pre-study and system design of a mobile platform simulator system1518885/... · 2021. 1. 17. ·...

EXAMENSARBETE INOM ELEKTROTEKNIK, GRUNDNIVÅ, 15 HP

STOCKHOLM, SVERIGE 2018

Pre-study and system design of a

mobile platform simulator system

Förstudie och systemdesign för ett mobilt simulatorsystem

LUIS KATEWA

KTH

SKOLAN FÖR KEMI, BIOTEKNOLOGI OCH HÄLSA

Pre-study and system design of a

mobile platform simulator system

Förstudie och systemdesign för ett

mobilt simulatorsystem

On behalf of Siemens Industrial Turbomachinery AB

Luis Katewa

Degree Project in Electrical Engineering, First Cycle 15.0 Credits Supervisor at KTH: Elias Said Examinator: Thomas Lindh TRITA-CBH-GRU-2018:55 KTH Skolan för kemi, bioteknologi och hälsa

Hälsovägen 11C

Sammanfattning

Det finns många sätt att producera energi, genom användning av exempelvis gas- eller hydroturbiner. För att garantera en stabil produktion är det viktigt att noga överväga kom-ponenter, som kan styra och justera uteffekten automatiskt.

Avsikten med detta arbete är att göra en förstudie och systemdesign av ett simulatorsystem som kan användas av företag som Siemens, med avsikt att hjälpa dem att minska sin drifts-kostnad (OPEX), och lättare kunna utvärdera sina AVR-lösningar (Automatic Voltage Re-gulator) och möjliga testförbättringar. För detta arbete har Siemens bestämt att kalla syste-met för ett mobilt simulatorsystem eller MPSS (Mobile Platform Simulator System).

Förstudien innehåller teorin bakom energiproduktion, synkrongenerator generator, simula-torsystem, AVR, styrsystem och elnät. Ett urval av de olika komponenterna för simulator-systemet och en slutgiltig design tas fram. Det kompletta simulatorsystemet kommer i ett senare skede att byggas av forsknings- och utvecklingsingenjörerna på Siemens.

Simulatorsystemet är avsett att testa AVR-prestanda, vilket är en komponent vars huvud-sakliga syfte är att upprätthålla utspänningsvärdena från en generator inom ett fast inter-vallvärde, oberoende av vilken effekt som en last drar. Det är viktigt att utgångsvärden ständigt regleras under elproduktionsprocesser så att utgångsvärden hålls inom systemets tillåtna gränser så att problem som över-/underspänning, över-/underström, över-/underfrekvens etc. kan förhindras.

Simulatorsystemet kommer också att kunna simulera verkliga arbetsscenarier för olika komponenter i ett energiproduktionssystem, såsom gas- och hydroturbin, synkrongenerator, AVR och laster, exempelvis elnät, samt kunna användas vid personalutbildning.

Simulatorsystemet kommer att bestå av tre huvudkomponenter; Simulator, AVR och styr-system. Inledande beskrivning av arbetets bakgrund och allmän teoretisk kring komponen-terna synkrongenerator, AVR och styrsystem, som används vid i kraftgenereringssystem, ges. Även en allmän bakgrund om elnätet och dess funktion presenteras. Därefter presente-ras förslag på bästa möjliga val av nödvändiga komponenter för att bygga ett simulatorsy-stem. Ett förslag om hur händelsesimulering görs samt vilken nödvändig dokumentation och kretsdiagram som behövs för att bygga ett simulatorsystem presenteras.

I slutet av detta arbete presenteras en allmän analys av de tekniska och icke-tekniska aspekterna kring val av komponenter, arbetsprocess samt metod och resultat.

Nyckelord

Automatisk spänningsregulator, styrsystem, synkrongenerator, gasturbiner, PID-kontroll, simulator.

Abstract

There are many ways to produce energy, using e.g. gas or hydro turbines. To guarantee a stable power output, it is important to consider components that could control and adjust the output power automatically.

The intention of this thesis work is to carry out a pre-study and system design of a mobile platform simulator system that could be used by companies like Siemens and help them to reduce their OPEX (Operational expenditure) and easily evaluate their AVR (Automatic Voltage Regulator) solutions and test improvements. In this document, Siemens has decid-ed to call the simulator system, MPSS (Mobile Platform Simulator System).

The pre-study includes the theory behind energy production, synchronous generator, simu-lator system, AVR, control systems and electrical grid. Furthermore, the pre-study includes selection of the proposed components for the simulator system and design of the complete simulator system that will be built by the Siemens R&D engineers at a later stage.

The Mobile Platform Simulator System (MPSS) is intended to test the AVR performance, which is a component with its’ prime purpose being to maintain the output voltage values from the generator at a fixed value, regardless of the current being drawn by the load. It is important that these output values are constantly regulated during the process of producing electricity, so that problems such as overvoltage, overcurrent etc. can be prevented.

The MPSS will also be able to simulate real working scenarios e.g. from the different com-ponents of an energy production system, such as gas and hydro turbine, synchronous gener-ator, AVR, electrical grid and serve for personnel training.

The MPSS will consist of three main components; Simulator, AVR and control system. Therefore, the report will initially provide the background and general theory behind the synchronous generator, AVR and control system used in power generation systems. Gen-eral information about the electrical grid is also provided. Furthermore, the report suggests the best possible choice for the necessary components to build a MPSS as well instructions on how to perform event simulation. The necessary documentation, including a circuit dia-gram to support the building of the MPSS by the R&D engineers at late stage, is also pro-vided.

Finally, the general analysis of the technical and non-technical aspects related to the choice of components, work process, method and result are discussed in the end of this report.

Keywords Automatic voltage regulator, control systems, synchronous generator, gas turbines, PID control, simulator.

Preface

This thesis work has been performed at Siemens as part of the final project in electrical and electronic engineering at KTH- Royal Institute of Technology. To fully understand the con-tent of this report, a basic knowledge of electricity, simulator, excitation and control sys-tems is required.

The opportunity to have worked at such an established and successful company as Siemens has provided me with general knowledge on how the complex and fascinating world of engineering works. I have had the opportunity to share the office and work side by side with well-experienced engineers, which has considerably enriched me personally and pro-fessionally. I must say that I have chosen the right profession.

I am glad to have been offered the opportunity to work on this project, therefore I want to thank Siemens who have trusted me with this assignment and provided the available re-sources to conduct this pre-study. I want also to thank both my supervisors Epaminondas Sotiriadis at Siemens and Elias Said at KTH and everyone at Siemens R&D Department for their engagement and guidance.

Finally, I want to thank my friends, relatives and especially my daughter, Matilda Biegler Katewa.

Luis Katewa

Stockholm 2018

Table of contents

1 Introduction ............................................................................................................................................ 1

1.1 Problem definition ........................................................................................................................... 1

1.2 Goal ................................................................................................................................................ 1

1.3 Delimitation .................................................................................................................................... 1

1.4 Expected result ................................................................................................................................ 1

2 Background and theory .......................................................................................................................... 3

2.1 Synchronous generator ................................................................................................................... 4

2.1.1 General description ............................................................................................................... 4

2.1.2 Basic principles of the synchronous generator ...................................................................... 6

2.1.3 Synchronous generator main components ............................................................................. 7

2.1.4 Excitation systems and limiters ............................................................................................ 11

2.1.5 Synchronous generator protection ....................................................................................... 15

2.2 Automatic voltage regulator ........................................................................................................... 18

2.2.1 General description .............................................................................................................. 18

2.2.2 Basic principles of the AVR .................................................................................................. 19

2.2.3 Variants of AVR systems ..................................................................................................... 20

2.2.4 AVR main components ......................................................................................................... 21

2.3 Control system ............................................................................................................................. 24

2.3.1 General description ............................................................................................................. 24

2.3.2 Basic principles of the control system ................................................................................. 25

2.3.3 Control system main components ....................................................................................... 26

2.4 Electrical grid ............................................................................................................................... 27

2.4.1 General description ............................................................................................................. 27

2.4.2 Basic principles of the electrical grid .................................................................................. 27

3 Mobile platform simulator system (MPSS) ........................................................................................... 29

3.1 Purpose of the MPSS .................................................................................................................... 29

3.2 General description ....................................................................................................................... 29

3.3 Basic principles of the MPSS ........................................................................................................ 30

3.4 MPSS main components ............................................................................................................... 30

3.4.1 Simulator ............................................................................................................................. 30

3.4.2 Automatic voltage regulator ................................................................................................ 38

3.4.3 Control system ..................................................................................................................... 44

4 Method and result ................................................................................................................................ 53

4.1 Setting the requirements ............................................................................................................... 53

4.1.1 Requirements elicitation ...................................................................................................... 53

4.1.2 Requirements specification .................................................................................................. 54

4.1.3 Requirements validation ...................................................................................................... 54

4.2 Project management ...................................................................................................................... 55

4.3 System design ............................................................................................................................... 55

4.3.1 MPSS electrical cabinet ....................................................................................................... 55

4.3.2 Communication architecture ............................................................................................... 56

4.3.3 Circuit diagram .................................................................................................................... 57

4.4 Event simulation on the MPSS ...................................................................................................... 57

4.4.1 Cascade parameter settings for generator event ................................................................. 58

4.5 Price for the MPSS components .................................................................................................... 60

4.6 MPSS documentation .................................................................................................................... 60

4.7 Result ........................................................................................................................................... 60

5 Analysis and discussion ....................................................................................................................... 63

5.1 General aspects ............................................................................................................................. 63

5.2 Simulator choice ........................................................................................................................... 63

5.3 AVR choice .................................................................................................................................. 64

5.4 Control system choice ................................................................................................................... 64

6 Conclusion .......................................................................................................................................... 65

6.1 Recommendations ......................................................................................................................... 65

7 Bibliography ........................................................................................................................................ 67

8 Appendix .............................................................................................................................................. 71

1 | INTRODUCTION

1 Introduction

1.1 Problem definition The R&D (Research and Development) Department at Siemens Industrial Turbomachinery AB is today unable to perform the tests in its facilities. This is because the R&D Depart-ment doesn’t own a simulator system and has been relying on services from an external company instead. This has presently lead the R&D Department to face the following is-sues:

The automatic voltage regulator (AVR) could be only tested on site. Being dependent on external companies to perform the tests on the AVR,

each time such is required e.g. an upgrade is done. Increased costs for the external personnel and rental of equipment. Could take longer to identify and solve errors on site.

In order to tackle these issues, the R&D Department at Siemens, Finspång has decided to take the necessary steps to build its own simulator system.

1.2 Goal

A pre-study and analysis that will result in a system description of a Mobile Platform Simulator System (MPSS), that will be used to test the AVR perfor-mance and serve for personnel training purposes.

1.3 Delimitation The scope of this thesis does not involve programming tasks nor building a prototype. It is a pre-study and research work that will permit building a Mobile Platform Simulator Sys-tem at a late stage by the R&D Department.

The simulator is intended to test the automatic voltage regulator from ABB called Unitrol 1020 AVR, already owned by the R&D department.

The Mobile Platform Simulator System will have to be operated by Siemens control system called SIMATIC PCS7.

A final report will be written, published and presented both at Siemens Industrial Turbomachinery AB and KTH- Royal Institute of Technology. However, the confi-dential information highlighted by Siemens will not be available in the report to be submitted at KTH.

1.4 Expected result The expected result is a full report containing the information, documentation and guidance on how to build a Mobile Platform Simulator System (MPSS) that will have the following characteristics:

A more automated test procedure and simulator system that performs tasks

much faster and more efficiently than currently.

2 | INTRODUCTION

Mobile Platform Simulator System that is reliable, flexible and can be

moved and used in different locations.

Used for personal training purposes.

Information and instructions on how to simulate real life scenarios, for in-

stances errors.

Analysis of the economic and other non-technical aspects will be included in this thesis work.

3 | BACKGROUND AND THEORY

2 Background and theory

Gas turbines are important for power generation, transportation and other applications. To-gether with a synchronous generator and the AVR this can be applied in energy production at a lower cost and be beneficial for the environment. The details regarding these compo-nents are described during the course of this chapter. Based on this, together with Siemens, this report has been produced, which will help the R&D Department to build a Mobile Plat-form Simulator System to test the AVR performance, simulate real working scenarios, for instances errors, and be used for training purposes.

Siemens Industrial Turbomachinery AB is a company based in Finspång, Sweden and has its focus on manufacturing, development and service of gas turbines, which represent the main component for a gas turbine power generation system to produce electricity.

For the gas turbine power generation system to produce and deliver a stable energy with correct frequency, the output values from the generator, for instance the voltage have to be regulated, monitored and maintained before sent to the electrical grid. The AVR is the hardware that carries out the regulation of the output values from the generator by means of amplitude, so that typical problems such as under- or overvoltage, overexcitation, electrical grid oscillations etc. can be prevented and solved.

The R&D Department at Siemens Industrial Turbomachinery AB is responsible for per-forming tests on the AVR unit supplied by the company ABB. These tests are performed each time an upgrade is made on the AVR unit, so that the device can adapt to Siemens products demands, for example the gas turbines and control systems developed by the com-pany. The tests are mainly intended to improve the AVR performance by upgrading and testing the new parameters of the AVR.

The development of a simulator system that can be owned by the R&D Department can be used to perform these tests contributing to reduce overall site testing-time, costs and offers potential for improved commercial operations. Additionally, the simulator system can be suitable for hands-on training of commissioning and maintenance personnel plant opera-tions and will be used to train R&D engineers.

This pre-study contains the required information for the R&D Department to build the MPSS (Mobile Platform Simulator System) at a later stage. More details of the MPSS are described in chapter 3.


2.1 Synchronous generator

2.1.1 General description The three-phase synchronous generator is a machine used in the vast majority of power plants, including gas turbine power plants. The main purpose is to convert the mechanical energy delivered for example by the gas turbine into electrical energy through the process of electromagnetic induction.

A synchronous generator consists of a base frame and a rotor. The base frame contains the stator and the bearing pedestals. The cylindrical bearing carries the rotor. In some cases, such as larger generators, an additional support bearing can be installed outside the exciter machine. A cooler, which can be mounted on the base frame, can cool the generator. An example of a synchronous generator can be seen in figure 2.1.

Figure 2.1: Synchronous generator [1].

1- Rotor. 2- Base frame. 3- Stator. 4- End shaft.


Two laws define the conversion of mechanical to electrical energy:

1. Law of electro magnetic induction

Known as Faraday’s first law of electromagnetic induction, this is related to the production of EMF (Electric magnetic field). This is processed by induced EMF in a conductor when-ever the magnetic field is cut across.

2. Law of interaction

The interaction law is related to the production of force or torque. When a current carrying conductor is placed in the magnetic field, through the interaction of the magnetic field, pro-duced by the current carrying conductor and the main field, a force is applied on the con-ductor producing torque.

The synchronous machine operation depends on the following relationship and will always keep the above relationship when it’s connected to an electrical power system, as illustrated in table 1 and equation (1).

Table 1: Synchronous operation machine relationship.

Ns =��∗�

� (1)

f– Frequency (Hz).

Ns – Synchronous speed (rpm).

P – Number of poles.


When the synchronous generator is connected to the network, it runs with a fixed speed, which is usually called the synchronous speed (Ns) to generate the power at specifc fre-quency f (Hz). In Europe and several other countries the frequency is either 50Hz or 60Hz as illustrated in figure 2.2 [2].

Figure 2.2: Countries and respective frequencies [3].

The synchronous generator used in gas turbine power plants generally consists of two mag-netic poles and rotates at 3000 or 3600 rpm at frequencies of 50Hz and 60Hz respectively.

2.1.2 Basic principles of the synchronous generator The gas turbine is one of the components used as a driver to provide the necessary mechan-ical energy to the synchronous generator. After the mechanical energy has been supplied to the generator, the rotor, the function of which is to produce the magnetic rotating flux starts to rotate. The armature coils are stationary and when the magnetic rotating flux associates with rotor rotation, it induces electricity on the armature coil.

An example of an electrical machine principle can be seen in figure 2.3.

Figure 2.3: Electric machine principle [4].


The figure shows two magnet poles N and S. The rotation is either at 3000 or 3600 rpm at frequencies of 50Hz and 60Hz respectively. The stationary armature coil (marked with blue and red colours) rotates anti-clockwise. Two slip rings that can be excited with DC power and carbon brushes used to carry current are also displayed. Rotor coils can be excited with DC power, whether from an external power source or DC generator fitted on the same shaft. This in combination with rotor rotation will produce what is called EMF. In the case of using the gas turbine as the driver, since the rotor and the gas turbine are coupled with a common shaft, the rotor rotates with the mechanical energy delivered by the gas turbine. This causes the rotor flux also to rotate along with it at the same speed. Then the revolving magnetic flux (light blue arrows) intercepts the armature coil, which is fitted around the rotor and this generates alternate EMF across the winding [5].

2.1.3 Synchronous generator main components A synchronous generator is normally built using 6 main components:

Stator Rotor Bearings Cooling circuit Water-cooled exchangers Instrument and monitoring

The following sections will describe each of these components and their main purpose on a synchronous generator.

2.1.3.1 Stator The stator as illustrated in figure 2.4, consists of the core that is supported in the base frame by means of guide bars and rings. The stator core is made of electrical steel in form of insu-lated laminations, which are stacked together, preventing the flow of eddy currents in the core. The core has slots to which the windings of the core are placed. The windings are made of copper.

Figure 2.4: Stator core [6].


2.1.3.2 Rotor The rotor of a synchronous machine as illustrated in figure 2.5, consists of a number of poles and two shaft ends. The number of poles depends on the desired synchronous speed of the machine. The difference between the number of poles and frequency and the given synchronous speed (Ns) is defined by Ns = 120 x f/P, as mentioned above in formula 1.

Figure 2.5: Typical rotor for synchronous generator [7].

The rotor of the synchronous machine is classified in two categories: Non-salient pole rotor or salient pole rotor, as illustrated in figures 2.6 and 2.7.

Figure 2.6: Cross sectional of non-salient pole rotor Figure 2.7: Cross sectional of Salient pole rotor [8].

The salient pole rotor consists of a number of projected poles (protruding poles) mounted on a magnetic wheel. A salient pole rotor is characterized by large diameter and short axial length. It is generally used in low speed (100 to 1500 rpm) electrical machines, where the prime mover is a turbine or combustion engine with low, medium or high speed with the help of gears. For example, the gears can reduce the speed of a turbine from 7000 rpm to 1500 rpm.

The non-salient rotor consists of a cylinder made of solid steel. The slots on which the windings are fixed are milled on the rotor. The non-salient pole rotor generally has 2 or 4 poles and is generally used in high-speed machines, usually 1500 and 3000 rpm at 50Hz and 1800 and 3600rpm at 60Hz. It can also be used in higher speed machines over 3600 rpm with the help of gears that can reduce the high speed down to 3600 rpm [9].


2.1.3.3 Bearings The bearings of a synchronous machine can be of pedestal type and they are mounted on the generator base frame. The bearings brushes are generally split on the horizontal centre line so that inspections and removal services can be carried out easily. An example of a shaft bearing is shown in figure 2.8.

Figure 2.8: Generator shaft bearing [10].

2.1.3.4 Cooling circuit The heat loss arising in the interior of a synchronous generator is generally dissipated through air. The rotor is directly air-cooled and the heat losses are transmitted directly from the winding copper to the cooling air. Indirect air-cooling is normally used for the stator winding. The generator’s cooling air is drawn by axial-flow fans, which are arranged on the rotor via lateral opening in the stator housing.

A cooling airflow as illustrated in figure 2.9, can be divided into three flow paths:

Into the rotor end winding space for cooling the rotor winding. Over the stator end windings to cold air ducts. Into the cold air compartments in the stator frame space between the generator hous-

ing and the stator core.

Figure 2.9: Generator cooling airflow [11].


2.1.3.5 Water-cooled exchangers The tubular type water-cooled heat exchanger section can be provided with a generator. The nests, which are thermostats to keep the generator within a preferred temperature range, are normally aligned so that the generator can deliver 67% output with one nest out of service for maintenance or repair. The cooler nest can be equipped with ventilation and drain valves. The cooler nests are normally provided with a drip tray, which are then con-nected to a leakage detector.

The complete cooler housing depends on the generator size and can be located on the top or on the side of the generator. The water cools the air circulating inside the generator.

However, there are more cooling systems available, such as:

Open ventilated where the ambient air is used directly for cooling. Air-to-air cooler where the internal air is cooled by the ambient air through a top

mounted tube heat exchanger. Hydrogen cooled generator.

For more details, see reference [12].

2.1.3.6 Instrument and monitoring These are instruments used on large generators with the main purpose being to oversee and protect the generator. These instruments are mainly temperature detectors for temperature monitoring and sensors for measuring of seismic or/and shaft vibration, as illustrated in figure 2.10.

1 2

3

Figure 2.10: Example for the typical arrangement of the instrument and monitoring [13].

1. Continuously monitors the stator windings for PD (Partial Discharge) activity and acquires PD data automatically.

2. Monitors the rotor magnetic flux and detects the presence of shorted rotor windings turns in 2 or 4 pole rotors.

3. Measures the level and trend in vibration from the stator end windings.

These instruments detect events such as:


Stator winding temperature. Cold cooling air temperature. Bearing metal temperature. Shaft vibration. Warming cooling air.

2.1.4 Excitation systems and limiters In order for the synchronous generator to start to generate EMF, the rotor windings of the synchronous generator need to be provided with the necessary field current. This happens when the excitation system produces the flux by passing direct current in the field winding. This process leads the core of the rotor of the synchronous machine to be excited and start to generate EMF. The type of system used to provide the necessary field current to the syn-chronous machine is called the excitation system and the device that transfers the excitation power from the stationary part to the rotating part is called the exciter.

The load, the power factor and the voltage level of the synchronous machine define the amount of excitation required. The more the load, the more excitation is required in the system.

The excitation system has a vast field of applications, namely in gas turbine power plant, hydro power plant, pumped storage power plant, nuclear power plant, steam turbine power plant and compensators [14].

There are two common types of excitation systems for example used in gas turbine power generation system, which will be further described in the following sessions:

Brushless excitation systems – details in section 2.1.4.1. Static excitation systems – details in section 2.1.4.2.

Limiters will be described in section 2.1.4.3.

2.1.4.1 Brushless excitation systems The output voltage and excitation power are sensed from the main generator output. The AVR controls, rectifies through diodes and transfers the excitation current to the fixed field of the exciter, as illustrated in figure 2.11.

Figure 2.11: Brushless excitation system circuit.


The excitation power is supplied from an AC pilot exciter with permanent magnet (PMG) that is directly connected to the generator shaft. Alternatively, the excitation power can also be taken directly from switchgear, which is the combination of electrical disconnected switches used to control, protect and isolate electrical equipment or from an excitation transformer connected to the bus duct between the generator main terminals and the genera-tor circuit breaker. Subsequently, from the excitation system, the field current is supplied to the rotating rotor through an exciter machine located at one of the shaft ends.

The electrical connection between the rotating rectifier bridges of the exciter machine and the rotor winding is normally secured by means of radical bolts and conductors located in the hollow bore of the rotor at the exciter end. An example of brushless excitation system components can be seen in figure 2.12.

Figure 2.12: Brushless excitation systems component.

2.1.4.2 Static excitation systems The excitation power and the voltage sensing are obtained from the main generator output. The AVR senses the output voltage from the generator and regulates the exciter field, forc-ing the exciter output to hold the main field at an acceptable level, as illustrated in figure 2.13.

Figure 2.13: Static excitation circuit diagram.

The excitation power normally originates from a connection on the bus duct between the generator main terminals and the generator circuit breaker. Since the voltage on the genera-tor main terminals needs to adapt to the excitation system voltage, an excitation transformer is normally used. From the excitation system, the field current is then supplied to the rotat-ing rotor through carbon brushes and two sliprings located at the exciter-end shaft end.


The terminal bolts located between the sliprings consist of steel, which are screwed into the field current lead in the shaft bore and connected to the sliprings through terminals lugs [15]. An example of a static excitation system component can be seen in figure 2.14.

Figure 2.14: Static excitation systems component.

2.1.4.3 Limiters The synchronous generator when operated requires observing the permissible combination of active (P) and reactive power (Q).

2.1.4.3.1 Underexcitation limiter The underexcitation limiter corrects the reactive power by increasing the generator voltage. When the operating point falls below the L-M-O limits, then the voltage is increased so that the operating point goes above the L-M-O limit to avoid trip, which is the stop on supply-ing energy due to equipment failure. For me details see figure 2.15. This limiter can be rep-resented by UEL2 model in IEEE 421.5-2005, which is the recommended practice for exci-tation systems.

Figure 2.15: Underexcitation limiter.

L-M-O-Limit Characteristic of the underexcited range.

O-P-Limit Characteristic set by the stator temperature.

P-Q -Limit Characteristic set by the rotor temperature.


2.1.4.3.2 Overexcitation limiter The overexcitation limiter makes sure that the operating point is always maintained within section P-Q of the generator capability diagram in the overexcitation range, as illustrated in figure 2.15.

In the event of voltage drops, usually caused by high reactive power requirements, faults or switching operations, the AVR will raise the excitation level so that the generator voltage can remain constant. The overexcitation limiter protects the rotor against thermal overload-ing.

During a limited period, in order to enable the generator to provide voltage support in re-sponse to short-time voltage dips on the power system, the overexcitation limiter allows excitation values between the maximum continuous current and the maximum excitation current, as illustrated in figure 2.16.

Figure 2.16: Overexcitation limiter and ceiling current limiter.

2.1.4.3.3 Excitation current limiter However, the excitation current limiter, also called field-forcing current, has the function to limit the excitation current to reach its permitted value as quickly as possible.

2.1.4.3.4 Stator current limiter The stator current limiter ensures that there is a delay limiting the continuous permissible stator current.

High reactive power (Q) at increased active power (P) can cause thermal overload of the generator stator, which can be prevented by the stator current limiter function. Additionally, for the generator to be enabled to provide voltage support for the power system, the stator current limiter also can increase excitation values for a limited period.


2.1.4.3.5 Flux limiter The Flux limiter purpose is to reduce the voltage during under frequency conditions. It also protects the load against magnetic saturation.

For more information on limiters refer to references [16] and [17].

2.1.5 Synchronous generator protection The purpose of the generator protection is to protect the generator from abnormal running conditions that can cause damage to the units. The protection is generally of full numerical type and can be rack mounted in a swing frame in one of the control cabinets. The lockout relays can also be placed in the rack. The set up and programming of the protection is nor-mally made via PC based software. The adjustment and reading of settings can also be done directly on the generator panel. A typical generator protection device can be seen in figure 2.17.

Figure 2.17: Typical generator protection device [18].

The synchronous generator is characterized by the typical generator protection functions:

Overexcitation – details in section 2.1.5.1. Overvoltage– details in section 2.1.5.2. Undervoltage– details in section 2.1.5.3. Overfrequency– details in section 2.1.5.4. Underfrequency– details in section 2.1.5.5. Rotor ground fault– details in section 2.1.5.6. Stator ground fault– details in section 2.1.5.7. Stator overheating– details in section 2.1.5.8. Out of step protection– details in section 2.1.5.9. Under impedance– details in section 2.1.5.10.

The following sections will describe each of these components and their main purpose on a synchronous generator.


2.1.5.1 Overexcitation The purpose of the overexcitation protection is to protect the unit transformer connected to the generator. It also protects the generator and the unit transformer from over excitation. The saturation of the magnetic core of the generator, as well as inducement of stray flux in components that are not fit to carry flux, can provoke overheating. This is noticed when the ratio of the voltage to frequency exceeds the generator acceptable value.

Overexcitation happens:

During start-up, when operating at lower frequency. During shutdown, when operating at lower frequency. During complete load rejection, leaving the transmission lines connected to

the generator station.

A voltage/frequency relay that incorporates an inverse time characteristic is usually used to protect the generator from over-excitation state.

2.1.5.2 Overvoltage The purpose of the overvoltage protection is to protect the generator from operating at overvoltage for a prolonged period, mainly caused by malfunction in the AVR or disturb-ance on the grid. The overvoltage in the generator occurs during load rejection.

The AVR controls and limits the generator regarding its voltage. In case of failure of the AVR, an overvoltage relay protects the generator. The relay should have a time delay pick up of around 110% and an instantaneous unit with pick up at 130% of the rated voltage.

2.1.5.3 Undervoltage The purpose of the undervoltage protection is to protect the generator from operating at undervoltage for a prolonged period of time. The undervoltage can occur at overload or failure in the AVR. Normal setting is 90%, mainly caused by failure in the excitation equipment or disturbance on the grid.

2.1.5.4 Overfrequency The purpose of the overfrequency protection is to detect operations at high frequency for a prolonged period. Systems transfer into islands operation can be the result of faults in the system, creating unbalance between the available load and generation. This causes the con-nected loads to have excess of power, which results in an overfrequency state as well as the possibility of overvoltage coming from the reduced load demand.

The generation frequency can be reduced by a control action from the turbine controller, without triggering the generator.

2.1.5.5 Underfrequency The purpose of the underfrequency protection is to detect operations at low frequency for a prolonged period. The underfrequency occurs when power generated for the connected load is insufficient or at low grid frequency.


Gas turbine generators can have problems if operated for a prolonged period during reduced frequencies. For example, if the fundamental frequency of any turbine blades is close to the generator speed, it will increase the vibration, damaging the blade structure.

2.1.5.6 Rotor ground fault The single ground fault does not affect the performance of the generator but serves as a reference point. However, a second ground fault will increase the stress to ground at other points in the field and causes damages such as:

Rotor heating due to unbalanced currents. Originate high unit vibrations. Reducing out parts of the field winding. Arc damage at the points of the fault.

Insulation failure is one of the main causes of ground fault.

2.1.5.7 Stator ground fault The purpose of the stator ground fault protection is to detect stator winding ground fault. The protection measures the voltage across the resistor, when the neutral is a distribution transformer. However, when the neutral has a grounding resistor, the protection measures the voltage across the resistor via a voltage transformer.

2.1.5.8 Stator overheating The stator overheating is usually caused by failure of the cooling system or by overloading. This is solved by the embedded resistance temperature detector coil (RTDs) in the slots with stator windings of the generator.

These detectors are placed at different places in the windings to provide indications of the temperature conditions through the stator. The detector providing the highest indication can be set to operate a temperature relay.

2.1.5.9 Out of step protection The purpose of the step protection is to protect the generator and the turbine for excess me-chanical stress due to fall out of step situations. This is normally caused by failure or weak excitation or when the prime mover input power of a generator exceeds the electrical power absorbed by the system. It can also be caused by power swings on the grid.

2.1.5.10 Under impedance The purpose of the under impedance protection is to detect overload situations, short cir-cuits in the generator and on the bus. The protection can also act as a backup for the differ-ential protection. Since the relay works with impedance, it provides safe function at reduced voltage and current [19].


2.2 Automatic voltage regulator

2.2.1 General description The Automatic Voltage Regulator (AVR) is a hardware device used for automatic control of the generator output terminal voltage at set (desired) parameters during load variation and operating temperatures. The AVR hardware is based on the use of programmable con-trollers and its purpose is to supply DC-current to the field winding of the generator. The AVR hardware device has the following objectives:

Supply variable DC current with short time overload capability. Regulate the generator voltage and keep the excitation voltage and current within

desirable levels. Regulate suitable reactive power share with parallel generators or electrical grid

(MVAR or PF control). Prevent the generator from operation outside its operational limits. Ensure stable operation with electrical grid or other machines. Improve power system stability with use of the Power System Stabilizer (PSS) con-

trol. However, the use of the PSS is optional. Contribute to transient stability subsequently to a fault. Communicate with the power plant control system.

The fluctuation voltage is usually caused by the variation in load on the supply system and the AVR normally protects the generator against possible thermal strains in windings and iron. An example of AVR hardware device can be seen in figure 2.18.

Figure 2.18: ABB Unitrol 1020 AVR [20].

The AVR has a wide range of applications, such in:

Power plants based on gas and steam turbines, diesel engines and hydro turbines. Traction: diesel electric locomotives. Wind: based on direct connected electric synchronous machines. Synchronous motors. Variable speed applications.


2.2.2 Basic principles of the AVR The Automatic Voltage Regulator (AVR) has several controllers and limiters, each of which is dedicated to a defined function, for example voltage control, field current control, field current limitation, etc. Refer to chapter 2.1.4 on excitation systems and limiters for more details.

The AVR works by detecting errors and this is achieved when the output (measure value) of an AC generator (Synchronous generator) that is obtained through a potential transform-er, after being ratified and filtered, is compared with a set (desired) parameter value. The error detected by the AVR is the difference between the actual voltage (measured value) and the reference voltage (set value). If a deviation exists, the controller/limiter produces a signal causing the excitation current to move in the direction required to eliminate the devi-ation. Before the error voltage is supplied to the main exciter or pilot exciter, it needs to be amplified by an amplifier. The amplified error signals, control the fluctuation of the volt-age. The working principle of the AVR is illustrated in figure 2.19.

Figure 2.19: Working principle of an Automatic Voltage Regulator (AVR).

1. Potential transformer. 2. Automatic voltage regulator (AVR). 3. Exciter. 4. Rectifier. 5. AC Generator (Synchronous generator). 6. Main transformer.

The AVR gets its operation power either from the main output or the shaft-driven high fre-quency sub-exciter. The voltage to be regulated is then sensed from the output side of the generator, just before the circuit breaker terminals. In the case of high voltage generators, the sensing circuit is processed through a measuring voltage transformer.

If the terminal voltage is below the desired limit, the AVR will then increase the field cur-rent (��). This is the field strength that will result in an increase in terminal voltage.

More details can be seen in references [21].


2.2.3 Variants of AVR systems The AVR system can be presented in two different variants on a power plant:

Dual channel. Single channel.

The following sections will describe each of these variants.

2.2.3.1 Dual channels When there are two AVR hardware devices operating, is one working as the main device and other as a redundant component. The redundant device will always be on standby mode, so that it can come to operations when required. Power station plants usually use the dual channel option to prevent energy interruptions due to malfunction of the main device, as illustrated in figure 2.20.

Where:

SM- Synchronous machine

E- Exciter

Optional: Figure 2.20: Back- up channel [22].

Power System Stabilizer (PSS). Synchronization unit. Data Logger. Event Recorder.

2.2.3.2 Single Channel The single channel only uses one AVR hardware device. In the absence of a redundant de-vice that can replace the main device in case of malfunction, it can represent a risk not only for the power station plan, but also for the electrical grid. An example of a single channel type is illustrated in figure 2.21.

Where:

SM- Synchronous machine.

E- Exciter.

PMG- Permanent Magnet Generator.

Figure 2.21: Generator or motor excitation with PMG or external supply [22].


2.2.4 AVR main components The AVR is normally built using the following main components:

PID – details in section 2.2.3.1. Regulator– details in section 2.2.3.1. PSS– details in section 2.2.3.1.

The following sections will describe each of these components and their main purpose on the AVR.

2.2.4.1 PID PID (Proportional, Integral, Derivate) is a controller mechanism that controls the output of a system by adjusting its control input. The controller measures the output and then com-pares it to the desired output (set point) and finally adjusts the input depending on the cal-culated error. PID is considered the most common feedback controller. Resuming it adjusts the control variable depending on the present error (P-proportional control), the accumulat-ed error in the past (I-integral control) and the predicted future error (D-derivate control) [23].

A block diagram of the PID controller can be seen in the figure 2.22. The process block represents a system with input (u) and output (x). And the calculation of PID regulators can be done using the equation (2)[24].

Figure 2.22: PID controller diagram [24].

(2)

Kp, Ki, Kd are the coefficients for the proportional, integral and derivate terms, respective-ly.

e(t) = Set point – Input = Error. The difference between desired output (Set point) and cur-rent position.

The different phase of the PID controller are described below:


P- Controller

The P- controller delivers an output proportion-ally to the current error e (t). It compares desired value or set point with the actual value or feed-back process value. The result is then multiplied with proportional constant to get the output. If error value = 0 (zero), the output = 0 (zero). This controller delivers stable operations but always keeps the steady state error. (See figure 2.23).

Figure 2.23. P-Controller [25].

I- Controller

To eliminate the steady state error due to limita-tions of P-controller, where an offset between the process variables and set point is always present, the I-controller is needed.

It integrates the error repeatedly over a period until the error value reaches zero. The integral control decreases its output each time negative error takes place, therefore limiting the speed of response and affecting the stability of the system. Figure 2.24. PI- Controller [25].

The speed of response increases when the integral gain Ki is decreased. (See figure 2.24).

D- Controller

Contrary to the I-controller, D-controller has the capability to predict the future behaviour of the error. D-controller tackles this problem by antici-pating future behaviour of the error.

Its output is calculated by multiplying the rate of change of error with respect to time by derivate constant. The output gets a kick-start, leading to increasing system response. (See figure2.25).

Figure 2.25: PID-Controller [25].

For more details on PID regulator see references [25] and [26].


2.2.4.2 Regulators The most common regulators for the AVR are:

Voltage regulation

The voltage regulation is the normal operation mode. When the voltage regulation is set in voltage regulation mode, the generator terminal voltage remains constant, independent of the generator load but the reactive power varies with the external grid voltages.

Field current regulator

The field current regulation allows manual control of the voltage. The field regulation can replace voltage regulation, for example in case of a fault in the voltage controller signal measuring circuit. A fault in the voltage controller signal measuring can cause an automatic change over to the field current control.

VAr regulator (Reactive power regulator)

The regulation of the reactive power is normally affected by using a three-state controller that controls the voltage regulator and the field current reference. This function is used to keep the reactive power constant. The reactive power control can be used when the genera-tor is synchronized to the grid.

Power factor regulator

This function is used to keep the ration of the active power to apparent power.

2.2.4.3 Power system stabilizer The Power system stabilizer (PSS) is the optional software that can be integrated in the AVR. Its purpose is mainly to improve the damping of the electromechanical oscillations by appropriately influencing the AVR. (See figure 2.26 and 2.27)

Figure 2.26: Function description [27]. Figure 2.27: Function description [27].

The PSS improves the stability of the generator when the possible highest operating range is in progress by increasing the generator’s exciter contribution.


Through additional influencing of the excitation, the PSS can also attenuate the local rotor oscillations in synchronous generators. These oscillations can be classified in four main categories:

Local oscillations – usually between 0.8 and 2.0 Hz. Occurs between a unit and the rest of the generating station and between the latter and rest of the power system.

Inter-plant oscillations – Usually between 1 and 2 Hz and occurs between two elec-trically close power plants.

Inter area oscillations – Usually between 0.2 and 8.0 Hz. Occurs between two major groups of power plants.

Global oscillations – The frequency is usually under 0.2 Hz. Occurs when there is a common in-phase oscillation of all generators found on an isolated system.

More details on PSS see reference [27].

2.3 Control system

2.3.1 General description The control system is a hardware device with software used to monitor, control, adjust and protect different components for example from a power plant system, such as gas/hydro turbines, generators, AVR’s and the electrical grid. This ensures that energy can be effi-ciently produced, distributed and consumed without major problems.

The control system is active during start up and normal operation and prevents injuries each time faults are detected in the power system through the protection system computers. It may be operated by electricity, mechanical means, fluid pressure (liquid and gas) or a com-bination of means.

In the case of a computer involved in the control circuit, it is usually advisable to operate all the control systems electrically, although combinations are common.

For example, the GT (Gas turbine) control system is normally connected to the AVR for superior control and logging of data such as:

Message sequence log. Message and archive log. Measured value log. Operator activity log. System message log. User log.

Additionally, the control system creates the perfect situation for optimization potential such as:

Improving the energy quality due to data consistency. Safe technology that protects personnel, machinery and the environment.


Time and costs savings. Flexibility in energy production due to integrated communication. Minimize downtime due to integrated diagnostic functions. Better performance in the power plant with the interaction of system-tested compo-

nents. Plant and electrical grid security provided by integrated security functions. Simplified implementation of automation solutions aligned with global standards.

The control system can be operated and monitored via Internet or intranet through a web client used by the operator to access the data provided by the control system web server. The communication with the AVR is processed through several communication protocols such as: PROFIBUS, Modbus interface, PROFINET interface etc. However, it might hap-pen that the control system uses a different communication protocol from the AVR; in this case it is necessary to add a converter communicator device, which facilitates the commu-nication between the control system and the AVR [28]. An example of a gas turbine pro-cess overview and its control system can be seen in figures 2.28 and 2.29 respectively.

Figure 2.28: Typical process overview (HMI) [29]. Figure 2.29: Typical gas turbine control system panel [30].

2.3.2 Basic principles of the control system The function principles of the control system are illustrated in figure below, which is basi-cally characterized by an input (desired value) and output (controlled value).

Figure 2.30. Typical closed - loop control system [31].


As illustrated in figure 2.30 a value (desired value) is set by the operator station in the con-trol terminal, also called human machine interface (HMI). When disturbances occur in the system, the output value might not be the one desired by the operator station. Therefore, the error detector rates the value as undesired and sends it to the controller to be corrected lead-ing to an actual output (controlled value.)

2.3.3 Control system main components The control system is built of the following components:

Automation device. I/O (Input / Output). Operator station. Converter communicator.

The following sections will describe each of these components and their function in the control system.

2.3.3.1 Automation device The automation device is formed by:

CPU (Central Processing Unit)- contains the memory, peripheral interfaces and other components of the computer. It is basically the brain of the whole control sys-tem.

Power supply unit- Device that converts the main AC to low voltage regulated DC power used for the internal components of the computer.

Communication module - The unit that allows running the different features of the control system separately.

2.3.3.2 I/O (Input/output) It is basically a distributed Input/output station used to process control applications with the control system. The distributed I/O station consists of:

Interfaces modules, to connect to the different communication protocols. Modules for diagnostic capability. Modules for counter procedures. Modules for failsafe applications.

2.3.3.3 Operator station Contains the operating system program that has an interface for the user (HMI). It can be extended to server/client solutions and remote access. The operator station has different authorization levels of operation and maintenance for the different users of the control sys-tem, such as engineers, administrators etc.


2.4 Electrical grid

2.4.1 General description The electrical grid is the section of the power system that receives the energy produced by the power plant generation. This section is mainly formed by several elements that are con-nected, such as transmissions substations, distributions substations, commercial and indus-trial business consumers, residential consumers etc. (See figure 2.31).

Figure 2.31: Example of an electrical grid [32].

The electrical grid is characterized by different sizes, for example:

Covering a single building. Regional network. National network. International network.

Problems such as over-under voltage, oscillations, short circuits etc. are common on the network section and are prevented through effective monitoring processes as well as the installation of different relays protections.

2.4.2 Basic principles of the electrical grid The electric power produced by the generator is delivered to the electrical grid through a transformer that is connected to the electric power transmission network. The referred transformer is a device with a purpose to transfer the electrical energy from one circuit to another. In the event of alternating current (AC), a transformer will either raise or lower the voltage as it executes the transfer.

The electric power transmission network will move the electric power for a distance, some-times across international borders until it reaches the wholesale consumer, for example the companies that own electric power distributions network. When the electric power arrives at the substation it will be stepped down from a transmission voltage level to a distribution voltage level. From the substation, the electric power enters the distribution network but before the electric power reaches the final consumer, for example commercial, industrial business and residential consumers, it is stepped down again at the service location from the distribution voltage level to the required service voltage level.

It is important that the generation and consumption of electric power be balanced across the entire electrical grid, since the energy is instantly consumed while being produced. The electric power has also to be distributed at the acceptable frequency levels, either 50 Hz or 60Hz [33].

29 | MOBILE PLATFORM SIMULATOR SYSTEM (MPSS)

3 Mobile platform simulator system (MPSS)

This chapter describes the different components and functionalities selected for the com-plete simulator system that has been designed. The selection of these components has been based on research and study carried out through the process of this thesis work. The simu-lator system is to be built by the Siemens R&D engineers at a later stage upon recommen-dations presented in the following chapters.

3.1 Purpose of the MPSS The purpose of the Mobile Platform Simulator System (MPSS) is to test the AVR perfor-mance and to be used as an effective training tool for the R&D engineers at Siemens Tur-bomachinery AB, based in Finspång, Sweden.

3.2 General description The MPSS will consist of three main components:

Simulator - Details in section 3.4.1. Automatic Voltage Regulator - Details in section 3.4.2. Control system- Details in section 3.4.3.

These components will represent the components described in the theory section of this report, in chapter 2. Therefore, the simulator component will act as a synchronous generator described in chapter 2.1 and its function will be to generate output voltage values to be sent to the AVR. The AVR will be the same component described in chapter 2.2 but with a fea-ture to have a redundant device. And its function will be to regulate the values coming from the acting synchronous generator (simulator). Finally, the control system will consist of a component with the same characteristics described in chapter 2.3.

More detailed information about the components of the MPSS is provided in this report on chapter 3.3 MPSS main components.

The components of the MPSS will be mounted on a common electrical cabinet as illustrated in figure 3.1. The control system will be connected to the AVR and simulator through a distributed input/output (I/O) station and a terminal block. The communication between the control system and these components will be facilitated using a converter communicator device. An overview of the MPSS is illustrated in figure 3.1.

Figure 3.1: Overview of the MPSS.


3.3 Basic principles of the MPSS The set values will be introduced through the control system user interface (HMI). The simulator acting as a synchronous generator will generate the output voltage values to be sent to the AVR to be regulated and adjusted. The control system is connected to the AVR through the I/O station and a terminal block and communicates through a converter com-municator device. Its interface user (HMI) will be used to operate and test the different pa-rameters on the AVR.

The individual configuration settings of the simulator and AVR components will be per-formed using two different control tools, the SMTS operates and ECT and these tools are described in more details in chapter 3.3.3 Control systems.

An example of the MPSS flow chart can be seen in figure 3.2

Figure 3.2: Flow chart for the MPSS.

As illustrated in figure 3.2, for example, in the case of low output voltage value generated by the acting generator (simulator) that is lower than the value set by the system operator. Through the control system terminal (HMI) and by the intervention of the AVR, this value will be corrected and adjusted. This will force the simulator to deliver output values desired by the system operator.

3.4 MPSS main components The details of the main components for the MPSS will be described in the following sec-tion.

3.4.1 Simulator The Mobile Platform Simulator System (MPSS) will be equipped with a simulator SMTS-RT 6000 Professional with power amplifier. The SMTS-RT 6000, which stands for Syn-chronous Machine Transient Simulator Real Time is a powerful tool for electricians and engineers working in the field of power generation, excitation systems and power distribu-tion. It’s a modern tool for real time simulations and close-loop testing of Automatic Volt-age Regulator (AVR) or Static Excitation Systems (SES). Its purpose is to assist in predict-ing and understanding the stationary and transient behaviour of synchronous machines in real time mode.

The SMTS-RT 6000 can be used in applications such as:


Complemented power interface to be connected to 100V/110V and 1A/5A inputs of AVR/SES of any brand.

Integrated function of UNITROL 6000 systems. Stand-alone unit for closed-loop tests of UNITROL 6000 systems in the factory or

at site.

The simulator enables the user to analyse the system response during typical disturbances such as:

Tuning and performance verification of the AVR, limiters, and PSS. Performance verification of the AVR under fault conditions. 3- phase short circuit at generator terminals. 3- phase short circuit at high voltage side of step up transformer. Fault synchronization. Field suppression from a defined initial load or fault condition. Load rejection.

The SMTS software runs on Microsoft Windows and enables the most complex simulations involving a synchronous generator.

The device can simulate the following plant devices:

Synchronous machine (Generator or Motor). Excitation systems either static or brushless. Power System Stabilizer (PSS). Field suppression circuit, field breaker and linear or non-linear discharge resistor. Turbine with governor (driving power ramp). Nonlinear speed dependent shaft load for motor applications. Step-up transformer. Network composed of the line series inductance and resistance connected to an infi-

nite voltage source.

Overview of the simulator is illustrated in figure 3.3.

Figure 3.3: Real time simulation of: Turbine and governor (simplified), Generator, Breaker and step up transformer, Grid repre-

sentation with infinite Bus Voltage [34].


This simulator model allows the user to have the flexibility to set generator and exciter pa-rameters as desired. The simulator offers also the possibility to be customized according to the user’s preference. The simulator can be seen in figure 3.4.

Figure 3.4: SMTS-RT 6000 [35].

3.4.1.1 Main features The graphical and numerical output-function of the UNITROL-ECT is used for data

recording and storage. The snapshot function (data-storage and recall) of the SMTS Operate can be used

for saving and reporting of the simulated case. Several SMTS-snapshots can be available to be used as references or training pur-

poses; especially where detailed transient representation may not be available. A series of events can be enabled by the Event control function. To facilitate the repetition of the simulated cases, the event parameters can be saved

separately [35].

3.4.1.2 Software licences There are two main types of licences used in the SMTS software: The Lite License and the Professional License. Both licenses are basic licenses with predefined set of machine pa-rameters (4 Turbo / 2 Hydro) and selectable exciter settings. The user can activate either the elementary (Lite License) or the more extensive functionality (Professional License). These active licenses are displayed in the parameters interface.

To cover a wide range of operations, extras add-on SW functions have to be considered. These add-on SW functions can be obtained from the company ABB. Once the company has provided the access password, the correspondent software licence can be activated on the device.


These add-on SW functions are:

Configurable sequence of events or event generator. White noise/sinusoidal signal generator or disturbance generator. Function generator. Synchronization functions. Power amplifier. UNITROL 6000.

The following section will describe each of these software functions.

1. Configurable sequence of events or event generator

This option offers the possibility to simulate cascade events, as illustrated in the fig-ure 3.5.

Figure 3.5: Simulation of subsequent events [35].

This may be a distant 200ms short-circuit followed by a timed line switch-ing/governor set –point change/generator breaker trip/.

In the absent of this option, the sequence of events is limited to a timed SC (se-quence) at the infinite bus.


2. White noise/sinusoidal signal generator or disturbance generator

Developed for special features, this option helps to analyse the response of the ex-citer upon external system disturbances.

This option gives the possibility for the user to inject a disturbance signal to several points in the model, such as; the infinite bus voltage (of sinusoidal or noise type), infinite bus frequency, exciter output voltage, governor setpoint and facilitates the analysis of different cases. An example of disturbance generator where the disturb-ance signal is added to the infinite bus (IB) magnitude, infinite bus (IB) frequency, governor output, governor setpoint. And control voltage Uc, as illustrated in figure 3.6.

Figure 3.6: Disturbance generator scheme.

3. Function generator

Allows the user to force the voltage and current outputs of the Power Amplifier to a desired value.

The user can control each output individually by means of amplitude and frequency (DC > 100Hz). This option empowers the simulator SMTS-RT 6000 to be used in applications other than closed loop testing of excitation systems. Therefore, may be used for open loop testing of protection relays or instrumentation equipment.

4. Synchronization functions

The facility that can be used to test synchronizing equipment in parallel to an excita-tion system is guaranteed by this option.

This option offers an analogue input that is received from the synchronizer, which is then added to the generator control loop and make it easy to analyse the interaction between these two systems.


5. Power amplifier

This licence allows the use of the SMTS-RT 6000 Power Amplifier with the genera-tor model. The purpose of the power amplifier is to amplify the DC current required from the exciter before it is sent to the generator rotor windings.

6. UNITROL 6000

This licence gives the possibility to use the generator model together with an UNITROL 6000 unit for instance the SMTS-RT 6000. Due to its importance this li-cence is always activated [36].

3.4.1.3 Operation modes The SMTS-RT 6000 operates in two different modes:

Real time with internal excitation control loop. - It sends analogue output signals to AVR as actual values. Real time with external excitation control loop (real AVR equipment). - Receives AVR control output as analogue signal. - Sends analogue output signal to AVR as actual values.

3.4.1.4 Excitation system AVR Control mode

The SMTS-RT 6000 through the AVRControlMode parameter offers three different options to select the AVR control mode:

1. Internal Loop The AVR included in the SMTS-RT is used when the internal control loop is selected by setting the ControlMode to 0 (zero). The parameter Calc int AVR Settings need to be adapted.

2. UNITROL 6000 The ControlMode is set to 1 (One). An external AVR provides the control signal leading the control loop to be closed via the UNITROL.

3. Power Amplifier Before the error voltage is supplied to the main exciter or pilot ex-citer, needs to be amplified by an amplifier.

The ControlMode is set to 2 (Two). In this mode, the control signal is also received from an external AVR and via the SMTS-RT 6000 Power Amplifier.

Settings for the Power Amplifier and external AVR refers to the document UNITROL SMTS-RT 6000 User Manual page 46 and 47.

3.4.1.5 Interface scaling The scale factor is used as the model communication between the SMTS and the excitation system so that the transmission range can be optimally utilized. The SMTS adjustments


must correspond 100% to the DUT (Device Under Test) adjustments. However, when sim-ulating short-circuits these factors might be necessary to be reduced so that the range over-flow can be prevented.

3.4.1.6 Synchronous machine input data The synchronous machine input data are:

Basic data. Reactance. Time constants. Calculate inertia constant H.

These input data for the synchronous machine are described in the following sections.

3.4.1.6.1 Basic data PPName - Plant name or other relevant information that needs to be associated to

the simulation case. Sn – Rated apparent power of the synchronous machine. Un – Rated voltage of the synchronous machine. Fn – Rated electrical frequency. Ifd0 – It’s the per unit base for field current that corresponds to the field current re-

quired to reach the rated machine voltage at the no-load air gap characteristic of the generator.

Rfdabs and Windingtemp – Field resistance and the corresponding winding temper-ature for this resistance values.

3.4.1.6.2 Reactance The dynamic behaviour of the synchronous machine is described by the parameters typical available as short-circuits non saturated reactance and time-constants. These parameters have to be obtained from the generator’s datasheet and have to be entered in p.u:

Xd – Direct axis synchronous reactance. Xdp1 – Direct axis transient reactance. XDp2 - Direct axis sub transient reactance. Xq – Quadrature axis synchronous reactance. Xqp1 – Quadrature axis transient reactance. Xqp2 – Quadrature axis sub transient reactance. Xas – Stator leakage reactance. Xc – Characteristic reactance.

3.4.1.6.3 Time constants The time constants parameters are also obtained from the generator’s datasheet.

Tdp1 – Direct axis short-circuit transient time constant. Tdp2 – Direct axis short circuit sub-transient time constant. Tqp1– Quadrature axis short circuit transient time constant. Tqp2 – Quadrature axis short circuit sub-transient time constant. Ta – Armature time constant.


3.4.1.6.4 Calculate inertia constant H The inertia constant for the entire shaft system can be entered in two ways:

By entering the inertia constant directly, after being calculated by the R&D engi-neers.

Also as inertia moment and the number of the generator poles. The ChangeIn-ertiaConstant-variable, which will calculate and replace the inertia constant that has previously set, must be released to true when entering the data in this way.

The calculation of the inertia constant can be done using the equation (3).

(3)

J – mass moment inertia [kg��].

Fn – Nominal electrical generator frequency [Hz].

Sn – Nominal apparent generator power [VA].

�� – Number of generator poles.

3.4.1.7 Software Installation For the software installation procedure refer to the document UNITROL SMTS-RT 6000 User Manual, page 61.

3.4.1.8 Input/Output (I/O) Terminals These are the input/output terminals of the SMTS-RT 6000 and can be seen in appendix A.

3.4.1.9 Simulator technical data These are the technical data of the SMTS-RT 6000 component and can be seen in appendix B [36].


3.4.2 Automatic voltage regulator The automatic voltage regulator (AVR) system used by Siemens in Finspång is a dual channels type. The dual channels (Channel 1, Channel 2) is built with two modules of UNITROL 1020 AVRs from ABB and together with auxiliary components mounted on the plate. The two UNITROL 1020 modules control the synchronous generator. While one works as the main device, other works as redundant device. The AVR system is illustrated in figure 3.7.

The UNITROL 1020 AVR, as described in section 3.4.1 is compatible to work with SMTS-RT 6000 simulator device.

Figure 3.7: Double channel UNITROL 1020 AVR’s.

The dual channels configuration is assembled on a plate and can be installed in the main terminal box of the generator or in a separate panel or cabinet. The UNITROL 1020 AVR’s allow to be controlled using Modbus RTU via RS-485 or Modbus TCP communications protocols via Ethernet.

The UNITROL 1020 AVR’s are fitted with most advanced microprocessor technology and IGBT semiconductor technology (Insulated Gate Bipolar Transistor). The device software allows optimization of operation and makes it easy for commissioning [37].


3.4.2.1 AVR System terminal connection blocks The terminal connection blocks show the interfaces to connect the simulator and the control system. For more details see appendix A.

3.4.2.2 AVR System features The AVR systems has the following features:

Operating modes. Power supply. Internal +Vdig (+24V) power supply. Excitation current output and Field current breaker (FCB) control. Channel changeover principle. Channel status: Main/Redundant active. Tripping logic. Field current breaker (FCB) close status. Generator current breaker (Gen CB) closed status. Synchronizing. Rotating trip. Rotating diode trip. External alarm. Reset alarm. Modbus.

The following sections will describe each of these features and their function in the AVR.

3.4.2.2.1 Operating modes The AVR system has three different operating modes:

Automatic Voltage Regulator (Auto)

Regulates the terminal voltage of the synchronous machine. The voltage control is provided by the voltage drop compensation (VDC) function when parallel generators are connected to a common bus.

Manual Control

Regulates the field current of the excitation machine. Limiters are active if this mode is active.

PF (Power factor) or Var Regulation

Regulates the power factor or reactive power of the synchronous machine

Var set point is usually normalized at 1pu terminal voltage of the generator.


3.4.2.2.2 Power supply The system has four power supply inputs:

Two power supply destined for excitation power (Upwr1, Upwr2), which are nor-mally supplied from a Permanent Magnetic Generator (PMG) mounted on the syn-chronous generator (separate AC or DC excitation power supply is possible).

Two-power supply destined for auxiliary electronics (Uaux1, Uaux2).

3.4.2.2.3 Internal +Vdig (+24V) power supply The components that consume current such as relays and digital inputs and outputs are normally supplied by the internal +24V power supply of both channels (G10:+24V;G20:+24V), using the distribution terminal blocks X10 and X10_1. Both UNITROL 1020 AVR’s modules may be loaded individually up to 600 mA.

3.4.2.2.4 Excitation current output and FCB control The two DC breakers, Q02 for channel 1 and Q02 for channel 2 are used for output of the excitation current. The two DC breakers are controlled through the field current breaker (FCB) Close and FCB Open digital outputs (DO) from the UNITROL 1020 modules.

The FCB Close (DIO3, 1 second pulse) activates the contactor Q02.1 for channel 1 and Q02.2 for channel 2 and it is electrically latched. However, the FCB Open (DIO 4,1 second pulse) energizes the relay K01 for channel 1 and K02 for channel 2, which releases Q02.1 for channel 1 and Q02.2 for channel. Basically, closing one field breaker causes the other to open (latch-to-release).

When Excitation is switched ON and OFF or when a changeover between channels takes place, the FCB Close and FCB Open commands are automatically sent by the AVR.

During the switching of the field breakers, two free wheeling diode bridges at the output, guarantee a free wheeling path for the excitation current.

3.4.2.2.5 Channel changeover principle The channel 1 is normally the primary channel to be in control. The channel 2 is intended to operate as the backup channel (redundant) used to extend the availability of the AVR plate. Therefore, the channel 2 is in standby, following the reference setpoint of channel 1 and capable to take over when a channel changeover is initiated. The channel 1 allows also au-tomatic change to manual operation mode (Field current regulation).

The internal fault detection (software monitoring functions) or external fault detection via hardwired digital inputs or Modbus may cause a channel transfer from channel 1 to channel 2.

The internal fault detection in UNITROL 1020 is organized in fault groups designated by the terms ‘Alarm 1’, ‘Alarm 2’ and ‘Trip’. In the event of being configured as digital out-puts, the fault groups are named ‘Supervision Alarm’ and ‘Supervision Trip’.


3.4.2.2.6 Channel status: Main/Redundant active The main refers to channel 1 and redundant to channel 2. When the Channel 1 is active, the relay -K09 is controlled by the switch over output and will be energized. However, when the Channel 1 is switched off or at standby, meaning that the channel 2 is selected, relay –K09 will be de-energized.

3.4.2.2.7 Tripping logic A hardwired Trip input signals should be available from external protection relays to termi-nals X3: 1,2. This Trip input signal energizes relay -K03, which will further open both channels field breakers. The auxiliary contacts of -K03 are used enable Emergency Excita-tion Off in both channels.

3.4.2.2.8 FCB close status The FCB Closed Status (X3: 5,6) indicates when one of the field breakers (-Q02.1 for channel 1 and -Q02.2 for channel 2) is closed. The AVR modules monitor FCB Status (DI11) and send an alarm over Modbus if the field breaker is not closing within 1 second from the command. However, the excitation shall be turned off over Modbus by the control system in case of failure of the field breaker.

3.4.2.2.9 Gen CB closed status The Gen CB closed status (X3: 7,8; X3: 7,9) communicates to the AVR when the generator circuit breaker (GCB) is closed; therefor the generator is connected on line. This enables the measurement of the generator current, droop functions and other current related meas-urement.

3.4.2.2.10 Synchronizing UNITROL 1020 system allows automatic synchronization of the generator to the grid. When the synchronized mode is active, the AVR will match the generator voltage with the grid voltage and at the right moment sends out a Close Generator CB command to close the generator circuit breaker exactly at phase coincident.

The selection of the parameters for the correct synchronization shall be executed over Modbus before the synchronizing process is started. Gen CB closed status feedback shall be re-directed or blocked during synchronizing to prevent from sending the Close CB com-mand.

After breaker has been closed, the Synchronize mode command shall be de-activated over Modbus. In case the synchronize command is kept active, the AVR will try to keep the re-active power over the breaker in zero, thus following the network voltage. The Close CB command energizes relay -K71 (X3: 18, 19) for channel 1 and relay -K72 (X3: 20, 21) for channel 2.


3.4.2.2.11 Supervision trip The Supervision Trip (DIO6) is the signal that has been connected to various monitoring functions using the CMT1000 Tool. Supervision Trip (DIO6) energizes relay -K90 (X3: 35, 36) for channel 1 and -K92 (X3: 35, 37) for channel 2. Both channels (Channel 1 and Channel 2) have the Supervision Trip configured with inverted polarity. Therefore, during the time the Supervision Trip is not active in both channels, for example if no issues are detected, -K92 will remain energized.

3.4.2.2.12 Rotating diode trip In the event of shorted diode, the Diode Trip output signal energizes relay –K77 (X3: 31, 32). The Diode trip delay parameters can be adjusted using the CMT1000 software, if re-quired.

3.4.2.2.13 External alarm The External Alarm DIO8 (X3: 10, 11; X3: 16, 17)) is wired to PT1 TRIP, according to the channel. External Alarm is an input to the supervision and when is triggered, it changes the Alarm 2 status to active, on correspondent channel.

3.4.2.2.14 Reset alarm The Reset Alarm (DIO (X3: 33, 34) is an input to the AVR plate and shall be consigned in order to clear the following memory-latched fault indications:

SW Alarm (Watchdog). Alarms 1/2 and Supervision Alarms 1/2 (Digital outputs). Trip and Supervision Trip (Digital outputs). Switch Over and Switch Over digital outputs.

The memory-latched indications may only be cleared after the corresponding fault (s) have been fixed or repaired. If a fault is still present, the corresponding fault indication may not be cleared with Reset Alarm. When all faults are previously fixed, the Reset Alarm brings the channel 1 back to Auto/PF/VAR operation mode.

The Reset Alarm can be initiated using a hardwired contact or Modbus.

3.4.2.2.15 Modbus The AVR system supports both Modbus RTU (RS-485) and Modbus TCP communication protocols for remote access. However, the new functions implemented in the latest software version, for instance Data logger, can only be accessed using the Modbus TCP. Therefor it high is recommended to use the Modbus TCP whenever possible, especially in new appli-cations.

For more details on system features see references [37] and [38].


3.4.2.3 Control and software The UNITROL1020 AVR has the capability to support a variety of operating modes and software features, such as machine voltage regulator (Auto), field regulator (Manual), as well measurements monitoring and others [37]. The software options, description and func-tion packages for the UNITROL 1020 AVR are shown in table 2.

Table 2: Software options [41].

The software functions for the UNITROL1020 AVR are defined as basic and full package, which include the PSS as an option.

The basic package features are enabled by default in each UNITROL1020 AVR unit and are called basic software package. More optional software features can be enabled by en-quiring a password in order to extended the UNITROL1020 AVR capabilities. However, the password code should be acquired from ABB and then optional software features can be enabled using the CTM1000 software.

3.4.2.3.1 Basic features of CMT1000 The basic features of the CMT1000 include:

Configurations of parameters and I/O signals. Measurements reading. Trending function for controller optimization (Oscilloscope, Power chart). Parameter File uploads or downloads. PID tuning, Set point steps and other powerful commissioning tools.

3.4.2.4 AVR Technical data The technical data is related to the requirements, dimensions and terminologies of compo-nents for the AVR. For more detail see appendix C Technical data.


3.4.3 Control system The MPSS will use the SIMATIC PCS7 control system from Siemens [44]. Additional, for the individual configuration of the Simulator and AVR system as stated in chapter 3.2, will use two more control tools, namely the SMTS Operates and ECT, both part of the UNITROL 6000 platform from ABB, as illustrated in figure 3.8.

Figure 3.8: Overview of the control systems and tools for the AVR and Simulator configuration.

The following sections will describe each of these control tools highlighted in figure 3.8.

3.4.3.1 UNITROL 6000 The SMTS-RT 6000 is equipped with UNITROL6000 control platform (AC 800PEC) for computation and the excitation control terminal (ECT) as a user interface (HMI).

The control platform allows the replacement of the analogue-to-digital converter data by real time simulated data samples at 40 kilosamples /second rates for 3-phase generator volt-age and current.

The UNITROL 6000 control platform will be connected to the real-time simulator via Ethernet or USB connection. While the real-time simulator will be connected to the excita-tion controller, through a safe and fast 10 Mbit optical link.

3.4.3.1.1 SMTS Operates software This is a control system tool that allows the user to set up configurations and simulate typi-cal load variations or system disturbances both in the SMTS-RT and internal AVR. Both the SMTS Operates and ECT tools can be installed in the ECT (HMI), which provides the user with an interface for operations, as illustrated in figure 3.9.

Figure 3.9: Block diagram of close loop simulation [39].


3.4.3.1.2 Excitation control terminal The Excitation Control terminal (ECT) provides the user with an interface to perform set up configuration both in the SMTS-RT and AVR. The ECT will be connected to the SMTS and AVR devices via Ethernet link. An overview of the ECT interface can be seen in figure 3.10.

Figure 3.10: ECT. Human Machine Interface (HMI) [39].

3.4.3.2 SIMATIC PCS7 It is an integrated and distributed control system designed to operate in industrial automa-tion applications. The system offers the advantage of being open to external control systems environment and in this case, will be used to test the AVR performance by changing its parameters and test new developed software applications.

The SIMATIC PCS7 is compatible to work with simulator and AVR components described in section 3.4.1 and 3.4.2. The SIMATIC PCS7 control system will be connected to the AVR through a converter device named Anybus communicator and a distributed station input/output (I/O) ET200M. Additional two different communication protocols will be used: MODBUS communication protocol from the AVR to the converter device Anybus communicator and PROFIBUS communication protocol from the converter device Anybus communicator to the SIMATIC PCS7 control system.

The SIMATIC PCS7 control system will be formed by four components:

Automation device AS410-5H. Distributed input/output station ET200M. Operation station IPC 547. Convertor communicator Anybus.

The following sections will describe each of these components and their functions in the control system.


3.4.3.2.1 Automation device AS410-5H The automation device, AS410-5H operates as control, safety and protection system. The system is formed by a CPU, power supply and communication module that are mounted on a 483 mm rack with 9 slots. In case of redundant system, the component offers the option to be separated.

The AS410-5H device can for example be used to control the operation of a gas turbine, safety and the protection functions. A typical automation device can be seen in figure 3.11.

Figure 3.11: Control/Safety system AS410-5H [40].

Function

The failsafe ET 200M modules and the F program of the CPU incorporate the safety func-tions of the F/FH systems. To ensure a safety PROFIBUS DP communication between the CPU and process I/O the PROFIsafe profile will be used. This additional safety messages will allow the F/FH systems and F/O modules to identify the corrupt data and start appro-priate error responses.

The AS410-5H engineering tool integrates a F-Tool called SIMATIC Manager. This tool enables the parameterization of the CPU and the F signal modules. Additionally, enables the generation of failsafe applications in the CFC that are based on predefined TUV-approved blocks. The failsafe blocks are capable to intercept programming errors and re-duce programming tasks to detect/react to errors. Available functions such as comparison F programs, detection of changes in F programming using checksum or access privileges us-ing password will provide further support to ensure a simple and safe operation.

The application program incorporates both failsafe (F) and non-failsafe standard programs (S). These programs components are separated and during data exchange, special conver-sion blocks will prevent conflicts. The CPU will not stop by an error detected in the F pro-gram. However, it will trigger the configurable shutdown logic settings.


3.4.3.2.2 Distributed input/output (I/O) station ET200M The distributed I/O stations, ET200M is used to process control applications with SIMAT-IC PCS7. The device contains a diversified selection of I/O modules in S/-300 as illustrated in figure 3.12 and is designed with special control functions such as:

Modules with enhanced diagnostics capability. Counter modules. F modules for failsafe applications.

The ET 200M distributed I/O stations consists of:

IM 153 interfaces modules, that allow connecting through protocol PROFIBUS DP with data transfer rates up to 12 Mbits/s.

A maximum of 8 I/O modules that allow connecting sensors/actuator technolo-gy.

Figure 3.11 shows a distributed I/O station with 8 I/O modules. It is recommended for the MPSS to have 8 I/O modules so that more functions can be connected.

Figure 3.12: SIMATIC PCS7 I/O ET200M [40].

The I/O modules are optically isolated from the backplane. A maximum of 12 I/O modules can be connected to one interface alone.

Function

When a fault occurs the module with diagnostic capability will automatically send the cor-respondent signal to the operator system. This will enable the trouble to be fixed fast and easily. The I/O ET200M can be operated in standard environment or in EX zone 2* if the right permit (e.g. fire certificate) is obtained.

The safety failsafe function ensures the plant safety in case the CPU should fail. The digital and analogue inputs of the failsafe signal modules can detect internal and external errors. In the presence of any differences the safety response is immediately triggered. However, in the event of a fault output, the digital output modules activate the safe disconnection through a second disconnected path.

*Zone 2 areas is classified as an atmosphere where a mixture of air and flammable substances in the form of gas, vapour or mist is not likely to occur in normal operation, but if it does occur, will persist for a short period only [41].


3.4.3.2.3 Operation station IPC547G The operation station, IPC547G represents the SIMATIC PCS7 single operator station (in-tegrated server/client) with user interface (HMI). It is a robust industrial PC in 482.60 mm wide rack format (4HU), as illustrated in figure 3.13.

The IPC 547G operating system program can be extended to server/client solutions, remote access and is running on Microsoft Windows operating system with windows standard user interface. The OS applications software is built in with function blocks (APL and IL) and both the system and application software are stored on a solid static drive.

Figure 3.13: IPC 547G [42].

The operator will be noticed about process and system fault thanks to different classes and priorities integrated in the alarm system. Different authorization levels of operation and maintenance are available for users such as viewers, three levels of operators, engineers and administrator. The English or an alternative language can be displayed in the HMI text. Tag names can be displayed using the numbering and identification system Kraftwerks-Kennzeichen system (KKS) or as customer tag (Optional).

Optional installations of cyber security software are available. The functionalities of the PCS7 are compatible with this solution and ensure the highest possible level of IT-security for windows platform.

HMI display

There are three types of display available in the HMI of the PCS7:

Process. Trend display. Alarm list.


The following sections will describe each of these types of display.

Process

Depending on the application, for example the standard menu of Siemens gas turbines, con-sists of 10 to 14 displays. The system offers the possibility to be expanded with additional displays, so that extended scope such as WHRU’s (Waste Heat Recover Unit) and switch-gears can be handled. A typical process overview is illustrated in figure 3.14.

Figure 3.14: Typical process overview [43].

The process displays of the PCS7 are graphic displays designed for applicable processes, both as overview log page and system display. These displays allow the operator to operate the unit. Most of the tasks such as load change, start/stop etc. are easily carried out.

Trend display

The analogue signals that are shown on the operator screen are archived. The sample time is 1-2 s and the values are stored for approximately one month using 30GB on the OS computer. However, a period of one month, the oldest values are overwritten. The archived values can be graphically presented on the OS as trend display.

Alarm list

The latest 1000 alarms and shutdowns of the alarm log are presented by the alarm list. The alarm archive stores around 250000 alarms and each alarm is time tagged with a 1ms reso-lution. The internal faults are monitored using the separate system alarm that is also availa-ble.

Operator commands

The keyboard and mouse are the operator command interface to be used. A faceplate pop-up window is presented by pressing the left button of the mouse. The faceplate provides information related to the object and the number of buttons for orders. When clicking the appropriate button, the required order can be easily executed. The flashing indicates the


order initiation and the button or symbol will be filled when the order has been consummat-ed.

OS auxiliaries - Hardcopy printer. It’s used for print screen on demand as well to print trend dis-

plays and sections of alarm/event list. - Start counter. The counter that display the total number of starts of the unit. - Operating hours. The counter that display the total number operating hours. - Equivalent operating hours. The counter that display the calculated equivalent op-

erating hours. - Equivalent operation cycles. The counter that display the calculated equivalent op-

erating cycles. - Emergency shutdown. The emergency shutdown button (ESD) for unit shutdown.

For more details on SIMATIC PCS7 see references [40] and [42].

4. Communicator converter Anybus AB7000

The SIMATIC PCS7 control system uses a different communication protocol from the AVR. For the communication between the two devices to take place, a converter device called Anybus communicator, model AB7000 will be used. The communicator converter is shown in figure 3.15.

Figure 3.15: Anybus AB7000 [44].

The Anybus communicator AB7000 is a converter device for PROFIBUS that acts as a gateway between virtually any serial application protocol and a PROFIBUS DP-based net-work.

The device is designed to exchange data between a serial sub-network and higher-level network. Compared to other devices of similar kind, the Anybus has the particularity of not having a fixed communication protocol for the sub-network and offer the possibility to be configured to handle any form of serial communication.

Serial telegrams are issued cyclically by the gateway, on change of state as well based on trigger events issued by the control system of the higher-level network. Additionally, it can


monitor certain aspects of the sub-network communication and when the data has changed, can also notify the higher-level network.

The integration of industrial devices is enabled without the loss of its functionality, control and reliability, both when retrofitting to existing equipment as well when setting up new installations.

Data exchange

Both data exchange on the subnetwork and the data exchange on the higher-level network reside internally in the same memory.

Input data

Subnetwork

The device can address up to 31 nodes and can support the following physical standards:

RS-232. RS-422. RS-485.

PROFIBUS Interface

The PROFIBUS connectivity is supplied through patent Anybus technology and is used by leading manufactures of industrial automation products.

Complete PROFIBUS-DP slave functionality. Support all common baud rates up to 12 Mbit (detected automatically). Up to 244 bytes of I/O data in each direction. Galvanically isolated bus electronics.

Protocol modes

The Anybus communicator is characterized by three distinct modes of operation regarding the subnetwork communication:

a) Master mode

Intended for query and response based products protocols. The gateway acts as a master on the subnetwork.

b) Generic mode

Primarily intended to produce and consume - based protocols. The nodes on the subnetwork and the gateway may spontaneously produce or consume messages.


c) DF1 Master mode

This mode is intended for the DF1 protocol. Using the DF1 protocol allows the gateway to act as a master slave on the network.

3.4.3.3 Control system technical data These are the technical for the CPU, I/O, operation station and communicator converter can be seen in appendix D.

53 | METHOD AND RESULT

4 Method and result

This chapter describes the methodology and on how to obtain results from the MPSS.

4.1 Setting the requirements The requirement engineering method has been used to identify the specific needs of the R&D Department and the best approach solution to enquire about the suitable components for the Mobile Platform Simulator System (MPSS).

Figure 4.1 represents the process to identify the specific requirements for the stakeholders, MPSS and the different project scopes.

Figure 4.1. Requirements management diagram.

4.1.1 Requirements elicitation

4.1.1.1 MPSS stakeholders Different stakeholders in the MPSS have been identified through meetings with the as-signed supervisor at Siemens. These are listed and organized cnsidering the stakeholders profile and level of involvement with MPSS in table 3.

Table 3: MPSS Stakeholders.

4.1.1.2 Stakeholder’s requirements The stakeholder requirements on the MPSS are listed below:

The MPSS shall be able to be moved around. Confidential documents shall be handled in a proper manner. For security reasons, when conducting the work on an external computer and

especially outside the office, the work shall be carried out on an encrypted memory driver supplied by Siemens.


Sub systems for the simulator system and other components such as cables, cab-inets etc. shall be obtained upon R&D Department recommendation.

The MPSS shall reflect the needs of the R&D Department. The MPSS shall be accessed remotely. The MPSS shall be able to be used for training purposes.

4.1.1.3 MPSS requirements The desirable requirements on the MPSS are listed below:

The MPSS shall be compact, reliable and easy to use. The MPSS shall be able to simulate real life scenarios. The MPSS shall be compatible with Siemens control system unit (SIMATIC

PCS7). The MPSS shall be compatible with ABB Automatic Voltage Regulator unit

(UNITROL AVR 1020). The converter device shall be the Anybus communicator AB7000 model. The cabinet shall have AC and DC power outlets.

4.1.2 Requirements specification The specification should include the requirements of both users and MPSS desirable re-quirements as mentioned before. Based on this specification the certain requirements will be prioritized and then validated.

4.1.3 Requirements validation The different requirements on the MPSS specification have been reviewed after being pri-oritized, which has led to the following results:

Provided with access to the R&D Department’s relevant information, related to gas turbines, generators and excitation systems.

The potential company from ABB Group, which will provide the simulator unit, has been identified. This company is based in Switzerland and is specialized in excita-tion and synchronous equipment.

The contact person within ABB, responsible for excitation and synchronous equip-ment has been identified.

Several emails and phone calls have been exchanged with the contact person within ABB. This has led to being provided with relevant information and password access to the ABB internal database, from where more relevant technical and non-technical information has been obtained.

The company Elektromontage to provide the MPSS electrical cabinet has been iden-tified. This company is based in Söderköping and has representation around Sweden and Finland. Several emails and phone calls have been exchanged with Elektromon-tage representative, which has led to meeting in person and discussing the different options for the electrical cabinet.


4.2 Project management The project manager structure illustrated in figure 4.2 has been used to execute successfully the different scopes of this project.

Figure 4.2: Project management structure

The project management structure as illustrated in figure 4.2, worked as a support tool to plan and schedule the different tasks to be executed. The beginning phase is where all the different tasks and respective budgets are planned, after the idea and proposal for the pro-ject have been approved. The middle phase is where the different tasks planned in the be-ginning phase are executed and then reviewed. The final phase represents the area where a final review and closure of the entire project is done. Using this particular project manage-ment structure has contributed to achieving good results such as:

To define the most effective way to communicate with the stakeholders. It has been decided to keep communications via emails, phone calls, personal meetings and the company’s communication tool, called Circuit.

To define the budget in terms of hours. To decide when to have project meetings with the different stakeholders. To define the deadlines. To define the different phases of the project, such as pre-study, research, execution

and reporting phase. Defining the time frame for each task to be executed.

4.3 System design

4.3.1 MPSS electrical cabinet The electrical cabinet for the system components will be ordered from an external company called Elektromontage after Siemens recommendations. The electrical cabinet supplier has previously worked with Siemens on different projects and has a vast expertise when it comes to electrical cabinets design and installation. Elektromontage will also be responsible for the assembly in the electrical cabinet of the MPSS components such as control system, converter, simulator and AVR. The electrical cabinet can be seen in figure 4.3.


The electrical cabinet will have the following characteristic:

Cabinet with 2000 mm tall and 482,6 mm wide design. Four Wheels. One Plexiglas door. Gables ceiling (cover). Outlet with 4 pieces. Three Handles. One 24vDC max 10A. Design with extra space to accommodate more devices in the

future.

Figure 4.3: Electrical cabinet.

The components will be placed vertically in the electrical cabinet as previously illustrated in figure 3.1.

4.3.2 Communication architecture The connections between the components are illustrated in figure 4.4

Figure 4.4: components connection.

Link 1- Ethernet connection.

Links 2 and 7 - Optical connection (10Mbit optical link).

Links 3 and 4 - Ethernet, USB connection and Modbus RTU or Modbus TCP protocol for remote access.

Links 5 and 6 - PROFIBUS communication protocol for remote access.


4.3.3 Circuit diagram The circuit diagram for the MPSS has been designed using the drawing software called Visio from Microsoft.

The completed circuit diagram shows the components of the MPSS, their interfaces and the connections between the components. The R&D Department at Siemens can use it as sup-port guide to build the MPSS at later stage. For more details please see appendix E Circuit diagram.

4.4 Event simulation on the MPSS Examples on procedures on how to simulate events are described below and the simulation overview can be seen in figure 4.5.

1. Open the control terminal.

2. Log in: Fill out your user ID and password,

Then click

3. Adjust parameters: i.e Change the GEN. voltage.

4. Click Init: Set normal system conditions: generator,

excitation system, governor and grid. The machine gets

initialized and is ready for simulation.

5. Click Run: simulation runs in a steady state.

Figure 4.5: Quickly simulation user guide [43].

6. Click any breaker to change its state. Same procedure applies for the selection of the ac-tive line impedances, grid voltage or setpoint of the internal controllers.


4.4.1 Cascade parameter settings for generator event When the user intends to execute several events in cascade the following settings in the control terminal under the Events folder should be introduced. An example for cascade pa-rameters can be seen in table 4.

Table 4: Event Generator parameters [43].

This event control configuration screen allows the user to execute these several events in a certain timed manner. The Trigger Event(s) is responsible for the release of the flow control of the events. However, the “Enable” parameters only activate the related events if its value is set to “True”. Example VGrid2Event1Enable when is set to “true” instead “false” means that the event is activated and the simulation can be executed.

Notice that when using the button “Trigger Event(s)”, the parameter “Pulse length ≤ 0” has to be entered otherwise only a grid voltage changeover will be triggered.

4.4.1.1 VGrid Event The process starts by setting the grid parameters values on the control terminal. An ex-ample for VGrid event parameters can be seen in table 5.

Table 5: VGrid Event parameters [43].

When the VGridEvent is triggered there’s a change of the grid voltage. The switches of the grid change their position whether from bottom to upper position or the opposite. The val-ues that have being entered in the main window will correspond to the new values.


To change back the grid voltage, both events will have to be activated serial. This is be-cause that the triggering of one Vgrid Even only provokes one voltage changeover. Mean-ing that the first event is responsible for the change of the grid voltage and second to re-verse the grid changeover. An example can be seen in figure 4.6.

These settings allow to simulate short-circuits. Note that they only present for a short period of time and are dis-connected from the respective protection device.

The parameter VGridEventGradientLim has to be set to 1 (one) to be activated so that doesn’t limit the gradient for all VGid Events and VGrid2FT Events.

R, S and T are the three phases of the grid voltage pa-rameters. They are the initially settings for the Ugrid (grid voltage), which represents the initial condition to start a simulated case. These values can be changed dur-ing the simulation period by manually procedure or by clicking the area (surrounded by the red colour) and the infinite bus voltage (Phase R) will change its value. Figure 4.6: VGrid Event [43].

Except for the grid, the parameters can be set for everything. The grid parameters are usual-ly calculated through internal procedures [43].

4.4.1.2 Frequency event The following parameters should be set as illustrated in table 6.

Table 6: Frequency event parameters [43].

When the FreqEvent is triggered, the grid frequency will change accordingly to the parame-ters that have been defined.

For more simulation events refer to the document Simulator STMS-RT 6000, page 87 [43].

Note that the referred document may change in the future. Page and chapter may also change.


4.5 Price for the MPSS components The prices have been obtained through the R&D engineers and price negotiator responsible at Siemens. Since the R&D Department is already in possession of the AVR system unit, only the following remaining components have to be purchased:

Simulator: N/A Simulator software licences N/A Control system: N/A Converter: N/A Cabinet N/A

Note that prices and modules may vary and updated quotation may need to be required.

4.6 MPSS documentation The documentation has been partly obtained through Siemens contacts, especially the R&D Department.

The documentation package refers to the operator’s manual for operation of the following MPSS main components:

Simulator SMTS-RT 6000. Automatic Voltage Regulator UNITROL 1020 AVR. Control System SIMATIC PCS7.

Additionally, this documentation includes information on service and maintenance, parame-ters tables and technical data.

4.7 Result The result presents a complete pre-study for a simulator system, which contains the basic theory on energy production and suggests the components to build the MPSS by the R&D Department engineers at Siemens Turbomachinery AB at a later stage.

The designed simulator system covers the R&D Department needs such as:

A more automated simulator system that performs tasks faster and more efficiently than currently.

A simulator system that can be moved and used in different locations. A simulator system that can be used to train the R&D engineers. Instructions on how to simulate real life scenarios, for instances errors.

Additionally, the prices for the MPSS components and quick user instructions on how to perform a simulation are also presented. However, the total price cannot be disclosed due to Siemens confidential agreement.

Furthermore, in order to assist the R&D engineers to build the MPSS, a detailed circuit dia-gram that can be seen in figure 4.7 has been designed.


Figure 4.7: Circuit diagram.

The circuit diagram shows the different components of the MPSS, assigned interface con-nections and the connection between these components

63 | ANALYSIS AND DISCUSSION

5 Analysis and discussion

5.1 General aspects The fact that Siemens Industrial Turbomachinery AB is an established and very prestigious company in the engineering world leads to high demands and expectations on the employ-ees.

The complex nature of this project has made the execution process interesting and challeng-ing. It has been difficult to find the correct information at earlier stage and when the infor-mation has been found most of the material has been considered confidential. This issue has been resolved after improvements in the communication procedures with the stakeholders by introducing a further weekly project meeting (PM). These meetings have improved the working practices for this project and have facilitated the access to more information. Addi-tional resources have been put at its disposal and these regular meetings have created a closer collaboration between the different stakeholders.

Another aspect to be mentioned is the short time initially assigned for this project. This has been noticed during and after the research phase. Several tasks have taken longer to be exe-cuted, for example it has been difficult to get in contact with the ABB contact person, re-sponsible for the excitation and simulator equipment. This has forced extension of the pro-ject scope, allowing more time to enquire for information.

During the research phase, it has been learned that the pretended MPSS would require three main components: The AVR, simulator and control system. The R&D department at Sie-mens already owns one of the three components, namely the AVR system. Therefore, only two components need to be obtained, which are the simulator and the control system. This will contribute to reduce the costs to build the MPSS by using the existing AVR system. This is in alignment within R&D Department goals, which is to keep within budget.

The resources made available by the R&D Department, such as access to relevant infor-mation, communications tools, supervisors, equipped workstation etc., have contributed to overcoming the different obstacles encountered through the entire process.

5.2 Simulator choice The R&D Department at Siemens has previously partnered with ABB Company on several projects. Part of the personnel had also attended excitation systems courses at ABB. This has led to the decision to select ABB to be the primary company to provide the simulator component.

The latest powerful SMTS-RT 6000 Simulator from ABB can be connected to any AVR/SES brand of external AVR system. Since an external AVR system is to be used, this simulator component has been selected for the MPSS.

The SMTS-RT 6000 Simulator from ABB offers the advantage to not require programming knowledge to set up simulation cases or event-series.

64 | ANALYSIS AND DISCUSSION

Another advantage of the SMTS-RT 6000 Simulator is that it does not require modifica-tions on other selected components, for instance the AVR and control system. This makes the simulator component compatible with other components.

However, until the end of this thesis work, it has not been possible to get the price for the extra software. This has been due to difficulties to get in contact with sales responsible per-sonnel at ABB, despite the effort.

5.3 AVR choice The AVR system, which is already owned by the R&D Department, is self-supervised and does not require any special service. But it is recommended to inspect the equipment for dirt or eventual loose connections, at least once a year.

However, the plant operators must be familiar with the layout of the control display ele-ments as well as with the effect of commands on the excitation system.

When using the control and display elements, the plant operators shall be able to adapt the generator parameters to adjust the excitation system circuits to the operating conditions of the power station and / or of the network.

5.4 Control system choice The Siemens SIMATIC PC7 control system is a powerful control tool with several applica-tions that can potentially extend the performance of the MPSS. The control system unit offers the advantage of being open for external control systems environment. This feature makes this device suitable for integrating the MPSS.

However, the price of the control system unit has not been disclosed due to confidentiality reasons raised by the control system stakeholders.

65 | CONCLUSION

6 Conclusion

The task in this thesis work has been to identify the suitable components to build a simula-tor system that could be used by Siemens to test the performance of the AVR. The AVR is a component with its’ prime purpose being to maintain the output voltage values from the generator at a fixed value, regardless of the current being drawn by the load.

The proposed components are compatible and meet the requirements and standards set by Siemens. These components, together with their functionalities are described in this thesis work to provide a clear understanding.

The choice of these components reflects the deep research carried out and advises from experts in the field of energy production, simulator, AVR and control systems. This thesis work will give a possibility for Siemens to identify solutions, which could minimize their OPEX (Operational expenditure) and easily evaluate their AVR solution and test improve-ments in a simpler and faster way.

The benefit to own and use of a simulator system by the R&D Department at Siemens will significantly contribute to eliminating the different issues previously raised by the R&D engineers such as:

The automatic voltage regulator could be only tested on sites. Being dependent on external companies to perform the tests on the AVR each time

such is required e.g. when an upgraded is done. Increased costs for the external personnel and rental of equipment. Could take longer to identify and solve errors on site.

The proposed design on the simulator system will be capable to test the AVR performance and serve for training purposes as required by the R&D Department at Siemens Industrial Turbomachinery AB.

To assist in building the MPSS, the proposed circuit diagram of the simulator system has been designed. The circuit diagram provides the layout of the components, connection in-terfaces and the connection between the MPSS components. Details of the circuit diagram can be seen in appendix E.

6.1 Recommendations The simulator component normally comes with basic software, called Lite licence. For simulator system to fully cover the R&D department requirements, extra software called Professional licence is recommended. This licence covers all the R&D department require-ments, for example the possibility to access and customize all the important model parame-ters. Additionally, it allows the user to adjust the generator and exciter parameters as de-sired.

This type of project requires a proper project management structure and allocation of extra time in the research phase, especially sourcing the phase to enquire for the right companies to provide the components and advice needed.

66 | CONCLUSION

67 | BIBLIOGRAPHY

7 Bibliography

[1] Large generator for power generation. https://www.siemens.com/global/en/home/products/energy/power- genera tion/generators.html#!/ , Obtained 2017-10-29.

[2] Elkraft Teknik, Thomas Franzen, Silvert Lundgren, Hombergs, 2012. [3] World Map of Mains Voltages and Frequencies

https://commons.wikimedia.org/wiki/File:World_Map_of_Mains_Voltages_a nd_Frequencies,_Simplified.png, Obtained 2017-10-29.

[4] Schematic diagram of a generator

.https://sasco54.wordpress.com/generator/schematic-diagram-of-generator/, Obtained 2017-09-27.

[5] Principles of Electric Machines and Power Electronics, P.C.Sen ,Wiley, 2013 [6] Stator core pictures. https://img.diytrade.com/smimg/2255823/42473025-

3344327-0/generator_stator_core/b795.jpg, Obtained 2017-09-27. [7] Synchronous rotor.

https://en.partzsch.de/files/Komponenten/Laeuferwicklungen/Polrad/Polrad_1 .jpg Obtained 2018-03-10.

[8] Electrical concepts http://electricalbaba.com/difference-between-cylindrical- and-salient-pole-rotor-synchronous-generator/, Obtained 2018-03-11.

[9] Salient-pole rotor vs non-salient pole rotor. http://www.electricaleasy.com/2014/03/salient-pole-rotor-vs-non-salient- pole.html Obtained 2017-09-28.

[10] Wärtsilä generator bearings, https://www.wartsila.com/products/marine-oil- gas/seals-bearings/wartsila-industrial-g-bearings, Obtained 2018-04-20.

[11] Generator cooling airflow, http://4.bp.blogspot.com/b2ilZg01vFc/UQA1Jo38XfI/AAAAAAAAJXA/GX FMVq9nTLw/s1600/Fig+2.1+TYPICAL+AC+GENERATOR.jpg, Obtained 2017-09-29.

[12] Protection and control devices. https://library.e.abb.com/public/f37f289ec523541dc1257b5500308dc3/ABB %20Technical%20note%20-%20Cooling%20systems_lowresf.pdf, Obtained 2017-09-30.

[13] Condition based monitoring. https://irispower.com/wp- con tent/uploads/2016/12/Iris-Power-Condition-Based-Monitoring-Turbo- GuardII.pdf , Obtained 2017-10-30.

[14] Instrumentation, control and electrical. Siemens, 2014. Siemens internal con fidential document, Obtained 2017-10-20.

[15] Electrical and control. Siemens: STI No. 4100-18E, 2012; Siemens internal confidential document, Obtained 2017-10-20.

[16] Instrumentation, control and electrical. Siemens, 2015. Siemens internal con fidential document, Obtained 2017-10-20.

[17] Electrical and control. Automatic voltage regulator. Siemens, 2012; Siemens internal confidential document, Obtained 2017-10-20.

[18] Protection relay and control product lines. http://w3.siemens.com/smartgrid/global/en/products-systemssolutions/, Ob tained 2017-10-12.

68 | BIBLIOGRAPHY

[19] Electrical and control. Generator protection. Siemens, 2012; Siemens internal confidential document, Obtained 2017-10-20.

[20] UNITROL 1020 Indirect excitation system. http://new.abb.com/power- electronics/excitation-systems/indirect-excitation-systems/unitrol-1020/main- features, Obtained 2018-02-18.

[21] G.N.Patchett, Automatic Voltage Regulators and Stabilizers, 3rd edition, Pit man , jul 1970.

[22] AVR Double and single channel. https://library.e.abb.com/public/767e4cdd90664ee3c1257b4f0028a64d/3BHS 353843_E01_B_O.pdf?xsign=vXABFbknIt+GE84kmbivHzLkafHgYMsiR4u 2md1AMGdSujX2BPfjKKkDWg5xHB82, Obtained 2017-09-11.

[23] Finn Haugen, PID Control, Tapir Academic Press, 2004 [24] Introduction to process control. https://www.dewesoft.com/pro/course/pid-

control-53, Obtained 2017-10-16. [25] PID Compensation animated.

https://commons.wikimedia.org/wiki/File:PID_Compensation_Animated.gif , Obtained 2017-10-16.

[26] Carl Johan Åström, Tore Hägglund, ISA-The instrumentation, Systems and Automation Society, 2006

[27] P. M. Anderson and A. A. Fouad, Power System Control and Stability, John Wiley& Sons, 2003.

[28] Philip Kiameh, Power Plant Instrumentation and Controls, McGraw-Hill Pro fessional; 1 edition 2015.

[29] System description. Control systems. Siemens, 2012. Siemens internal confi dential document, Obtained

[30] Gas turbine control system. http://www.constructionweekonline.com/pictures/TS_Control_web.jpg, Ob tained 2017-10-14.

[31] Closed-loop feedback control system. https://www.britannica.com/technology/closed-loop-feedback-control-system , Obtained 2018-04-21.

[32] Turan Gören, Electrical Power Distribution, Third edition, CRC Press 2014 [33] Juan M. Gers and Edwards J. Holmes, Protection of Electricity Distribution

Network (3rd Edition) IET, 2011 [34] Improving power system stability through integrated power systems stabilizer,

ABB Group 2018 [35] SMTS-RT 6000. Synchronous Machine Transient Simulator- Real Time.

https://library.e.abb.com/public/55dcb956701f0257c125775e0052ab82/3BHT 490488_E01_B_O.pdf (14/09/2017)

[36] Power Electronics Excitation Systems. Siemens 2017. Siemens internal confi dential document, Obtained 2017-10-22.

[37] Document UNITROL 1020 Double Channel, Standard AVR System plates. ABB (23/11/2017); Siemens internal confidential document, Obtained 2017- 10-22.

[38] Document UNITROL 1020 User Manual, Automatic Voltage Regulator ABB (14/09/2017); Siemens internal confidential document, Obtained 2017-10-22.

[39] SMTS-RT 6000. Synchronous Machine Transient Simulator- Real Time. https://library.e.abb.com/public/55dcb956701f0257c125775e0052ab82/3BHT

69 | BIBLIOGRAPHY

490488_E01_B_O.pdf, Obtained 2017-09-16. [40] SIMATIC PCS 7, Process Control System, Siemens, Edition 2017 [41] Material handling. http://www.pyroban.com/en/material-handling/more-

aboutzones/what-is-zone2, Obtained 2017-10-16. [42] SIMATICIPC547G PC- based Automation. https://w3.siemens.com/mcms/pc-

based-automation/en/industrial-pc/rack-pc/simatic- ipc547g/pages/default.aspx, Obtained 2018-04-20.20.

[43] Electric Equipment. SGT-600, SGT-700, SGT-750, SGT-800 Siemens: Sie mens internal confidential document, Obtained 2017-10-22.

[44] Anybus Communicator PROFIBUS. www.anybus.com, Obtained 2017-10-16.

70 | BIBLIOGRAPHY

71 | APPENDIX

8 Appendix

Appendix A. Simulator I/O Terminals

72 | APPENDIX

Appendix B: Simulator technical data

The simulator unit can be connected to 100 V/ 110 V and 1A / 5A inputs of the AVR/SES of any brand. A 10Mbit optical link is used to establish the connection between the simula-tor and the excitation controller.

Simulator hardware requirements

Operating system: Windows XP (SP)

CPU: Pentium (or equivalent) min. 2GHz

RAM: 2.00 GB

Free Hard disk space: 10 GB

73 | APPENDIX

Appendix C. AVR System terminal connection blocks

74 | APPENDIX

75 | APPENDIX

AVR Technical data

System Requirements for the UNITROL 1020 AVR

Minimum Pentium 1 GHz or equivalent processor. It is recommended to use Penti-um III or Celeron 1 GHz or equivalent processor or higher.

Requires a minimum 512 MB RAM. Minimum screen resolution of 800x600 pixels. It is recommended 1024x768 pixels

or higher. CD-ROM drive. Microsoft Windows XP, Vista or Win 7. Minimum 10 GB or free hard disk space

76 | APPENDIX

Mechanical dimensions (Dimensions are in dm)

Top view Lateral view

77 | APPENDIX

Components and designations

78 | APPENDIX

Appendix D: Control system

CPU and HMI technical data

CPU

Product type designation CPU 410-5H Process Automation Integrated 48 Mbytes load memory, not expandable Integrated 32 Mbytes RAM, not expandable CPU processing speed 450 MHz Average processing time of APL typical Approx. 110μs Up to 2600 process objects Emission of radio interference EN 55011 Limit class A for use in industrial areas Operation temperature 0 to 60°C Operation relative humidity 0 to 95%rH without condensation Standards, specifications and approvals: CE mark, cULus, CSA, FM, ATEX HMI

Intel Core i5 3.6GHz 16 GB DDR4 SDRA 2x480GB SSD, RAID 1 2xGBit LAN (RJ45) DVD±/-R/RW optical drive Standard keyboard Windows Simatic PCS7 software Temperature during operation 0°C to 40°C at maximum configuration Humidity during operation 5 to 80%rH @ 25°C non condensing Emitted interference (AC) EN 55022 class B, FCC class A Approvals and safety regulations Safety regulations IEC 60950-1; UL 60950-1; CSA Approvals cULus 60950 CE marking Use in the office and industrial sectors Emitted interference: EN 61000-6-3:2007 Noise immunity: EN 61000-6-2:2005 19” Screen integrated in cabinet

79 | APPENDIX

IPC547G Technical Data

80 | APPENDIX

81 | APPENDIX

82 | APPENDIX

83 | APPENDIX

Converter Technical data

System requirements

Pentium 133 MHZ or higher

650 MB of free space on the hard drive

32 MB RAM

Screen resolution 800 x 600 (16 bit color) or higher

Microsoft Windows® 2000 / XP / Vista / 7 (32- or 64-bit)

Internet Explorer 4.01 SP1 or newer (or any equivalent)

Installation

- Anybus communicator CD - From HMS website (www.anybus.com)

Connector Pin assignment

84 | APPENDIX

Converter technical specification

85 | APPENDIX

Appendix E. MPSS Circuit diagram

86 | APPENDIX

87 | APPENDIX

88 | APPENDIX

TRITA CBH-GRU-2018:55

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