turbine integration - sales training

8/8/2019 Turbine Integration - Sales Training

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Turbine Integration - Sales Training - May 2003Confidential & Proprietary

Integration with turbine control systemsIntegration with turbine control systems

http://web.iac.sea.honeywell.com/IS/OPCMark/default.asp

Sales TrainingSales Training

For centralized monitoring & control of the whole plant

Presenter: Sambasivam, Hariharan (SN01)Presenter: Sambasivam, Hariharan (SN01)


AgendaAgenda

GE turbines (OPCMark - using GE proprietary GSM protocol)

Alstom/ABB turbines (OPCBridge - using OPC protocol)

Need for integrating turbine control system with DCS

Limitations of MODBUS & why use GSM or OPC protocol?

Typical integration architecture with TPS or Experion

Integration feature summary

Product Technical Overview

Opportunity Identification

Beating Competition


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The need for integration turbine controls with DCSThe need for integration turbine controls with DCS

FUELSYSTEMS

ELECTRICALDISTRIBUTION

SYSTEMS

WATER, WASTEWATER

TREATMENT

HEAT RECOVERYSTEAM

GENERATOR HRSG

TURBINE

CONTROL

Main DCS

BOP

Single w indow to entire plant process

Supervisory control functionsStart-up and shutdown sequences

Speed & Load controlAutomatic synchronizationRemote turbine alarm acknowledgment

HRSG and BOP control

Consolidation of alarms and events(SOE) in

one console

Plant efficiency calculations

UTILITIES,THIRD-PARTY

SYSTEMS

MODBUS

New GSM / OPC


MODBUS Vs GSM / OPC protocolMODBUS Vs GSM / OPC protocol

MODBUS does not transmit alarm and event data (SOE) as they occur and hence turbineSOE data were not available in DCS for consolidated supervision and analysis. GSM / O P Csupports alarm and event (SOE), a key need in pow er generation

Scaling of decimal values to integers and re-conversion at receiving end results in lossof accuracy. GSM/ OPC transmits decimal values directly.

DCS serial ports: DCS should dedicate 2 serial ports (dual) for each turbine controller .Thus, for 4 controllers, DCS would require 8 ports. Note: Daisy chaining would affecttransfer rates, hence not recommended. GSM/OP C is on Ethernet and hence not an issue.

Master-slave: Only one MODBUS master can be talking to a MODBUS slave at anyinstance. GSM/ OPC is client-server and allows multiple hosts to access it

simultaneously. This helps in redundancy and load balancing.

Transmission rate - Serial comms has baud rate limitations (56Kb); Ethernet provideshigh speed 10Mbaud rate. This particularly helps to transfer large throughputs i.e.1000-

2000 parameters / sec. Asynchronous data transmission helps this. No pol l ing

Turbine alarms at GEs HMI server (or Alstom/ABB OPC server) acknowledged at DCSconsole - MODBUS does not do this while GSM/OPC protocol supports this.

Limitations of MODBUSLimitations of MODBUS


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UDH B(Arcnet

/Ethernet)

UDH B(Arcnet

/Ethernet)

UDH A(Arcnet

/Ethernet)

UDH A(Arcnet

/Ethernet)

GEs HMI

server A

GE / Alstom / ABBturbine controllers

APP node 1 (OPC server) APP node 2 (OPC server)

OPCMark/OPCBridge(Primary & Backup)

OPCMark/OPCBridge(Primary & Backup)

Block 1

Dual Ethernet

LCN (DCS)

GT1 GT2 ST1

Block 2

GT3 GT4 ST2

GEs HMI

server B

GEs HMI

server C

GEs HMI

server D

APP node 4 (OPC server)APP node 3 (OPC server)


Alstom / ABB

OPC servers

Alstom / ABB

OPC servers

Typical turbine integration architecture in TPSTypical turbine integration architecture in TPS


UDH B(Arcnet

/Ethernet)

UDH B(Arcnet

/Ethernet)

UDH A(Arcnet

/Ethernet)

UDH A(Arcnet

/Ethernet)

GEs HMI

server A


OPCMark/OPCBridge

(Primary & Backup)

Block 1

Dual Ethernet

FTE

GT1 GT2 ST1

Block 2

GT3 GT4 ST2

GEs HMI

server B

GEs HMI

server C

GEs HMI

server D


Alstom / ABB

OPC servers

Alstom / ABB

OPC servers

Experion PKS

servers A/B

Typical turbine integration architecture in ExperionTypical turbine integration architecture in Experion


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Integration summaryIntegration summary

Bi-directional integration between DCS and GEs HMI server or Als tom/ABBOPC server (e.g. GSM->DCS and DCS->GSM point mappings - analog and digital)

Grouping of points for periodical data (different interval)

Integration of points from multiple turbine controllers through a commonHMI server

OPCMark supports both Mark V and M ark VI type of GE turbine controllers(GSM protocol is different)

Redundancy at multiple levels ( OPC server, HMI server, Ethernet etc)

Fetching alarm and event ( SOE) data from turbine controllers andconsolidation at DCS (traditionally, trip contacts are duplicated to a separate SOE

instrumentation rack)


Integration summary (continued)Integration summary (continued)

Alarming in DCS when any controller or active HMI server/ OPC server fails.(Automatically switches over to the backup HMI/ OPC server)

Alarming in DCS when OP CMark or OPCBridge application itself fails. (Thepartner OPCMark or OPCBridge takes over)

Daily trouble-shooting logs - activity and error information

User-friendly OPCMark/ OPCBridge configuration tool w ith Excelexport/import

Automatic detection of recovery of failed controller (avoids cumbersomemanual verification or re-registration process)


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Examples of events Changes in process alarm state.

Changes in digital input (SOE card).

Software detected changes in pre-

defined Boolean variables.

Dead-band crossings detected in pre-

defined analog variables.

Changes in control ler alarm (diagnostic)

state.

Alarm Events (62 msec)

Digital Input Events (1 msec - SOE)

Software Events (62 msec)

Turbine alarms and events (including SOE)Turbine alarms and events (including SOE)


OPCMark main screen (for GE turbines)OPCMark main screen (for GE turbines)

Guard House


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OPCBridge main screen (for Alstom/ABB turbines)OPCBridge main screen (for Alstom/ABB turbines)

Guard House


How does it look in DCS?How does it look in DCS?

H200

OPCMark OperatorInterface

Area Alarm Summary Process & Turbine graphics (Level 2)

MiscellaneousOperator Work Area

Turbine Load Control &Process (Level 2)

Control PointManipulation (Level 2)


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Turbine Graphic TemplatesTurbine Graphic Templates

Around 25 gas and 25 steam turbine graphics templates (GUS / HMIWeb)replicated from GE or Alstom turbine graphics

Gives a jumpstart in turbine graphic engineering rather starting from

scratch (quickens engineering time)

Standardizes and maintains uniformity across various sites

Modification work involves tag mapping, other minor functions


Current OPCMark ReferencesCurrent OPCMark References


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Current OPCBridge ReferencesCurrent OPCBridge References


Opportunity IdentificationOpportunity Identification

Any site having or requiring power generation facilities

Electric utilities IPPs (independent power producers)Co-generation needs in refineries and other HPI/chemicals plants

(Majority of our installed base has cogeneration needs)

Role of DCS is greater in combined cycles due to complex processes

New projects

Retrofits and upgrades (obsolete technology, expansions etc)

Alliances with turbine manufacturers ie. GE, Alstom and ABB, Siemens

Awareness with EPC contractors (Chiyoda, Toyo, JGC, IHI, Samsung, Hyundai etc

Contractors, GE/ABB/ Alstom & end-customers have started insisting/specifying

GSM or OPC protocol based integration with DCS.


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Existing Honeywell sites using GE turbinesExisting Honeywell sites using GE turbines

Arizona Public Service Palo Verde 1,2,3 Oklahoma Gas&Electric Sooner 1,2

Basin Electric Power Coop. Laramie River 1,2,3 Pacific Power & Light Jim Bridger 1,2,3,4

Consumers Power Dan E. Karn 3,4 Pennsylvania Electric Conemaugh 1,2 1994

Cooperative Pwr Assoc. Coal Creek 1,2 Pennsylvania Power Mansf ield 1,2,3 1993

Dayton Power & Light Stuart 1,2 Potomac Electric Chalk Point 3,4 1991

Florida Power Corp. Crystal River 12,4,5 Public Service Co. of NM San Juan 3,4

Florida Power Corp. Anclote 1,2 Public Service E & G Hope Creek 1 1994

Illinois Power Co. Baldwin 3 Salt River Project Navajo 1,2,3 1996

Iowa Power & Light Council Bluffs 3 San Antonio CPS Braunig 3 2001

Iowa Southern Util. Co. Ottumwa 1 Southern California Ed. Etiwanda 3, 4 2001

Kansas City Power & Light LaCygne 1,2 1995 Southwestern Pub Service Nichols 3

Kansas City Power & Light Iatan 1 Tampa Electric Big Bend 1,2,4

Louisville Gas & Electric Mill Creek 1,2,3,4 1997 Texas Utilities Elec Co. Lake Hubbard 2 1994

Mississippi Power & Light Gerald Andrus 1 Tri-State G&T Assn Inc. Craig 1,2,3 2001

Nebraska Pub Pwr Dist Gentleman 2 1996 Wisconsin Elec Pwr Co. Oak Creek 7,8New England Power Brayton Point 1,2, 4 1994 Wisconsin Pwr & Light Columbia 2

Northeast Utilities Montville 6 Wisconsin Public Svc Pulliam 3,4,5,6,7,8 1990

Ohio Edison/Penn Power Mansfield 2,3,1

International Spain

Tata Electric, India Trombay 6 Empresa Nacional De Elect Almeria 1,2

Puerto Rico Water Resources South Coast 1&2 Hidroelectrica Espanola S.ACastellon 1&2


Beating CompetitionBeating Competition

Gives Honeywell a competitive edge in main DCS bidding

Proven and standard product (reference list,commendation letters)

Standard product, hence lower cost than other DCS bidders andannual product support (turbine integration is mission critical )

Ready off the shelf, plug and play type interface

Matrikon is the only known competitor providing a similarfunctionality for GE (but lacks redundancy & cannot work di rect ly withTPS or Experion PKS - requires another middleware)


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ContactContact

Hariharan S

Email : Sambasivam, Hariharan (SN01)

T e l : 6 5- 65 80 33 76 (Si ngapor e - GM T + 8 h ou rs )

Sales & Technical Support: How we can help?

Technical Support,

Budgetary estimates,

Proposal generation,

Customer presentations

http://web.iac.sea.honeywell.com/IS/OPCMark/default.aspProduct information:

Thank YouThank You

turbine integration - sales training

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