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ELECTRICAL AND I&CCODES AND INSPECTION
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Day 4
7. I&C Structures, Systems and Components (SSCs) - Introduction
Structure of the I&C sessions is similar to structure of the electrical sessions.
IEEE Std 603 is a common starting point for
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IEEE Std 603 is a common starting point for the hierarchy of standards.
Other applicable standards common to both I&C and electrical SSCs include IEEE Std 323, 336, 338, 344, 379, 384, 420, 497, 498, and 572.
7. I&C SSCs - Introduction
Differences (compared to electrical SSCs):
“Half-life”: I&C technologies change more rapidly
Low signal levels (e.g., 10-9 A, mA, mV); potential for
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Low signal levels (e.g., 10 A, mA, mV); potential for hardware common cause failure (CCF) from electromagnetic interference (EMI)
Use of real-time software to perform safety and control functions (new failure modes & effects; potential for CCF from software bug)
More dependencies on process systems
7. I&C SSCs - Introduction
Therefore, there is more emphasis on:
Rigorous control of the software life cycle process for digital systems
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Use of diversity for defense-in-depth
Electromagnetic compatibility (EMC)
Process system characteristics
7. I&C SSCs - Introduction
Additional standards for digital systems are used, beginning with IEEE Std 7-4.3.2,
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used, beginning with IEEE Std 7 4.3.2, which supplements IEEE Std 603.
7. I&C SSCs - Introduction
IEEE Std 7-4.3.2, IEEE Standard Criteria for Digital Computers in Safety Systems of Nuclear Power Generating Stations
Additional computer specific requirements to supplement the criteria and requirements of IEEE Std 603 are specified in IEEE Std 7-4.3.2.
Within the context of IEEE Std 7 4 3 2 the term “computer” is a
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Within the context of IEEE Std 7-4.3.2, the term computer is a system that includes computer hardware, software, firmware, and interfaces.
Criteria contained in IEEE Std 7-4.3.2, in conjunction with criteria in IEEE Std 603, establish minimum functional and design requirements for computers used as components of a safety system.
IEEE Std 7-4.3.2 and subtier standards will be covered in Session 15.
7. I&C SSCs - Introduction
Analog Systems
“Real” real-time: continuous signal flow
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Can test more exhaustively
Not many surprises – failure modes and effects are usually well known
7. I&C SSCs - Introduction
Digital Systems
Serial data processing
Cannot test exhaustively
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Can have surprises; different failure modes and effects
Must use a life cycle process for software that results in sufficiently low probability of undetected, unacceptable errors
Independent verification and validation (IV&V)
Use diversity selectively to manage risk
7. I&C SSCs - Objectives
Identify the major I&C structures, systems, and typical components
P id l i f th
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Provide a general overview of the purpose of these SSCs
Discuss how these SSCs relate to new reactor inspection
7. I&C SSCs
I&C Structures
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I&C Systems
I&C Components
I&C Structures
Main Control Room
Instrument Rack / Cable Spread Rooms
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Remote Shutdown Panel Room
Various Structures Containing Field Instruments (Containment, reactor auxiliary building, etc.)
Main Control Room: Old vs. New
Analog TechnologySwitches, meters, status lights, alarm windows
Hardwired circuits: many cables
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Digital (Computer) TechnologyInteractive graphic displays: fewer devices
Smart alarms: fewer windows
Serial data processing: fewer cables
Main Control Room - Analog
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Main Control Room - Digital
[From US-APWR DCD Figure 7.1-3]
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Main Control Room - Digital
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Main Control Room Attributes
Seismic Category I Structure
No interaction of Seismic Cat II with Cat I (“2 over 1”)
Controlled ambient temperature & humidity
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Independence maintained among redundant channels / trains (IEEE Std 603, IEEE Std 379, IEEE Std 384)
No sources of high energy – relaxed separation criteria
Human Factors
Instrument Rack / Cable Spread Room Attributes
Seismic Category I Structures
No interaction of Cat II with Cat I (“2 over 1”)
Controlled ambient temperature & humidity
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Controlled ambient temperature & humidity
Independence maintained among redundant channels / trains (IEEE Std 603, IEEE Std 379, IEEE Std 384)
No sources of high energy – relaxed separation criteria
Remote Shutdown
A remote shutdown panel is provided outside the control room as a means of achieving and
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as a means of achieving and maintaining safe shutdown independent of the control room / control complex
Remote Shutdown Panel (RSP)
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RSP Attributes
RSP is normally inactive and electrically isolated from the control room
RSP status is continuously monitored
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RSP transfers control of circuits required for safe shutdown, and
RSP isolates the control room circuits
Remote Shutdown Panel (RSP)
[US-APWR DCD Figure 7.4-2: Cable routing to the Remote Shutdown Room]
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MCR Isolation - Testing
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I&C Field Areas (Typical)
Containment – 10 CFR 50.49 EQ for LOCA / MSLB
Containment electrical penetration area – Nuclear instrumentation preamplifiers
Reactor Aux Bldg – 10 CFR 50.49 EQ for HELB and dose from post-LOCA recirculating fluids; “shine” from penetrations; also consider effects of airborne particulate
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penetrations; also consider effects of airborne particulatespurious actuation of sensitive process radiation monitor)
Main steam isolation valve and main steam line areas
Remote I/O areas (switchgear, various process areas, etc., where data is acquired or outputs provided)
Student ActivityCritical Attributes Matrix
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I&C Structures: Critical Attributes
Structure Critical Attribute(s)
Main Control Room
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Instrument Rack / Cable Spread Room
Remote Shutdown Panel
Various Field Areas
I&C Systems
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I&C Systems
Safety (Protection) Systems (Class 1E): Reactor Trip and ESF Actuation
Safe Shutdown Systems (remote shutdown capability using safe shutdown systems was previously discussed)
Information and Control Systems:
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y
- Information Systems Important to Safety (e.g., RGs 1.97, 1.47)
- Interlock Systems Important to Safety (e.g., Accum. MOVs)
- Control Systems (non-Class 1E) & Potential for Interaction with Safety System
I&C Systems
Diverse Systems
- ATWS (non-Class 1E reactor trip for AOOs using diverse variables and hardware)
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using diverse variables and hardware)
- Diverse actuation system as defense-in-depth, in the event there is a CCF of the I&C Safety Systems software; reactor trip and selected ESF functions
I&C Systems
Data Communication Systems (DCS)
Supports communication for safety and
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- Supports communication for safety and non-safety systems
I&C Systems: Safety Systems
Reactor Trip System
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Engineered Safety Features Actuation System (ESFAS)
Reactor Trip System - Functions
Sense: Sense / measure variables used for reactor trip, such as neutron flux; rod position; RCS, main steam, / and feedwater thermal/hydraulic variables
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Condition/Compute: Condition/process the sensed variables; calculate derived values such as DNB, kW/ft, etc.
Command: Compare value to setpoints, apply decision and voting logic
Execute: Trip/scram reactor
Reactor Trip System - Example
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Reactor Trip System - Example
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Reactor Trip System - Attributes
Single Failure Criterion (IEEE Std 379):
The safety systems shall perform all required safety functions for a design basis event in the presence of the following:
a) Any single detectable failure within the safety systems concurrent with all identifiable, but non-detectable failures
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b) All failures caused by the single failure
c) All failures and spurious system actions that cause, or are caused by, the design basis event requiring the safety function
The single failure could occur prior to, or at any time during, the design basis event for which the safety system is required to function.
Reactor Trip System - Attributes
Single Failure Criterion (IEEE Std 379 –nondetectable failures):
Detectable failures: Failures that can be identified through periodic testing or that can be revealed by alarm or anomalous indication. Component failures that are detected
t th h l di i i t l l d t t bl
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at the channel, division, or system level are detectable failures.
NOTE: Identifiable, but nondetectable failures are failures identified by analysis that cannot be detected through periodic testing or revealed by alarm or anomalous indication.
Reactor Trip System - Attributes
Single Failure Criterion (IEEE Std 379 –nondetectable failures):
When nondetectable failures are identified, one of the following courses of action shall be taken:
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Preferred course: The system or the test scheme shall be redesigned to make the failure detectable.
Alternative course: When analyzing the effect of each single failure, all identified nondetectable failures shall be assumed to have occurred.
Reactor Trip System - Attributes
Independence (IEEE Stds 603, 384, 7-4.3.2)
- Separation (IEEE Std 384)
- Electrical Isolation (IEEE Std 384)
I l ti D i ( ti l il t t t )
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- Isolation Devices (optical, coil-contact, etc.)are considered part of the Class 1E system and must be qualified, usually by laboratory test
- Input (Class 1E) and output (non-1E) wiring to the isolation device must be separated IAW IEEE Std 384
- Data Isolation - IEEE Std 7-4.3.2
Reactor Trip System - Attributes
Testing and Calibration (IEEE Std 603 / IEEE Std 338)
Capability for testing and calibration of safety system equipment shall be provided while retaining the capability of the safety systems to accomplish their safety functions.
The capability for testing and calibration of safety system
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The capability for testing and calibration of safety system equipment shall be provided during power operation and shall duplicate, as closely as practicable, performance of the safety function.
Testing of Class 1E systems shall be in accordance with the requirements of IEEE Std 338-1987.
Reactor Trip System - Attributes
Indication of Bypasses (IEEE Std 603; see also RG 1.47))
If the protective actions of some part of a safety system have been bypassed or deliberately rendered inoperative for any purpose other than an operating bypass, continued indication of this fact for each affected safety group shall be provided in the control room.
(a) This display instrumentation need not be part of the safety systems.
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( ) y y y
(b) This indication shall be automatically actuated if the bypass or inoperative condition is expected to occur more frequently than once a year, and is expected to occur when the affected system is required to be operable.
(c) The capability shall exist in the control room to manually activate this display indication.
Reactor Trip System - Attributes
Reliability (IEEE Stds 603, 352, 577, 7-4.3.2)
For those systems for which either quantitative or qualitative reliability goals have been established, appropriate analysis of the design shall be performed in order to confirm that such goals have been achieved [IEEE Std 603]
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have been achieved [IEEE Std 603].
IEEE Std 352 and IEEE Std 577 provide guidance for reliability analysis.
IEEE Std 7-4.3.2 provides guidance on the application of these criteria for safety system equipment employing digital computers and programs or firmware.
ESFAS - Functions
Sense: RCS and Steam/feedwater T/H variables, et al
Condition/Compute: Condition/process the sensed variables; calculate derived values
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sensed variables; calculate derived values
Command: Compare to setpoints, perform ESF initiation and voting logic
Execute: Initiate ESF systems/components such as ECCS, EFW, containment isolation, et al
ESFAS - Attributes
ESFAS attributes are similar to reactor trip system attributes
However, there are some additional
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considerations:
- Safety consequences of unintended initiation
ESFAS - Attributes
Potential for system actuation due to single failure (IEEE Std 379):
The potential for system actuation due to single failure shall be examined to determine whether such actuation will constitute an event with unacceptable safety consequences
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event with unacceptable safety consequences.
For any such actuation thus identified as being unacceptable, the single-failure criterion shall be met (i.e., the safety systems must not initiate the actuation as a result of any single detectable failure in addition to all nondetectable failures in the systems).
I&C Systems -Information and Control
Information Systems Important to Safety
Interlock Systems Important to Safety
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Interlock Systems Important to Safety
Control Systems not Required for Safety
Control / Protection Interaction
I&C Systems -Communication and Diversity
Data Communication Systems
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Use of Diversity to Preclude CCF
I&C Systems -Information and Control
Information Systems Important to Safety
Interlock Systems Important to Safety
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Interlock Systems Important to Safety
Control Systems not Required for Safety
Control / Protection Interaction
Information Systems Important to Safety
Bypass and Inoperable Status Indication (RG 1.47)
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Accident Monitoring Instrumentation
(RG 1.97/IEEE-497)
Information Systems Important to Safety – RG 1.47
Selected RG 1.47 Guidance:
Provide indication system that automatically indicates, for each affected safety system or subsystem, the bypass or deliberately induced inoperability of a safety function and the systems actuated or controlled by the safety function.
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The indicating system should be activated automatically by the bypassing or the deliberately induced inoperability of any auxiliary or supporting system that effectively bypasses or renders inoperable a safety function and the systems actuated or controlled by the safety function.
Information Systems Important to Safety – RG 1.47
Bypass and inoperable status indicators should be designed and installed in a manner that precludes the possibility of adverse effects on plant safety systems.
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The indication system should not be used to perform functions that are essential to safety, unless it is designed in conformance with criteria established for safety systems.
Information Systems Important to Safety – RG 1.47
Operating bypass*: Inhibition of the capability to accomplish a safety function that could otherwise occur in response to a particular set of generating conditions.
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Different modes of plant operation may necessitate an automatic or manual bypass of a safety function. Operating bypasses are used to permit mode changes (e.g., prevention of initiation of ECCS during cold shutdown mode). *IEEE Std 603
Information Systems Important to Safety – RG 1.47
Maintenance bypass*: Removal of the capability of a channel, component, or piece of equipment to perform a protective action due to a requirement for replacement, repair, test, or calibration.
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Not the same as an operating bypass. A maintenance bypass may reduce the degree of redundancy of equipment, but it does not result in the loss of a safety function.
*IEEE Std 603
Information Systems Important to Safety – RG 1.97
Accident Monitoring Instrumentation (RG 1.97 / IEEE Std 497)
Design and qualification requirements for accident
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gmonitoring instrumentation depend on the use of the instrument for accident monitoring (RG 1.97 Type A, B, C, D, and/or E)
The design and qualification can range from Class 1E to commercial grade.
Information Systems Important to Safety – RG 1.97
Accident Monitoring Instrumentation
Type A - Necessary manual actions
Type B - Accomplishment of safety functions
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Type B Accomplishment of safety functions
Type C - Potential for breach of barrier
Type D - Operation of individual safety systems
Type E - Release of radioactive materials
Information Systems Important to Safety
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I&C Systems -Information and Control
Information Systems Important to Safety
Interlock Systems Important to Safety
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Interlock Systems Important to Safety
Control Systems not Required for Safety
Control / Protection Interaction
Interlock Systems Important to Safety - Examples
Valve Interlocks:
- ECCS accumulator outlet MOVs
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- RCS / RHR isolation MOVs
Nuclear Instrumentation: Operating Bypass
I&C Systems -Information and Control
Information Systems Important to Safety
Interlock Systems Important to Safety
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Interlock Systems Important to Safety
Control Systems not Required for Safety
Control / Protection Interaction
Control Systems Not Required for Safety
Accident analysis does not take credit for control system actions
Examples:- Pressurizer pressure control
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- Steam generator level control- Rod control
Potential for unacceptable interaction of control system with protection system must be analyzed (IEEE Std 603)
I&C Systems -Information and Control
Information Systems Important to Safety
Interlock Systems Important to Safety
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Interlock Systems Important to Safety
Control Systems not Required for Safety
Control / Protection Interaction
Control / Protection Interaction
IEEE Std 603, Section 6.3.1
Where a single credible event can cause a non-safety system action that results in a condition requiring protective action, andcan concurrently prevent the protective action designated to provide principal protection against the condition, one of the following requirements shall be met:
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following requirements shall be met:
(a) Alternate channels satisfying certain IEEE Std 603 requirements [explained later] can be provided, or:
(b) Equipment not subject to failure caused by the same single credible event shall be provided to detect the event and limit the consequences to a value specified by the design bases. Such equipment is considered a part of the safety system.
Control / Protection Interaction
IEEE Std 603, Section 6.3.1: Requirements for “Alternate channels”:
Alternate channels not subject to failure resulting from the same single event shall be provided to limit the consequences of this event to a value specified by the design basis. Alternate channels shall be selected from the following:
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channels shall be selected from the following:
- Channels that sense a set of variables different from the principal channels
- Channels that use equipment different from that of the principal channels to sense the same variable
- Channels that sense a set of variables different from those of the principal channels using equipment different from that of the principal channels
Control / Protection Interaction
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Data Communication Systems (DCS)
Data Communication:
A method of sharing information between devices that involves a set of rules,
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,formats, encodings, specifications, and conventions for transmitting data over a communication path, known as a protocol.
I&C Systems -Communication and Diversity
Data Communication Systems
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Use of Diversity to Preclude CCF
Data Communication Systems (DCS)
Computer-based safety systems use DCS to communicate:
Divisionally, with input and output devices in each division (Remote I/O)
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Across and among redundant divisions, for voting logic (isolated)To control systems (isolated)To display and information systems (isolated for non-safety displays / info systems)
Data Communication Systems (DCS) Attributes
Where safety related, the DCS must satisfy the same criteria as for an analog system:
- Quality / Qualification
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- Single Failure Criterion- Independence- Reliability- Testability- Diversity- etc.
Data Communication Systems (DCS) Attributes
However, the DCS has additional considerations relative to analog communication:
EMI
Time coherency of data (sequence of data packets)
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y ( q p )
Error detection and recovery
Safety system timing must be deterministic or bounded
Data isolation (e.g., data from safety system is read-only to control system)
Protocols: minimize unneeded functions and complication
Data Communication Systems (DCS)
Typical DCS Configurations: Remote I/O
Analog instruments provide signals (4-20 mA, 1-5 Vdc, contact closure, etc.) to data acquisition units (remote I/O) in plant process areas
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A/D conversion of signals in remote I/O unit
Digital data is then multiplexed (signals shared over wire or fiber-optic cable) to protection or control systems
Protection or control systems can provide outputs to remote I/O units to open valves, start / stop pumps, etc., as prescribed by the control logic
Data Communication Systems (DCS)
Following is a typical example of a plant wide DCS (US EPR) and
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plant-wide DCS (US-EPR) and Protection System
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DCS Symbols (Typical)
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Data Communication Systems (DCS)
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Defense-in-Depth: Example
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DCS Independence
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DCS Independence
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I&C Systems -Communication and Diversity
Data Communication Systems
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Use of Diversity to Preclude CCF
DCS and Safety System Diversity
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Student ActivityCritical Attributes Matrix
I&C Systems
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I&C Systems
I&C Systems Critical Attributes
I&C System Critical Attribute(s)
Reactor Trip
ESFAS
Remote Shutdown
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Remote Shutdown
Information (Safety)
Interlocks (Safety)
Control (Non Safety)
Data Communication
Diversity
I&C Components
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I&C Components
Sensors and Signal Conditioners
A l / Di i l C (ADC )
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Analog / Digital Converters (ADCs)
Bistables (analog comparators)
I&C Components
Displays and Alarms
- Video screen displaysDedicated meters bargraphs etc
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- Dedicated meters, bargraphs, etc.- Dedicated status lights- Alarm panels / alarm conditioning
I&C Components: Sensors
Nuclear instruments
Process instruments- Temperature
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- Pressure- Flow- Level
- Position
Nuclear Instruments
Excore Neutron Flux DetectorsSource range
Intermediate range
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Intermediate range
Power range
Incore DetectorsMovableFixed
Nuclear Instrumentation - Excore
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Nuclear Instrumentation - Excore
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Fission Chamber (W)
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Excore Detector (Gamma-Metrics)
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Incore Detector System - W Moveable
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Incore Detector System – Fixed
Self-Powered Neutron Detectors (SPNDs)
• Platinum emitter produces current proportional to neutron flux
• Need no power supply• Simple and robust structure
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• Simple and robust structure• Relatively small size for in-core installation• Good temperature/pressure stability • Compensation for background noise required (for some
emitters)• Delayed signal response (for some emitters)
Nuclear Instrumentation - Excore: Attributes
IEEE Std 603 and supporting standards, including IEEE Stds 323, 336, 338, 344, 379, 384, 420, 497, 498, 572, etc.
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Triax cable / connectors for EMC purposes
Baseline Time Domain Reflectometry (TDR) for NI cables
Temperature Sensors
Resistive Temperature Detectors (RTDs)
Process and component temperatures
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Thermocouples
Core exit temperatures
Temperature Sensors: RTD
RTD probe & head (Conax)
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Temperature Sensors: RTD
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Temperature Sensors: RTD
RTD (resistive temperature detector)
Resistance varies with temperature
Typically mounted in thermowell
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Typically mounted in thermowell
Resistance can be measured with a bridge circuit, which produces a voltage signal
Temperature Sensors: RTD – 2 Wire
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Temperature Sensors: RTD – 3 Wire
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Temperature Sensors: RTD – 4 Wire
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Temperature Sensors: RCS RTDs
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Temperature Sensors:
RTDs – Potential Problems
Process temperature stratification / “swirling”Cracked thermowellIntrusion of chemicals from connection head into thermowell Cracked or open sensing element Thi i f th RTD l ti i f h i l ti
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Thinning of the RTD platinum wire from chemical reactionWrong calibration tables (configuration control)Inadequate dynamic response Failure of extension lead wires Low insulation resistance between RTD lead and groundLoose or bad connections.Imbalance in lead wire resistance.
Temperature Sensors: T/Cs
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Temperature Sensors: T/Cs – Potential Problems
Cable/connector problems
EMI from incorrect grounding / multiple grounds / routing
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Reverse connection
Long-term degradation of response time from aging
Temperature Sensors: Attributes
RTDs
IEEE Std 603 and supporting standards, including IEEE Stds 323, 336, 338, 344, 379, 384, 420, 497, 498, 572, etc., if safety related
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, , , y
Shielded / twisted quad wiring
Single point ground
Loop current step response (LCSR) test
Temperature Sensors: Attributes
For RTDs used as protection system inputs (e.g., Thot, Tcold), the installation of a calibrated RTD should include a test procedure to demonstrate the response time applicability of the laboratory test results.
Loop current step response (LCSR) testing is an acceptable way to
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Loop current step response (LCSR) testing is an acceptable way to verify that the conditions of the installed RTD are adequately correlated to the laboratory test data.
Response time testing of the installed RTDs using LCSR should use an analytical technique such as the LCSR transformation identified in NUREG-0809, “Review of Resistance Temperature Detector Time Response Characteristics,” to correlate the in-situ results with the results of a laboratory-type temperature test.
Temperature Sensors: Attributes
Core Exit Thermocouples
IEEE Std 603 and supporting standards, including IEEE Std 323, 336, 338, 344, 379, 384, 420, 497, 498, 572, etc.
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Type K (Chromel-Alumel) is typical for core exit temperatures
Shielded / twisted pair, single point ground
Mineral insulated (MI) cable for harsh environment
Pressure Sensors
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Pressure Sensors: Attributes
Proper slope and configuration of sensing (impulse) line
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Static head correction
Pulsation dampeners
Freeze protection
Flow Sensors – DP Type
A Orifice
B Venturi
C Flow nozzle
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D Pitot Tube (velocity head)
E Elbow Taps
Flow Measurement Regimes
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Flow Sensors – Orifice
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Flow Sensors – Pitot Taps
Pitot tubeVelocity head
Impact port (upstream)
Static (stagnant) port (downstream)
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Static (stagnant) port (downstream)
Commonly used for airflow
Annubar™ uses Pitot principle, reconfigured using multiple impact ports
Sometimes used for raw service water
Like Pitot tube, can plug up
Flow Sensors – DP Sensing Line Issues / Features
Leaks
Trapped gas in liquid lines
Liquid in gas lines
Diff i l / d i i
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Differential temperatures / densities
Tube track / seismic supports
Thermal expansion loops
Flow Sensors – DP Sensing Line Installation
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Flow Sensors – DP Sensing Line Issues
For liquid, slope sensing (impulse) lines at least 1 inch per foot upward from the transmitter toward the process connection
For gas / steam, slope sensing lines downward from the transmitter toward the process connection
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p
Avoid high points in liquid lines and low points in gas lines
Both sensing legs should be at the same temperature
Vent all gas from liquid sensing lines
Flow Sensors – DP Sensing Line Issues
When using a sealing fluid (e.g., steam service), fill both legs to the same level.Corrosive or hot process material should not make direct contact with the sensor module and flanges.Prevent sediment deposits in the impulse piping (tap li id f th id f th i t / t f th
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liquids from the side of the pipe; tap gas / steam from the top or side of the pipe).Plug and seal unused conduit connections on the transmitter housing to avoid moisture accumulation in the terminal side.For harsh EQ environments, qualified environmental seals are required.
RG 1.151 / ISA 62.02.01 – Sensing Lines
RG 1.151 accepts the recommendations of ISA 62.01.02, Nuclear Safety-Related Instrument Sensing Line Piping and Tubing Standard for Use in Nuclear Power Plants with exceptions and clarifications;
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Plants, with exceptions and clarifications; sampling lines are not included in the RG basis.
Selected (highlights) guidance follows
RG 1.151 / ISA 62.02.01 – Sensing Lines
A single process pipe tap to connect process signals to redundant instruments should not be used.
If a single process connection cannot be avoided, justification shall be provided to permit its use. J tifi ti h ll dd th d ff t f
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Justification shall address the common mode effects of both plugging and breakage.
Instrument-sensing lines shall be routed such that no single failure can cause the failure of more than one redundant sensing line unless it can be demonstrated that the protective function is still accomplished.
RG 1.151 / ISA 62.02.01 – Sensing Lines
In hostile areas subject to high-energy jet stream, missiles, and pipe whip, the routing of redundant sensing lines shall be documented with analysis or calculations as necessary to prove that the routing protects the redundant sensing lines from failure due to
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a common cause.
Instrument-sensing lines shall be run along walls, columns, or ceilings whenever practical, avoiding open or exposed areas, to decrease the likelihood of persons supporting themselves on the lines or of damage to the sensing lines by pipe whip, missiles, jet forces, or falling objects.
RG 1.151 / ISA 62.02.01 – Sensing Lines
Routing of the nuclear safety-related sensing lines, except capillary lines, shall ensure that the function of these lines is not affected by the entrapment of gas (liquid-sensing lines) or liquid (gas-sensing lines).
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( q g ) q (g g )New designs and redesigns should consider instrument location early in the design process to eliminate the need for high point vents or low point drains while maintaining sensing line slope.
RG 1.151 / ISA 62.02.01 – Sensing Lines
Where adequate slope requirements cannot be maintained and it is not feasible to relocate the instrument so that adequate slope can be maintained, a high point vent for liquid measurement or a low point drain for gas measurement should be provided to ensure that all trapped gas or liquid can be purged from the sensing line.
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g
Potential inaccuracies in water level indication during and after rapid depressurization events have been identified as industry concerns and shall be considered. Inaccuracies result from noncondensable gases collecting in the condensate pot (chamber) of instrument reference legs and migrating down the reference leg.
RG 1.151 / ISA 62.02.01 – Sensing Lines
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RG 1.151 / ISA 62.02.01 – Sensing Lines
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Differential Pressure (DP) Cell
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Flow Sensors – Other Types
Ultrasonic (clamp-on for testing)
Magnetic (boric acid)
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Flow Sensors – Ultrasonic (Panametrics)
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Flow Sensors – Magnetic
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Flow Measurement: Attributes
Sufficient upstream and downstream unobstructed straight run for repeatable flow conditions (head type and ultrasonic)
Primary element accuracy
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Proper configuration / slope of impulse lines
Temperature (density) correction for operation at substantially higher temperature (e.g., measured RHR flow used for acceptance test )
Pulsation dampeners – possible effect on measurement
Flow Measurement: References*
ASME Fluid Meters
Liptak, Bela G., Instrument Engineers Handbook, Chilton Book Co.
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ISA 67.04 Part 2
* These can be useful technical references, but they do not necessarily represent NRC regulatory requirements or guidance, or licensing commitments.
Level Instrumentation
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Level Instrumentation (dp) – Vented Vessel
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Level Instrumentation (dp) – Closed Vessel
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Level Instrumentation (dp) – Closed Vessel – Steam
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Level Measurement: Attributes
Closed vs. vented vessel
Effect of reference leg heatup
Configuration of condensing chambers (“pots”)
Effect of vortexing
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Effect of velocity head at dp tap in pipe (rather than vessel tap)
Heat tracing
Non-condensable gases in reference leg (e.g., VCT level)
Position Indication
Valve position (open/close)Stem actuated limit switch
Typical for air operated valves
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Gear actuated limit switchTypical for motor operated valves
Used for status lights and interlocks
A/D Converter
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A/D Converter (ADC)
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A/D Converter
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A/D Converter - Attributes
Relative accuracy
Conversion time
Linearity
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Power supply sensitivity
Temperature coefficients
Sampling rate
Student ActivityCritical Attributes Matrix
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I&C Components
I&C Components Critical Attributes
Component Critical Attribute(s)
Sensors
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Signal Conditioning
A/D Converters
Bistables / Comparators
Displays and Alarms
I&C Components: Sensors
Nuclear instruments
Process instruments- Temperature
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- Pressure- Flow- Level
- Position
7. I&C Structures, Systems and Components Objectives Review
Identified the major I&C structures, systems, and components
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Provided a general overview of the purpose of these SSCs
Discussed how these SSCs relate to new reactor inspection
QUESTIONS ?
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