Appendix - JICA · 2012-05-09 · Appendix Study for Updating Syrian Electricity Sector in Syrian...

Appendix Study for Updating Syrian Electricity Sector in Syrian Arab Republic

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Table of contents

Part A Transfer of technology to the counterpart

1. Purpose of Technical transfer and training

1.1 Transfer of technology to the counterpart and development of

human resources......................................................................................................A1-1

1.1.1 Implementation of technology transfer ........................................................A1-2

1.2 Function and procedures of Power and energy demand forecasts........................A1-3

1.2.1 Structure of power demand forecasting model ............................................A1-3

2. Model building for power and energy demand forecasts

2.1 Seminar program and participants..........................................................................A2-1

2.2 Seminar style and textbook.......................................................................................A2-1

2.3 .TEXT Energy Demand Forecasting Model............................................................A2-3

3. GDP potential and Energy price estimation

3.1 Seminar program and prticipants............................................................................A3-1

3.2 Seminar style and textbook.......................................................................................A3-1

3.3 TEXT Syria Crude oil & natural gas price .............................................................A3-2

4. Technology Transfer for Power Development Plan Preparation

4.1 Technology transfer related to Power Development Plan Preparation ................A4-1

4.1.1 First Counterpart Training Seminar ............................................................A4-1

4.1.2 Second Counterpart Training Seminar ........................................................A4-7

4.2 TEXT Power Developmetn Planning on Syria Energy ..................................... A4-t1

4.3 TEXT Outline of Thermal Power Generation Energy...................................... A4-t2

4.4 TEXT PDCA Cycle for Thermal Power Plant Operation & Maintenance ..... A4-t3

4.5 TEXT Management of Equipment Failure and Human Error ........................ A4-t4


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Part B Basic Design of Terhmal Power Plants

1.1 Basic Design of Terhmal Power Plants ....................................................................................B-1

1.2 Basic Design of Combined Cycle Thermal Power Plant ........................................................B-5

1.2.1 Outline of Plants .......................................................................................................B-5

1.2.2 Operation of Power Generating Equipment ..........................................................B-5

1.2.3 Outline of Generating Equipment Control ............................................................B-7

1.2.4 Ezamnation of Basic Technical issues .....................................................................B-9

1.2.5 Optimization of bottoming Cycle .......................................................................... B-11

1.2.6 Exhaust Gas Turbine Equipment..........................................................................B-15

1.2.7 Auxiliary Steam Boiler ...........................................................................................B-17

1.2.8 Standard and Criteria ............................................................................................B-17

1.2.9 Environment ...........................................................................................................B-18

1.2.10 Gas Turbine...........................................................................................................B-19

1.2.11 HRSG.....................................................................................................................B-19

1.2.12 Steam Turbine .......................................................................................................B-19

1.2.13 Fuel Supply Equipment .......................................................................................B-20

1.2.14 Water Treatment Apparatus................................................................................B-21

1.2.15 Wastewater Treartment Unit ...............................................................................B-21

1.2.16 Firefighting Equipment........................................................................................B-21

1.2.17 Electrical Equipment ...........................................................................................B-22

1.2.18 Power Generation Equipment Protection andControl......................................B-26

1.2.19 Civil and Building Works ....................................................................................B-28

1.2.20 Construction Cost.................................................................................................B-29

1.3 Basic Plan of the Coal-fired Thermal Power Plant ..............................................................B-32


List of Tables

Table a-1 Detailed items to be used for technical transfer knowledge ................................................ A1-2

Table a-2 Schedule and seminar contents............................................................................................ A1-1

Table a-3 Name list of the participants................................................................................................ A2-1

Table b-1 Examination Results and Recommendations .................................................................B-2

Table b-2 Startup Time Schedule ................................................................................................B-6

Table b-3 Startup Frequency ....................................................................................................B-7

Table b-4 Vibration Control Values ..............................................................................................B-8

Table b-5 Gas Turbine Model Performance .................................................................................B-10

Table b-6 CCPP Model Performance ....................................................................................... B-11

Table b-7 Bottoming Cycle Performance .....................................................................................B-13

Table b-8 Bottoming Cycle Construction Cost ...........................................................................B-14

Table b-9 Limit Values on Concentration of Air Pollutant Emissions..........................................B-18

Table b-10 Noise Standard ...........................................................................................................B-18

Table b-11 Protected Areas and Firefighting Equipment .............................................................B-22

Table b-12 Generator Specifications ............................................................................................B-23

Table b-13 Standard Specifications of Transformers ...................................................................B-25

Table b-14 Generator Protective Circuit.......................................................................................B-26

Table b-15 Construction Cost Calculation ...................................................................................B-29

List of Figures

Figure a-1 Block flow of power demand forecasting model ............................................................... A1-1

Figure a-2 Data processing of power demand forecasting model ....................................................... A1-1

Figure b-1 Examination Flow ............................................................................................................. B-1

Figure b-2 Priority Implementation Items in the Next Plan .................................................................. B-4

Figure b-3 Combined Heat Balance ................................................................................................. B-31

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A1-1

1. Technical transfer and training

1.1 Transfer of technology to the counterpart and development of human resources

After the electric power system has been worked out by the JICA Study Team, the Syrian side is

required to take charge of revision of the power development plan, periodic prediction of

electricity demand prediction and review and reexamination of the power system plan. To

achieve this objective, it is important to implement technology transfer effectively within the

limit period of time. Efforts were made to implement strategic technology transfer through a

seminar or similar events. Technology transfer is one of the major items in this survey activity.

Particularly with reference to the electricity/energy demand prediction procedure and power

development plan included in the present survey work, such basic technologies as the concept of

supply reliability, economical operation of the power supply system, and power development

planning technique are essential to the PEEGT as a counterpart organization which is responsible

for continued development of the Syrian electricity sector. Accordingly, the above-mentioned

technologies shall be transferred in such a way that the counterpart organization can use these

technologies independently after completion of this survey.

(1) Electricity/energy demand prediction procedure In the project, an electricity/energy demand prediction model is worked out to predict

the electricity demand for the power development plan. For the supply of primary energy required for power generation, it is important to ensure consistency with the amount of power generation. The technology regarding a series of the related work is transferred to the PEEGT and related organizations.

(2) Power development planning procedure For the power development planning procedure, the results of studies on optimization

of power source based on a development scenario and system reliability as well as the supply-demand operation simulation program (PDPAT II) are transferred to the counterpart organization. The data employed in the study made so far is used for instruction of the operation method and training to enhance the level of skill. Further, instruction and training will be provided regarding the method of analyzing the power development plan using a supply-demand operation simulation program.

The following shows specific implementation items:


A1-2

Table a-1 Detailed items to be used for technical transfer knowledge

Implementation items Trainee Description

First power development plan induction course (Within the country)

Related persons of the counterpart organization Four persons

Acquisition of the concept and technique of power development plan

Concept of supply reliability Concept of economical operation of

power source Economic viability assessment

technique Hands-on training by PDPAT II Visit to thermal power plants within

the jurisdiction of TEPCO

Second power development plan induction course (Within the country)

Related persons of the counterpart organization Four persons (changed to six)

Preparation of the Syrian power development plan based on the result of field survey, and discussion

Introduction of Japanese technologies for diversification of power sources for Syria

Explanation of the result of survey made so far, and discussion on the result of study

1.1.1 Implementation of technology transfer

1) Power development planning procedure In the first technology transfer meeting, four engineers of Syrian PEEGT Planning

Bureau were invited to Tokyo during the period from July 16 (Sun) through July 31 (Sun), and training was provided regarding simulation programs and domestic power generation facilities, where a visit to manufacturers was included.

In the second technology transfer meeting, six engineers of Syrian PEEGT Planning Bureau were invited to Tokyo during the period from November 13 (Sun) through November 27 (Sun), and training was provided regarding simulation programs and domestic power generation facilities, where a visit to manufacturers was included.

2) Electricity/energy demand prediction procedure During the period from September 18, 2011 through September 20 in the third field

survey, a seminar was held for six engineers of Syrian PEEGT Planning Bureau to explain about the electricity/energy demand development program developed for this project (at the work office of TEPSCO, Amman, Jordan due to aggravating public security in Syria).


1.2 Power and energy demand forecasts

1.2.1 Structures of power demand forecasting model

(1) Required functions of power demand forecasting model

The following functions are required by the energy demand forecasting model in the project.

The model has to link social economic activities.

The model has to be affected by the changes of energy prices and energy efficiency and

conservation (EE&C) policies.

The model has to be able to forecast power and final energy demands by sector

(Agriculture, Industry, Commercial & Services, Public, Transportation and Residential

sectors).

The model has to be able to forecast power, final energy and primary energy demands in

whole country and those should be compared to other countries.

(2) Block flows of power demand forecasting model

At first, the energy demand forecasting model calculates sectoral power demand and final

energy demand, after that, power generation, energy resources for the power sector and

primary energies are calculated. Econometric theory is used for model building methods.

The following figure is the procedure that shows the power and energy demand forecasting

model.

Figure a-1 Block flow of power demand forecasting model

A1-3


Source: JICA Study Team

Figure a-2 Data processing of power demand forecasting model

(3) Procedures of power demand forecasting

The targeted sectors are Power, Industry, Commercial & Services, Public, Transportation and

Residential sectors. The forecasting procedures are as follows;

The power and energy demands of the sectors are estimated with future energy intensities per

sectoral GDP (for residential sector, energy consumption per population is used) extended

from the past trends.

The power and fossil energies are estimated by sectoral GDP, power ratio, energy price

elasticity, energy conversion policy (share functions of energies) and introduction of energy

management system (EMS).

The consumed energies in power sector are estimated under power development plan.

Finally, sectoral power demand, final energy demand, primary energy demand and energy

intensities after implementing EMS are forecasted.

A1-4


A2-1

2. Model building for power and energy demand forecasts

2.1 Seminar program and Participants

(1) Seminar room

Meeting room of TEPSCO in Amman

(2) Seminar contents

The following contents are explained in two and half days. For explaining the contents, three

day are needed originally. However the seminar is implemented in two and half days due to

short time staying of the C/P in Amman.

Table a-2 Schedule and seminar contents

Date Time Contents 20th Sep 10:00~16:30 1. Growth rate, Intensity and Elasticity

2. Economic data analysis 3. Methods of energy demand forecasting

21st Sep 10:00~16:30 4. How to use Simple E 5. Energy Demand Forecasting Model on SEEX 6. Syria Demand Forecasting Model (Model structures)

22nd Sep 9:30~11:30 7. Syria Economy and GDP potential 8. Power & Energy Demand Forecasts (Simulation Results)

(3) Names of participants

Six persons participate from PEEGT as C/P

Table a-3 Name list of the participants

NO Names Title 1 Mr. Nabil Al Sharaa PEEGT Planning Director 2 Mr. Fawaz Al Dhaher PEEGT Deputy Manager of Dispatching Center 3 Mr. Sameer Ishak PEEGT Electric engineer, Planning Dept. 4 Mr.Adnan Al Hallaq PEEGT Power Plant, Construction Dept. 5 Ms.Mona Mtawej PEEGT Planning Dept 6 Ms.Fatima Hamza PEEGT Electric Engineer, Planning Dept

2.2 Seminar style and textbook

(1) The instructor explained the following PPT files to the participants. The participants use

PCs delivered by JICA Amman and practiced the exercises for their understanding


A2-3-1


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A2-3-21



A3-1-1

3 GDP potential and Energy price estimation

3.1 Seminar program and Participants

(1) Seminar room

Meeting room of JICA Training center

(2) Seminar contents

The following contents are explained in 2.5 hour seminar in JICA training center on date

24th September 2011

Table a-4 Seminar contents

Time Contents 13:30~16:00 Crude oil & Natural gas Market in middle and long term

1. Factors for Crude Oil Price 2. Crude oil market in middle & long term 3. Natural gas market in middle & long term

(3) Names of participants

Six persons participate from PEEGT as C/P

Tablea-5 Name list of the participants

NO Names Title

1 Mr. Nabil Al Sharaa PEEGT Planning Department Planning Director

2 Mr. Maher Bakla PEEGT Dispatching Department Operator

3 Mr. Sameer Ishak PEEGT Planning Department Technical Engineer

4 Mr. Mohamad Farham Alhussen PEEGT Dispatching Department National Dispatching Center Operator

5 Ms. Nour Aldabak PEEGT Studies Department Technical Engineer

6 Ms. Reem Alhomsi PEEGT Construction Power Plant Department Technical Engineer

3.2 Seminar style and textbook

The instructor explained the following PPT files to the participants.


A3-2-1


A3-2-2


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A4-1

4.1 Technology Transfer Related to Power Development Plan Preparation

The power development plan is not only be prepared during the present study, but even after

the end of this study, it is necessary to carry out review and optimization of the plan according

to the progress of the study. In order to proceed with the work from now on efficiently,

technology transfer to the concerned persons in the Syrian organizations is necessary since it is

essential to learn the method of using the simulation software (PDPAT-II and RETICS) used at

the time of formulating the power development plan in the present study. In view of these

purposes, in the present survey, a training seminar was conducted related to the preparation of

the power development plan (counterpart training seminar).

4.1.1 First Counterpart Training Seminar

(1) Training seminar period

July 19 to 29, 2011

(2) Schedule

The schedule of the training seminar was as shown in Table 11.1-1.

(3) Participants

The participants from the counterpart organizations were the persons listed in Table 11.1-2.

The participants were selected mainly from the planning department of PEEGT, and

constituted of a group consisting of a director, key persons in charge of technology and

finance, and the leader of the organization governing the system operation (who is actually

the head of the National Dispatching Center).

All these members were capable persons well-versed in their respective fields, and the

combination of persons was not only one that suited the intent of this training, but also

these persons were considered to be very important for spreading the technology and

knowledge acquired through this training seminar.

(4) Contents and results of training seminar

(a) Lectures and demonstrations related to power development planning

Explanation of the general theory of electric power development planning, description of

the functions of the tools (PDPAT-II and RETICS), and demonstration using the tools were

provided during the training seminar.

In the lectures on the method and general theory of preparing an electric power

development plan, there were many parts providing new knowledge or concepts to the

participants, and it is thought that they not only listened intently but also deepened their

understanding.

In the lectures and demonstrations using the tools, there were some that used material based

on the current status and plan of their country, and it appears that they obtained a more

realistic understanding. Also, they exhibited quick grasp of the details and the method of

handling the software. It was possible for them to acquire not only the basic knowledge


A4-2

but also understanding of the more advanced functions, and the training seminar appears to

be very meaningful.

There were frequent questions from the participants during the lectures and demonstrations,

and it was possible to carry out very dynamic and interactive lectures and demonstrations.


A4-3

Table a-6 Schedule of the first counterpart training seminar

18-Jul Mon Come to Japan

19-Jul Tue 09:00 ～ 12:00 Briefing, Orientation (JICA) JICA Tokyo

14:00 ～ 16:30 L Power Sector in Japan JICA Tokyo

20-Jul Wed 09:00 ～ 10:00 L About TEPCO JICA Tokyo

10:00 ～ 12:00 DDiscussion about Progress ReportConfirmation of discussion points

JICA Tokyo

13:30 ～ 16:00 DCurrent status and development plan of powersystem in Syria (presentation from Syria)

JICA Tokyo

21-Jul Thu 09:00 ～ 12:00 L Outline of Power Development Planning JICA Tokyo

13:30 ～ 17:00 L How to use PDPAT and RETICS JICA Tokyo

22-Jul Fri 13:30 ～ 16:30 VSite visit (factory of thermal power plant facility,MHI Takasago Works)

MHI Takasago Works

23-Jul Sat ～ Himeji - Tokyo24-Jul Sun ～ Holiday

25-Jul Mon 09:00 ～ 12:00 L,E Lecture and Exercise regarding PDPAT and RETICS JICA Tokyo

13:30 ～ 16:30 L,E Lecture and Exercise regarding PDPAT and RETICS JICA Tokyo

26-Jul Tue 09:00 ～ 12:00 L,E Lecture and Exercise regarding PDPAT and RETICS JICA Tokyo


27-Jul Wed 10:30 ～ 14:30 VSite visit about Renewable energy power station(solar power, micro hydropower)

Komekurayama, Hokuto, inYamanashi Pref.

28-Jul Thu 09:00 ～ 12:00 L,E Lecture and Exercise regarding PDPAT and RETICS JICA Tokyo


29-Jul Fri 09:30 ～ 12:00 D Confirmation about discussion items JICA Tokyo

13:30 ～ 14:00 Action plan JICA Tokyo

14:30 ～ 15:00 Close ceremony JICA Tokyo

30-Jul Sat Return to SyriaD:Discussion, L:Lecture, E:Exercise, V:Visit

Date VenueTime Item


A4-4

Table a-7 Participants of the first counterpart training seminar

No. Name Occupation

1 Mr. Nabil Alsharaa

PEEGT (Public Establishment of Electricity for

Generation and Transmission)

Planning Department

Planning Director

2 Mr. Sameer Ishak

PEEGT

Planning Department

Technical Studies

3 Ms. Mona Mtawej

PEEGT

Planning Department

Economic Studies

4 Ms. Fawas Alzaher

PEEGT

National Dispatching Center

Head of Dispatching Department

Fig. a-3 Scenes from lectures, discussions, and demonstrations (first training seminar)

(b) Study and inspection tours of power generation facilities

With the purpose of providing an opportunity to see in person the electric power generation

facilities in Japan so that it can be used as reference material for preparing the power

development plan, this training seminar included study and inspection tours of electric

power generation facilities and equipment.

The following three locations were selected this time for the visits: the Takasago Works of

Mitsubishi Heavy Industries Ltd., which is manufacturing thermal power plant facilities

(mainly gas turbine facilities) and has the track record of having made several deliveries to

Syria; the construction site of the large scale solar electric power generation facility located

in Yamanashi Prefecture (the Konekurayama Mega Solar Power Plant), as the site of an


A4-5

electric power generation facility of Tokyo Electric Power Company; and the

Rokkason-seki hydroelectric power plant in Hokuto City, Yamanashi Prefecture, also,

similarly, as an example of a power generation facility using renewable sources of energy, .

In the site of manufacture of gas turbines with which the participants were familiar, the

participants appeared to be surprised at the highly precise management that was beyond

their imagination. Further, even about solar power generation and small hydroelectric

power generation, they seemed to have a strong feeling that these should be introduced

aggressively in their country as well, they appeared to observe everything very keenly.

Fig. a-4 Visit to Takasago Works of Mitsubishi Heavy Industries

Fig. a-5 Visit to Konekurayama Mega Solar Power Plant Construction Site


A4-6

Fig. a-6 Visit to Rokkason-seki micro hydroelectric power plant

(c) Discussions

Discussions were held for confirming and agreeing on the preconditions for preparing the

power development plan, the set values, the policies of the country, etc. In a broad

classification, presentations were made by the Syrian side about the organization of the

electric power sector, electric power supply conditions, etc., confirmation was made of

items about which they had been requested to prepare in advance, and confirmation and

discussions were made about some aspects that needed discussions.

Fig. a-7 Scenes from discussions


A4-7

4.1.2 Second Counterpart Training Seminar

(1) Training seminar period

November 15 to 25, 2011

(2) Schedule

The schedule of the training seminar was as is shown in Table 11.1-3.

(3) Participants

The participants from their side were as listed in Table 11.1-4.

Except two persons, all participants were new participants who had not participated in the

first training seminar, and similar to the participants in the first training seminar, the

participants included key persons and persons in charge of technology of PEEGT, and

persons in charge of governing the system operation.

(4) Contents and results of training seminar

(a) Understanding the outlines of preparing the electric power development plan using the

simulation software (lectures and demonstrations)

The training seminar participants included two persons who participated in the previous

first training seminar (the remaining four persons came to Japan for the first time), and

since they had mastered to some extent the basic functions and the method of use of the

simulation software (PDPAT-II and RETICS) during the previous training seminar, they

appeared to proactively guiding the new participants.

In the lectures and demonstrations using the simulation software (PDPAT-II and RETICS),

after a review of the contents of the first training seminar, the data of the current status in

Syria, and the data of the electric power development plan prepared by this survey team

were used concretely, and a concrete procedure for preparing the future optimal plan was

taught in the form of a practice session. The method of selecting based on the differences

between the methods of operating gas turbine and combined cycle type power plants, future

necessity of coal fired thermal power plants which are not existing at present, differences in

whether or not pumped storage hydroelectric power plants are introduced, etc., were

explained in detail, and all participants followed the lectures and demonstrations intently,

and seem to have acquired all the knowledge presented to them. In particular, regarding

the investigation of international coordination, one of the participants had studied

international coordination during the university thesis and hence showed particularly deep

interest, and left the impression that detailed investigations will be done from now on using

the software.


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Table a-8 Schedule of the second counterpart training seminar

14-Nov Mon Come to Japan

15-Nov Tue 09:00 ～ 12:00 Briefing, Orientation (JICA) JICA Tokyo

13:30 ～ 16:00 L,E Power Development Planning Simulation JICA Tokyo

16-Nov Wed 09:30 ～ 12:00 L,E Power Development Planning Simulation JICA Tokyo

13:30 ～ 16:00 L,E Power Development Planning Simulation JICA Tokyo

17-Nov Thu 09:30 ～ 12:00 L,EPower Development Planning Simulation(Role of pumped storage power station)

JICA Tokyo

13:30 ～ 16:00 LOperation and Maintenance of Thermal PowerStation

JICA Tokyo

18-Nov Fri 10:00 ～ 12:00 V TEPCO Chiba Thermal Power Station

14:30 ～ 16:30 V TEPCO Kawasaki Thermal Power Station

19-Nov Sat Holiday20-Nov Sun Holiday

21-Nov Mon 11:30 ～ 15:00 V TEPCO Kannagawa Hydroelectric Power Station by Bus

22-Nov Tue 11:00 ～ 16:30 V MHI Nagasaki Shipyard & Machinery Works

23-Nov Wed Nagasaki - Tokyo

24-Nov Thu 09:30 ～ 12:00 L,E Power Development Planning Simulation JICA Tokyo

13:30 ～ 16:00 L Power Demand Forecast JICA Tokyo

25-Nov Fri 09:30 ～ 12:00 DPower Development Planning SimulationConfirmation about discussion items

JICA Tokyo

14:00 ～ 14:30 Action plan JICA Tokyo

14:30 ～ 15:00 Close ceremony JICA Tokyo

26-Nov Sat Return to SyriaD:Discussion, L:Lecture, E:Exercise, V:Visit

VenueTime ItemDate


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Table a-9 Participants of the second counterpart training seminar

No. Name 名前 Occupation 職業

1 Mr. Nabil ALSHARA

PEEGT (Public Establishment of Electricity for Generation and Transmission) Planning Department Planning Director

2 Ms. Reem ALHOMSI PEEGT Construction Power Plant Department Technical Engineer

3 Mr. Sameer ISHAK PEEGT Planning Department Technical Studies

4 Mr. Maher BAKLA PEEGT Dispatching Department Operator

5 Ms. Nour ALDABAK PEEGT Studies Department Technical Engineer

6 Mr. Mohamad Farhan ALHUSSEN

PEEGT Dispatching Department, National Dispatching Center Operator

Fig. a-8 Scenes from discussions (Second training seminar)

(b) Study and inspection tours

Actual installed facilities of combined cycle power plant and pumped-storage hydroelectric

power plant were visited because of the high probability of their being adopted from now

on in Syria. The visited locations were the Chiba thermal power station, the Kawasaki

thermal power station, and the Kannagawa power station of Tokyo Electric Power


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Company. In addition, in continuation of the previous training seminar, a visit to

Mitsubishi Heavy Industries Limited which has the track record of having delivered several

thermal power plants to Syria, and following the visit last time to their Takasago Works

(gas turbine facilities), this time a visit was made to their Nagasaki Shipyard and

Machinery Works (HRSG and steam turbine facilities).

In the Chiba thermal power station, the participants showed interest in the operation

management organization of the existing power generation facilities, the power generation

cost, etc., and a very active question and answer session was carried out. In addition, in

the Chiba thermal power station, although at present the construction work method of

firstly installing the gas turbines and then adding thereafter the steam turbine facilities is

being made as the No. 3 system (this is the first attempt of this kind in Tokyo Electric

Power Company), since the same method is being planned to be used even in Syria, the

participants appeared to show deep interest in the methods of construction and installation

works.

In the Kawasaki thermal power station, the participants saw with their own eyes a

combined cycle thermal power generation facility which boasts the highest level of thermal

efficiency in the world, and again asked questions actively. They entered the central

operating room where the operations of running the plant are made, showed interest in the

number of operators and the method of giving power dispatching commands, etc., and

again asked various questions.

In the Kannagawa power station, it appeared that the participants obtained a real feel by

seeing the actual plant and not by theory of the construction and role of pumped-storage

hydroelectric power generation plant. They were able to go close to each of the facilities

that were operating and the facilities that were under construction, and appeared to be

satisfied.

In the Nagasaki Shipyard and Machinery Works of Mitsubishi Heavy Industries, the

participants were not only surprised by the hugeness of the factory, but also appeared to be

deeply impressed by the very detailed quality management methods adopted in spite of the

huge size of the factory.


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Fig. a-9 Visit to Chiba thermal power station of Tokyo Electric Power Company

Fig. a-10 Visit to Kawasaki thermal power station of Tokyo Electric Power Company


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Fig. a-12 Visit to Nagasaki Shipyard and Machinery Works of Mitsubishi Heavy Industries

Fig. a-11 Visit to Kana gawa power station of Tokyo Electric Power Company

1

Power Development Planning on Syria

November 2011Tokyo Electric Power Co.

2

2010 (Net) CapacityTotal

North 1065 450 1200 2715 35.0%Aleppo ST 1065 Zezon CC 450 Althwra 680

Albaeth 20Tishren dam 500

West 520 260 0 780 10.0%Banias ST1,2 240 Banias GT 260Banias ST3,4 280

Central 1105 600 0 1705 22.0%Refinery Homs 45 Jander CC 600Meharda ST 400Alzara ST 660

South 400 1850 0 2250 29.0%Tishren ST 400 Nasrieh CC 450

Tishren GT 200Tishren CC 450Dir-Ali-1 CC 750

East 0 315 0 315 4.1%Tayem GT 90Swedieh GT 150Swedieh Petro G 75

Total 3090 3475 1200 7765 100.0%39.8% 44.8% 15.5% 100.0%

HFO Gas Hydro

3

0

100

200

300

400

500

600

700

800

900

1,000

0 50 100 150 200 250 300 350 400

[MW]

[US$

/kW

]Construction Cost of GT

[MW] 30 60 75 100 300Equipment 360 310 290 270 220Civil 44 38 35 33 27Engineering 32 24 20 24 16Erection 44 38 35 33 27Total 480 410 380 360 290

4

0

200

400

600

800

1,000

1,200

0 200 400 600 800 1000 1200

[MW]

[US$

/kW

]Construction Cost of CC

MW 300 450 750Equipment 520 490 450Civil 50 50 50Engineering 50 50 50Erection 80 70 60Total 700 660 610

5

Annual Expense

Construction cost Annual expense (USD/kW/year)

Gas-fired thermal (C/C: 750MW) 610 USD/kW 98.0

Gas-fired thermal (GT: 150MW) 340 USD/kW 56.3

Oil-fired thermal (ST: 250MW) 1,100 USD/kW 154.8

Coal-fired thermal (ST: 250MW) 1,800 USD/kW 271.3

6

Fuel Cost

IEA forecast (2020) Fuel price

(USC/kcal) Efficiency Fuel cost (USC/kWh)

Gas C/C 12.10 USD/Mbtu 4.0 kcal/Btu 4.8 56% 7.4

Gas GT Ditto Ditto 4.8 32.5% 12.7

Oil ST 100.0 USD/bbl 9,600 kcal/kg 7.3 44% 14.3

Coal ST 104.16 USD/ton 6,000 kcal/kg 1.7 44% 3.4

7

Generating Cost - 1

0

10

20

30

40

0% 20% 40% 60% 80% 100%Capacity factor

PSPP Gas CC Gas GT Coal Oil ST

(Cent/kWh)

8

Annual Expense & Fuel cost of Old Facilities

Annual fixed cost

(USD/kW/year)

Fuel price

(USC/kcal)Efficiency

Fuel cost

(USC/kWh)

New Gas-fired C/C 98.0 4.8 56% 7.4

Old Gas-fired C/C 41.2 4.8 49.5% 8.3

Old Gas-fired GT 25.5 4.8 30% 13.8

Old Oil-fired ST 41.3 7.3 42% 14.9

9

Generating Cost - 2

0

10

20

30

0% 20% 40% 60% 80% 100%Capacity factor

New Gas CC Old Gas CCGas GT Oil ST

(Cent/kWh)

10

Relation between Reserve Capacity Rate and LOLE

0

20

40

60

80

100

-2% 0% 2% 4% 6% 8% 10%Reserve capacity rate

LOLE

(H

ours

)

11

Sensitivity Analysis - 1Demand Forecast Error

0%

2%

4%

6%

8%

10%

12%

0% 1% 2% 3% 4% 5%

Demand forecast error (%)

Rese

rve

capa

city

rat

e

LOLE=50hrs LOLE=24hrs LOLE=5hrs

12

Sensitivity Analysis - 2Forced Outage Rate

0%

2%

4%

6%

8%

10%

12%

14%

Base +1% +2% +3% +4%

Forced outage rate

Rese

rve

capa

city

rat

e

LOLE=50hrs LOLE=24hrs LOLE=5hrs

13

Peak Supply PowerGas GT Vs. Gas CC

-140-120-100-80-60-40-20

0204060

0 500 1000 1500 2000 2500 3000

Gas turbine Capacity (MW)

Fixed cost Fuel cost Total(mil. USD)

14

Peak Supply PowerGas GT Vs. Gas CC with PSPP

-120

-100

-80

-60

-40

-20

0

20

40

60

0 500 1000 1500 2000 2500

Gas turbine Capacity (MW)

Fixed cost Fuel cost Total

15

Peak Supply PowerChange in Fixed Cost

-160-140-120-100-80-60-40-20

02040

0 500 1000 1500 2000 2500 3000

PSPP Capacity (MW)

1.4 times 1.2 times Base 0.8 times

16

GT: 2100MWGT: 0MW

17

Base Supply Power

-4000

-3000

-2000

-1000

0

1000

2000

0 2000 4000 6000 8000 10000 12000 14000

Coal-fired thermal Capacity (MW)

Fixed cost Fuel cost Total(mil. USD)

18

Base Supply PowerChange in Fuel Price

-2000

-1500

-1000

-500

0

500

1000

0 2000 4000 6000 8000 10000


Base 0.8 times 0.6 times(mil.

19

Fuel Consumption

0

5

10

15

20

0 2000 4000 6000 8000 10000


(mil. toe)

12.6 million toe

20

Configuration of Capacity

0%

20%

40%

60%

80%

100%

0 2000 4000 6000 8000 10000


Hydro & others Oil Gas Coal

21

Unevenly Distributed Power Plants

Site location of Coal-fired thermal : West areaWest area demand : 11%Necessity of large amount of transmission lines

22

CO2 Emissions

0

20000

40000

60000

80000

0 2000 4000 6000 8000 10000


0

0.2

0.4

0.6

0.8

CO2 emissions Unit emission rate

(mil. kg-CO2) (kg-CO2/kWh)

2010 (present)25,000 mil. kg-CO20.5 kg-CO2/kWh

23

Effect of 1000MW development

680 million kg-CO20.28 million toe20%Solar

1,020 million kg-CO20.41 million toe30%Wind

2,700 million kg-CO21.10 million toe80%Nuclear

Reduction of CO2 emissions

Reduction of Fossil fuel consumption

Capacity factor

24

Recommendation of 2030 Configuration

MW % MW %Hydro 1,200 5 0 0PSPP 0 – 1,200 0 – 5 0 – 1,200 0 – 5HFO 2,500 10 1,000 5

Gas GT 1,500 – 2,500 5 – 10 1,000 – 2,000 5 – 10Gas CC 10,000 – 13,000 45 – 55 6,000 – 8,000 40 – 50Coal 3,000 – 4,000 15 3,000 – 4,000 20 – 25

Nuclear 0 – 2,000 0 – 10 0 – 2,000 0 – 10Renewable 500 – 1,500 2 – 5 500 – 1,500 5 – 10

Total 25,000 100 16,000 100

2030 2016 - 2030

1

Outline of Thermal Power Generation

November 20November 201111Thermal Power DepartmentThermal Power Department

TEPCOTEPCO

All Rights Reserved, Copyright TEPCO 2011 2

Contents

1. TEPCO Corporate Overview

2.TEPCO’s Thermal Power Plants

3.Characteristics of TEPCO’s Thermal

Power Generation


-- Part 1 Part 1 --TEPCO Corporate OverviewTEPCO Corporate Overview


TEPCO Corporate Overview

Okinawa

Kyushu

Chugoku

Shikoku

Kansai

Hokuriku

Tohoku

TEPCO

Hokkaido

Chubu

total898,896

GWh

ShikokuKyushu

Chugoku

Kansai

Hokuriku ChubuTohoku

Hokkaido

TEPCO293,386 GWh

Historical Data in FY2010

The The NineNine Japanese CompanyJapanese Company’’s Power Saless Power Sales

Service Area of Service Area of JapanJapan’’s Ten Power s Ten Power CompaniesCompanies

As of the end of March 2011

38,38,671671Employees:Employees:

14,255.9 billion JPY14,255.9 billion JPYTotal Assets:Total Assets:

293,386 293,386 GWhGWh4,796.5 billion JPY4,796.5 billion JPY

Power Sales:Power Sales:Sales:Sales:

900.1 billion JPY900.1 billion JPYCapital Stock: Capital Stock:

1 1 May 1951May 1951Establishment:Establishment:

TEPCO Energy SourceTEPCO Energy Source

Source : TEPCO ILLUSTRATED in 2011

New Energy etc,0%

Hydro14%

Nuclear27%

Coal2% Oil

17%

LNG, LPG40%


-- Part 2 Part 2 --TEPCOTEPCO’’s Thermal Power Plantss Thermal Power Plants


TEPCO’s Thermal Power Stations

Conventional 24,635 MW (63.2%)LN(P)G 12,285 MW(31.5%)

Oil 10,750 MW (27.6%)

Coal 1,600 MW (4.1%)

CC&GT 14,321 MW (36.8%)Total 38,956 MW

Hitachinaka

15 15 Thermal Power StationsThermal Power Stations889 Units9 Units

Central TPO

West TPO

East TPO

As of the end of March 2011


East TPO* 17,317 MW (44.5%)West TPO 10,249 MW (26.3%)Central TPO 11,390 MW (29.2%)Total 38,956 MW

*TPO = Thermal Power Office

○Generating Capacity


TEPCO Overseas IPP Plants

U.A.E.Umm Al Nar Power : 2257MW

Water : 65,000t/dTaiwan

Chang-Bin (GTCC) : 490MWFong-Der (GTCC) : 980MWStar-Buck (GTCC) : 490MW

Viet NamPhu-my2-2 (GTCC) : 715MW

IndonesiaPaiton1 (Coal) : 1,230MWPaiton3 (Coal) : 815MW (COD 2012)

AustraliaLoy Yang-A (Coal) : 2,195MW

the PhilippinesPagbilao (Coal) : 735MWSual (Coal) : 1,218MWIlijan (GTCC) : 1,251MW

Thai (EGCO)GTCC : 2,742MWLNG : 824MWCoal : 1,434MW(SPP : 512MW)(Overseas : 1,754MW)

TotalTotal16,000MW (gross) 16,000MW (gross)

3,360MW (net)3,360MW (net)


Organization Chart

Chairman

Thermal Power Department

East Thermal Power Office

Thermal Power Plant Engineering Center

Thermal Power Plant O&M Training Center

…..

HQ

BO

5 Thermal Power Stations

West Thermal Power Office

Central Thermal Power Office



President


-- Part 3 Part 3 --Characteristics of TEPCOCharacteristics of TEPCO’’ssThermal Power GenerationThermal Power Generation


A. Contribution to “Best Mix” Power Generation

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

1973 1975 1985 1995 2000 2005 2007 2008 2009 2010

FY

NuclearCoalOil

Other GasesLNG, LPG

GeothermalNew Energy etc,Hydro

19851985～～1,100 1,100 degdeg--CC

CCCC

19961996～～1,300 1,300 degdeg--CC

ACCACC

20072007～～1,500 1,500 degdeg--CC

MACCMACC

1970～Introduction of LNGLNG


Increase in gas consumptionOil-fired : 72% (1973) → 26% (1985)Gas-fired: 9% (1973) → 26% (1985)


B. TPG as Middle & Peak Power Supply



C. Thermal Efficiency Trend

LHV Combined CycleCombined CyclePower PlantsPower Plants

19851985～～1,100 1,100 degdeg--CCCombined CycleCombined Cycle(CC)(CC)

19961996～～1,300 1,300 degdeg--CCAAdvanceddvanced CCCC(ACC)(ACC)

20072007～～1,500 1,500 degdeg--CCMore Advanced CCMore Advanced CC(MACC)(MACC)

Steam Steam Power PlantsPower Plants

Source : TEPCO Environment Highlights 2009

1,1,6600 deg00 deg--CCMACC IIMACC II


Typical TEPCO’s CC

1,300℃


D. Addressing Environmental Issues

Example of air pollution countermeasuresat a thermal power plant



Hitachinaka Power Station

(Coal-fired)

Turbine

Boiler

Fuel Gas Denitrification

Facility

Electrostatic Precipitator

Fuel Gas Desulphurization

Facility



Source : TEPCO Environment Highlights 2009



1. Shells

2. Used Generator Brush

FertilizerIntermediate treatment

Shells in the water intake

Used generator brush

Graphite particle Extra lead

- Examples of waste recycling -


PDCA Cycle for PDCA Cycle for Thermal Power Plant Thermal Power Plant

OperationOperation && MaintenanceMaintenance

November 20November 201111Thermal Power Plant Thermal Power Plant

Engineering Center, TEPCOEngineering Center, TEPCO


AgendaAgenda

1. Plant Operation

2. Daily Maintenance

3. Periodic Inspection Program

4. Plant Engineering and Plant Diagnosis

5. Maintenance Plan and Budget

6. Work Preparation / Implementation / Commissioning


Plant OperationPlant Operation

• Monitoring critical parameters

• Site inspection

• Standard operation procedure

• Thermal efficiency / condition monitoring


Daily MaintenanceDaily Maintenance

• Daily maintenance standards

Preventive maintenance

– Time based

– Condition based

Maintenance Maintenance Maintenance Maintenance

MaintenanceMaintenance

PlantOperation

1week 1week 1week 1week

2weeks2weeks

A' equipment

B' equipment


Periodic Inspection Program Periodic Inspection Program

• The electricity utilities industry law

• Voluntary preservation of safety

• Safety rule

• Principles and manuals on periodic inspection

• Scope, interval for each equipment and their reasons

2years 2years 2years 2years

?years

Inspection Inspection Inspection Inspection

PlantOperation

Major Inspection Based on… ‐ law ‐ rule ‐ manuals ‐ Principle

PlantOperation Trouble !

If no maintenance...


What is PWhat is P--DD--CC--A Cycle?A Cycle?

Plan

Do

Check

ActionThermal

Power PlantMaintenance


Plant Diagnosis Plant Diagnosis

• Plant failures in own plant/ other plant

• Results of previous inspection

• Results of plant life assessment

• Operational history / date

• Results of condition monitoring

• OEM information / recommendation

• Changes of laws/ regulations

• New technologiesPlan

Do

Check

ActionThermal



Plant Engineering and Plant DiagnosisPlant Engineering and Plant Diagnosis

• Critical part of the maintenance PDCA cycle

Plant Diagnosis Procedure– Check engineering information / site condition

– Carry out hazard identification and risk assessment

– Discuss most appropriate action ;

when, where, what, how, who, why and how much

– Prepare plant diagnosis report

– Authorization

– To be followed by maintenance work plan Plan

Do

Check

ThermalPower PlantMaintenance

Action


Maintenance Plan / Annual BudgetMaintenance Plan / Annual Budget

• Prioritize all the maintenance work plan to meet budget guideline on – Thermal power plant– Thermal power office– Thermal power department

• Build up 5-year maintenance plan – Outage schedule – Optimized maintenance works

• Set up annual budget

• Design of inspection / repair / modification work Do

Check

ActionThermal


Plan


Preparation of Maintenance WorkPreparation of Maintenance Work

• To manage safety, schedule and quality of work

• Preparation by TEPCO operation / maintenance team and contractors through close communication

• Hazard identification and risk assessment

Plan

Check

ActionThermal


Do


Implementation of Maintenance WorkImplementation of Maintenance Work

• Daily and weekly meeting

• Change of schedule

• Supervise– Isolation

– Work and plant conditions

– Inspection data

• Commissioning– Data to be checked carefully

Plan

Check

ActionThermal


Do


What we learned about maintenance PDCA?What we learned about maintenance PDCA?

Safety is always the first priority in our business

Diligent operation, daily maintenance and periodic inspection, complying with standard procedure, are fundamental

Plant engineering and plant diagnosis are key steps for maintenance PDCA cycle – Plant diagnosis report is the key document

Careful design and preparation are important for successful maintenance work

Communication between operations, maintenance and contractors is indispensable for work preparation, implementation and commissioning

Management ofManagement ofEquipment FailureEquipment Failure andand

Human ErrorHuman Error

November 2011Thermal Power Department

TEPCO


1. What is Trouble Data Base＜PURPOSE＞To reduce unplanned-shutdown and to improve the quality of daily work by developing preventive measures through information sharing of troubles occurred at thermal power stations.

＜Basic Principle＞We consider equipment failures and human errors as good opportunities for improvement.

Trouble Data Base (DB)

・Trouble which affected power output・Trouble which extended planned maintenance duration・Trouble which led to severe disasters

(e.g. Fire, Oil leakage)・Trouble caused by human error

＜Troubles to be controlled＞

Analysis

Utilization of the DB

・Deploy preventive measures to other power plants by:- issuance of Technical Information Letters,- revision of maintenance manuals, etc.

・Reflect to design of new power plants

・To promptly send trouble information・To share information without boundaries・To carry out preventive measures promptly


Method of

Information

Sharing

【TP Department/Office】--everyday--・Reporting troubles・Conducting supplemental investigations

and developing countermeasures ・Judging application to similar

equipment

2. Utilizing Trouble Data Base

【TP Station】--everyday--・Reporting troubles・Root cause analysis・Execution of temporally and

permanent countermeasure

TP StationTP OfficeTP DepartmentTrouble occurrence

Input trouble informationoccurred at other companies

Measures

Completion

Judgment of applicationto similar equipment

Application to similar equipment

Data input

Trouble ＤＢ

Analysis of troubles

Every1 year

Instruct all TP Offices/Stations（by Campaign）

Judgment of applicationto similar equipment

Application to similar equipment

Select priority issues


Others

BreakdownMaintenance

Deterioration

Design

MaintenanceWork

ManualOperation

Troubles related to human factor

Troubles related to equipment

• Analyze human factors not only for operation but also for maintenance.

• Decrease unplanned shutdown from the view of “What we should have done.“

TP Department analyzes the equipment failures every 1 year from the view point of “What we should have done to minimize or prevent the trouble.“ In addition, in order to further decrease such troubles, we prioritize the troubles and focus on certain incidents. The result is shared among all power plants and take certain actions.

- To revise maintenance manuals

-To carry out periodic meeting with maintenance companies to share information and thorough prevention of trouble reoccurrence

- To apply countermeasures to similar equipment and determine the scope of inspection using the Trouble DB

- To reflect to plants under construction

Maintenance Management

3. Failure Analysis

Not predictable


4. Measures against Human ErrorIn case a human error incident occurs, thorough analysis and development of recurrence prevention measures are necessary to prevent recurrence. TV conference is used to confirm and share its background and to exchange opinions among all related parties.

Occurrence of Human Error

TV conference : after 1 week passed(temporary countermeasure)

TV conference : after 1 month passed)(permanent countermeasure)

TP StationTP OfficeTP Department

Trouble ＤＢ

Temporary Measures

Completion

Judge necessity of application to other plants

Application to other plants

Judge necessity of application to other plants

Application to other plants

Permanent Measures

Appendix

Study for Updating Syrian Electricity Sector in Syrian Arab Republic (Draft Final Report)

B―1

1. Basic Design of Thermal Power Plants

1.1 Basic Design of Thermal Power Plants

When constructing new thermal power plants, it will be necessary to conduct ample

examination on the installation sites, generating capacity, funds and environmental issues, etc.

Figure b-1 shows the examination flow, while Table b-1 shows the results of examination and

recommendations.


Figure b-1 Examination Flow

Examination Flow

Confirmation of macro

Environmental trends

Politics

Economy

Technology

Resources

and energy

Population

statistics

Energy and Electric

Power Sector

Demand forecast

Power source

Network system

Electricity tariff system

Fundraising

Securing of energy

Environmental and social

consideration

Stable and economic

provision of energy

(electricity) to the

Syrian people

Best matching of

primary resources

Appropriate

power

development plans

Power sector

master plan

review

Appendix


B―2

Table b-1 Examination Results and Recommendations

Item Examination Results Recommendations

Demand

forecast

Power demand growth rate: 4.6

percent between 2010~2030

Improvement of 20 percent in the

energy saving rate in industry,

commerce and the public sectors

GDP elasticity of demand:

Reduction from 1.4 to 0.9

Increase in share of the industrial

sector and commercial sector: 34

percent (2030)

Energy saving plans in the industry,

commerce and the public sectors

Building of the natural gas and coal supply

systems

Reduction of distribution losses and

building of statistics in the electric power

sector

Improvement in legal efficiency of devices

used in traffic agencies (especially

automobiles) and the domestic sector

Power

development

evaluation

Reflection in abolishment of

equipment, etc. in line with

deterioration

Estimation of supply shortage at

time of peak demand in 2012

GCC, etc. between 2012~2014

Improvement at 2,000 MW

Development of 12,200 MW

required between 2021~2030

Development of gas turbine and

pumped-storage hydroelectric power

equivalent to 10 percent of plant capacity

Development of coal thermal power

Development of renewable energy

Transmission

network

system

Confirm that the power

transmission network system is

almost integral without serious

problems.

Make the maximum possible efforts to

maintain the local supply-demand balance

in future as well

Separation of operation between 230 kV

and 400 kV systems

Increase transmission capacity of the

transmission lines

Electricity

tariff system,

Disparity in timing of fuel price

hikes and tariff hikes

Revision of electricity tariffs that

are low in international terms

Price difference between imported

gas and domestically produced gas

(see below)

Cost cutting among electric utility operators

Revision of electricity tariffs (weighted

mean of imported natural gas and domestic

natural gas)

Improvement of the time zone-based

electricity tariff system

Appendix


B―3

Fundraising

for power

source

development

Deterioration in supply spare

capacity

Development of a total of 16,000

MW of power sources between

2016~2030

Increase in own funds

Utilization of international ODS funds (not

applicable to coal-fired thermal power)

Utilization of private capital (IPP, BOT,

BOOT)

Diversification of fundraising sources based

on PEEGT privatization and splitting

Also, utilization of low-interest funds

(funds from Arabian countries)

Energy

securing

Reduction in production of crude

oil

85 percent of gas is for power

generation, the remainder is

consumed domestically.

Ongoing import of gas + new

imports (Egypt, Iran, Iraq, etc.)

Energy best mix

Diversification of energy supply sources

Early implementation of renewable energy

projects

Encouragement of the early development

and utilization of confirmed reserves of

shale gas

Discussions on securing energy with

neighboring countries

Cooperation with construction of crude oil

and gas pipelines that can contribute to the

international community

Environmental

and social

consideration

Environmental standards exist but

they are not an important factor.

Formulation and implementation of

internationally acceptable EIA System and

environmental standards

Renewable

energy

Abundant resources (solar power,

wind power)

Start on small-scale projects

Continuation of sustained and phased

development

International cooperation (Japan,

surrounding countries, Europe)


＊In future, if imports of gas increase, price disparities with domestic gas will become a

problem. Particularly concerning gas-fired power generation, since the generating cost more

than doubles between using imported gas and domestic gas, it will be necessary to place the

burden on consumers through applying a weighted average. Such work will be carried out by

the Power Regulatory Authority, and this function will become more important in the future.

Figure b-2 shows the priority implementation items in the next plan.

Appendix


B―4


Figure b-2 Priority Implementation Items in the Next Plan

Priority Implementation Items in the Next Plan

b. Best mix of energy

Reexamination Items Important enforcement Items

b. Development of coal thermal power c. development renewable energy

a. Increased in own funds

b. Utilization of international ODA funds

c. Utilization of private capital (IPP)

a. Cost cutting among electric utility operators

b. Revision of electricity tariffs

c. Improvement of the time zone based Electricity tariff system

Review of demand forecast

Power sources development plan

a. Development of gas turbine and pumped storage hydroelectric power

Electricity tariff system

d. Diversification of fundraising sources based on PEEGT privatization and splitting

Fundraising

e. Encouragement of the early development and utilization of confirmed reserves of shale gas

f. Discussion on securing energy with

neighboring countries

Renewable energy

c. Improvement in legal efficiency of devices used in traffic modes (especially

automobiles) and the domestic sector

a. continuation of sustained and phased development

b. International cooperation (Japan, surrounding countries, Europe)

a. Energy saving plans in the industry, commerce and the public sectors

b. Reduction of distribution losses and building of statistics in the electric power sector

Energy Saving Securing of energy

a. Building of the natural gas and coal supplysystems

c. Diversification of energy supply sources

d. Early implementation of renewable energy projects

a. Compilation of internationally acceptable Syrian environmental evaluation criteria

a. Boosting of transmission lines in case where

The future balance cannot be maintained b. separation of operation between 230kv and

400kv systems

Environmental and social consideration Transmission network system

Appendix


B―5

1.2 Basic Design of Combined Cycle Thermal Power Plant

1.2.1 Outline of Plans

The combined cycle power plant (CCPP) is planned as a high-efficiency multiaxial CCPP

comprising one F-type gas turbine generator (GT), one exhaust heat recovery boiler (HRSG), one

steam turbine generator and related instruments and possessing net output of 360 MW. For the

steam turbine condenser cooling equipment, a naturally ventilated cooling tower will be adopted.

1.2.2 Operation of Power Generating Equipment

(1) Outline

The main and auxiliary power generating equipment will be designed to have no problems when

startup and stopping and in ordinary operation throughout the service life of the equipment. The

auxiliary unit will be given ample redundancy to ensure that there is a high degree of reliability.

The main and auxiliary power generating equipment will be designed so that operation from

startup to rated load can be performed from the keyboard panel with mouse.

(2) Generating equipment operation plan

Generating equipment that can secure high efficiency and high reliability based on proven and

sophisticated technology will be adopted. In the generating equipment design, equipment shall be

able to withstand the operating plan prescribed in the basic design. Moreover, the annual average

operating factor must not fall below the figure of 86.8 percent that is defined in

ISO3977-9:1999(E) (Gas Turbine Procurement) Part 9 (Reliability, Operating Factor, Ease of

Maintenance, Safety).

(a) Schedule requirements for startup time

Startup time will be shortened as much as possible to enable responsiveness to the generating

equipment functions. The generating equipment will be designed to satisfy the startup times

indicated in the following table. Startup time is defined as the time required from selecting the

startup phase to establishment of condenser vacuum, HRSG startup, GT startup, and attainment of

the rated load state after going into parallel operation. The GT air purge and parallel time are

omitted.

Appendix


B―6

Table b-2 Startup Time Schedule

Startup Process Time (minutes)

Cold startup following stoppage of 36

hours or longer Max. 240 minutes

Warm startup following stoppage of less

than 36 hours Max. 180 minutes

Hot startup following stoppage of less

than 8 hours Max. 120 minutes

Very hot startup following stoppage of

less than 1 hour Max. 60 minutes


(b) Operation service life

The main and auxiliary power generating equipment will be designed and constructed based on the

following operation service life:

Operation service life = 30 years

Operation service hours = 183,960 hours at rated load (equipment utilization factor 70 percent)

The generating equipment will be designed so that it can be operated continuously for at least

6,132 hours at rated load.

Incidentally, the times required in the startup and stopping processes are not included in the above

operation time. The main and auxiliary power generating equipment will be continuously operated

with high efficiency, reliability and economy during the operation service life. Concerning

equipment in which there is a possibility that the operation service life will drop below the above

value, it will be designed with consideration given to ease of replacement and maintenance.

(3) Startup and stop times

Starting and stopping of generating equipment will be carried out automatically from the

central control room. The generating equipment will have monitoring and control functions in

order to enable safe, reliable and efficient operation.

It will be possible to carry out parallel and load change operation of the generating equipment

from the central control room. It is assumed that the generating equipment can be operated at

rated load while maintaining high efficiency and reliability over the warranty period of 30

years. The aforementioned conditions are designed based on the annual startup frequency

indicated below.

Appendix


B―7

Table b-3 Startup Frequency

Startup process Number of

startups per

year

Number of startups

over the warranty

period

Cold startup (following stoppage of

36 hours or longer)

2 60

Warm startup (following stoppage of

less than 36 hours)

5 150

Hot startup (following stoppage of

less than 8 hours)

30 900

Very hot startup (following stoppage

of less than 1 hour)

5 150

Total 42 1,260


A turbine bypass system will be attached to the steam turbine system in order to enhance

operating reliability at startup times, load change times, stop times and in emergencies.

1.2.3 Outline of Generating Equipment Control

(1) Scope of automation

In order to enable the operators to monitor and control the generating equipment from the

central control room, the equipment start/stop control and protection functions will be totally

automated. However, manually operated break points will be included as necessary in the

start/stop control sequence. Startup operation can be selected and automatically controlled

according to each startup condition, i.e. very hot, hot, warm and cold.

(2) Generating equipment operation

The central control room will be equipped with the latest DCS (distributed control system)

including data log system with automatic control of generating output in order to enable

demand to be satisfied. An operator’s console equipped with LCD (liquid crystal displays) for

monitoring operation conditions and a keyboard panel with mouse for operating the generating

equipment will be installed in the central control room. LCD control will be adopted in order

to simplify the interface between humans and machines and enhance the monitoring and

control and operating reliability of generating equipment. A standby redundant system

comprising a dual structure will be adopted for the central processing unit (CPU) in order to

Appendix


B―8

secure reliability of the control system. Moreover, parallel and parallel-off operation based on

the generator circuit breaker will be conducted from the central control room.

(3) Operation during high and low system frequency

The GT generator and ST generator are designed to withstand continuous operation under

conditions of system frequency fluctuation of 48.5~51.5 Hz during load operation. Moreover,

loaded operation at low frequency of 46.5~48.5 Hz shall be possible on condition of limited

operating time. The control device required for loaded operation will be designed upon

considering the power system conditions.

(4) Vibration value control

In rated load operation from GT startup, the shaft vibration value of the GT and GT generator

and ST and ST generator will be limited. ISO7919 or an appropriate standard will be followed

regarding the method for measuring shaft vibration. In the bearings of the GT/ST shafts, the

unfiltered comparative shaft oscillation displacement will be measured as the vibration value.

Concerning control of the vibration value during operation, as is shown in the following table,

ISO7919-2:2001(E) part 2 (Large land stead turbine generator set) and ISO7919-4:1996(E)

part 4 (Gas turbine set) will be followed.

Table b-4 Vibration Control Values

Equipment Vibration Value

(p-p μm)

Gas turbine and gas turbine generator 80 μm or less

Steam turbine and steam turbine generator 80 μm or less


The shaft vibration value in GT and GT generator and ST and ST generator must not exceed

80 μm in reliability testing. If the vibration value in any of these units exceeds this value

during two weeks of reliability testing, the testing will be suspended, countermeasures will be

taken and a new reliability test will be conducted for another two weeks. The vibration value

shall not exceed 80 μm during the defect liability period following receipt of the generating

equipment. The vibration value shall be adjusted so that it doesn’t go higher than 120 μm in

the GT and GT generator and ST and ST generator. In cases deemed permissible based on

operating experience of similar type GT and GT generator and ST and ST generator, the trip

value may be set at 240μm.

Appendix


B―9

(5) Load control

The power load of generating equipment is requested to the generating equipment from the

central dispatch room based on the SCADA system. After the operator sets the power demand

of generating equipment by the DCS via the operator’s console to ensure that the demand on

power load in the generating equipment is satisfied, the generating equipment will be

automatically operated.

1.2.4 Examination of Basic Technical Issues

(1) Selection of CCPP model

On the international market, there are four models of combined cycle power generating

equipment (CCPP) composed of a 50 Hz large capacity gas turbine model in which the turbine

inlet temperature is at the F-class level. These CCPPs, which are based on abundant operating

experience, are F-class gas turbines by four manufacturing companies (OEM). According to

the Gas Turbine World 2007-2008 GTW Hand book, these four models are as follows.

GT OEM maker CCPP model No.

Alstom KA26-1 AQC

GE S109FA, S109FB

Mitsubishi Heavy Industries MPCPI (M701F)

Siemens SCC5-4000F 1x1

Alstom can supply two types of gas turbine. One of these is equipped with an air-based cold

air cooling device, and the other has a steam-based cold air cooling device. Steam is used to

cool the air that is extracted from the air compressor used for cooling the hot parts of the gas

turbine, and the equipment cannot be operated without the steam media.

(2) Rated and maximum capacity performance

Utilizing the performance particulars under gas turbine ISO conditions that are stated in the

GTW Handbook, the performance of each CCPP model is indicated in the following table.

Appendix


B―10

Table b-5 Gas Turbine Model Performance

Gas turbine model GT26(AQC) PG9371(FA) M701F4 SGT5-4000F

ISO base rating (MW) 288.3 255.6 312.1 286.6

Efficiency (%) 38.1 36.9 39.3 39.5

Pressure ratio 33.9 17.0 18.0 17.9

Air flow (kg/s) 648.6 640.9 702.6 689.4

Exhaust air

temperature (℃)

616.1 602.2 596.7 577.2

Fuel gas flow (kg/s) 15.4 14.09 16.16 14.76


The equipment capacity of the plant generating equipment and auxiliary units needs to be

determined according to the maximum operating capacity of the gas turbine and the

corresponding capacity of bottoming equipment (HRSG and steam turbine). The maximum

operating capacity of the gas turbine differs greatly depending on the air temperature.

Therefore, in order to decide the equipment capacity of the plant generating equipment and

auxiliary units, it is necessary to determine the site atmospheric conditions that define the

maximum operating capacity of the gas turbine. Providing that the maximum operating

capacity of the gas turbine is within the design permissible maximum capacity, it will increase

in line with the atmospheric temperature. The atmospheric temperature at which the gas

turbine reaches the design permissible maximum capacity is usually given as minus 10� or

less, although this depends on the design philosophy of the maker.

The cycle composition and parameters of the CCPP bottoming system differ according to the

design philosophy of the maker, however, the case of a similar CCPP is indicated below.

GT inlet air cooling equipment: Not used

GT outlet exhaust air gas leakage: 0.5percent

Cycle composition: Triple pressure, reheating

Cooling equipment: Mechanical ventilated cooling tower

HRSG type: Non-supporting system

HP steam conditions: Temperature 560℃ , pressure 11.8Mpa

IP steam conditions: Temperature 560℃ , pressure 2.94Mpa

LP steam conditions: Temperature LP SH and IPT outlet steam mixing temperature,

pressure 0.34 Mpa

Appendix


B―11

(3) The following table shows rough performance of the four CCPPs under conditions of no

supporting combustion.

Table b-6 CCPP Model Performance

CCPP model KA26-1 S109FA M701F SCC5

Rated Max. Rated Max. Rated Max. Rated Max.

Total generating

output (MW)

374.7 433.5 344.9 396.3 403.9 465.0 365.6 421.1

Gas turbine (MW) 245.5 288.7 221.8 260.8 270.5 318.1 244.1 287.0

Steam turbine

(MW)

129.2 144.8 123.1 135.5 133.4 146.9 121.5 134.1

Total thermal

efficiency (%)

54.8 56.6 54.6 56.0 55.8 57.3 55.8 57.3

Auxiliary power

(MW)

12.4 14.2 9.9 11.4 11.6 13.4 10.5 12.1

Net generation

output (MW)

362.3 419.3 335.0 384.9 392.2 451.6 355.1 409.0

Net thermal

efficiency (%)

53.0 54.7 53.0 54.4 54.2 55.6 54.2 55.7


1.2.5 Optimization of Bottoming Cycle

(1) Examination contents

Combined cycle power generation entails combining differing thermal cycles in the high

temperature zone and low temperature zone. In the high temperature zone thermal cycle, the

Brayton cycle (gas turbine cycle), in which the combustion heat of fuel is used as the heat source,

is used, while in the low temperature thermal cycle, the Rankine cycle (steam cycle), in which the

excess heat of combustion exhaust gas (that is the operating media in the high temperature thermal

cycle) is used as the heat source, is used. These two cycles are incorporated into a combined

engine in which the operating temperature range is extended to include the low temperature zone

and thus improve the overall thermal efficiency.

The performance and construction cost in combined cycle power generation differs according to

the way in which the bottoming cycle (steam cycle) is designed with respect to the given topping

cycle (gas turbine cycle). Generally speaking, if the bottoming cycle becomes complicated, the

performance and construction cost of combined cycle power generation will become higher. In the

case of combined cycle power generation based on T-type gas turbine, three types of bottoming

Appendix


B―12

cycle can be considered, i.e. triple pressure reheating type, triple pressure non-reheating type, and

double pressure non-reheating type. Concerning performance, since the topping cycle incoming

heat is similar, this corresponds to the difference in generating output. The disparity in power

generating output is the disparity in the amount of sold power during operation. The triple

pressure reheating type has higher performance than the triple pressure non-reheating type and

double pressure non-reheating type. On the other hand, construction cost is higher in the triple

pressure reheating type than in the triple pressure non-reheating type and double pressure

non-reheating type. Accordingly, it can be evaluated whether the disparity in construction cost

between these three bottoming cycles can be complemented through differences in the present

value of revenue from power sales during the operating period.

(2) Examination criteria

(a) Performance conditions

Gas turbine model: Siemens SCC5-4000F

With or without reheating burner: None

Atmospheric temperature: 35℃

Atmospheric pressure: 0.1013Mpa

Cooling water temperature (condenser inlet): 26.7℃

Fuel type: Natural gas

Lower heating value 50,011kj/kg

(b) Economic conditions

Operating period 30 years

Utilization factor 70 percent

Annual operating time 6,132 hours

Load factor 100 percent

First year power sale price 3.2 US cents/kwh

Discount rate 8percent

(c) Performance

The following table indicates the performance of the triple pressure reheating type, triple pressure

non-reheating type and double pressure non-reheating type.

Appendix


B―13

Table b-7 Bottoming Cycle Performance

Triple pressure

reheating type

Triple pressure

non-reheating

type

Double pressure

non-reheating

type

Gas turbine total output

(MW)

244.1 244.1 244.1

Steam turbine total

output (MW)

121.5 116.3 114.3

Total gross output (MW) 365.6 360.4 358.4

Total generating

efficiency (%)

55.8 55.0 54.7


Under the same incoming heat conditions, total output in the case of the triple pressure reheating

type is 5,200 kW higher than in the triple pressure non-reheating type and 7,200 kW higher than in

the double pressure non-reheating type. Moreover, annual generated electric energy in the case of

the triple pressure reheating type is 31.9 million kwh higher than in the triple pressure

non-reheating type and 44.2 million kwh higher than in the double pressure non-reheating type.

(d) Disparity in construction cost

The following table shows the construction cost in each type of system.

Appendix


B―14

Table b-8 Bottoming Cycle Construction Cost

Unit: US$ 1,000

Item

Triple pressure

reheating type

Triple pressure

non-reheating

type

Double pressure

non-reheating

type

1. Generator and installation cost

and parts procured overseas (FOB

price)

a) Gas turbine and accessories 84,865 84,865 84,865

b) HRSG and accessories 36,419 34,952 34,242

c) Steam turbine and accessories 42,216 40,515 36,692

d) Bottoming cycle equipment 66,958 64,261 62,957

e) Electrical equipment and

instrumentation and control

equipment

45,750 43,906 43,015

2. Overseas transportation and

insurance

7,312 7,018 6,876

3. Domestic transportation and

insurance

3,659 3,511 3,440

4. Construction, trial operation and

insurance

73,093 70,148 68,724

5. Construction cost (excluding

power plant, transmission line, tax

and contingency costs)

360,272 349,176 343,811

Construction cost disparity with the

triple pressure reheating type

0 11,095 16,461


(e) Conclusion

From the above table it can be gathered that the disparity in the present value of power sales

revenue during the operating period is larger than the disparity in construction cost. This indicates

that the triple pressure reheating type is more economical than the triple pressure non-reheating

type and the double pressure non-reheating type.

Appendix


B―15

1.2.6 Exhaust Gas Turbine Equipment

In multiaxial CCPP systems, exhaust gas turbine equipment is usually equipped in order to

enable simple cycle operation in the event where some kind of trouble arises in the bottoming

cycle. This equipment is needed when the power supply is tight and it is necessary to conduct the

commercial operation of gas turbine generating equipment (topping cycle) before the bottoming

cycle. For this reason, it is necessary to install a bypass stack and damper within the high

temperature gas flow in between the gas turbine exhaust system and waste heat recovery boiler

(HRSG). These equipment items comprise a giant mechanical unit that can withstand high

temperatures of up to 650℃; therefore, there is a possibility that operability of the generating

equipment will be reduced. In addition, there is a risk that partial leakage of gas turbine exhaust

gases into the atmosphere will lead to performance losses.

(1) Operating flexibility

The operating flexibility of the CCPP differs according to whether or not there is bypass

equipment for the exhaust gas. If there is such equipment, in the event where a problem arises in

the bottoming cycle, the system can switch to simple cycle operation without interruption.

However, depending on the type of trouble that occurs in the bottoming cycle, there may be cases

where the generating equipment needs to be stopped. For example, if a problem occurs only in the

steam turbine part, since all the generated steam is discharged into the condenser via the steam

turbine bypass line, the generating equipment can continue operation through the simple cycle.

However, since this type of operation is not viewed as normal, it should be limited to certain times

only. Even so, there is no doubt that operating flexibility can be expanded through installing

exhaust gas bypass equipment. Concerning the startup performance of power generating

equipment, in the case where exhaust gas bypass equipment is installed, high temperature steam

can be quickly generated, warming of the steam turbine is speeded up and the startup time can be

slightly shortened compared to the case where there is no exhaust gas bypass equipment.

(2) Operating reliability

In gas turbine equipment that includes HRSG, a conventional diverter or flapper type damper is

used. Dampers used in F-type gas turbines are very large with dimensions of 7 m x 7 m.

Meanwhile, exhaust gases that are exposed to the damper reach high temperatures of 650℃ . The

damper is designed to operate stably, smoothly and rapidly and with minimum losses from gas

leaks during the service life of the generating equipment. It is very difficult to design the damper

to operate under such harsh conditions in a manner that completely satisfies these contradictory

requirements. This is because the massive metal damper that is exposed to very hot gases cannot

maintain its original dimensions and shape over the service life of the generating equipment. No

Appendix


B―16

specific figures concerning the operating reliability of exhaust gas bypass equipment has been

provided by power plant users, however, it is inevitable that operating reliability of the entire

power generating system will decline if this equipment is adopted.

(3) Cost impacts

Adopting the exhaust gas bypass equipment will additionally entail the following equipment

and works:

- Bypass stack fitted with silencer (top diameter 7.5 m, height 45 m)

- Diverter damper

- Guillotine damper (for maintenance of the bottoming cycle during simple cycle

operation)

- Gas damper and expansion joint

- Associated site assembly, installation and civil engineering works

- Other related costs

It is estimated that the above items will incur an additional cost of US$6.4 million.

(4) Phased construction

Through adopting exhaust gas bypass equipment, it becomes possible to conduct the phased

construction of the topping and bottoming cycles. Such phased construction is adopted in cases

where the power supply situation is tight and it is necessary to achieve power supply at an early

stage. The total works period of phased construction is longer than the case of simultaneous

construction, however, the start of commercial operation of the gas turbine generating equipment,

which constitutes the topping cycle, is speeded up by approximately six months. This advantage is

evaluated by the purchaser of the generating equipment according to the degree of necessity for

early power supply.

(5) Other perspectives

In the case of an F-type gas turbine in which wider installation space is required for the bypass

equipment, the system becomes approximately 15 meters longer in the axial direction. If the

bypass stack is not equipped with a silencer, there is concern over noise from the stack even if

bypass operation is limited to a short time.

There is concern over whether or not the silencer, which is exposed to high temperature and high

speed gases, can sustain sure and appropriate functions over the service life of the power

generating equipment. Since the exhaust gas bypass equipment is not used all the time, this is all

the more reason to conduct careful routine maintenance to ensure that it can be used normally in

emergencies.

Appendix


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(6) Summarization of examination

As was mentioned above, adoption of the exhaust gas bypass equipment of course enhanced the

operating flexibility of generating equipment, however, this inevitably leads to decline in

operating reliability and increase in project costs.

1.2.7 Auxiliary Steam Boiler

(1) Necessity

In a multiaxial CCPP with no auxiliary steam boiler, it is necessary to simultaneously start up the

gas turbine and HRSG. If it becomes possible to supply the steam that is required for starting the

HRSG, gland sealing of the steam turbine and so on is completed, however, oxygen concentration

in feed water at the HRSG inlet during startup time becomes higher than the concentration during

operation. In the multiaxial CCPP equipped with auxiliary steam boiler, the steam required for

gland sealing of the steam turbine is supplied from the auxiliary steam boiler before the generating

equipment is started up. Compared to the multiaxial CCPP with no auxiliary steam boiler, the

HRSG and steam turbine can be started without waiting for steam from the HRSG and the oxygen

concentration in feed water at the HRSG inlet during startup time is the same as the concentration

during operation.

(2) Examination items

It is necessary to start up the HRSG and accessories in the shortest time in the case of both gas

turbine individual operation and combined cycle operation. In the case where the auxiliary steam

boiler is not applied, it is necessary to ascertain the startup procedure, startup time, oxygen

concentration in feed water at the HRSG inlet during startup and permissible oxygen concentration

in feed water at the HRSG inlet in this case.

1.2.8 Standards and Criteria

(1) Machinery, electricity and control units

Excluding specially requested items, equipment shall be designed according to the following

international criteria and standards.

Japanese Industrial Standards (JIS)

U.S. standards (ASME, ASTM, etc.)

IEC standards

ISO standards

British standard (BS)

German standards (DIN)

Appendix


B―18

1.2.9 Environment

(1) Concentrations of air pollutant emissions shall be planned not to exceed the following

levels over the range of 75~100percent output.

Table b-9 Limit Values on Concentration of Air Pollutant Emissions

Pollutant Emission concentration limit value

Gas No more than 40

ppmv NOx

Light oil No more than 100

ppmv

Gas No more than 20

ppmv CO

Light oil No more than 50

ppmv

Gas 10mg/m3N Particulates

Light oil 10mg/m3N

SO2 Light oil No more than

200ppmv


(2) Noise

The noise level of all operating equipment during regular operation will be planned no higher than

85 db (A) at a distance of 1 meter (height of 1 meter) from the edge of the equipment or enclosure.

Moreover, at the site perimeter, the noise level shall be planned to exceed no more than 70 db (A).

Noise measurement and testing will be carried out according to ANSI B133.8. Also, noise

proofing equipment such as silencers and soundproof walls will be installed in order to conform to

the noise standards.

Table b-10 Noise Standard

Maximum noise

level

Distance of 1 meter (height of 1 meter) from the edge

of the equipment or enclosure

No more than

85db(A)

Site perimeter No more than

70db(A)


Appendix


B―19

1.2.10 Gas Turbine

The gas turbine is usually operated on natural gas, however, in the event where natural gas is

in short supply, equipment will be equipped with the function to enable operation on diesel oil

equivalent to No. 2 GT oil as designated in ASTM D 2880. In the case where it is operated on

the designated natural gas over the range of 75~100 percent load, the gas turbine shall have a

sophisticated design satisfying the NOx emission requirement of less than 40 ppm (15 percent

O2 dry volume standard) with no injection of steam or water under all atmospheric

temperature conditions. Moreover, in the case of operation on diesel oil, it shall be possible to

inject pure water and operate while satisfying the NOx emission requirement of less than 100

ppm (15 percent O2 dry volume standard).

The gas turbine must be designed and verified according to the design criteria of the

manufacturer (OEM) upon basically satisfying the ISO21789 Gas Turbine Application-Safety

requirements. In axial design of the gas turbine, the minimum bearing is used on a steel frame

or appropriate steel structure or concrete foundation with sufficient size to withstand

instantaneous maximum transfer torque in the event of either generator shorting or phase

shifting simultaneous operation, whichever one is larger.

1.2.11 HRSG

(1) Circulation method

The HRSG circulation method can either be a natural circulation system or a forced

circulation system. In the natural circulation system, circulating force is secured by means of

the density difference between boiler water in downcast pipes and the steam-water mixture in

the steam generating tubes. In the forced circulation system, circulating force is secured by

forcibly circulating the steam-water mixture from the drum to the steam generating tubes and

from the steam generating tubes. With the forced circulation system, it is possible to conduct

rapid warm or hot startup. In the natural circulation system, since no circulating pump is

required, operating costs entailed in pump breakdowns and maintenance can be economized

on. At times of cold startup, since time is required to increase the temperature of the HRSG

unit and boiler water, there is no difference in startup time between the natural circulation

system and forced circulation system.

1.2.12 Steam Turbine

The steam turbine will be a reheat, triple pressure, two-cylinder or single-cylinder condensing

type directly coupled to the generator. In this, steam is discharged to the surface condenser in

the downward or axial direction and cooled by the circulating water. The circulated water is

cooled in the naturally ventilated cooling tower. Maximum capacity of the steam turbine shall

Appendix


B―20

be enough to accept the steam at the pressure, temperature and flow conditions generated by

the HRSG when the gas turbine is operated under the conditions that exhibit the maximum

capacity. When the steam turbine is operated for the designated period under the designated

conditions, the main components (cylinders and shaft) must be designed so that the level of

life consumption at the end of the operating period does not exceed 75 percent of the

remaining life of the main components.

1.2.13 Fuel Supply Equipment

(1) Fuel gas supply equipment

The gas turbine will be designed so that it can operate using the designated natural gas. The

fuel gas supply equipment will include the step-up compressor, pretreatment equipment and

pressure regulator that are required to conduct the starting, stopping and continuous operation

of the gas turbine. The pretreatment equipment is intended to pretreat the natural gas in order

to enable the gas turbine to be continuously operated.

(2) Fuel oil supply equipment

The gas turbine will be designed so that it can operate using the designated light oil. As with

the fuel supply equipment, the fuel oil supply equipment will be designed so that it is possible

to conduct the starting, stopping and continuous operation of the gas turbine. Concerning how

much emergency light oil needs to be stored, it is estimated that a light oil tank with enough

capacity to hold a seven-day supply of light oil (2,000kl/day x 7 days = 14,000 kl, however,

20,000 kl to be on the safe side) for emergencies in the event of gas equipment breakdown will

be needed.

Appendix


B―21

1.2.14 Water Treatment Apparatus

Process water including pure water, potable water, cleaning water, firefighting water and

miscellaneous water will be manufactured from groundwater using a pretreatment unit.

Groundwater will be directly utilized to provide the makeup water for the cooling tower. Pure

water will be used as HRSG makeup water, auxiliary equipment cooling water, chemical

injection water and for injection to the gas turbine during oil combustion and so forth. The

pretreatment unit will comprise coagulating sedimentation tank and filter, while the pure

water unit will comprise a chemical storage tank and regeneration unit, etc. Moreover, the

question of whether or not to install a pretreatment unit and the specifications of the unit will

be determined by the quality of the groundwater.

1.2.15 Wastewater Treatment Unit

Wastewater comprises HRSG blow water, floor drainage from the gas turbine and steam

turbine house, and neutralized surface wastewater from the transformer area. Domestic

wastewater such as sanitary sewage and toilet wastewater will be treated in a septic tank,

whereas the floor drainage from the gas turbine and steam turbine house and surface

wastewater from the transformer area will be treated in a wastewater treatment unit after

passing through an oil separator.

1.2.16 Firefighting Equipment

(1) Fire safety methods

In order to protect plant employees and equipment from fires and other disasters, the facilities will

be designed and planned so that there is ample space secured between equipment units and

fireproof specifications are adopted in equipment and materials. Risk areas will be configured

separately according to types of hazardous objects and handling methods. In order to protect

equipment, zones and buildings that entail differing methods of operation, it is necessary to install

different types of firefighting equipment. The CCPP firefighting equipment will have enough

capacity to withstand fire for at least two hours (capacity 300 m3, pressure 10 bar) according to

NFPA850. Fire pumps will comprise the following equipment:

- Electric jockey pump, 100 percent capacity: 1 unit

- Main electric pump, 100 percent capacity: 1 unit

- Main diesel pump, 100 percent capacity: 1 unit

The main electric pump will secure the necessary water flow and pressure under the harshest

conditions, while the main diesel pump will be kept on standby to cover in the event where the

main electric pump breaks down. The capacity of the main diesel pump will be the same as

that of the main electric pump.

Appendix


B―22

Table b-11 Protected Areas and Firefighting Equipment

Item Building and Area Firefighting Equipment

１ Gas turbine Carbon dioxide firefighting equipment

２ Steam turbine lubricating oil and

lubricating pump

Powder firefighting equipment

３ Steam turbine bearings Powder firefighting equipment

４ Steam turbine building Stand type equipment

５ Generator, main transformer and

starting transformer

Powder firefighting equipment

６ Oil tank Installation of foam firefighting

equipment and oil fence

７ Control room

Cable treatment room: sprinkler unit

Control room: argon type or similar type

８ Electric equipment and switchgear Water sprinkler or, where necessary,

mobile fire extinguishers

９ Common Protective device for detecting fire or gas

in the control room


(2) Outline of firefighting equipment

Generally, NFPA specifications will be adopted for the CCPP firefighting equipment, however,

the fire control law will also be complied with. Fire extinguishers will be categorized and

arranged according to NFPA10. Moreover, according to NFPA72, building fire detectors,

automatic fire detectors and fire display panel will be installed. The firefighting system will

be designed so as to supply firefighting water for two hours according to NFPA. It will be

necessary to separately design the firefighting water supply system to ensure that firefighting

functions can be maintained even if part of the supply system breaks down.

1.2.17 Electrical Equipment

(1) Electric system

(a) Electric system from the generator to the substation

Electricity generated in the gas turbine generator will be stepped up in the gas turbine step-up

transformer, while electricity generated in the steam turbine generator will be stepped up via the

steam turbine step-up transformer, and the stepped-up electricity will be connected to the

substation for transmission to the external power transmission network. The power source for the

Appendix


B―23

in-station auxiliary power, etc. will be the unit type whereby it is separated from the generator

main circuit during regular operation and power is supplied via the in-station transformer. At

startup time, when the gas turbine generator reaches the rated speed and rated voltage, it will be

connected to the external power transmission network by means of the gas turbine generator

circuit breaker. Next, when the steam turbine generator reaches the rated speed and rated voltage,

it will be connected to the external power transmission network by means of the steam turbine

generator circuit breaker.

(b) Generator main circuit

The system will be composed of the gas turbine generator and steam turbine generator. Each

generator, main transformer, excitation transformer and instrumentation transformer will be

connected to the isolated-phase bus (IPB) and eventually to the external transmission network

after passing through the secondary side generator circuit breaker and generator disconnecting

switch.

(2) Generators

The generator specifications are as indicated below.

Table b-12 Generator Specifications

Type of generator Gas turbine generator Steam turbine generator

Type Three-phase AC

synchronous generator

Three-phase AC

synchronous generator

Number of poles 2 2

Phases 3 3

Capacity 248MVA 131.6MVA

Frequency 50Hz 50Hz

Rotating speed 3.000rpm 3.000rpm

Terminal voltage 16kv 11kv

Power factor 0.8 0.8

Rotor cooling

method

Hydrogen or air Hydrogen or air

Stator cooling

method

Hydrogen or air Hydrogen or air


Appendix


B―24

(3) Generator cooling system

Generator cooling systems for gas turbines and steam turbines will comprise the air cooled

type and the hydrogen gas cooled type. According to IEC conditions, the generator

manufacturer (OEM) will need to have a past record of supplying at least two air cooled

generators and two hydrogen gas cooled generators.

(4) Comparison of generator cooling equipment

Recently, as a result of technological progress in cooling performance and reduction of windage

loss, air-cooled equipment is adopted in generators with output of 300 MVA or more. Compared to

hydrogen gas-cooled equipment, the air-cooled equipment is simpler, entails easier operation and

maintenance and is more cost effective. On the other hand, the hydrogen gas-cooled equipment is

more compact and is more advantageous for transportation and installation.

(5) Excitation method

In each generator, a static thyristor excitation device will adjust the field current and control

voltage at the generator terminals. The thyristor excitation device includes an excitation

transformer, automatic voltage regulator (AVR), thyristor unit and field circuit breaker.

The automatic voltage regulator adopts a generator excitation device for detecting the generator

voltage and controlling reactive power so that the voltage is at the set level.

(6) Transformer

(a) Gas turbine transformer

The gas turbine transformer, which will step up the generator voltage to the transmission voltage

level, will comprise either an oil-insulated three-phase transformer with load tap switcher or four

single-phase transformers (including one for backup), and the oil natural air forced (ONAF)

method will be adopted as the transformer cooling system. The transformer winding method will

be Δ-Y.

(b) Steam turbine transformer

The steam turbine transformer, which will step up the generator voltage to the transmission

voltage level, will comprise either an oil-insulated three-phase transformer with load tap switcher

or four single-phase transformers (including one for backup), and the oil natural air forced

(ONAF) method will be adopted as the transformer cooling system. The transformer winding

method will be Δ-Y.

Appendix


B―25

(c) In-station transformer

The in-station transformer, which will step down the generator voltage to the station level, will

comprise either an oil-insulated three-phase transformer with load tap switcher or four



be Δ-Y.

(d) Startup transformer

The in-station transformer, which will step down the external transmission voltage to the station

level, will comprise either an oil-insulated three-phase transformer with load tap switcher or four



be Y-Y-Δ stable winding. Through adopting the Y-Y-Δ method, it will be easier to detect grounding

failure current. The following table shows the standard specifications of each transformer.

Table b-13 Standard Specifications of Transformers

Item GT transformer ST transformer In-station

transformer

Startup

transformer

Primary 16kv 11kv 16kv 132kv Rated

voltage Secondary 230kv 230kv 6.9kv 6.9kv

Primary 11,547A 8,398A 722A 87.5A Rated

current Secondary 803A 402A 1,674A 1,674A

Primary 320MVA 160MVA 20MVA 20MVA Rated

capacity Secondary 320MVA 160MVA 20MVA 20MVA

Phase wiring Δ-Y Δ-Y Δ-Y Y-Y-Δ

Cooling method ONAF (oil

natural air

forced)

ONAF (oil

natural air

forced)

ONAN (oil

natural air

natural)

ONAN (oil

natural air

natural)


(e) Single-phase transformer and three-phase transformer

When it comes to replacing a single-phase portion of a transformer at times of transportation or

failure, it is more advantageous to have three single-phase transformers. Meanwhile, in cost terms,

adopting three single-phase transformers is more expensive because it is necessary to have a spare

transformer and control devices and foundations for each transformer unit. The single-phase

Appendix


B―26

transformer and three-phase transformer systems are similar in terms of performance.

(7) In-station power supply

Concerning the in-station power supply, the power supply system is composed of the in-station

transformers and startup transformer. In the system used in the CCPP, power will be supplied from

the in-station transformer, while the power for common equipment (water treatment and

wastewater treatment equipment, etc.) will be supplied from the startup transformer. Also, one

three-phase diesel generator will be installed as the emergency power supply in order to enable the

protective power supply to be secured when the CCPP is entirely suspended. Power supply for C

load will be obtained from the DC distribution panel. It shall be possible to secure safe stoppage

of the generating equipment when the CCPP is entirely suspended.

1.2.18 Power Generating Equipment Protection and Control

(1) Protection of generators and transformers

The generator main circuit is composed of the GT generator, GT transformer, ST generator

and ST transformer. The relays for protecting the main circuit will be as follows.

Table b-14 Generator Protective Circuit

Name Element

GT generator operating ratio 87G1

GT transformer operating

ratio

87T1

ST generator operating ratio 87G2

ST transformer operating ratio 87T2

Reversed phase 46

Field loss 40

Generator reverse power 67

Grounding overcurrent 51GN

Over excitation 24

Generator over-voltage 59

Generator low voltage 27G

Frequency high and low 81


Appendix


B―27

(2) Control and monitoring system

The control and monitoring system will be designed to ensure that the maximum safety of CCPP

employees and equipment can be secured and enable the CCPP to be operated safely and

efficiently under all conditions while bearing in mind the peak potential. The control and

monitoring system to enable fully automatic operation of the generating equipment will comprise

a distributed control system (DCS) in consideration of technical and cost factors. The DCS

equipment will enable the control and monitoring of the entire generating system including the

control and monitoring of common equipment.

Basic composition of DCS:

Calculation and power source circuitry will be duplexed and the input/output circuitry will

be single line.

Dual power supply, i.e. AC and DC, will be adopted (matching system).

The core transmission network will be duplexed.

Operations will basically be carried out by mouse.

(3) Generating equipment control and monitoring unit

The generating equipment control and monitoring unit will be composed of DCS equipment,

information control system, maintenance system, transmission network system and related devices.

The DCS equipment will comprise the operator’s console, turbine control system, data collection

system, sequence control system, process I/O system and peripheral equipment all connected in a

transmission network configuration. The GT control system, ST control system, HRSG and local

control system will be connected to the DCS by redundant communications link and hard wiring

signals. Detection for carrying out protective control of the GT, ST and HRSG will be a redundant

triple composition geared to enhancing the reliability of the generating equipment. The control

system will be designed to enable the generating equipment to be operated and controlled by an

automatic system. Also, this will convey to operators information on the status of generating

equipment, start and stop operations, troubleshooting and the routine operating status. The control

logic and graphic display composition of the control system will be designed to ensure that

maintenance staff can easily and correctly make revisions and changes on the ground.

DCS equipment will be planned to possess the following functions.

(a) Turbine control and monitoring function

GT control and monitoring and GT protective circuit

HRSG control and monitoring and HRSG protective circuit

Appendix


B―28

ST control and monitoring and ST protective circuit

High voltage control hydraulic system control

Generator protection, excitation control, voltage control, parallel/parallel-off control

Auxiliary unit control and monitoring

(b) Information collection and control functions

Scan and warning

Process calculation (including performance calculation)

Data log function and data display

(c) Common equipment control and monitoring function

Fuel oil equipment

Water treatment equipment

Wastewater treatment equipment, etc.

1.2.19 Civil and Building Works

The civil and building works will include geologic survey, site creation, design and construction

of rainwater and site wastewater drainage equipment, underground utilities and water intake pipes,

road works, paving and surface gravel laying and compaction, main and auxiliary buildings and

structures including foundations, foundations for indoor and outdoor equipment, building

equipment such as lighting, lightning conductor equipment, sanitary sewage equipment, air

conditioning and ventilation equipment.

The applicable international criteria and standards are indicated below:

The American Concrete Institute concerning concrete works (ACI318)

The American Institute of Steel Construction (AISC) concerning steel structures

American Iron and Steel Institute (AISI)

American Society of Civil Engineers (ASCE)

American Society For Testing and Materials (ASTM) concerning materials quality

control

American Association of State. Highway and Transportation Officials (AASHTO)

concerning road drainage

American Welding Society (AWS) concerning welding

American Water Works Association (AWWA) concerning concrete pipes and distribution

pipes

The National Fire Protection Association (NFPA)

The American Society of Mechanical Engineers (ASME)

Appendix


B―29

The American National Standards Institute (ANSI)

1.2.20 Construction Cost

Table b-15 shows the results of calculating the rough cost of constructing an 800 MW class

combined cycle power plant according to the above basic plan using TEPSCO software and taking

the site conditions in Syria into consideration.

Based on the basic plan, this cost estimation assumes a multiaxial combined cycle power plant

(gas turbines x 2 units, heat recovery boilers x 2 units, steam turbine x 1 unit) of a type that is

frequently adopted in developing countries, uses gas as the main fuel and can combust auxiliary

fuel (in the event where there is a shortage of gas). For steam cooling, considering the

environment in Syria, ACC (draft direct air cooled condenser) will be adopted, the transmission

end output will be 803 MW and the efficiency will be 55.6 percent as indicated in the heat balance

given later.

Table b-15 Construction Cost Calculation

Unit: US$x1000

Description Equipment Material Labor Total

Combustion Turbine & Accessories 175,635 4,956 2,813 183,404

Inlet Filtration System 4,701 459 543 5,703

Electrical Systems - Combustion

Turbine 21,282 373 1,924 23,579

Condensate Heating System 5,002 18 915 5,935

HRSG & Accessories 64,508 1,297 12,023 77,828

Deaeration System 314 128 356 798

Steam Piping 0 14,059 9,043 23,102

Electrical Systems - HRSG 171 316 827 1,314

Steam Turbine & Accessories 52,857 3,447 2,118 58,422

Steam Bypass System 1,769 61 317 2,147

Electrical Systems - Steam Turbine 9,379 2,266 2,458 14,103

Condenser & Accessories 38,593 2,724 12,216 53,533

Water Treatment System 2,370 808 1,291 4,469

Waste Water Treatment System 1,541 61 628 2,230

Auxiliary Boiler & Accessories 2,617 663 691 3,971

Boiler Feed System 2,705 321 982 4,008

Condensate System 400 201 440 1,041

Buildings 1,613 19,570 12,786 33,969

Appendix


B―30

Description Equipment Material Labor Total

Fire Protection System 1,467 56 1,146 2,669

Fuel Systems 3,805 825 1,639 6,269

Fuel Gas Compressor & Accessories 15,590 2,517 1,160 19,267

Bypass Stack & Diverter Valve 12,094 380 4,198 16,672

Main Exhaust Stack 0 3,127 2,011 5,138

Station & Instrument Air System 1,287 619 508 2,414

Closed Cooling Water System 1,019 791 528 2,338

Cranes & Hoists 225 200 224 649

Plant Control System 2,300 0 203 2,503

Continuous Emission Monitoring

System 1,556 1,003 2,033 4,592

Total Process Cost 424,800 61,246 76,021 562,067

General Facilities (Adm bldg, workshop bldg, warehouse, etc.) 21,078

Engineering Fees for plant design by EPC contractor 31,616

Consulting Fees 21,078

Physical Contingency 28,103

Total Plant Cost 663,942

Net Plant Power Output (MW) 802.3

Total Plant Cost per Net kW

(US$/kW) 828


As is shown above, the total construction cost is US$663.9 million. In terms of kW unit cost, this

comes to 828US$/kW. This unit cost does not include Syrian taxation, civil engineering works in

consideration of the site conditions, spare parts required for periodic inspections, gas supply

equipment to the plant, and the construction contingency fund.

Appendix


B―31

274.1 G 40.1 G 432.8 G 2,357.0 G

1.4 G 3,515.9 H 2,923.6 H 230.8 H 98.1 H275.6 G 237.7 T 13.0 P 53.8 G 0.54 P 0.71 P 93.0 P

3,503.1 H 568.0 T 3,053.7 H 232.9 T 55.0 T 93.8 T

13.0 P 3.25 P

563.0 T 326.0 T

2,357.0 G

662.7 H96.5 kPa

599.7 T

319.5 G

3,607.3 H3.15 P

568.0 T

275.6 G G t/hr3,501.5 H H kJ/kg

12.4 P 80.1 G P Mpa

1.4 G 560.0 T 2,918.3 H ToC

237.7 T 0.51 P

11.8 G 641.8 G 229.9 T Steam662.7 H 3,589.8 H Water

93.0 kPa 2,368.8 G 3.09 P Cooling Water599.7 T 662.7 H 560.0 T 740.5 G Gases

96.5 kPa 3,061.1 H599.7 T 120.7 G (Ambient Air) 265.7 G 0.49 P

15.0 T 3,162.7 H 298.1 T

3.31 P

372.0 T

*1 370.9 G

165.2 H0.81 P

39.3 T

740.5 G

300.0 T 2,455.2 H52.59 G 9.1 P(kPa)

49,348 *1 2,316.3 G 31,300 G 38.0 T

15.0 T 15.1 H 30.0 T

93.0 kPa

15.0 T

741.8 G

160.1 H0.81 P

49,790 740.5 G 38.1 T

49,518 200.0 T 159.1 H92.2 T 182.7 T 6.6 P(kPa)

38.0 T

15.0 T

Wet Bulb Temperature

49,320 kJ/kg

Ambient Pressure 93.0 kPa

Relative Humidity 50.0 %

Operating Conditions

Dry Bulb Temperature 15.0 oC

Plant Gross Power Output

kW

kW

kW Total 826,900

Gas turbine (2× 281,950 kW)

Steam turbine

563,900

263,000

57.4 Plant Gross Thermal Eff %

24,600 kW Auxiliary Power Plant Net Power Output

Type of Fuel Natural Gas

10.9 oC

Plant Net Thermal Efficienc 55.6 %

802,300 kW

LHV+Sensible Heat (kJ/kg)



Net Specific Energy

Preliminary Heat and Mass Balance Diagramof 800MW Natural Gas Fired Combined Cycle Power Plant

with Forced Draft Direct Air Cooled Condenser

at Site Conditions

HP SH

RHTR

IP SH LP SHHP EVA IP EVA LP EVAHP ECO IP ECO LP ECO

HPT IPT LPTTurbine Air Compessor

Combustor

from Gland Seals

TCACoole

Fuel GasHeater

Fuel GasComp

from NO.2 HRSG

to NO.2 HRSG

from NO.2 HRSG

Steam Turbine to NO.2 HRSG

Steam Turbine GeneratorNO.1 Gas Turbine Generator

NO. 1 Gas Turbine

NO. 1 HRSG

from NO.2 HRSG

Air Cooled Condenser

Condensate Drain Pot

Figure b-3 Combined Heat Balance


Appendix


B―32

1.3 Basic Plan of the Coal-fired Thermal Power Plant

(1) Rated output and mode of power generation

The plant will be planned assuming rated output of 600 MW at the transmission end and

subcritical pressure equipment (steam pressure 16 MPa, steam temperature 538℃) as the mode of

power generation. The main reasons for selecting subcritical pressure equipment are as follows:

Base load operation with operating factor of around 80 percent entailing few starts and

stops and load change commands will be planned for.

When adopting supercritical pressure (22.1 MPa or higher) for the plant steam conditions,

since there is no specific gravity disparity between steam and water and water cannot be

circulated in water-cooled walls, inevitably a through flow boiler is adopted. In the case

of a through flow boiler, because no drum for separating steam and water is installed, it is

not possible to blow impurities from the feed water as in the case of a drum boiler. In

order to prevent steam containing impurities being conveyed to the turbine, in the case of

a through flow boiler, it is necessary to comply with strict water quality standards such as

preparing extremely high purity boiler feed water.

In supercritical pressure equipment, high plant efficiency can be obtained, however,

compared to subcritical pressure equipment, construction costs are more expensive due to

the use of expensive materials and installation of a condensate demineralizer.

In supercritical pressure equipment, sophisticated technology is required for conducting

the welding repair of high temperature high pressure materials.

Subcritical pressure equipment is numerously proven and entails easy operation and

maintenance.

(2) Equipment Composition

(a) Outline of boiler equipment

The equipment will be planned as a pulverized coal-fired subcritical pressure forced

circulating drum-type boiler. For the burner, a low NOx burner will be adopted, the ventilation

method will be balanced ventilation, and smoke tunnel equipment will comprise major fans

such as primary air fan, forced draft fan and induced draft fan as well as air preheater, electric

dust collector, desulfurization equipment and other environmental instruments, etc. As for the

fuel-related equipment, a coal pulverizer, coal bunker, coal feeder and belt conveyor

equipment, etc. will be installed.

Appendix


B―33

Boiler type: Pulverized coal-fired forced circulating drum-type boiler

Steam flow rate: 1,800 t/h

Superheater outlet steam: 17MPa/541℃

Reheater outlet steam: 3.5MPa/300℃

Burner type: Pulverized coal-fired low NOx burner

Furnace outlet temperature: This shall be at least 50℃ lower than the used fuel ash

melting temperature.

Boiler efficiency: Approximately 80 percent

Soot blowers: Install in the furnace, superheater, reheater, coal economizer and air

preheater.

Coal pulverizer: Install six units with 50 t/h capacity, and use one of these for standby

purposes.

Air and combustion gas equipment: Install balanced ventilation, electric dust collector

and desulfurization equipment.

(b) Outline of turbine equipment

The turbine is composed of the turbine generator unit, condenser equipment, condensing

equipment, feedwater superheater equipment, feedwater pump equipment, cooling water

equipment, seawater system equipment, sealed oil equipment and stator cooling equipment, etc.

Concerning the turbine unit, a tandem compound condensing turbine comprising four cylinders, i.e.

high pressure cylinder, medium pressure cylinder and two low pressure cylinders, will be adopted.

The four-flow type will be adopted for low-pressure air exhaust. For governor control, electronic

hydraulic control will be adopted and high-pressure and low-pressure turbine bypass devices will

be equipped. The feedwater superheater system will comprise three low pressure feedwater

superheaters and three high pressure feedwater superheaters. For the condenser cooling water

pipes, super stainless pipes will be adopted. The condenser will be a surface contact type with one

path and two chambers, and a continuous washing unit will be installed. Moreover, the turbine

drive system will be adopted for the feedwater pump and this will be used during normal operation,

while a powered water feed pump will be used at times of equipment starting and stopping.

The generators will be cooled by the hydrogen cooling method. As accessories, stator cooling

equipment, sealed oil equipment and hydrogen ventilation equipment will be installed. Moreover,

for adjustment of the generator voltage, an AVR (automatic voltage regulator) system will be

adopted and a PSS (power system stabilizer) will be used to stabilize the power system.

Steam turbine: 4 cylinder, reheat condensing extraction turbine

Output: 600MW

Appendix


B―34

Revolutions: 3,000rpm

Governor control system: Electronic hydraulic governor

Condenser: Horizontal, surface cooling, 1 path, double partition of water chamber,

continuous washing unit

Turbine bypass system: High pressure and low pressure turbine bypass system

(c) Outline of water treatment equipment

Because there is no large freshwater resource close to the power plant, a desalination plant

utilizing river water will be installed. The water making capacity will be approximately 2,000

cubic meters per day. This freshwater will be planned so that it can be used not only in the

power generating equipment but also for making coal slurry in the desulfurization equipment.

Concerning the desalination process, either the evaporation method or the reverse osmotic

membrane method can be adopted, however, the latter one will be adopted here.

(d) Outline of coal equipment and coal unloading, storage and transporting equipment

The coal equipment and coal unloading, storage and transporting equipment will be designed

based on the transportation method, heating value of coal, density of coal, unloading speed

and conveyance speed, etc. The equipment will comprise the coal receiving jetty, coal storage

yard and the belt conveyor for linking these items of equipment. In terms of coal lifting

capacity, there will be two lines with capacity of approximately 800 tons per hour, while

concerning the coal conveyance capacity, it is planned to install two lines with capacity of

approximately 500 tons per hour. Capacity of the coal yard will depend on the coal

transportation method, however, it is desirable that enough capacity for around 60 days will be

secured.

Coal unloader (continuous): 800t/h x 2 units

Receiving conveyor: 800t/h x 2 lines

Stacker and reclaimer: 800t/h x units

Issuing conveyor: 800t/h x 2 lines

(e) Ash treating equipment

Ash that is melted in the coal combustion will fall into the hopper and will be collected underneath

the boiler furnace. This ash is known as clinker. Generally speaking, around 5~15 percent of the

entire ash quantity will be captured. The clinker ash that is discharged from the bottom of the

boiler will be carried by truck to the ash dump. Meanwhile, the combustion ash that is captured by

the electric dust collector will be collected in the hopper underneath the dust collector. This

Appendix


B―35

combustion ash is known as fly ash. Roughly 80~90 percent of the total ash volume will be

collected here. After the fly ash is carried to the silo by compressed air, it will be carried to the ash

dump by truck. The capacity of the ash dump will be enough to hold the ash generated over the

service life of the power plant. The combustion ash from the coal-fired thermal plant and gypsum

generated in the desulfurization equipment has the potential to be used as mineral resources, and

approximately 50 percent of coal ash in Japan is utilized in the cement field.

Furnace bottom ash equipment: 1 unit

Ash collection equipment: 1 unit

Fly ash storage and issue equipment: 1 unit

(f) Water intake equipment

The water intake equipment will be composed of water intake pipes, intake equipment, screen

equipment and water circulation equipment. Two circulating pumps with 50 percent capacity each

will be installed.

(g) Wastewater treatment equipment

The wastewaters that are generated on both a routine basis and non-routine basis in coal-fired

thermal power will undergo physical and chemical treatment to ensure that they satisfy

wastewater standards. Wastewater from coal-fired thermal power includes the following.

Living wastewater from hand washing and toilets, etc.

Wastewater from coal handling equipment such as unloading, transporting and storage

equipment

Wastewater from ash treating equipment generated in handling of clinker and ash from

the electric dust collector

Wastewater from the smoke exhaust plant comprising air preheater, electric dust collector

and desulfurization equipment

Power plant waste water from the boilers, turbines and condensing system

(h) Desulfurization equipment

The desulfurization equipment will be installed downstream of the electric dust collector. The

wet limestone–gypsum method is widely used throughout the world. The desulfurization

equipment will be composed of four processes, namely the limestone supply process, which

supplies the limestone (an alkaline absorption agent), the absorption process for removing

SO2 from exhaust gases, the gypsum recovery process for recovering the byproduct gypsum,

Appendix


B―36

and the ventilation process which introduces exhaust gas and reheats the gas. The SO2 in the

exhaust gas will react with the limestone and will be oxidized by oxygen in the air, thereby

producing gypsum. The system will be designed in combination with related equipment such

as electric dust collector to ensure that the dust concentration of exhaust gas is within the

designated standard and the gypsum concentration is 95 percent or higher based on data such

as the coal characteristics and limestone concentration and so on.

Oxidation air compressor: 50 percent x 3 units

Service water pump and associated equipment: 100 percent x 2 units

Mist eliminator: 1 set

Limestone slurry system: 1 set

Dewatering equipment and vacuum filter system: 1 set

(i) Limestone and gypsum equipment

Following unloading, limestone will be carried to the limestone storage yard by belt conveyor.

From the storage yard, the limestone will be carried by bulldozer to the plant limestone

storage silo. Assuming that the S content of limestone is 1 percent, the required amount of

limestone will be approximately 250 tons per day, and it will be necessary to design the

limestone and gypsum equipment in consideration of this point.

Limestone unloader: 1 unit

Limestone receiving conveyor: 1 unit

Limestone storage silo: 1 unit

Gypsum issuing equipment: 1 unit

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Appendix - JICA · 2012-05-09 · Appendix Study for Updating Syrian Electricity Sector in Syrian...

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