features:
a.
Shall support at least 500 events.
b.
The number of records in the log shall be programmable.
c.
Each event shall be recorded with the date and time of the event, the cause and effect of
the event, and the priority of the event.
d.
Events relating to setpoint activity, relay operation, and self-diagnostics shall be recorded in
the event log.
e.
Time stamps shall have a resolution of 1 millisecond.
f.
Time stamps can be synchronized to within 100 ms between devices on the same serial
communications medium.
g.
Minimum event recording response time shall be 1/2 cycle (8.3 ms 60 hertz, 10 ms 50
hertz) for high speed events and 1 second for other events.
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h.
5.
J.
The PMS instrument shall be able to log any parameter in the meter, including, but not limited to,
minimum/maximum and waveforms.
Alarming:
1.
The PMS instrument shall have setpoint driven alarming capability.
2.
The PMS instrument shall be able to generate an email on an alarm condition.
3.
The PMS instrument shall have millisecond time stamp resolution on alarm entries.
4.
The PMS instrument shall be able to readjust alarm setpoints based on the alarm quantity (alarm
setpoint learning).
a.
The user shall be able to enable the PMS instrument to learn the characteristics of normal
operation of metered values and select alarm setpoints based on this data.
b.
The quantities to be learned shall be user selectable, including, but not limited to, standard
speed and high speed analog alarms, disturbance alarms, and voltage transient alarms.
c.
The user shall be able to configure this feature using one of two modes:
d.
K.
The priority of setpoint events shall be programmable.
1)
Manual: Once the learning is completed, the recommended values shall be stored for
review and manual installation.
2)
Automatic: Once the learning is completed, the recommended values shall be
automatically installed and operational.
The learning period shall be user configurable from 1 to 365 days to ensure system stability
prior to determining the recommended setpoints.
5.
The PMS instrument shall support consecutive high speed alarm conditions which shall trigger on
a cycle-by-cycle basis with no dead time between events (i.e., no need for a rearming delay time
between events)..
6.
The PMS instrument shall be able to operate relays on alarm conditions.
7.
The PMS instrument shall be able to initiate datalog captures on alarm conditions.
8.
The PMS instrument shall be able to control digital output relays in an AND or an OR
configuration, using pulse mode or latch mode operation, for control and alarm purposes.
9.
The PMS instrument shall be able to combine any logical combination of any number of available
setpoint conditions to control any internal or external function or event.
Communications:
1.
The PMS instrument shall be capable of the following communications methods simultaneously
and independently:
a.
Ethernet over fiber or copper media.
b.
Serial.
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c.
1)
RS-232.
2)
RS-485.
Serial.
1)
2.
RS-485.
d.
Modem.
e.
I/R.
The PMS instrument shall support any one of the following communications protocols on any one
port at any one time:
a.
ION.
b.
Ethergate.
c.
Modemgate.
d.
DNP 3.0.
e.
Modbus:
1)
Modbus RTU.
2)
Modbus TCP.
3)
Modbus mastering of Serial RS-485 slaves.
f.
SMTP.
g.
SNTP.
h.
MV-90 compatibility.
i.
XML compatibility.
j.
HTTP (web pages).
3.
The PMS instrument shall support GPS time synchronization.
4.
The PMS instrument shall be able to support at least 32 concurrent Modbus TCP connections.
5.
The PMS instrument shall have a Modbus TCP gateway for reading Modbus serial devices
connected to a serial port on the instrument.
6.
The PMS instruments that are equipped with an Ethernet port shall be internet enabled and shall
support the following functions:
a.
Automatically email alarm notifications or scheduled system status updates. Email
messages sent by the PMS instruments shall be able to be received like any ordinary email
message. Data logs shall also be able to be sent on an event-driven or scheduled basis.
b.
Built in web pages in the PMS instruments shall enable access to real-time values and
basic power quality information using a standard web browser. Basic configuration of the
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PMS instruments shall also be able to be performed through the browser.
c.
Integration with custom reporting, spreadsheet, database, and other applications with XML
compatible data.
d.
IEC 61850 compliance with the following features:
1)
Four concurrent client connections.
2)
File based setup via FTP.
3)
Network time sync via SNTP.
4)
Configurable reports, including, but not limited to, selectable dataset member and
configurable deadband values.
5)
Support four buffered reports and 20 unbuffered reports (one buffered and five
unbuffered per client).
6)
Map up to 16 analog and/or 16 digital calculated values for reporting in IEC 61850.
7)
Fault capture data for three-phase voltage and current channels in COMTRADE
format, including, but not limited to, the following:
8)
L.
a)
At least 1 Mb of storage for fault capture files.
b)
The files shall be downloadable via standard ftp client.
c)
The device shall support client notification through IEC 61850 to signal when
new fault captures have been created and are available (RDRE logical node).
The following logical nodes shall be supported in addition to LLNO and LPHD
(mandatory):
a)
MHAI; harmonics.
b)
MMTR; metering.
c)
MMXU; measurement.
d)
MSQI; sequence and imbalance.
e)
MSTA; metering statistics.
f)
GGIO; the ability to view data from and control all I/O points in the meter.
g)
RDRE; disturbance recorder function.
I/O Options:
1.
The PMS instrument shall be capable of having 16 digital inputs capable of 1/2 cycle timing
resolution.
2.
The PMS instrument shall have digital outputs that 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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M.
3.
The PMS instrument shall have three Form C relays which shall be isolated for up to 5000 volts
AC for 1 minute and 10 amperes continuous for 30 volts DC and up to 240 volts AC.
4.
The PMS instrument shall be able to have four Form A analog inputs which shall be optically
isolated.
5.
The PMS instrument shall be able to have four analog outputs with a 0 mA to 20 mA range.
Display:
1.
The PMS instrument shall have two display options: an integral display and a remote mounted
display.
a.
The integral display shall be a 320 x 240 pixel backlit LCD display, 3.43 inches (87 mm) by
4.41 inches (112 mm).
b.
The remotely mounted display shall be a 320 x 240 pixel backlit color LCD display, TFT,
5.7 inch (145 mm) screen (3.4 inches [86 mm] by .4.5 inches [115 mm]).
c.
The remote display shall be capable of communicating with the PMS instrument via RS485 or Ethernet.
d.
The displays shall be suitable for NEMA 12 (IP 52) enclosures.
2.
The PMS instrument shall support direct display of all parameters on the front panel.
3.
The PMS instrument shall provide a trend display of any parameter internally recorded at regular
intervals.
4.
The PMS instrument shall have a user-programmable custom display that shall be capable of
displaying up to 20 quantities on a single screen.
5.
The PMS instrument shall be able to display advanced graphical representations of metering
information, including, but not limited to, spectral components, phasor diagrams, and trending
charts.
6.
The PMS instrument shall be able to display measurements in either IEC or IEEE formats.
7.
The PMS instrument display shall support multiple languages, including, but not limited to,
English, Spanish, and French.
8.
The PMS instrument shall be able to display the following front panel screens:
a.
Numeric: Display 2, 3, 3 with timestamp, 4, 8, 10 or 20 parameters at a time.
b.
Event Log: Display recent events written to the PMS instrument’s event log, including, but
not limited to, diagnostic events.
c.
Nameplate: Display information in a tabular format (default nameplates shall show Owner,
meter, and power system details).
d.
Trend Bar: Display up to four real time numeric parameters along with their upper and
lower extremes.
e.
Histogram: Display harmonics content in histogram format, including, but not limited to, 2nd
to 63rd harmonic, THD (total, even, odd); current harmonics histogram screens display K
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factor and crest factor.
f.
N.
O.
Phasor: Display phase information in phasor diagram format, including, but not limited to,
phase, voltage and current magnitudes; phasors that are too small in magnitude shall be
shown as table entries only.
Field Programmability: The PMS instrument shall be field programmable as follows:
1.
Provide voltage input scale, voltage mode (wye, delta, single-phase), current input scale, auxiliary
input and output scales, and communications setup parameters that shall be programmable from
the front panel.
2.
Basic parameters described above, plus additional setpoint/relay and data log setup parameters
may be programmed via the communications port using a portable or remotely located computer
terminal.
3.
Custom configuration of operating parameters shall be possible through a graphical, flexible
programming language.
4.
The configuration of the device shall be done using programmable modules. The modules shall
be linked together in an arbitrary manner to create arbitrary functionality. Some example module
types include, but shall not be limited to, minimum, maximum, setpoint, digital input, and digital
output.
5.
Programming through a computer shall be secured by user ID and password.
6.
Programming through the front panel shall be secured by password.
7.
Programmability shall be sectioned such that when the meter is sealed it shall still be configurable
to an extent that does not affect the accumulation of revenue metering related data.
Power Quality:
1.
Without the use of separate software, the PMS instrument shall be able to evaluate power quality
statistically in accordance with IEC 61000-4-30 Class A Edition 2
2.
The PMS instrument shall be certified by a third party as compliant with IEC 61000-4-30 Class A,
Edition 2.
3.
Without using separate software, the PMS instrument shall determine statistical indicators of
power quality parameters that shall include, but shall not be limited to, flicker, dips and swells,
harmonics, and interharmonics, in accordance with the EN 50160 standards.
4.
Without the use of separate software, the PMS instrument shall 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, IEC 61850), or via an analog transducer
interface.
5.
Without the use of separate software, the PMS instrument shall monitor the value of any
statistical indicator of power quality (present, predicted, average, or otherwise manipulated value)
with an absolute or relative setpoint. When such setpoint is exceeded, an alert shall be issues via
email or pager, or control shall be enabled via a local interface to mitigation equipment or control
systems through relays and analog or digital outputs.
6.
The PMS instrument shall support symmetrical components.
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P.
Q.
Transients:
1.
The PMS instrument shall provide sub-cycle transient detection at 1024 or 512 samples per
cycle.
2.
The PMS instrument shall be able to perform 17 microsecond transient captures at 60 hertz or 20
microsecond transient captures at 50 hertz.
Waveform Capture:
1.
The PMS instrument shall be able to perform 1024 or 512 samples per cycle waveform capture
recording.
2.
The PMS instrument shall have nine programmable oscillographic waveform recorders. Each
waveform recorder shall have the following features:
3.
R.
a.
Able to record a digitized representation of any phase voltage or current signal with no
dead time between such recordings, and the ability to trigger multiple such recordings in
continuous succession, and at different resolutions simultaneously.
b.
Enabled and triggered manually or through internal operating conditions, including, but not
limited to, periodic timer or setpoint activity.
c.
High speed triggering shall be supported.
d.
The number of records (depth) of each data recorder, and the overflow conditions (stopwhen-full or circular) shall be programmable.
The PMS instrument shall be able to record continuously to capture long duration waveforms.
The duration of the waveform capture shall be limited by memory alone.
Advanced Features:
1.
The PMS instrument firmware shall be field upgradeable.
2.
Onboard meter clock shall be able to be paced by a choice of sources, including, but not limited
to, GPS, power line, or internal clock.
3.
The PMS Instrument shall have multi-level security which shall support customized access for up
to 16 users.
4.
The PMS instrument shall have revenue security capabilities, including, but not limited to, the
following:
a.
Password protected, no hardware lock, or
b.
Password protected and hardware locked, or
c.
The following data shall be protected from alteration when locked:
1)
kWh and kVARh (import, export, net, and total).
2)
kVAh (total).
3)
kW, kVAR, kVA demand (thermal and sliding window).
Section [26 09 13.11] [16295]
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4)
5.
The PMS instrument shall have provisions for conformal coating of its internal circuitry for
installations exposed to high degrees of humidity (tropicalization treatment).
6.
The PMS instrument shall have provisions for creating periodic or non-periodic schedules for up
to two years. These schedules shall be used to perform the following functions:
a.
Time of use (TOU).
b.
Demand control.
c.
Load scheduling.
d.
Logging.
e.
Periodic resetting.
f.
Alarm gating.
7.
The PMS instrument shall have multiple tariffs and 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.
8.
The PMS instrument shall be able to determine (with a level of confidence) whether a disturbance
event occurred upstream or downstream of the meter (disturbance direction detection).
9.
The PMS instrument shall support three languages without having to upgrade its firmware.
10.
The PMS instrument shall support trending and forecasting of logged data values feature both on
the meter display and via the web pages.
PART 3
EXECUTION
3.1
EXAMINATION
A.
Verification of Conditions: Examine areas and conditions under which the work is to be installed, and
notify the Contractor in writing, with a copy to the Owner and the Architect, of any conditions detrimental
to the proper and timely completion of the work. Do not proceed with the work until unsatisfactory
conditions have been corrected.
1.
3.2
kWh, kVARh, kVAh pulse outputs.
Beginning of the work shall indicate acceptance of the areas and conditions as satisfactory by the
Installer.
INSTALLATION
A.
3.3
Install advanced metering with power control in accordance with reviewed product data, final shop
drawings, manufacturer’s written instructions and recommendations, and as indicated on the Drawings.
DEMONSTRATION
A.
Provide the services of a factory-authorized service representative of the manufacturer to provide start-up
service and to demonstrate and train the Owner’s personnel.
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3.4
1.
Test and adjust controls and safeties. Replace damaged or malfunctioning controls and equipment.
2.
Train the Owner’s maintenance personnel on procedures and schedules related to start-up and
shutdown, troubleshooting, servicing, and preventive maintenance.
3.
Review data in operation and maintenance manuals with the Owner’s personnel.
4.
Schedule training with the Owner, through the Architect, with at least seven day’s advanced notice.
PROTECTION
A.
Provide final protection and maintain conditions in a manner acceptable to the Installer, that shall
ensure that the advanced metering with power control shall be without damage at time of Substantial
Completion.
END OF SECTION
Section [26 09 13.11] [16295]
Advanced Metering with Power Control
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