Download section 16290 - Rockwell Automation

SECTION 16290
POWER MEASUREMENT AND CONTROL
PART 1 GENERAL
1.01
1.02
SUMMARY
A.
This section describes the requirements for the design, configuration, programming,
testing, installation and commissioning of a Power & Energy Management System
(PEMS). The PEMS shall interface with new and existing electrical apparatus in the
owners distribution system. The system shall monitor and display the state of electrical
apparatus such as circuit breakers, automatic transfer switches, generators, etc. The
system shall alarm on abnormal electrical system conditions and provide real-time display
and logging of electrical parameters on selected circuits. The system shall also provide
the control functionality described below.
B.
This specification along with the attached I/O list, power monitor list, one-line diagram and
site drawings provides the basis for the supply of a complete and fully functional Power &
Energy Management System.
SECTION INCLUDES
A.
Power monitoring devices
B.
Programmable logic controllers, including:
1. Processors
2. Chassis
3. Power supplies
4. I/O devices
5. Communication networks
C.
Control enclosures, including
1. Equipment mounting requirements
2. Wiring requirements
3. Grounding requirements
4. Labeling requirements
NOTICE: The specification guidelines shown in this document are intended to aid in the specification
of products. Specific installations have specific requirements, and Rockwell Automation does not
recommend or intend any specific application based solely upon the guidelines provided here.
Because of the variety of uses for this information, the user of, and those responsible for applying this
information, are responsible for ensuring the acceptability of each application and appropriate use of
the guidelines. In no event will Rockwell Automation be liable for misuse, misapplication or reliance
on these guidelines in connection with any specific application. Rockwell Automation also disclaims
indirect or consequential damages resulting from the use or application of this information.
POWER MEASUREMENT AND CONTROL
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D.
Personal computers, including:
1. PC Hardware
2. Operating system software
3. PLC programming software
4. HMI software
5. Communications hardware and software
E.
System engineering services, including:
1. Preparation and development of system functional specifications
2. PLC and HMI configuration (programming)
3. Hardware and communications network design and assembly
4. Factory and on-site testing services
5. Installation supervision (optional)
6. Start up services
7. Documentation
8. Training
F.
System functional requirements, including:
1. Definition of field I/O points
2. Definition of alarms
3. Description and total scope of operational system functionality
PRODUCTS SUPPLIED BUT NOT INSTALLED UNDER THIS SECTION
A.
Power monitoring devices
B.
Control enclosures, housing:
1. PLC’s
2. I/O
3. Related support equipment
C.
Personal computers
PRODUCTS INSTALLED BUT NOT SUPPLIED UNDER THIS SECTION
A.
Electrical apparatus including, but not limited to:
1. Switchgear
2. Generators
3. Automatic transfer switches
4. Uninterruptible power supplies
B.
Current transformers
C.
Potential transformers
D.
Uninterruptible power supplies
E.
Communications networks such as:
1. Ethernet
2. ControlNet
3. Data Highway Plus
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Remote I/O
DeviceNet
DNP 3.0
Modbus
RELATED SECTIONS
A.
Section 01600 – Owner-Furnished Products
B.
Section 13410 – Basic Measurement and Control Instrumentation Materials and Methods
C.
Section 13430 – Boxes, Panels, and Control Centers
D.
Section 13450 – Central Control
E.
Section 13480 – Instrument List and Reports
F.
Section 13800 – Building Automation and Control
G.
Section 15900 – HVAC Instrumentation and Controls
H.
Section 16050 – Basic Electrical Materials and Methods
I.
Section 16230 – Generator Assemblies
J.
Section 16260 – Uninterruptible Power Supplies
K.
Section 16270 - Transformers
L.
Section 16280 – Power Filters and Conditioners
M.
Section 16320 – High Voltage Switching and Protection
N.
Section 16330 – Medium Voltage Switching and Protection
O.
Section 16430 – Low-Voltage Switchgear
P.
Section 16480 – Motor Control Centers
REFERENCES
A.
National Electrical Manufacturers Association (NEMA)
1. IA 2.1/IEC 1131, Part 1 Programmable Controllers - General Information
2. IA 2.2/IEC 1131, Part 2 Programmable Controllers - Equipment Requirements and
Tests
3. ICS 1 Industrial Control and Systems: General Requirements
4. ICS 6 Industrial Control and Systems: Enclosures
5. 250, Enclosures for Electrical Equipment (1000 Volts Maximum)
6. EI 21.1 Instrument Transformers for Revenue Metering (110 kV BIL and less)
7. EI 21.2 Instrument Transformers for Revenue Metering (125 kV BIL through 350 kV
BIL)
B.
Institute of Electrical and Electronic Engineers (IEEE)
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518 IEEE Guide for the Installation of Electrical Equipment to Minimize Noise Inputs
to Controllers from External Sources
C12.11 Instrument Transformers for Revenue Metering, 10kV BIL through 350kV BIL
(0.6kV NSV through 69kV NSV)
C.
National Fire Protection Association (NFPA)
1. 70, National Electrical Code (NEC)
D.
National Electrical Contractors Association
1. National Electrical Installation Standards (NEIS)
E.
Society of Automotive Engineers
1. SAE HS-1738, Electrical Standard for Industrial Machinery
1.07
DEFINITIONS
A.
Owner - The party purchasing the power management system for use in his facility.
Additionally, the owner is responsible for hiring the installing contractor.
B.
Owner’s engineer – The party, hired by the owner, to specify the purchase and installation
of a power management system.
C.
System integrator - The party responsible for providing the hardware, software and
engineering services required to provide a fully operational power management system.
D.
Installing contractor - The party, hired by the owner, responsible for installation, wiring and
other work specified herein not supplied by the system integrator.
E.
PC – Personal Computer
F.
HMI – Human Machine Interface. Usually refers to the personal computer running
dedicated software, which allows a user to view the status, alarms and parametric trends
of the electrical distribution system.
G.
PLC – Programmable Logic Controller
H.
PM – Power monitor
I.
PEMS - Power & Energy Management System
J.
CT – Current Transformer
K.
PT – Potential Transformer
L.
RTU – Remote Terminal Unit
M.
SCADA – Supervisory Control and Data Acquisition
N.
WYSIWYG – What You See Is What You Get
O.
PWM – Pulse Width Modulated
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SYSTEM DESCRIPTION
A.
The fully configured system shall consist of digital power monitors, programmable logic
controllers, Pentium-based personal computers, MS Windows-based HMI and PLC
programming software, and appropriate communication networks. The system must be
fully engineered, programmed, assembled and tested to provide the functionality described
below.
B.
The Power & Energy Management System must provide the following basic functionality:
1. Power monitoring - Includes the acquisition, display, logging and reporting of real-time
electrical system status and parameter values. This information is useful for:
Improved day-to-day operation of the electrical system, quicker system recovery in
the event of partial or total electrical system outage, and providing valuable historical
views of load profiles and harmonic and voltage trends which can be used in future
electrical system design and purchase decisions in a deregulated utility environment.
Additionally, power-monitoring functionality may be expanded to include remote
control of breakers, switches, and load controlling equipment as appropriate.
2. Cost Allocation & Load profiling - Includes the careful synchronization and recording
of power consumed by various loads or cost centers within the facility so that
electrical and other utility costs can be fairly and accurately charged to the appropriate
departments by the percentage used versus the accumulative total. The reports
provided with the cost allocation functionality shall allow the owner to verify its utility
bills.
3. Demand management - Includes proactive control on the part of the PLC to limit the
plant kW demand to a user-defined value. The PEMS adds and sheds loads based
on available capacity, both utility and Co-Generated, with the objective of controlling
electrical costs to target levels.
4. Emergency load shedding - Includes shedding and balancing of plant loads at very
high speeds to preserve limited plant operation when generators, operating in parallel
with the utility or other generators, are abruptly overloaded either by the loss of the
utility feed, the failure of a transformer, or the loss of other generators within the
facility.
5. Voltage and VAR control - Includes active control on the part of the PLC to operate
capacitor banks, voltage regulators and load tap changers on transformers to
optimize power factor and the voltage profile within the electrical distribution system.
C.
Power monitoring locations:
1. Power monitors shall be installed at the following locations. See the attached power
monitor list and system one-line diagram for a complete list of all power monitors to
be supplied with this system.
a. Utility main breaker(s)
b. Main breaker on all buses, switchgear and switchboards
c. All generators
d. Large harmonic producing loads to be outlined by IEEE 5.19 guidelines and
reviewed by the engineer.
2. Instrument transformers used in connecting the power monitors to the monitored
circuits should be of metering class.
D.
The Power & Energy Management System shall display status information, alarm
conditions and provide control of typical power distribution equipment. Refer to the
attached I/O list for the exact points included in this system. Typical status, alarm and
control points are shown below for the generic types of equipment listed.
1. Circuit breakers
a. Open/Closed/Tripped status
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b. Truck position status
c. Trip status (alarm)
d. Lockout Status
e. Open command (PLC output for breakers capable of remote control)
f.
Close command (PLC output for breakers capable of remote control)
Automatic transfer switches
a. Normal power available status (alarm on loss of normal power)
b. Emergency power available status
c. Switch in normal position status
d. Switch in neutral position status
e. Switch in emergency position status
f.
Switch bypassed to normal position status
g. Switch bypassed to emergency position status
h. Truck position status
Disconnect and sectionalizing switches
a. Open/closed status
b. Kirk key locations
Transformers
a. High oil temperature status (alarm)
b. High oil pressure status (alarm)
c. Fans running status
d. Fans on command (PLC output for transformers with fans)
e. Tap position (analog or series of discrete inputs)
f.
Tap raise command (PLC output for transformers with Load Tap Changer)
g. Tap lower command (PLC output for transformers with Load Tap Changer)
Generators
a. Fail to synchronize (alarm)
b. Overload (alarm)
c. Reverse Power (alarm)
d. Over voltage (alarm)
e. Under voltage (alarm)
f.
Over-frequency (alarm)
g. Under-frequency (alarm)
h. Field temperature (alarm)
i.
Excitation limit (alarm)
j.
Exciter control output
Diesel engines
a. Engine running
b. Engine start signal received
c. Engine not in auto (alarm)
d. Engine locked out (alarm)
e. Engine over-speed (alarm)
f.
Engine over-crank (alarm)
g. Battery charger, AC voltage failure (alarm)
h. Low battery voltage (alarm)
i.
High battery voltage (alarm)
j.
Low fuel level (85%) warning (alarm)
k. Low fuel level (50%) warning (alarm)
l.
Critical low fuel shutdown (alarm)
m. Low oil pressure (alarm)
n. Low coolant temp warning (alarm)
o. High coolant temp warning (alarm)
p. High coolant temp shutdown (alarm)
q. Low water level warning (alarm)
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r.
System under speed/voltage test
s. Start signal output
t.
Governor speed control output
7. Steam turbines
a. Inlet steam pressure (alarm)
b. Outlet steam pressure (alarm)
c. Inlet steam temperature (alarm)
d. Outlet steam temperature (alarm)
e. Oil pressure, before filters (alarm)
f.
Oil pressure, after filters (alarm)
g. Bearing oil temperature (alarm)
h. Turbine over speed (alarm)
i.
Oil pump power available (alarm)
j.
Speed control, auto/manual (alarm)
k. Low oil pressure switch (alarm)
l.
High vibration shutdown (alarm)
m. Tripped (alarm)
n. Governor safety trip (alarm)
o. Governor speed control output (either analog output or PWM pulses)
p. Oil pump start/stop output
q. Trip solenoid valve output
r.
Oil heater on/off output
8. Uninterruptible power supplies
a. Normal status
b. Manually bypassed status (alarm)
c. Load connected to bypass source status (alarm)
d. Load connected to UPS status
e. Shutdown status (alarm)
f.
On battery power status (alarm)
9. Motor starters
a. Motor running status
b. Motor tripped status (alarm)
c. On/Off control output
10. Lighting contactors
a. On/off status
b. On command (PLC output for system control of lighting)
c. Off command (PLC output for system control of lighting)
1.09
PERFORMANCE REQUIREMENTS
A.
Power monitoring
1. The system shall allow the operator to monitor, trend, log, and generate reports on
typical power parameters from one or more personal computer HMI workstations.
Typical power parameters include:
a. Line current on phases A, B, C and neutral
b. Line-to-line voltages on phases A, B and C
c. Line-to-neutral voltages on phases A, B and C
d. Average 3-phase KW
e. Average 3-phase KVAR
f.
Average 3-phase KVA
g. Average 3-phase power factor
h. Average 3-phase line frequency
j.
Average 3-phase voltage % THD on phases A, B and C
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The system shall produce alarm messages based on pre-defined electrical system
I/O status points or conditions.
Where appropriate, the system shall allow a user to remotely control electrical
apparatus. See the attached I/O list for control output points.
B.
Cost allocation
1. The system shall synchronize all recorded measurement with the utility provided end
of interval pulse (EOI). If the EOI pulse is not available the system shall produce an
internal EOI pulse based on the time of day. The internally generated EOI pulse shall
have a user configurable demand period length of 1, 2, 3, 4, 5, 6, 10, 12, 15, 20, 30 or
60 minutes.
2. The system shall accept measurement data from the following types of devices:
a. Power monitors
b. Transducers
c. Pulse generating meters
d. Internally calculated “constant load devices”
3. The system shall record the following parameters for each measurement point for
each demand interval:
a. KWh consumed by the load in the demand interval.
b. KVARH consumed by the load in the demand interval.
c. Average kW demand over the demand interval.
4. The system shall record all measurements in a Microsoft Access or SQL Server
format.
5. The system shall provide reports on demand with user supplied beginning and ending
times. The following reports shall be supplied with the system:
a. Monthly utility bill verification report
b. Monthly consumption summary report
c. Monthly cost allocation summary report
d. Monthly demand summary report
e. Monthly cost center detailed billing report
f.
Daily load report
6. The system shall be easily extensible to include synchronized measurements of other
utilities such as natural gas, water, steam, etc.
C.
Demand Management
1. The system shall automatically perform demand management, tripping individual
breakers and motor starters to maintain total facility load below a specified limit. The
system shall allow the operator to select which loads are available for shedding and
select those loads that must remain enabled.
2. The system shall provide a screen where an operator can assign a priority to every
load in the system thereby determining its order in the load shed and load addition
sequences.
3. The system shall dynamically calculate the projected demand based on a rolling
average of once-per-minute kW readings.
4. The system shall proactively shed the minimal amount of load necessary to keep the
projected and actual plant demand below the user-definable set point.
5. When spare capacity exists, the system shall automatically add as many loads as
possible while still maintaining plant demand below the user-definable set point.
D.
Emergency load shedding
1. The system shall automatically perform emergency load shedding upon loss of
source power. The system shall allow the operator to select which loads are available
for shedding and which loads must remain active.
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The system shall “pre-calculate” which loads should be shed in the event of a loss of
utility. Calculations will be based on historical data of the device loads. Actual load
shedding will occur in response to a discrete shed input, provided from the owner’s
switchgear.
The system shall provide a screen where an operator can assign a load to a “shedblock”. Every load shall be given a priority within the shed-block. The screen shall
also allow an operator to assign priorities to the shed-blocks. The screen shall
provide the ability to individually choose whether a load and/or block can participate in
the emergency load shed sequence.
The system shall provide a “projected action” screen, which shows the operators
which loads would be shed if a shed event occurred.
The system shall be designed to have a total reaction time of “X” milliseconds, which
preserves system stability.
Voltage and VAR control
1. The system shall control switched capacitor banks to regulate VAR’s from the utility to
within a dead-band equal to 33% of the smallest capacitor step-size leading and 66%
of the smallest capacitor step-size lagging.
2. The system shall enforce an interlock that prevents reconnecting a capacitor step to
the electrical system until it has had a minimum of 5 minutes to discharge.
3. Load tap changer and voltage regulator tap raise and lower signals generated by the
system shall be coordinated with capacitor bank switching actions to minimize voltage
swings on the electrical system.
4. The system shall provide the following user adjustable voltage control parameters:
a. Voltage level (100V-135V in 0.1V increments)
b. Dead band (0.5V-6V in 0.1V increments)
c. Time delay (3sec - 200sec in 1 sec increments)
d. Voltage limits (96V-144V in 0.1V increments)
e. Tap position limits (-16 to 16)
5. The system shall provide the following operator control operations
a. Automatic/Off/Manual - controlling operation of the LTC and VAR controls.
b. Raise/Lower - this allows the operator to manually raise or lower the LTC.
6. The system shall provide the following operational functions:
a. Two modes of operation
1) Standard sequential operation - unit pauses after each step operation to
assess need for another tap change operation.
2) Non-sequential operation - unit averages voltage and determines number of
steps required to achieve desired voltage. Once time delay is finished, the
unit moves the calculated number of steps without an intentional time delay.
The delay timer must be set to greater than 30 seconds for this mode to
function correctly.
b. Voltage and tap position limiting with automatic runback
c. Tap position tracking - Utilizing a tap position transducer such as a Selsyn,
discrete inputs or by tracking position with internal up/down movement registers.
d. Two operations counters - One software counter tracks all operations. A second
software counter is user reset table for tracking number of operations since last
reset.
e. Transformer paralleling utilizing a modified circulating current method.
f.
Operator notification of events, alarms and set-point violations:
1) Out-of-band raise
2) Out-of-band lower
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3)
4)
Voltage out of band
VAR’s out of band
F.
Time synchronization
1. The PEMS shall be designed such that the master HMI station and power monitor
clocks are automatically synchronized to the PLC clock once per day to ensure close
agreement of event time-stamps.
2. Time synchronization differences between the HMI, PLC, and power monitor shall be
within +/- 5 seconds.
3. The PEMS shall allow a user at the HMI station to manually invoke a time
synchronization operation.
G.
Diagnostics and maintenance
1. The system shall automatically produce alarms when fault conditions are detected
within the PLC, communications network or remote field I/O devices.
2. The system shall have the capability of being programmed on-line. It shall not be
necessary to shutdown the system during programming operations.
H.
System I/O capacity:
1. The system shall by suitably sized to accommodate all I/O points shown in the
attached I/O list including 15% pre-wired, spare inputs and outputs.
2. The system shall by suitably sized to accommodate all power monitors shown in the
attached PM list.
3. The system shall be capable of accommodating 100% future I/O growth and 50%
power monitor growth without additional PLC programming.
I.
HMI screens
1. All HMI related software, including runtime and configuration packages, necessary for
the owner to operate, program, configure and maintain the PEMS HMI screens after
system integrator has completed the work specified in this section shall be provided.
2. The PEMS shall be fully configured to include all screens necessary to display, alarm,
log and control the electrical distribution system in an intuitive, easy-to-use format to
be approved by the engineer prior to implementation.
3. HMI screen navigation shall be designed in a detail oriented hierarchical fashion such
that high-level, low-detail overview screens appear at the top and lower level screens
reveal more component detail as a user “drills down” into the hierarchy of screens.
4. The screens shall be dynamic, such that real-time device status and electrical
parameter values drive screen animation. Refer to the attached I/O and power
monitor lists for an exact accounting of those status points.
5. The screens shall display the status and alarm conditions for selected electrical
system devices. Likewise, the screens shall display selected real-time parameters
derived from the power monitors and power information devices. Refer to the
attached I/O and power monitor lists for an exact accounting of those status points.
6. Access to system screens shall be limited by the security provided by the HMI
software package which shall tie in to the Microsoft Operating System Security
Technology. The system integrator shall provide the following levels of security,
shown from lowest to highest as a minimum, for the PEMS (Note that each level
should have all of the rights and privileges of all security levels below that level):
1) User - View system status and alarms (lowest access rights).
2) Operator - Control electrical system devices.
3) Supervisor - Modify system parameters and settings.
4) PEMS administrator - Programming and configuration of HMI software
(highest access rights).
7. The system shall include at a minimum, the following screen displays:
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a.
b.
c.
d.
e.
f.
g.
h.
J.
1.10
Initial System Startup and Security Logon, menu screen.
One-line diagram(s) - system integrator shall provide as many screens as
necessary to display the owner’s one-line diagram in a clear, intuitive and
uncluttered fashion.
Power monitor pop-up displays - pop-up windows showing the real-time
parameters from selected power monitors and power related devices.
System health screen - showing the health of the PLC’s and communication
networks. This screen should closely align with the system physical architecture
drawing.
Breaker status and control pop-up screen - a pop-up window that displays
detailed breaker status. It shall also allow an operator to select and open or
close a breaker when remotely controllable breakers are within the scope of the
PEMS and the operator has the appropriate security logon required. Refer to the
attached I/O list for an exact accounting of those status points.
Alarm summary screen showing all active, active and acknowledged, inactive
and unacknowledged alarms. Refer to the attached I/O list for an exact
accounting of those status points.
Trend display(s) showing the following real-time and historical values, which are
logged once every 15 minutes (user configurable), from each power monitor:
1) Total 3-phase kW
2) Total 3-phase KVAR
3) Total 3-phase KVA
4) Average 3-phase power factor
5) Average 3-phase %THD, voltage
6) Average 3-phase Line-to-line voltage
All other screens required to deliver system functionality described in this
section, but not specifically listed in this paragraph.
Sequence of events reporting
1. The PEMS shall be configured to time stamp and log all PLC control operations
initiated by any HMI operator, all control actions automatically performed by the PLC
and all field device status changes detected by the PLC.
2. Time stamping shall occur in the PLC, not in the HMI software. Time stamping
resolution shall be determined by PLC scan time and shall be on the order of 50100msec.
3. A display tool shall be provided, which displays the sequence of event records sorted
in either forward or reverse chronological order. This tool shall reside on the master
HMI station along with the HMI software and shall be seamlessly integrated with the
HMI screens. It shall also allow for a printed record of these events for review at any
time.
BID SUBMITTALS
A.
A written proposal describing system hardware, integration, startup and testing,
documentation examples and training outline shall be provided. The proposal shall
include, as a minimum, the following items:
1. A bill of materials and a list of spare parts.
2. A system architecture diagram describing the interconnection of system components.
This drawing should show, as a minimum, the interconnection of power monitors,
PLC’s, remote I/O devices and HMI stations. It should also show all interfaces with
existing building or information networks or devices.
3. A fixed price, lump sum bid for the system that includes all hardware, spare parts,
engineering and startup services, documentation, and owner training.
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PROJECT SUBMITTALS
A.
A time-line, outlining major milestones and expected submittal and system delivery.
B.
Written functional specification with owner review/approval cycle. This document will fully
describe the system including:
1. System objects and their attributes and methods, including:
a. Inputs and outputs
b. Alarms
c. Internal data points
d. Initialization methods
2. A process model describing how requests, control commands, and status values are
sent between objects and used.
3. A complete I/O list including programmable logic controller address, signal type, units,
object instance names, attributes, and use.
4. A complete power monitor list including circuit designation, I/O address and CT and
PT ratios.
5. System architecture drawing(s)
6. HMI display sketches and description of operation
7. Flow-Charts and associated drawings depicting control algorithm operation
C.
Shop drawings including fabricated control cabinet point-to-point interconnection drawings
showing cable types and PEMS terminal numbers, with owner review/approval cycle.
1. Approval submittals shall be 11” x 17” hardcopy.
2. Final-as-built drawings shall be delivered with the systems user manuals both in 11” x
17” hardcopy and AutoCad *.dwg electronic file formats.
D.
Power monitor user’s manual describing the following items:
1. Dimensions
2. Mounting and installation details
3. CT and PT connection diagrams
E.
Written factory test script describing the tests to be performed and the result that indicates
successful completion of the test.
F.
Written field test/startup procedure.
G.
System users manuals, including:
1. Fully updated functional specification including all revisions made over the course of
project implementation.
2. Detailed software engineering documentation created during the course of project
implementation.
3. Programmable logic controller, ladder logic listings and cross reference reports
4. HMI tag database listing report
5. Final-as-built I/O listing
6. Final-as-built PM listing
7. Final-as-built drawings of all provided materials within scope.
8. Product manuals or data sheets for all equipment supplied with the system.
9. All configured software files including PLC programs and HMI project files.
DELIVERY, STORAGE, AND HANDLING
A. System components shall be shipped via air-ride van.
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B. Owner or installing contractor shall be responsible for delivery, storage, protection and
installation of all PEMS equipment and materials.
C. Owner or installing contractor shall protect all PEMS equipment and materials from damage
during construction and installation. All PEMS equipment and materials shall be protected
from dust, water and any other physical damage.
D. Once installation is complete, and field wiring has been thoroughly tested by the owner or
installing contractor, the system integrator shall be notified to schedule system startup,
commissioning, final as-built wiring diagram completion and field acceptance testing.
1.13
ACCEPTANCE AT SITE
A. Owner or installing contractor shall inspect equipment upon receipt and notify system
integrator and shipping company immediately of any damaged or missing components.
B. Owner or installing contractor shall be responsible for unpacking and installing equipment.
C. Owner shall accept the system after startup / field-testing has been completed and
witnessed by the owner’s representative. The field acceptance test shall be performed in
accordance with the written field startup and test procedure.
1.14
SEQUENCING
A.
Upon acceptance of bid, system integrator shall schedule a kick off meeting and site
survey with the owner, owner’s engineer and installing contractor.
B.
The system integrator shall then submit, within 6-8 weeks, the functional specification and
interconnection drawing for approval.
C.
The owner, owner’s engineer and installing contractor shall review, comment (if required)
and approve the functional specification and interconnection drawings within 4 weeks.
D.
Upon receipt of the approved submittals, the system integrator shall commence equipment
and material procurement, assembly and testing of control enclosure. Software
engineering, PLC and HMI configuration shall proceed in parallel with the control enclosure
production.
E.
Once control enclosures, PLC configuration and HMI configuration are complete, the
system shall be setup and fully tested at system integrator or manufacturer’s facility to the
extent possible in a factory setting. At this point, the test script shall be submitted to the
owner for review.
F.
Once factory integration and testing are complete, the system integrator shall notify the
owner and installing contractor to schedule an owner witnessed factory test.
G.
Upon successful completion of the owner witnessed factory test, the system equipment
and materials shall be shipped to the owner. The installing contractor shall be responsible
for system installation and preliminary testing of system wiring. The system integrator
shall coordinate with the owner, owner’s engineer and installing contractor to ensure
smooth system installation. The system integrator shall provide telephone support (up to
16 hours) as required to answer system installation questions.
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H.
I.
1.15
Once the installing contractor has fully installed all equipment and tested all system wiring,
the system integrator shall be notified to schedule the field-testing and startup.
Upon completion of the system startup and field acceptance testing, the owner shall sign off and
take complete possession of the Power & Energy Management System.
SCHEDULING
A.
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The system integrator shall submit a time-line to the owner outlining major milestones and
expected system delivery during the kick-off meeting.
SYSTEM STARTUP
A.
System startup shall be done according to the written field test/startup procedure.
B.
Owner’s representative shall witness and sign-off when field-testing is successfully
completed.
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PART 2 PRODUCTS
2.01
2.02
SYSTEM INTEGRATOR
A.
System integrator must specialize in the engineering and implementation of power and
energy management systems and must be prepared to demonstrate application
knowledge.
B.
System integrator shall provide a project list of system installations similar to that
described in this section.
C.
System integrator shall be ISO 9001 certified.
D.
The following system integrators are considered qualified:
1. Rockwell Automation Power & Energy Management Solutions – No Substitution.
SYSTEM COMPONENTS
A.
Digital power monitor:
1. Power monitors shall be microprocessor-based with a base sampling frequency rate
of at least 10.8kHz. Measured parameters (Volts, Amps, and Frequency) shall have
accuracy in percent of full scale of 0.05% and all calculated parameters shall be
0.1%. Harmonics shall be measured to at least the 41st and have an accuracy of no
less than +/- 5%.
2. Refresh rate for display and transmission of measured parameters shall be user
configurable.
3. The metering unit shall contain self-powered status inputs capable of detecting dry
contact closure.
4. The metering unit shall be capable of directly communicating via Ethernet or
DeviceNet. Intermediate bridges or gateways are not acceptable.
5. The meter shall be supplied with either a unified or separate display unit. If a separate
unit is supplied, the display shall be rated for NEMA 4 indoor use. The separate
display unit shall be connected to the base unit utilizing a UL approved low voltage
connection All metering data, logs and harmonic information contained within the
meter shall be accessible via the display unit.
6. The following logs shall be contained within the unit with a nominal date/time
stamping resolution of 0.01 seconds. The unit shall maintain all logs and
configuration parameters in the event of loss of control power.
a. Min/Max log capable of retaining and displaying the minimum- and maximumrecorded values for all real-time power system parameters.
b. Snapshot log – A user configurable time/event driven based log.
c. Event logs - Configurable to user defined measurable events. The unit shall be
capable of retaining the most recent 100 events.
7. Setpoints. The metering unit shall have the ability to date/time stamp excursions
beyond user-defined values for multiple parameters. These set point excursions shall
be capable of triggering a log entry into the event log, triggering an oscillographic
recording, and/or energizing one of the meter’s onboard relays.
8. Oscillographic waveforms shall be available as (1) Simultaneous, with all channels
recorded for at least two cycles; and (2) User configurable with at least 75% cycles of
pre-trigger data. Oscillographic recordings can be either manually triggered or
internally triggered from a set point or event.
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9.
The metering unit and all accessories shall be listed and/or certified by UL, CSA, and
CE and built in accordance with ISO 9000.
10. The following power monitoring devices are approved – no substitutions:
a. Allen Bradley Powermonitor-II
b. Allen Bradley Powermonitor-3000
B.
Programmable Logic Controller:
1. General
a. Provide a microprocessor based programmable logic controller that can be
networked into a larger system. The unit shall be fully programmable and
capable of performing control relay logic, including timing, counting, sequencing,
and interlocking.
b. The PLC shall have a modular chassis design, which allows for ease of future
expansion. The processor module shall be easily removed from the I/O chassis
for service or repair. The I/O chassis shall have slots for installing I/O cards,
communications, or other special function modules. All I/O cards and modules,
including the CPU, shall be capable of being installed in any open slot in the
chassis.
c. The PLC shall have a modular power supply, which mounts directly on the I/O
chassis and can be easily serviced or replaced. The system shall be capable of
being powered on 24VDC, 48VDC, 125VDC or 120VAC, by simply choosing
different power supply modules.
d. The PLC shall be of high quality and reliability with replacement processors,
power-supplies, chassis, I/O and specialty modules that are readily available on
an urgent or emergency basis. All PLC products shall be fully supported and
available for purchase for up to seven (7) years from the date of the original
system purchase.
e. Product maintenance training shall be available from factory trained support
representatives.
2. Processor
a. The processor shall have solid state RAM memory to store the application
program, process data, and alarm status. This memory shall have both capacitor
and battery backup in the event that input power to the processor is lost. It shall
also have the capability of EEPROM backup, which automatically reloads the
memory on a power cycle. The processor shall have the ability to automatically
go into the RUN mode on a power cycle.
b. The processor RAM shall be sized to meet the specific requirements of the
power management system.
c. Processor scan time shall not exceed 1 msec per 1K of typical ladder program.
d. Basic processor functions
1) Real-time control of output points for turning on and off digital devices such
as motor starters and solenoids.
2) Read the status of real world digital inputs from limit switches, float
switches, and other field devices.
3) Real-time control of analog process control variables.
4) Read the status of real-world analog set points and feedback values.
5) Perform timing, counting, sequencing, and interlocking functions for pump
control.
6) Process local alarm handling functions
d. Math and advanced functions
1) Four-function math in floating point or signed integer format.
2) Full PID Instructions for control of process control variables such as flow
and pressure.
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3)
3.
4.
5.
Built-in processor interrupt functionality to report recoverable processor
faults back to the polling master
4) Trigonometric and exponential math functions.
e. Real-time calendar clock for time stamping alarms and events. Clock must be
accurate to within plus or minus 60 seconds per month while operating at 25
degrees C. PLC shall be Year 2000 compliant.
f.
Built-in RS-232 port for SCADA serial communications.
g. Removable processor key switch to guard against program tampering by
unauthorized personnel.
I/O Chassis
a. The chassis shall be sized such that there is room to add additional modules for
future process expansion. At least one open slot shall be available on chassis
sized 8 slots or smaller, and a minimum of two open slots shall be available on
chassis larger than 8 slots.
b. The PLC system must have the ability to add both local and remote expansion
chassis.
I/O Cards
a. Discrete Input Cards: Solid-state input circuits rated for suitable input voltage
operation. Cards must be available in 8 and 16 point. Each input point shall
have a status LED that indicates the ON or CLOSED condition for that field
sensor or switch. Cards with 16 points must have removable terminal strips so
that module can be easily replaced without disturbing the field wiring.
b. Discrete Output Cards: Relay-contact output circuits rated for 5-265VAC or 5125VDC operation. Cards must be available in 4, 8, and 16 point configurations.
c. Analog Input Cards: Analog inputs shall be capable of reading in -20 to +20mA,
0 to +20mA, 4 to 20mA, 0 to 10V, or –10 to +10V. The A/D converter shall
provide a minimum 4095:1 resolution (12 bits) over the full range from module
minimum to module maximum.
d. Analog Output Cards: Analog Outputs shall be capable of outputting -20 to +
20mA, 0 to +20mA, 4 to 20mA, or 0-10V signals. The A/D converter shall provide
a minimum 4095:1 resolution (12 bits) over the full range from module minimum
to module maximum.
e. All cards shall also have available, pre-wired remote terminal blocks. Thus
allowing field wiring to be terminated on a block that is connected to the I/O card
via a factory designed and fabricated extension cable.
Communications
a. The PLC shall include communications of the following types: SCADA serial
communications, Remote I/O Control Network and Peer-to-Peer
communications utilizing at least one of the following networks:
1) DeviceNet
2) Ethernet
b.
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The PLC shall have resident at its RS-232 port, a Half-duplex communications
protocol that is suitable for a multi-drop single master and multiple slave SCADA
network. The protocol shall be capable of supporting up to 255 stations including
the polling master. The communications performance between the PLC
processor and remote PLC’s shall be capable of following:
1) The PLC processor shall be capable of performing polling master
functionality in the SCADA network.
2) The communications protocol shall provide Report by Exception (RBE)
functionality. With RBE, remote PLC’s do not transmit any message back to
the master unless a new event or alarm has occurred since the last time the
slave was polled. Each remote PLC shall have the ability to initiate a
command, either to the master or a peer station.
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3)
6.
7.
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The PLC processor shall be capable of remote on-line programming, as
well as monitoring of remote PLC data, via the telecommunications
network.
4) Communications protocol must be “open”, published, and readily available.
Protocol must be compatible with a variety of modem/radio manufacturers.
c. Processor shall have a built-in communications port that allows it to
communicate on a multi-point, peer-to-peer, data communications network with
the following performance:
1) The network shall support a minimum of 16 connections, allowing
simultaneous communication with up to 16 PLC’s or Computers.
2) The network shall communicate at 10Mbps-baud rate.
3) The network shall use shielded, non-shielded twisted pair (10Base-T) or
fiber optic cable (10BaseFL) as its communications medium.
4) The network shall support the TCP/IP communication protocol.
5) The network protocol shall use CSMA/CD (Carrier Sense, Multiple Access
with Collision Detection) as its network access method.
6) The network shall support the Simple Network Management Protocol
(SNMP) for network management in the TCP/IP environment.
d. The PLC system shall be capable of controlling remote I/O Racks, Variable
Frequency Drives, Operator Interface Terminals (OIT) and any other devices that
can be configured as Remote I/O adapters. This shall be accomplished through
a rugged Industrial Control Network with the following criteria:
1) The Remote I/O network shall be a Master-Slave configuration with the
scanner acting as the master and all remote devices acting as slaves.
2) The network shall be capable of controlling remote output modules and
reading the status of remote input modules.
3) The PLC shall have a scanner that is either a slot-mounted module in the
chassis or is resident in the PLC itself.
4) The Remote I/O network shall be capable of communications at the
following distances from the scanner module at the baud rate indicated,
without the use of repeaters, line drivers or bridges:
a. 10,000 ft. maximum @ 57.6 Kbaud
b. 5000 ft. maximum @ 115 Kbaud
c. 2500 ft. maximum @ 230 Kbaud
5) The network shall use twin-axial, shielded cable (Belden 9463 or equivalent)
as its communications medium.
Diagnostics
a. The processor shall have built-in diagnostics and self-test, such that each time
power is cycled, the processor does a complete CPU and RAM memory test.
b. The processor shall have a built-in watchdog timer to ensure that all processor
program scans occur within the time limit set by the watchdog timer.
c. The processor shall have individual LED indicators that are clearly visible and
labeled for easy identification. At a minimum the following indicators must be
provided:
1) CPU is in RUN mode
2) CPU is FAULTED
3) CPU battery is LOW
4) I/O points are FORCED and are not under program control
3) COMMUNICATION channels are active
The following programmable logic controllers are approved – no substitution:
a. Allen Bradley PLC-5
b. Allen Bradley SLC-500
c. Allen Bradley ControLogix
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Personal computers:
1. Each personal computer connected to the PEMS network shall have equal access to
information provided by PLC’s and power monitoring devices.
a. In a stand-alone configuration, each PC shall be independent of other PC’s,
each with its own software to allow a user to retrieve and configure information
based on the user’s needs.
b. In a client-server configuration, client PC’s with their own software rely on the tag
servers residing on the master HMI station. This configuration allows users on
both the HMI master and all HMI clients equal access to PEMS resources.
2. Provide a personal computer to function as the system master HMI station. The PC
shall be provided to accommodate the requirement of the HMI software package
included with the system. The PC shall have the following minimum specifications
and features:
a. Intel 800MHz (minimum) Pentium III processor
b. 512MB RAM
c. 19" color SVGA monitor
d. 20GB hard drive
e. 48X CD-ROM drive
f.
3.5" 1.44MB diskette drive
g. (1) serial and (2) parallel ports
h. Keyboard
i.
56 kbaud modem, K56flex
j.
Ethernet network interface card
k. MS IntelliPoint Mouse
l.
Windows 2000 operating system software
3. Provide the following printers with the master HMI station:
a. Laser printer for report printing.
b. Wide-carriage dot matrix printer for alarm printing.
4. Provide a laptop personal computer to function as the remote programming terminal.
The laptop PC shall be provided to accommodate the requirement of the PLC
programming software package included with the system. The PC shall have the
following minimum specifications and features:
a. Intel 800MHz (minimum) Pentium III processor
b. 512MB RAM
c. 12” (minimum) Active matrix color VGA display
d. 20GB hard drive
e. 48X CD-ROM drive
f.
3.5" 1.44MB diskette drive
g. (1) serial and (1) parallel port
h. 56 kbaud modem, K56flex
i.
Ethernet network interface card
j.
Carrying case
k. Windows 2000 operating system software
5. All network interface cards (NIC’s) required for the PC’s to connect to the PEMS shall
be installed and configured in the PC’s by the system integrator. These would include
as a minimum any combination of the following, depending on networks utilized in the
PEMS:
a. Ethernet NIC
b. ControlNet NIC
c. Data Highway Plus NIC
d. DeviceNet NIC
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Software
1. HMI (operator interface) software shall be loaded and pre-configured by the system
integrator and should have the following minimum capabilities:
a. Capacity for at least 1,000 tags, expandable to 70,000 tags
b. Advanced Direct Data Exchange (DDE) drivers to communicate with other DDE
server applications.
c. Interoperability with Microsoft products such as Excel, Word, Access, and Visual
Basic.
d. Object Linking and Embedding (OLE). The software will allow third party OLE
applications to be seamlessly embedded into graphic displays for in-place
editing.
e. Productivity tools such as a graphic editing while running other displays, testing
animation before going online, and modifying tag addresses, node addresses,
PLC networks, and device drivers on the fly.
f.
Open Database Connectivity (ODBC). The software shall store all tag and
system configurations in an ODBC compliant database.
g. Digital and analog alarms with multiple thresholds and levels of security.
h. Real-time and historical trending with at least 8 pens per trend.
i.
Networking capabilities so that multiple nodes can retrieve information from a file
server.
j.
Ability to create and modify custom graphics such as one-line drawings,
equipment drawings and icons representing electrical system devices such as
circuit breaker, automatic transfer switches, etc.
k. Provision for up to 8 levels of security, limiting user access to screens and
functions.
l.
Log all alarms to disk for display or printing.
m. Log all HMI events to disk for display or printing
2. Power monitoring software
a. Power monitoring software shall be provided with the system. The power
monitoring software shall be capable of downloading and uploading configuration
parameters and power settings to and from the power monitoring hardware from
the master HMI PC.
b. The power monitoring software shall allow the user to view the harmonic content
of an electric signal on the computer screen with both spreadsheet and bar
graph views.
c. The power monitoring software shall capture waveforms of all line voltage and
current elements; and provide a numerical and graphical harmonic analysis for
each line current and voltage parameter.
d. The power monitoring software shall allow the user to review power monitor
historical logs, including: current and voltage snapshot logs, power logs, event
logs, and minimum/maximum logs.
3. PLC programming software
a. The system integrator shall provide PLC programming which allows the owner to
program, configure and maintain the PLC system, once the system integrator
has completed to work described in this section.
b. The PLC programming software shall have the following minimum capabilities:
1) Ladder editor that consolidates and displays all project information as a
project tree with "Point-and-Click" accessibility. The editor must allowing
editing of several rungs simultaneously.
2) Possess the ability to move to any rung or instruction you need by clicking
on the cross-referenced item in a split-window format using the Online
Cross-Reference.
3) Provide drag-and-drop editing which allows the user to add addresses to
instructions by dragging them from the data table monitor, database files, or
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5.
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the Address/Symbols picker to the desired instruction, or quickly move
instructions within a project or from one project to another, or move data
table elements from one data file to another.
4) Provide diagnostics, which allows a user to locate problem areas in the
application using advanced diagnostics. Locate and replace addresses and
description text easily using search and replace. Examine the status of data
table elements simultaneously with a custom display monitor. Review
status bit settings including scan time, math registers and interrupt settings
using tabbed displays. Access I/O configurations, program files, data table
files and more from the consolidated project view.
5) Provide database editing to build and classify groups of symbols using the
symbol group editor. Assign addresses or symbols to ladder instructions
using a symbol selection application.
6) Provide a WYSIWYG reporting tool that lets the user preview every detail of
the data before sending it to a printer.
7) Operates and provides native linking capabilities to any MS Windows OS,
or native application environment.
Approved software – No substitutions
a. HMI
1) RSView32 (works & runtime)
2) RSView32 Active Display Server
b. Power Monitoring
1) RSEnergyMetrix (Entire suite)
c. Communications
1) RSLinx
d. PLC programming
1) RSLogix5
2) RSLogix500
3) RSLogix5000
Office application software
a. The following Microsoft Office products, of the latest version available, shall be
supplied with the system:
1) Access - database
2) Excel - spreadsheet
3) Word - word processor
4) SQL Server
5) Internet Information Server
SHOP ASSEMBLY
A.
The system shall be fully assembled, wired and tested at the integrator’s facility.
B.
Unless otherwise noted, all materials and equipment supplied by the system integrator
shall be new, of the type, capacity and quality specified and free from defect.
C.
The panel fabricator shall be ISO9000 certified.
D.
The PEMS enclosure(s) shall be rated NEMA 12 and be suitably sized to house the PLC,
power supply, I/O chassis and related support equipment.
E.
General enclosure and sub-panel requirements:
1. A 10-32x1” ground-stud shall be welded on the lower, inside corner on all enclosure
doors on which electrically powered devices are mounted.
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2.
3.
4.
5.
F.
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All punched holes through which wires and cables are run shall be protected with
edge grommet material.
All fasteners shall be tightened in accordance with the manufacturer’s torque
recommendations using a calibrated torque wrench.
All wire-duct (Panduit) shall be mounted utilizing double-sided tape and plastic push
rivets. This method of installation provides a completely non-conductive environment
within in the duct.
Ground-buses shall be mounted directly on bare metal. All paint shall be completely
removed where ground-buses are attached to the enclosure or sub-panel.
Wiring Conventions
1. All wiring shall conform to the following color scheme:
a. AC power:
1) 120VAC, 240VAC and 480VA “hot” conductors shall be black.
2) All grounded, neutral conductors shall be white or natural gray.
b. AC control. Control wiring originates from where AC power has been switched
by relay contacts, switched by a PLC or is connected to the secondary side of a
transformer.
1) All “hot” control conductors up to 120VAC shall be red.
2) All grounded, neutral conductors shall be white or natural gray.
c. Externally powered interlock circuits, where control power is supplied from and
external power source.
1) All “hot” control conductors shall be yellow.
2) All grounded, neutral conductors shall be white or natural gray.
d. DC control and power:
1) All “+” conductors shall be blue.
2) All “-“ conductors shall be blue with a white trace.
e. All ground conductors shall be green.
2. All wiring shall be of the following minimum size:
a. Power wiring to power PLC power supply shall be #14 AWG MTW.
b. PLC chassis shall be connected to the enclosure ground bus with #8 AWG
MTW.
c. Enclosure doors with electrically powered devices shall be connected to the
enclosure ground bus with #8 AWG MTW.
d. Single conductor I/O wiring shall be #16 AWG MTW.
3. Cabling
a. Analog I/O shall be wired with Belden 8760 or equivalent, single twisted pair,
shielded cable. The drain-wire from each cable shall be connected an isolated
ground bus. All shields shall be covered with clear Teflon tubing. The black
conductor shall carry the positive signal (+) and the clear conductor shall carry
the negative signal (-).
b. Data Highway Plus (DH+) and Remote I/O (R I/O) communications circuits shall
be wired with Belden 9463 or equivalent, twin-axial, shielded cable.
Communications wiring shall cross AC conductors at a 90-degree angle. Where
communication wiring must run parallel to AC conductors, a minimum of 2”
separation must be maintained.
4. Termination:
a. Conductors connected to terminal blocks without pressure-plates shall be
terminated with insulated, fork-tongue type crimp lugs.
b. Conductors connected to studs, grounding screws and meters shall be
terminated with insulated, ring-type crimp lugs.
c. Conductors connected to PLC I/O modules and terminal blocks with pressureplates shall be stripped, inserted and tightened. No crimp lugs are required.
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2.04
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Labeling requirements:
1. An engraved device tag showing the name of each device, as shown on the electrical
and mechanical shop drawings shall be placed the on sub-panel as near as
practicable to each physical device. Engraved device tags shall have a white face
with black lettering.
2. Engraved device tags shall be no smaller than 1/2” high x 1-1/2” long with 1/4” high
text and shall be affixed to the sub-panel with adhesive.
3. External enclosure tags for overall enclosure identification shall be no smaller than 3”
high x 5” long with 1/2” high text.
4. The PLC I/O chassis slots shall be identified with the provided adhesive labels using a
black, indelible ink marker.
5. Incoming AC power conductors shall be labeled as follows:
a. Single-phase 120VAC circuits: L1 and N
b. Single-phase 240VAC and 480VAC circuits: L1 and L2
c. All three phase circuits: L1, L2 and L3
6. I/O wiring shall be labeled with the PLC I/O address on which the conductor or cable
terminates.
7. Power distribution conductors within the enclosure shall be identified with a label
containing the page and line number of the shop drawing on which the conductor
appears.
8. Wiring labels shall be printed on white shrink tubing and applied such that they are
read from left to right on wires which terminate horizontally and from top to bottom on
wires which terminate vertically. On wires where the numeral 0 appears, the numeral
shall be printed with a slash in order to distinguish it from the letter O (example: Ø).
TESTS, INSPECTION
A.
The fully assembled and configured system shall be set up and tested at the integrator’s
factory according to the test script for adherence to the functional specification. The
integrator shall provide a checklist outlining all of the tests.
B.
The factory witness test shall be “mocked-up”, to the extent possible in a factory setting, to
represent the actual system, as it will be installed in the field. The owner’s representative
shall witness the factory test.
C.
As each test is completed, the owner’s representative shall initial the checklist signifying
that the test has been successfully completed.
D.
At the completion of the factory test, the owner will sign-off, indicating that the system has
performed as described in the functional specification. Final owner acceptance will occur
at the completion of the field acceptance testing.
SPARE PARTS
A. As a minimum, spare parts consisting of at least one of each component type or one
component for every ten components (10%), whichever is greater shall be provided with the
system.
B. Spare parts for the following typical major components shall be supplied in the quantities
described in paragraph A above:
1. PLC processor
2. Power supply
3. I/O modules
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Owner’s Name
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Power & Energy Management System
Rockwell Automation PEMS
5/8/2017
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4.
5.
6.
7.
8.
9.
10.
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POWER & ENERGY MANAGEMENT SYSTEM
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Power Monitors
Protocol conversion modules
Modems
Indicator lamp bulbs
Relays
Circuit breakers and fuses
Other specialty equipment supplied with system.
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Power & Energy Management System
Rockwell Automation PEMS
5/8/2017
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Project Number
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POWER & ENERGY MANAGEMENT SYSTEM
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PART 3 EXECUTION
3.01
SERVICES
A.
3.02
3.03
INSTALLATION
A.
Installing contractor shall provide all labor, materials, and equipment to install the system
in accordance with the manufacturer’s and system integrator’s instructions as indicated
and as specified herein.
B.
Installation contractor shall verify the following items:
1. HMI workstations have been installed at the location(s) indicated in accordance with
manufacturer’s recommendations.
2. All control enclosures and power monitors shall be properly installed and wired in
accordance with the manufacturer’s guidelines and recommendations.
3. All field devices have been properly configured in accordance with configuration data,
including DIP switch settings and PM configuration parameters, provided by the
system integrator.
4. All communications cables have been properly installed per manufacturer and
integrators specifications and all field devices are connected.
5. All hardware is free from damage. It has been visually inspected, cleaned and is
ready for startup.
C.
Good workmanship shall be evidenced in the installation of all electrical materials
equipment. Equipment shall be level, plumb, and true with the structure and other
equipment. All materials shall be firmly secured in place and adequately supported and
permanent. The requirements of the codes are minimum standards. The
recommendations of the National Electrical Contractors Association Standard of
Installation shall be followed except where otherwise specifically directed.
D.
System integrator shall provide, as an option, daily charges for installation supervision
services, which can be purchased by the owner or installing contractor at their discretion.
INTERFACE WITH OTHER WORK
A.
3.04
The system integrator shall provide all services required to design, configure, program,
test and commission a fully functional power and energy management system as
described in this section.
The system integrator shall coordinate with the owner, installing contractor and other
electrical apparatus suppliers, to the extent necessary to ensure that all I/O interface
points associated with the power management system are defined, provided and
understood.
SITE TESTS, INSPECTION
A.
The system integrator shall verify that the system components and field wiring have been
installed and configured correctly before system startup.
B.
The system integrator shall provide a minimum of five (5) 8-hour days for system startup
following installation of the system.
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Owner’s Name
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Power & Energy Management System
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5/8/2017
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Project Number
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C.
The system integrator shall perform startup according to the written field test/startup
procedure.
D.
As a part of the startup activities, the system integrator along with an owner’s
representative shall perform field acceptance testing requiring owner’s witness signatures
per the written field test/startup procedure.
E.
The system integrator shall provide a final written report outlining system startup activities
and owner acceptance of system.
TRAINING
A.
System integrator shall provide on-site training on system operation, modification, and
basic maintenance to owner’s staff.
B.
System integrator training personnel shall be factory trained and shall have a thorough
working knowledge of the software, hardware and system programming required to
operate, maintain, and enhance the installed system.
C.
System training shall consist of two (2) 8-hour days and shall cover the following topics:
1. Hands-on training of site personnel
2. Explanation of system design and operation
3. Explanation of system hardware and devices
END OF SECTION
Project Name
Owner’s Name
16290 - 26
Power & Energy Management System
Rockwell Automation PEMS