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Siemens Gas Turbine SGT5-4000FAdvanced performance

Answers for energy.

_SGT5_4000F.indd Abs1:1_SGT5_4000F.indd Abs1:1 14.05.2008 14:18:07 Uhr14.05.2008 14:18:07 Uhr

Increasingly fierce competition fueled by deregulation and privatization is dictating ever lower power generation costs. One approach to cost-cutting is economical plant operation centering on low investment costs and in particu-lar on lowest life-cycle costs.

The SGT5-4000F – Siemens

Gas Turbine (SGT™) – our

high-performance workhorse

is tailored to meet these re-

quirements. With its inno-

vative design, mate rials and

thermodynamic processes,

the SGT5-4000F ensures you

a strong position in a com-

petitive market.

The machine is character-ized by the use of a proven concept:

Two rotor bearings

Cold-end generator drive

Built-up rotor with Hirth

serrations and central tie

bolt

The combination of this proven design and innova-tive features results in:

Low investment costs per

installed kilowatt

High efficiency

Low maintenance expen-

diture

Long service life

Fast payback on invested

capital

Based on the standard design

concepts of our modular

reference power plants for

single-shaft and multi-shaft

application we have defined

several scope of supplies

around the SGT5-4000F.

These packages from compo-

nent through SGT-PAC to the

full Turnkey scope support all

your needs. The intelligent

with a range of modules and

options brings you benefits

in terms of deadlines and

quality.

2

The SGT5-4000F – Designed for competitive power generation


The SGT5-4000F gas turbine concept builds on more than 40 years‘ experi-ence with heavy-duty gas turbines at Siemens and Siemens Westinghouse. This is the solid technical foundation, on which innovative technology is based. Consistent application of the accumulated know-how on a wide range of disciplines was implemented. For instance, development and manu-facture of this technology involved not only aeroengine manufacturers but also precision casting specialists, research institutes and technical uni-versities.

The task in hand was to ensure

maximum operating economy.

The first crucial questions we

had to answer were:

Does an appropriate technical

platform for this development

already exist?

Where do new solutions have

to be found?

The key technical starting

points:

Compression and combustion.

We had to push forward into

new thermodynamic ranges

and higher combustion tem-

peratures, while still fulfilling

the requirements for an easy-

to-service design and long

intervals between major over-

hauls.

Today, the SGT5-4000F is proof

that it is possible to reconcile

ambitious economic and envi-

ronmental targets – through:

Effective use of resources

Low NOx content of exhaust

gas

Lowest CO2 emissions

* Standard design; ISO ambient conditions

** Length incl. transmission

*** Weight main frame + transmission

Siemens Gas Turbine*

SGT5-4000F SGT5-3000E SGT-1000F

Grid frequency (Hz) 50 50 50/60

Gross power output (MW) 292 191 68

Gross efficiency (%) 39.8 36.8 35.1

Gross heat rate (kJ/kWh) 9,038 9,794 10,265

Gross heat rate (Btu/kWh) 8,567 9,283 9,730

Exhaust temperature (°C/°F) 577/1,071 575/1,068 583/1,081

Exhaust mass flow (kg/s) 692 512 192

Exhaust mass flow (lb/s) 1,526 1,129 422

Pressure ratio 18.2 13.3 15.7

Length x width x height (m)* 13x6x8 13x6x8 11x4x4.8**

Weight (t) 308 308 53 + 20***

3

SGT5-3000E SGT-1000F

50 50/60

191 68

36.8 35.1

9,794 10,265

9,283 9,730

575/1,068 583/1,081

512 192

1,129 422

13.3 15.7

13x6x8 11x4x4.8**

308 53 + 20***


Optimized flow, combustion and cool-ing systems as well as new materials add up to a gas turbine efficiency of nearly 40%. To highlight a few features:

The SGT5-4000F – Innovative design on a proven basis

Very compact casing

15-stage high-efficiency

compressor

Optimized design point for

compressor pressure ratio

and boundary-zone-correct-

ed compressor blades

(controlled diffusion airfoils)

Annular combustion

chamber with 24 hybrid

burners for uniform flow

and temperature distribu-

tion

Compact design and fully

ceramic heat shields to

minimize cooling air require-

ments

Single-crystal blades made

of high-grade alloys with

additional ceramic coating

High-efficiency vortex and

convection cooling in the

blade interior with film

cooling of the blade surface

The latest vintage SGT5-

4000F also features fail-safe

hydraulic turbine blade tip

clearance control for opti-

mized radial clearances and

hence maximimum perfor-

mance

Easy-to-service design

thanks to an annular walk-

in combustion chamber,

which enables inspection of

hot-gas-path parts without

cover lift

The compressor

The compressor with

optimized flow path and

controlled diffusion air-

foils for more efficient

operation. Ruggedized

compressor design to

withstand underspeed

and overspeed conditions,

ensuring reliable operation

of the SGT5-4000F in grids

with major frequency

fluctuations.

The turbine blades

The blades of the first and

second turbine stages have

to withstand thermal

stresses and are therefore

fabricated from a heat-

resistant alloy which is

allowed to solidify as a

single-crystal structure.

They also have an additional

ceramic coating. They are

cooled internally through

a complex array of air

channels and externally

by film cooling. These mea-

sures combine to ensure a

long blade service life.

4


Proven design features at a glance

The SGT5-4000F is based on

the SGT5-2000E/SGT6-2000E,

our reliable runners. These

gas turbines are of proven

ruggedness, as attested by

more than 380 machines sold

and more than 8.8 million

cumulative operating hours.

Main features include:

Horizontally split casing

Two rotor bearings

Disk-type rotor with Hirth

serrations and a central tie

bolt

All blades removable with

rotor in place

Multi-stage axial-flow com-

pressor with variable-pitch

inlet guide vanes, four-stage

axial-flow turbine, all

moving blades free-standing

Hybrid burners for premix

and diffusion mode opera-

tion with natural gas and

fuel oil

Combustion chambers lined

with individually replace-

able ceramic heat shields

Generator coupled to com-

pressor (cold-end drive)

Axial exhaust gas flow

The enhanced hybrid burner

The dual-fuel hybrid burner for premix

and diffusion combustion of gas and oil

consists of a system of rugged individual

burners. This configuration permits

flexible, stable, clean – and therefore

economical – operation.

The rotor

The rotor is designed as a

disk-type rotor with Hirth

serrations and central tie

bolt. This proven design

principle combines low

weight with high stiffness

and ensures smooth

running and low thermal

stresses under all operating

conditions, resulting in the

familiar short run-up times

of Siemens gas turbines.

The annular combustion chamber

The enhanced hybrid

burner (HR3) with its cylin-

drical burner extensions

and modified flow path

results in stable, low noise

combustion.

5


6

The Siemens Gas Turbine Package (SGT-PAC) comprises the gas turbine and generator, and all major mechani-cal, control and electrical equipment required for safe and reliable opera-tion of these components.

The SGT5-PAC 4000F

We deliver our Siemens Gas

Turbine Packages largely pre-

assembled, including piping

and wiring to a major extend.

The auxiliary systems are com-

bined in groups and installed

as prefabricated packages.

This reduces installation and

commissioning expenditures

and durations.

Pre-engineered options are

available to meet project- and

site-specific requirements or

to increase operating flexibil-

ity and performance of the

power generating system.

Options (selection)

Liquid fuel system

Dual-fuel operation

NOx water injection

system for liquid fuels

Inlet air evaporative

cooling

Inlet air anti-icing

system

Inlet air self-cleaning

pulse filter

Gas turbine stack

for simple cycle

Diverter damper

and bypass stack

for combined cycle

Further noise abatement

Fin-fan cooling systems

for generator and lube

oil

Base scope

Gas turbine

Electrical generator

Fuel gas system

Hydraulic oil system

Instrument air system

Lube oil system

Compressor cleaning

system

Air intake system

Exhaust gas diffuser

Instrumentation &

Control

Electrical equipment

Power Control Centers

Noise enclosures

Fire protection

Starting frequency

converter

Scope of SGT5-PAC 4000F


7

The SGT5-4000F has been in service since 1997. We have sold nearly 290 gas turbines of the SGT-1000F series, SGT5-4000F and SGT6-4000F with more than 3.6 million cumulative operating hours and a fleet reliability exceeding 99%.**

World experience

** Status December 2007

Didcot B, England

National Power plc. operates

the combined cycle power

plant with two multi-shaft 2x1

units that has a total capacity

of 1390 MW and nearly

220,000** operating hours for

V94.3A (new: SGT5-4000F).

Mainz-Wiesbaden, Germany

Kraftwerke Mainz-Wiesbaden

AG operates the combined

cycle cogeneration power

plant with one multi-shaft 1x1

unit that has a total capacity

of 410 MW, featuring the

latest vintage V94.3A (new:

SGT5-4000F) design already

with over 52,000** operating

hours.

Seabank 1&2, England

Seabank Power Ltd./Scottish

& Southern Energy operate

one multi-shaft 2x1 and one

single-shaft combined cycle

power plant with a total

capacity of 1,140 MW and

nearly 150,000** operating

hours.

Genelba, Argentina

PECOM ENERGIA S.A. operates

the combined cycle power

plant with a multi-shaft 2x1

unit that has a total capacity of

660 MW and over 133,000**

operating hours.

* ISO conditions, natural gas fuel

Performance* SGT5-4000F SGT5-3000E SGT-1000F

Siemens Gas Turbine Packages 50 Hz 50 Hz 50/60 Hz

Net power output (MW) 288 188 66

Net efficiency (%) 39.5 36.3 34.6

Net heat rate (kJ/kWh) 9,114 9,908 10,396

Net heat rate (Btu/kWh) 8,638 9,391 9,854

Exhaust temperature (°C/°F) 580/1,075 579/1,073 586/1,087

Exhaust mass flow (kg/s) 688 512 190

Exhaust mass flow (lb/s) 1,516 1,128 418

Generator type Air-cooled Air-cooled Air-cooled

Siemens Combined Cycle Power Plant

Single-Shaft


Net efficiency (%) 58.4 56.5 52.6



Multi-Shaft 2x1


Net efficiency (%) 58.5 56.3 52.5



SGT5-3000E SGT-1000F

50 Hz 50/60 Hz

188 66

36.3 34.6

9,908 10,396

9,391 9,854

579/1,073 586/1,087

512 190

1,128 418

Air-cooled Air-cooled

290 101

56.5 52.6

6,368 6,844

6,036 6,487

576 201

56.3 52.5

6,389 6,858

6,056 6,501


r


SGT5-4000F adjustment to site conditions

Power Output and Efficiency at Generator Terminals

-20 -10 0 10 20 30 40 50

1.12

1.08

1.04

1.00

0.96

0.92

0.88

0.84

0.80

0.76

Ambient temperature [°C]

Efficiency atGenerator Terminals

Power Output atGenerator Terminals

Power Output at Generator Terminals1.05

1.00

0.95

0.90

0.85

0.80

Altitude [m]

16000 200 400 600 800 1000 1200 1400

Power Output at Generator Terminals

1.008

1.004

1.000

0.996

0.992

0.988

Relative humidity [%]

1000 20 40 60 80

30°C

45°C

15°C

0°C

Efficiency at Generator Terminals

1.012

1.008

1.004

1.000

0.996

0.992

Relative humidity [%]

1000 20 40 60 80

0°C

15°C

30°C

45°C

_SGT5_4000F.indd 9_SGT5_4000F.indd 9 14.05.2008 14:18:03 Uhr14.05.2008 14:18:03 Uhr

www.siemens.com/energy

Published by and copyright © 2008:

Siemens AG

Energy Sector

Freyeslebenstrasse 1

91058 Erlangen, Germany

Siemens Power Generation, Inc.

4400 Alafaya Trail

Orlando, FL 32826-2399, USA

For more information, contact our

Customer Support Center.

Phone: +49 180/524 70 00

Fax: +49 180/524 24 71

(Charges depending on provider)

e-mail: [email protected]

Fossil Power Generation Division

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Printed in Germany

Dispo 05400, c4bs No. 1359, 805

108411M WS 05083.

Printed on elementary chlorine-free bleached paper.

All rights reserved.

Trademarks mentioned in this document are

the property of Siemens AG, its affi liates, or their

respective owners.

Subject to change without prior notice.

The information in this document contains general

descriptions of the technical options available, which

may not apply in all cases. The required technical

options should therefore be specifi ed in the contract.

_SGT5_4000F.indd 10_SGT5_4000F.indd 10 14.05.2008 14:18:06 Uhr14.05.2008 14:18:06 Uhr

Application HandbookSGT5-PAC 4000F

Siemens AG . Power Generation Transmittal, reproduction, dissemination and/or editing of this document as well as utilization of its contents and communication thereof to others without express authorization are prohibited. Offenders will be held liable for payment of damages. All rights created by patent grant or registration of a utility model or design patent are reserved.

non-binding values / information Application Handbook SGT5-PAC 4000F I Revision 3 I 23.05.2007 I H. Bauer I Section 5 I Page 1 of 15

5 Performance Summary

5.1 Performance Overview for ISO Conditions

5.2 Thermal Performance for Site-Specific Conditions

5.3 Performance Optimization

5.4 Emissions Performance

5.5 Start-up Performance

5.6 Steam Production Capability

5.7 Acoustic Performance

5.8 Online Fuel-Changeover

5.9 Generator Performance

5.10 Reliability and Availability

5.11 Combined-Cycle Performance

Tables 1: Thermal Performance and Emissions Overview 2: Start-Up Performance 3: Acoustic Performance - Surface Sound Pressure Levels and Sound Power Levels 4: Reliability and Availability

Figures 1a: Ambient Pressure - Effect on Power Output, Mass Flow 1b: Site Elevation - Effect on Ambient Pressure 2: Compressor Inlet Temperature - Effect on Power Output, Efficiency, Exhaust

Temperature, Mass Flow 3: Relative Humidity - Effect on Power Output, Efficiency, Exhaust Temperature,

Mass Flow 4: Inlet and Outlet Pressure Loss - Effect on Power Output, Efficiency, Exhaust

Temperature, Mass Flow 5: Fuel Gas Lower Heating Value - Effect on Power Output, Efficiency, Mass Flow 6: Speed - Effect on Power Output, Efficiency, Exhaust Temperature, Mass Flow 7: Degradation - Effect on Power Output, Efficiency 8: Part Load - Effect on Efficiency, Exhaust Temperature, Mass Flow 9: NOx Emissions for Natural Gas Fuel in Premix Mode, Light Distillate Fuel in

Premix Mode, Light Distillate Fuel in Premix Mode and Water Injection 10: Start-Up of Gas Turbine to Full Load 11: Variable-Pitch Inlet Guide Vane Operation 12 Steam Production - Steam Production Capability, HRSG Steam Rejection 13: Online Fuel-Changeover – Gas to Oil, Oil to Gas 14: Air-Cooled Generator: Reactive Capability Curve, Saturation Curves, V-Curves




5 Performance Summary

5.1 Performance Overview for ISO conditions

Base load plant thermal performance and emissions performance under ISO conditions for a standard SGT5-PAC 4000F Siemens Gas Turbine Package is provided in Table 1.

5.2 Thermal Performance for Site-Specific Conditions

This section provides a systematic method of determining the performance of a Siemens Gas Turbine Package for specific site conditions. Five basic parameters are used to measure thermal plant performance:

• power output • efficiency or heat rate • fuel mass flow • turbine exhaust flow • turbine exhaust temperature • compressor mass flow Conditions that directly affect thermal performance are

• site elevation • compressor inlet temperature • compressor inlet and turbine exhaust losses • fuel gas lower heating value • rotor speed • degradation • load level

Using correction factors, the effects of site conditions on plant performance can be estimated for a variety of operating configurations. The performance data is presented for natural gas and liquid fuel for base loads. Net power is the power at the generator terminals minus Package plant auxiliary loads. Net power and net heat rate are provided for an Gas Turbine Package with an air-cooled generator.

The thermodynamic design data at ISO conditions and base load can be approximately converted to other ambient conditions using appropriate correction factors. Figures 1 - 8 depict these correction factors as curves plotted as a function of the individual ambient conditions. Data calculated with these correction factors must not be used as guarantee data. Guarantee data for conditions other than ISO ambient conditions must be calculated with a cycle calculation program specified by Siemens.




Power Output at generator terminals

PGT-CORR = PGT • P*1 • P*2 • P*3 • P*4 • P*5 • P*6 • P*7 • P*10

where

PGT-CORR Corrected output at generator terminals PGT Output at generator terminals under ISO conditions P*1 Correction factor for ambient pressure P*2 Correction factor intake pressure drop P*3 Correction factor for exhaust pressure drop P*4 Correction factor for lower heating value P*5 Correction factor fur humidity P*6 Correction factor for speed P*7 Correction factor for ambient temperature P*10 Correction factor for aging

Efficiency at generator terminals

ηGT-CORR = ηGT • E*2 • E*3 • E*4 • E*5 • E*6 • E*7 • E*8 • E*10

where

ηGT-CORR Corrected efficiency at generator terminals ηGT Efficiency at generator terminals under ISO conditions E*2 Correction factor for intake pressure drop E*3 Correction factor for exhaust pressure drop per E*4 Correction factor for lower heating value 7 E*5 Correction factor for humidity E*6 Correction factor for speed E*7 Correction factor for ambient temperature E*8 Correction factor for part load (at rated load, η*GT8 = 1.0) E*10 Correction factor for aging

Fuel Mass

mF-CORR = PGT-CORR/(ηGT-KORR . LHV)




Turbine Exhaust Mass Flow

mTDO-CORR = mTDO . M*1 . M*2 . M*4 . M*5 . M*6 . M*7 . M*8

where

mTDO-CORR Corrected turbine exhaust mass flow mTDO Turbine exhaust mass flow under ISO conditions M*1 Correction factor for ambient pressure M*2 Correction factor for intake pressure drop M*4 Correction factor for lower heating value M*5 Correction factor for humidity M*6 Correction factor for speed M*7 Correction factor for ambient temperature M*8 Correction factor for part load (at rated load, M*8 = 1.0)

Turbine Exhaust Temperature

ϑTDO-CORR = ϑTDO . T*2 . T*3 . T*5 . T*6 . T*7 . T*8

where

ϑTDO-CORR Corrected turbine exhaust temperature ϑTDO Turbine exhaust temperature under ISO conditions 1 T*2 Correction factor for intake pressure drop T*3 Correction factor for exhaust pressure drop T*5 Correction factor for humidity T*6 Correction factor for speed T*7 Correction factor for ambient temperature T*8 Correction factor for part load (at rated load, T*8 = 1.0)

Compressor Mass Flow

mCI-CORR = mTDO-CORR - (1 + mH2O / mF ) . mF-CORR




5.3 Performance Optimization

Gas Turbines may degrade in performance due to a number of factors such as:

• Deposits on flow surfaces • Roughing of flow surfaces • Foreign object damage • Gross distortion of parts • Seal and blade tip wear

Figures 7 show the typically expected effect of degradation on power output and efficiency related to a reference condition. This reference condition is, among other things, the guaranteed performance for „new and clean“ and operation of the gas turbine with conventional gaseous or liquid fuels. Furthermore the compliance with recommendations on compressor cleaning must also be given (more details in Chapter “Auxiliary Systems”).

The magnitude in performance recovery resulting from maintenance activities depends on the scope of the work (more details in Chapter “Service Aspects”). The curve for long-term degradation depicts how performance is recovered after a major inspection has been performed, including manual compressor cleaning of all stages.

The only degradation that is recoverable by cleaning is that due to removable deposits on flow surfaces. These deposits cause increased friction and separation losses, and are not confined to the compressor. The following deals only with compressor cleaning, but it is important to realize that the effectiveness of cleaning may not be noticed if the degradation due to the other factors becomes large. The degradation due to such wear and tear, however, should be recoverable at major overhaul with individual component restoration.

Typical fouling characteristics in the compressor are due to a build-up of an oily/greasy surface in several early stages of the compressor flow path components. This surface, in turn, acts to trap other drier particulate matter, and a layering cycle begins to take place. Siemens recommends both an on-line and an off-line cleaning to help recover losses in performance from these deposits. Compressor deposits can generally be removed by on-line cleaning to render partial restoration. Shutdown and off-line cleaning with a water-detergent solution will result in relatively full restoration in most environments.

The severity and rate of degradation, and hence the choice and frequency of the application of these procedures, depends upon the environment in which the engine is operating. Some units are situated in environments that are more conductive to fouling than others. For example, in clean, in-land locations, the air is usually free of dust and binding agents (oil vapors, airborne chemicals, etc.). When the atmosphere is contaminated, more frequent cleaning is necessary to recover the lost efficiency. High efficiency, multi-stage inlet filters may help in certain applications. Turbine water cleaning is required only for ash producing fuels, such as crude and residual oil fuel.




5.4 Emissions Performance

The SGT5-4000F gas turbine includes dry low-NOx technology to control NOx emissions. Water injection to the fuel can be provided as an option to further reduce emissions when operating on fuel oil.

Dry low NOx technology utilizes lean premix combustion in conjunction with a pilot zone. The intense mixing and overall lean conditions result in lower flame temperatures and minimal NOx generation. The conventional diffusion-flame zone is used to meet the operational requirements of the gas turbine: ignition, fuel staging sequence through the engine load range, and flame stability.

The NOx production of the combustor is a direct function of the amount of fuel that is burnt in the pilot zone, where the fuel burns close to the stoichiometric flame temperature. At base load firing temperature, over 90% of the fuel is burned in the lean, premixed zones.

The NOx control performance is illustrated in Table 1 and Figures 9.




5.5 Start-Up Performance

The SGT5-PAC 4000F Siemens Gas Turbine Package has short start-up times which are defined by the time needed to reach full rotor speed, time for synchronization and time to reach full load. Figure 10 shows a typical start-up profile.

The procedure for automatic start-up and shutdown passes through the following sequence (for simple-cycle operation):

• If the gas turbine is not in turning gear operation mode, the lubrication oil system is started and brought up to full pressure.

• The turbine-generator rotor is accelerated to turning gear speed of 120 rpm.

• The starting frequency converter then begins to accelerate the unit shaft.

• The gas ignition system is activated at 500 rpm. Minimum fuel (approximately 10 % flow) is admitted to the gas turbine at about 700 rpm when the fuel stop valve is opened.

• At 1000 rpm the fuel flow is gradually increased to accelerate the unit shaft.

• The variable frequency converter is switched off at 2100 rpm. Further acceleration up to synchronous speed of 3000 rpm is maintained by the turbine itself.

• Automatic synchronization with a stable electrical system is possible within approx. 20 seconds.

• The loading procedure begins with a 5 MW load step. Subsequently, loading up to base load can be accomplished at a constant gradient of 13 MW/min.

• Full exhaust-gas temperature is reached at about half load.

• Then the compressor variable-pitch guide vanes are modulated towards the fully open positions at base load.

The gas turbine is unloaded after shutdown command in accordance with the same gradient as for loading. There is no difference of the above described procedure in restarting from cold, warm or hot start conditions.

The start-up performance is given in Table 2




5.6 Steam Production Capability

Variable-Pitch Inlet Guide Vane Control

When operating the gas turbine in heat-recovery applications, it is generally desirable to hold the turbine inlet temperature constant at part load to maintain a low plant heat rate. To achieve this, the Siemens Gas Turbine utilizes variable inlet guide vanes.

The flow of air through the gas turbine is controlled by adjusting the pitch of the compressor inlet guide vanes. When the inlet guide vanes are “opened“, the air flow through the gas turbine increases, when they are “closed“ it decreases. This makes it possible to maintain a constant exhaust temperature in the upper output range when load changes are made. As a result, the part-load efficiency of combined-cycle plants is improved.

Figure 11 demonstrates how power and exhaust temperature are affected by opening the IGVs during start-up or closing the IGVs for part load operation. Below approximately 60% of base load, the inlet guide vanes cannot be closed any further, and a reduction in turbine inlet temperature must be used to lower power.

CHP Applications

Fitted with a heat-recovery steam-generator, the Siemens Gas Turbine Package can be used in heat recovery applications to produce steam for industrial process use or for cogeneration (cogen), also known as combined heat and power (CHP). Cogen/CHP is the simultaneous production of electricity and useful heat from the same fuel or energy. A compilation of waste-heat recovery steam curves are provided in Figure 12. For this purpose a single-pressure steam boiler has been used as a reference. Multiple-pressure steam cycle will be applicable for cogen projects as well.

The gas turbine performance data reflects the effects of a GT inlet pressure loss of 3.4'' H2O (approx. 9mbar) and GT outlet pressure drop of 11'' H2O (approx 27.4 mbar). All ratings are specified for base load output at 15° C (59 F) sea level conditions on natural gas fuel.

For this purpose the single-pressure steam boiler is configured with state-of-the-art values component performance:

- Approach Point=10°F (5.5K) - Pinch Point=15°F (8.3K) - Pressure losses - Economizer = 3% - Superheater = 3% - Drum-Blow-Down = 1% - Condensate Temperature = 227.8°F (108.2°C)

Although, steam production varies depending on site conditions, these steam curves will enable users to determine the amounts of steam that can be expected, at different pressure and temperature conditions, from ducting gas turbine exhaust into a single- pressure level waste heat recovery boiler without supplementary firing.




5.7 Acoustic Performance

Near Field Sound Level

The spatially averaged near field A-weighted sound level resulting from the operation of one Siemens Gas Turbine Package is estimated to be as shown in Table 3 under the following conditions:

• measured in a free field environment • measured on the near field source envelope contour located 1 meter from major surfaces

of equipment and/or enclosures, at a height of 1.5 meters above ground level • Siemens Gas Turbine Package is operating at steady state base load conditions, exclusive

of transients, startup and shutdown, off-normal and emergency conditions, and pulse filter cleaning operations (if applicable)

In the event the Siemens Gas Turbine Package scope of supply excludes exhaust components, as in combined-cycle applications, the estimated sound levels given are exclusive of all sound from the gas turbine exhaust.

Far Field Sound Level

The spatially averaged far field A-weighted sound level resulting from the operation of one Siemens Gas Turbine Package is estimated under the following conditions:

• measured in a free-field environment over flat unobstructed terrain with porous ground

• measured at a horizontal distance 122 meters from the equipment sound source envelope, at a height of 1.5 meters above ground level

• Siemens Gas Turbine Package is operating at steady state base load conditions, exclusive of transients, startup and shutdown, off-normal and emergency conditions, and pulse filter cleaning operations (if applicable)

The far field sound source envelope, to which far field sound levels are referenced, is defined as the smallest rectangle which encloses the Siemens scope of supply equipment.

In the event the Siemens Gas Turbine Package scope of supply excludes exhaust components, as in combined cycle applications, the estimated sound levels given are exclusive of all sounds from the Gas Turbine exhaust.

The far field A-weighted sound level for a multiple-unit Siemens Gas Turbine Package may be approximated by:

Sound Level (N Siemens Gas Turbine Packages) = Sound Level (Single Siemens Gas Turbine Package) +10 log N




5.8 On-Line Fuel Changeover

Switching from operation on natural gas to fuel oil and vice versa is possible during operation of the engine (Fig. 13).

5.9 Generator Performance

Reactive Capability Curve, Saturation Curves and V-Curves for the air-cooled generator are shown in Figures 14.

5.10 Reliablity and Availability The 12-month rolling average of the reliability and availability of the SGT5-PAC 4000F fleet based on the units reporting is shown in Table 4. Reliability Factor is calculated by:

PHFOHPHRF )(%100 −⋅=

Availability Factor is calculated by:

PHSOHFOHPHAF ))((%100 +−⋅=

PH = period hours FOH = forced outage hours SOH = scheduled outage hours

5.11 Combined-Cycle Performance

Combined-cycle performance for typical Siemens single-shaft and multi-shaft arrangements can be performed with the web-based Siemens Performance Estimation Program SIPEP • for user specified ambient conditions • with a choice of different back cooling (cold end) systems • with a choice of different fuels • for design, off-design and part load calculations.

The program neither does require extensive training classes nor every-day use. The user interface is easy to use and features logic and clear selections. For each input detailed online help is just a mouse click away.




Table 1: Thermal Performance and Emissions Overview at ISO Baseload Conditions (Simple cycle)

Conditions Ambient Conditions: Turbine inlet temperature Ambient pressure (sea level) Relative humidity of the air

ISO: 15 °C / 59 °F

1.013 bar / 14.7 psi 60 %

Load Level 100 % Turbine Rotor Speed 3000 min-1 Design Pressure Loss Compressor Air Intake System

9 mbar

Design Pressure Loss Exhaust Gas System

10 mbar

Generator Power Factor 0.85 Fuel Methane Fuel Oil No.2 Fuel Oil No. 2 Lower Heating Value 50035 kJ/kg Fuel Mass Flow 13.9 kg/s Emission Control dry dry water Water Injection Ratio - - 1.0 kg/kg

Thermal Performance Gross* Power Output 283 MW Gross* Efficiency 39.2 % Gross* Heat Rate 9175 kJ/kWh Exhaust Flow 687 kg/s Exhaust Temperature 581°C

* at generator terminals

Siemens Gas Turbine Package Emission Performance Nitrogen Oxides * (NOx) 25 / 15 ppm 73 / 58 ppm 42 / 42 ppm Carbon Oxide (CO) < 10 ppm < 10 ppm < 10 ppm Unburned Hydrogen Carbons 4 ppm 6 ppm 6 ppm Volatile Organic Compounds 2 ppm 3 ppm 3 ppm Soot (Bacharach Nr.) - < 2 < 2

* values are for: base load / operation at lower turbine inlet temperature, and dry exhaust with 15% O2




Table 2: Start-Up Performance

(for simple-cycle operation)

Time to Full Speed * Time to Full Load **

about 5 min. about 27 min.

(loading with 13 MW/min.)

* from turning gear speed ** = time to full speed + synchronization time + loading time




Table 3: Acoustic Performance - Surface Sound Pressure Levels and Sound Power Levels

Component Indoor Installation

Outdoor Installation

Enclosure casing Base L'P < 75 dB(A) Openings of enclosure air handling units

Base Lw < 91 dB(A)

Air intake opening of GT seal air cooler

Option L'P < 80 dB(A)

Gas Turbine

Air exhaust opening of GT seal air cooler

Option Lw < 86 dB(A)

Fuel gas system Base Annex connected to GT enclosure L'P < 75 dB(A)

Hydraulic oil system Base L'P < 83 dB(A) Inside Enclosure for

Base Module Instrument air system Base

L'P < 80 dB(A) Inside Enclosure for Base Module

HCO power unit Base L'P < 83 dB(A) Inside Enclosure for

Base Module Lube oil system Base

L'P < 80 dB(A) Inside Enclosure for Base Module

Air Dryer Base L'P < 80 dB(A) Inside GT Encl. Fuel oil system Option

L'P < 83 dB(A) Inside Enclosure for Option Module

Auxiliary Systems

NOx water system Option L'P < 80 dB(A) Inside Enclosure for

Option Module Enclosure for Base Module for fuel gas operation


Enclosure for Option Module for fuel oil operation


1 duct wall indoor Lw < 93 dB(A)

Vertical compressor air intake duct

Base

Whole duct indoor Lw < 98 dB(A)

Air Intake System

Filter house openings, including anti-icing if applicable, excl. pulse noise if appl., silencer casing, ellbow casing,

Base (Pulse System Option) Lw < 105 dB(A)

Lw < 105 dB(A)




outdoor parts of vertical duct if applicable

Filter house openings, including anti-icing if applicable, incl. pulse noise, silencer casing, ellbow casing, outdoor parts of vertical duct if applicable

Option

Lw < 105 dB(A) Lw < 105 dB(A)

Diffuser Base Lw < 114 dB(A) Diverter damper or lower part of stack (elbow)


Exhaust Gas System

Upper part of stack incl. silencer casing


Lube oil fin-fan cooler (6 fans)


Generator fin-fan cooler (16 fans)


Fin-Fan Cooler

Pumps for generator fin-fan cooler


each Air Condition unit of the PCC (3 units)

Base Lw < 82 dB(A)

Excitation transformer Base Lw ≤ 78/88 dB(A) 1)

Electrical System

Start-up transformer (SFC-Transformer)

Base Lw ≤ 81/91 dB(A) 1), 2)

Generator Standard Enclosure Base L'P < 80 dB(A) L'P < 80 dB(A) Standard Enclosure Option L'P < 75 dB(A) L'P < 75 dB(A)

• The surface sound pressure levels L'P and sound power levels LW mentioned above are

defined as described in ISO 3740-46.

• Surface sound pressure levels are to be measured at a distance of 1m from the component and its sound attenuation device respectively.

• On the assumption that the individual noise limits given above are not exceeded and that diffuser and diverter or lower part of stack are equipped with additional sound barrier walls from 1mm trapezoidal steel sheet, the following spatially averaged A-weighted sound pressure levels (Leq) measured at a distance of 1m from the equipment or its acoustic attenuation device and at a height of 1,5m above ground floor level can be kept: - Turbine building: Leq < 85 dB(A) - General work areas (indoor and outdoor): Leq < 85 dB(A)

• Reduced noise emissions are possible on request.

• 1) Maximum sound level during sinusoidal load / non-sinusoidal load. 2) During GT start-up in operation only.




Table 4: Availability and Reliability

Reliability Factor Availability Factor

99.1 % 95.5 %

* 12-month rolling average of the SGT5-PAC 4000F fleet’s reporting units (status: December 2006)



Application Handbook SGT5-PAC 4000F I Revision 3 I 23.05.2007 I H. Bauer I Section 5 - Figures I Page 1 of 25non-binding values / information

Figure 1a: Ambient Pressure

Figure 1b: Site Elevation

Effect on Power Ouput, Mass Flow

Effect on Ambient Pressure

0,80

0,85

0,90

0,95

1,00

1,05

0,75 0,8 0,85 0,9 0,95 1 1,05

pam b [bar] Am bient Pressure

P* G

T1

m* C

I1 ;

m* T

DO

1

Pow

er O

utpu

t at G

ener

ator

Ter

min

als

Com

pres

sor I

nlet

and

Tur

bine

Out

let M

ass

Flow

1.013 bar = 760 Torr = 1.0332 ata

0,80

0,85

0,90

0,95

1,00

1,05

0 200 400 600 800 1000 1200 1400 1600

a [m ] Altitude

p*am

b A

mbi

ent P

ress

ure




Figure 2: Compressor Inlet Temperature

Effect on Power Output , Efficiency

Power P*7

Efficiency E*7

0.70

0.75

0.80

0.85

0.90

0.95

1.00

1.05

1.10

1.15

-20 -10 0 10 20 30 40 50

Compressor Inlet Temperature [°C]

Cor

rect

ion

fact

ors

for P

ower

P*7

, Effi

cien

cy E

*7

Kurvenverlauf bei Erreichen der Grenzleistung (beispielhaft)Course when mechanical limit is reached (example)

Erreichen der Grenzleistung zu erwartenReaching of mechanical limit

(fuel gas)




Figure 2: Compressor Inlet Temperature

Effect on Exhaust Temperature, Mass Flow

Turbine Mass Flow M*7

Turbine Outlet Temperature T*7

0.75

0.80

0.85

0.90

0.95

1.00

1.05

1.10

1.15

-20 -10 0 10 20 30 40 50Compressor Inlet Temperature [°C]

Cor

rect

ion

fact

ors

for T

urbi

ne M

ass

Flow

M*7

, Tur

bine

Out

let T

empe

ratu

re T

*7

Kurvenverlauf bei Erreichen der Grenzleistung (beispielhaft)Course when mechanical limit is reached (example)

Erreichen der Grenzleistung zu erwartenReaching of mechanical limit

(fuel gas)




0 °C15 °C

28 °C

35 °C

45 °C

0.990

0.992

0.994

0.996

0.998

1.000

1.002

1.004

1.006

1.008

1.010

1.012

0.0 0.2 0.4 0.6 0.8 1.0

Rel. Humidity [x 100 %]

Cor

rect

ion

fact

ors fo

r Effi

cien

cy E

*5

0 °C

0 °C

28 °C

28 °C

35 °C

35 °C

45 °C

45 °C

15 °C

15 °C

0.995

0.996

0.997

0.998

0.999

1.000

1.001

1.002

1.003

0.0 0.2 0.4 0.6 0.8 1.0


Cor

rection factor

s for P

ower P*5

Figure 3: Relative Humidity

Effect on Efficiency

Effect on Power Output(fuel gas)

Compressor Inlet Temperature





0 °C

15 °C

28 °C

35 °C

45 °C

0.970

0.975

0.980

0.985

0.990

0.995

1.000

1.005

1.010

1.015

1.020

1.025

1.030

1.035

1.040

0.0 0.2 0.4 0.6 0.8 1.0


Correction factors for T

urbine

Mas

s Flow

M*5

0 °C

15 °C

28 °C

35 °C

45 °C

0.980

0.985

0.990

0.995

1.000

1.005

1.010

1.015

0.0 0.2 0.4 0.6 0.8 1.0


Cor

rection factor

s fo

r Tur

bine

Out

let T

empe

ratu

re T*5

Figure 3: Relative Humidity

Effect on Exhaust Temperature

Effect on Mass Flow

(fuel gas)






Efficiency E*2

Power P*2



0.970

0.975

0.980

0.985

0.990

0.995

1.000

1.005

1.010

0 2 4 6 8 10 12 14 16 18 20Compressor Inlet Pressure Loss [mbar]

Correction factors

Efficiency E*3

Power P*3



0.965

0.970

0.975

0.980

0.985

0.990

0.995

1.000

1.005

1.010

1.015

1.020

0 10 20 30 40 50 60 70 80

Diffusor exhaust pressure loss [mbar]

Cor

rection factor

s

Figure 4: Inlet and Outlet Pressure Loss

Inlet Pressure LossEffect on Power Output , Efficiency, Exhaust Temperature, Mass Flow

Outlet Pressure LossEffect on Power Output , Efficiency, Exhaust Temperature, Mass Flow

(fuel gas)




2.979

3.300

3.150

3.450

0.990

0.992

0.994

0.996

0.998

1.000

1.002

1.004

1.006

1.008

1.010

1.012

1.014

1.016

1.018

1.020

35.000 37.000 39.000 41.000 43.000 45.000 47.000 49.000

Fuel Gas LHV [MJ/kg]

Cor

rection factor

s for P

ower P*4

2.979

3.150

3.300

3.450

0.997

0.998

0.999

1.000

1.001

1.002

1.003

1.004

1.005

1.006

1.007

35.000 37.000 39.000 41.000 43.000 45.000 47.000 49.000Fuel Gas LHV [MJ/kg]

Cor

rection factor

s for E

fficien

cy E*4

Figure 5: Fuel Gas Lower Heating Value

Effect on Power Output


(fuel gas)




0.998

0.999

1.000

1.001

1.002

1.003

1.004

1.005

1.006

1.007

1.008

1.009

1.010

35.000 37.000 39.000 41.000 43.000 45.000 47.000 49.000Fuel Gas LHV [MJ/kg]

Cor

rection factor

s fo

r Tur

bine

Mas

s Flow

M*4

Figure 5: Fuel Gas Lower Heating Value

Effect on Mass Flow

(fuel gas)




0 °C

15 °C

30 °C

45 °C

0.988

0.990

0.992

0.994

0.996

0.998

1.000

1.002

1.004

1.006

1.008

1.010

0.980 0.985 0.990 0.995 1.000 1.005 1.010 1.015 1.020

Engine Speed [n/n0]

Cor

rection factor

s fo

r Effi

cien

cy E*6

0 °C

30 °C

45 °C

15 °C

0.940

0.952

0.964

0.976

0.988

1.000

1.012

1.024

1.036

1.048

1.060

0.980 0.985 0.990 0.995 1.000 1.005 1.010 1.015 1.020

Engine Speed [n/n0]

Cor

rection factor

s for P

ower P*6

Figure 6: Speed

Effect on Power Output


(fuel gas)






0 °C

15 °C

30 °C

45 °C

0.980

0.984

0.988

0.992

0.996

1.000

1.004

1.008

1.012

1.016

1.020

0.980 0.985 0.990 0.995 1.000 1.005 1.010 1.015 1.020

Engine Speed [n/n0]

Cor

rection factor

s for T

urbine

Outlet T

empe

rature T*6

0 °C

15 °C

30 °C

45 °C

0.940

0.950

0.960

0.970

0.980

0.990

1.000

1.010

1.020

1.030

1.040

1.050

1.060

0.980 0.985 0.990 0.995 1.000 1.005 1.010 1.015 1.020

Engine Speed [n/n0]

Cor

rection factor

s for T

urbine

Mas

s Flow

M*6

Figure 6: Speed

Effect on Exhaust Temperature

Effect on Mass Flow

(fuel gas)






0,96

0,97

0,98

0,99

1,00

0 2000 4000 6000 8000 10000

equivalent operating hours (EOH)

degr

adat

ion

fact

ors

P*

GT1

0, η

* GT1

0

700

η*GT10

P*GT10

First ignition

0,90

0,91

0,92

0,93

0,94

0,95

0,96

0,97

0,98

0,99

1,00

0 25000 50000 75000 100000

Equivalent Operating Hours (EOH)

Deg

rada

tion

Fact

or

P*

GT1

0, η

* GT1

0

700

First Firing

η*GT10

P*GT10

Figure 7: Degradation

Effect on Power Output, Efficiency

Effect of Long-Term Degradation

(fuel gas)




Efficiency

0.00

0.10

0.20

0.30

0.40

0.50

0.60

0.70

0.80

0.90

1.00

1.10

0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0Rel. Power [%]

Cor

rection factor

s for E

fficien

cy

Turbine Mass Flow

Turbine Outlet Temperature

0.50

0.55

0.60

0.65

0.70

0.75

0.80

0.85

0.90

0.95

1.00

1.05

0.0 0.2 0.4 0.6 0.8 1.0Rel. Power [%]

Cor

rection factor

s fo

r Tur

bine

Mas

s Flow

, Tur

bine

Out

let T

empe

ratu

re

Figure 8: Part Load


Effect on Exhaust Temperature, Mass Flow

(fuel gas)




CO emission: CO* ≤ 10 ppm from 60% to base loadUnburned hydrocarbons: UHC* ≤ 4 ppm from 70% to base load* 15 Vol.-% O2, dry

Figure 9: NOx Emissions

Natural Gas Fuel in Premix Mode

- will be provided in future revision of AHB -




0

50

100

150

200

250

300

0 10 20 30 40 50 60 70 80 90 100Power Output / Base Load [%]

NO

x*

[p

pm]

Base load 73 ppm

58 ppm

CO emission: CO* ≤ 10 ppm from 70% to base loadUnburned hydrocarbons: UHC* ≤ 6 ppm from 70% to base loadSoot emission: Bacharach 1-2 from 50% to base load* 15 Vol.-% O2, dry


Light Distillate Fuel Oil in Premix Mode




0

50

100

150

200

250

300

0 10 20 30 40 50 60 70 80 90 100 110Power Output / Base Load without Water Injection [%]

NO

x*

[p

pm]

NOx = 42 ppmWater Injection = 100%

58 ppm

without Water Injection with Water Injection

CO emission: CO* ≤ 10 ppm from 70% to base loadUnburned hydrocarbons: UHC* ≤ 6 ppm from 70% to base loadSoot emission: Bacharach 1-2 from 50% to base load* 15 Vol.-% O2, dry


Light Distillate Fuel Oil in Premix Mode and Water Injection




Figure 10: Typical Start-Up of Gas Turbine to Full Load

Power Output

Speed

Exhaust Temperature

Exhaust Mass Flow




Figure 11: Variable-Pitch Inlet Guide Vane Operation




Figure 12: Steam Production - Capability

SGT5-4000F Power Plant Steam Production Capability

90

95

100

105

110

115

120

125

130

135

140

145

150

5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80

Steam pressure - bar

Stea

m p

rodu

ctio

n - k

g/s

Saturated 204°C 260°C 316°C 371°C427°C 482°C 538°C

Saturated

204 oC

260 oC

316 oC

371 oC

427 oC

482 oC

538 oC




Figure 12: Steam Production - Capability

SG T5-4000F Power Plant Steam Production Capability

700

750

800

850

900

950

1000

1050

1100

1150

1200

50 15 0 25 0 350 450 550 6 50 7 50 8 50 95 0 1050 1150 125 0

Stea m pre ssure - psia

Stea

m p

rodu

ctio

n - k

pph

Sa turate d 400 F 50 0 F 600 F 70 0 F 800 F 1000 F




Figure 12: HRSG Heat Rejection

HRSG Heat Rejection

120

125

130

135

140

145

150

155

160

165

170

175

180

185

190

150 200 250 300 350 400 450 500

Steam Tem perature - °C

Stac

k Ex

haus

t Tem

pera

ture

- °

C

Satura tion Points 3 .5 bar steam 6.9 bar steam 13.8 bar steam 27.6 bar steam41.4 bar steam 55.2 bar steam 82.4 bar steam 68.9 bar steam

3.5 bar

= Saturation Points

6.9 bar

13.8 bar

27.6 bar

41.4 bar

55.2 bar

68.9 bar

82.4bar




Figure 12: HRSG Heat Rejection

H RSG Hea t Reject ion

250

260

270

280

290

300

310

320

330

340

350

360

370

380

390

300 400 50 0 600 700 800 90 0 100 0

S te am Tem pe rature - °F

Stac

k Ex

haus

t Tem

pera

ture

- °

F

S aturat io n P oin ts 1 00 p sia s te am 3 00 p sia s te am40 0 ps ia s tea m 6 00 p sia s te am 5 0 ps ia s tea m80 0 ps ia s tea m 1 000 ps ia steam 1 200 ps ia steam




Fuel Changeover

Operating ModeChangeover

FG Premix FO

Diffusion FO

Premix

~ 28 min FG premix to FO premix ~ 35 min FO premix to FG premix

~ 5 min →

~ 3 min

50 8 13 18 28

100%

0%

~ 50%

~ 75%

~ 2 min ←

Fuel ChangeoverFG

Premix FO

Diffusion

~ 13 min FG premix to FO diffusion

~ 13 min FO diffusion to FG premix

~ 3 min

50 8 13

100%

0%

~ 75%

Premix = Standard operation with low NOxDiffusion = Primarily used for start-up

Calculation is based on: Loading / Unloading: 13 MW/min

Power

Power

Figure 13: Online Fuel-Changeover

Fuel Gas / Fuel Oil Premix to Fuel Oil / Fuel Gas Premix

Fuel Gas Premix to Fuel Oil Diffusion / Fuel Oil Diffusion to Fuel Gas Premix

~ 5 min →~ 15 min ←




Figure 14: Air-Cooled Generator - SGen 1000A

Reactive Capability Curve





Staturation Curves





V-Curves

Industrial Applications

sPower Generation

Siemens Steam Turbines (SSTTM)

SST-800 steam turbine for economical production of heat and power

Chorzow, Poland, one of two 116 MW extraction-condensing steam turbosets for district heating

Turboset with SST-800steam turbine up to 150 MW

Whether you need power generation forindependent power production or forany industrial application, the SST-800offers you the flexibility, reliability andeconomy of operation you demand.

The SST-800 range: proven design for a wide range of applicationsThe SST-800 is a single casing center-admissionsteam turbine with reverse steam flow inside casing,designed for operation at 3,000 or 3,600 rpm forgenerator drive up to 150 MW. For compressordrives variable speed up to 5,000 rpm is possible. It represents a solution based on long experience of industrial steam turbines, covering industrialapplications such as:

• Compressor drive

• Generator drive

• Power plants – pure power production

• Combined cycle plants

• Seawater desalination plants

• Petrochemical industry

• Industrial CHP (Combined Heat and Power), for e.g. chemical industry, pulp and paper mills,steel works, mines

Design featuresThe SST-800 single casing steam turbine can be used for both condensing and back-pressureapplication. It is built up from pre-designed modules combined to a single unit for optimummatching of the required parameters.

The SST-800 turbine can be equipped with impulsecontrol stage and reaction blading fixed in bladecarriers. Each front section, which includes themain steam admission, is available in a number of geometrically scaled sizes to match different

volumetric flow rates. Steam is led into the turbineby one or two emergency stop valves, which,together with the control valve chest, form an integral part of the turbine casing. It is directly connected with the inner casing in the middle part of the turbine body.

The intermediate section of the turbine is highly customized. It can be equipped with one or twointernally controlled extractions and steam bleeds as required.

The exhaust section is standardized into differentsizes for back pressure and condensing applications.It is prepared for axial or downward connection forcondensing, while for back pressure an upward ordownward connection is provided.

The casing is supported by a front bearing pedestalbalancing axial movements and a fixed rear bear-ing pedestal. Bearing pedestals are fixed on thesimple base frame directly anchored to a concretefoundation.

Turbine auxiliary systems are also pre-designed into modules covering the complete range of turbine sizes.

Operational flexibility The turbine concept together with its modular configuration ensures high stress absorption during turbine operation whilst maintaining highflexibility in design.

The combination of the inner and outer casing subs-tantially reduces weight, dimensions and axial forces.Together with the bearing pedestal arrangement italso improves the thermal stability of the turbine (andreduces stresses during operation).

Optimum performanceThe SST-800 offers an extensive range of inlet steam parameters. Variable inlet control valve configuration and high flexibility for arrangement of controlled extractions and bleeds guarantee anoptimum performance for almost all requirements in regard to plant configuration and operational conditions.

Blades configured into groups mounted into sepa-rate blade carriers support high optimization of thecomplete steam path, which, together with theadvanced design of the blades themselves, formsthe basis for achieving the highest efficiency.

Modular arrangement The turbine consists of three main modules: inlet, intermediate and exhaust section, which are available in various sizes and configurations.

The complex inlet section consists of emergency stopvalve, control valve chest, internal casing with blad-ing and external casing. Blading in the internal casingis aligned for the steam to flow in the opposite direct-ion to the intermediate section. The intermediatesection can be designed for straight flow, orequipped with bleeds and/or extractions, dependingon the application requirements. A wide range ofexhaust sizes and types is available, as described inthe following section.

Layout conceptsThe versatile design of the turbine and its auxiliariesprovides for a wide range of layout concepts andsolutions, where the most typical are standardized.For ground-level installations the turbine isequipped with axial or upward exhaust, yieldingsubstantial savings in foundation and building cost.For the axial exhaust alternative, the embeddedbearing is supported by the exhaust casing itself.Where space is restrictive, an arrangement withdownward exhaust and underslung condenser canbe selected.

These typical arrangements cover the majority ofsteam turbine installations, but the turboset canmeet any project-specific requirements thanks to the versatility of its individual parts and their highconfiguration adaptability.

Easy installation and maintenance The modular design simplifies the installation andmaintenance of the turbine. A high level of pre-assembled and pre-tested components (turbine package, generator, oil unit etc.) minimizes the man-power and time for installation and commissioning at site. The horizontally split outer casing permits easyaccess. Stop valves and steam strainers are accommo-dated in the steam chest and can be removed withoutdismantling the piping.

Flexible design for individual customer needs

VW Wolfsburg, Germany,one of two 68 MW steamturbosets for the automotive industry

3-D section of extraction-condensing steam turbine,center admission with axialexhaust

Modular layout and compact design

SST-800 technical data

Power output ................. up to ............150 MW

Speed

generator drive .................................. 3,000 / 3,600 rpm

compressor drive .......... up to ............ 5,000 rpm

Live steam conditions

pressure ....................... up to ............140 bar / 2,031 psi

temperature ................. up to ............ 540°C / 1,004°F

Bleed .............................. up to 6 ......... at various pressure levels

Controlled extraction (single or double)

pressure ....................... up to ............45 bar / 653 psi

Exhaust steam conditions

pressure ....................... up to ............14 bar / 203 psi

All data are approximate and project-related.

Legend

1 Steam turbine

2 Generator

3 Condensate and vacuum pump package

4 Oil unit

5 Base frame

6 Condenser

Typical dimensions

L Length ............20 m / 66 ft

W Width ............. 7 m / 23 ft

H Height ............ 5.8 m / 19 ft

Features and benefits

Design features

• Single casing

• Modular

• Flexible

• Reverse steam flow

• Customized steam path

• Axial or radial exhaust

• Proven

Customer benefits

• Variable layout

• Wide application range

• High reliability / availability

• High efficiency

• Remote control

• High quality standard

Typical layout for turboset with a SST-800 condensing steam turbine

1

3

2

H

W

6

L

4 5

Published by and copyright © 2006:Siemens AGPower GenerationFreyeslebenstrasse 191058 Erlangen, Germanye-mail: [email protected]/powergeneration

Siemens AGPower GenerationOil & Gas and Industrial ApplicationsWolfgang-Reuter-Platz47053 Duisburg, Germany

Siemens Industrial Turbomachinery, Inc.10730 Telge RoadHouston, Texas 77095, USA

Order No. A96001-S90-A561-X-4A00Printed in Germany1387 177480M DA 10062

Subject to change without prior notice.Printed on paper treated with chlorine-free bleach.

Trademarks mentioned in this document are the property of Siemens AG, its affiliates, or their respective owners.

The information in this document contains generaldescriptions of the technical options available,which may not apply in all cases. The required technical options should therefore be specified in the contract.

SST-100

Type Output (MW)Steamparameters

SST-200

SST-300

SST-400

SST-500

SST-600

SST-700

SST-800

SST-900

65 bar, 480°C

Double flow

Dual casing/reheat

Center admission

Single casing/non-reheat Dual casing/reheat

80 bar, 480°C

120 bar, 520°C

120 bar, 520°C

30 bar, 350°C

140 bar, 540°C

165 bar, 565°C

140 bar, 540°C

165 bar, 585°C

10 30 50 70 130 150 +

Reference examples

SST-800 has been sold for a rich variety of applications around the world. The following references are typical examples of this versa-tility of application.

Quality and experience in one product family

Wisaforest, Finland, 143 MW single-casing back-pressure steam turbine, the largest single casingturbine generator set ever installed in a pulp andpaper mill

Jiang Lin, China, one of two extraction-condensingsteam turbosets for the pulp and paper industry duringblow-off of inlet steam piping

SST-800 steam turbines are part of a modern range of Siemens steam turbines developed tomeet the most demanding customer requirements for cost-efficient power generation and mechani-cal drive applications in power plants and industri-al environments. This is achieved by using a highly modularized system of state-of-the-art components, with wellproven design features. Its development is based onexperience accumulated during a century of steamturbine design, manufacturing and operation.

The SST range of turbines cover the complete spectrum from 2 to 180 MW and are available in back pressure, condensing and extraction design.The table above shows the Siemens full range ofindustrial steam turbines and their most importantparameters.Whether you need a generator drive for power generation or a mechanical drive for compressors,blowers and pumps, just tell us your needs andtogether we can select the optimum turbine or turboset which is most suited to respond to them.

BUILDING LEGEND

UBA91/92 POWER CONTROL CENTER STATION SERVICES

UBA21/22 POWER CONTROL CENTER STEAM TURBINE

UBA01/02 POWER CONTROL CENTER GAS TURBINE

UBA03 POWER CONTROL CENTER 6.6KV STATION SERVICE

UMC COMBINED GAS AND STEAM TURBINE BUILDING

UBE STRUCTURE FOR AUXILIARY STATION TRANSFORMER

UBF STRUCTURE FOR UNIT TRANSFORMER

UEN FUEL GAS FILTERING/OPERATIONAL METERING STATION

UHA STRUCTURE FOR HEAT RECOVERY STEAM GENERATOR

UHN STRUCTURE FOR BY PASS STACK

ULA STRUCTURE FOR FEEDWATER PUMP HOUSE

URC STRUCTURE FOR GENERATOR FIN FAN COOLER GAS

TURBINE

URD STRUCTURE FOR MAIN COOLING WATER CIRCULATION

PUMPS

UMY STRUCTURE FOR HP/IP/LP PIPE DISTRIBUTION

DESCRIPTION:

The shown layout is based on a common building (UMC) for gas turbine and steam turbine. The

gas turbine is arranged in 90° opposite to the steam turbine generator set. Due to this

arrangement the main machine house crane can serve both turbine generator sets, which limits

the investment. The design is further based on Siemens power control centers which contain

the related electrical, instrumentation and control equipment (UBA). The most economical

solution for the main transformer is a three winding main transformer, this limit the costs for the

investment. Alternatively for each generator a main transformer can be used.

The plant layout is considered as conceptual and for consideration of the minimum required

space requirements.

PKZ/PC UA/Type of Doc.: Inhaltskennzeichen / Contents Code Zhl. Nr.:/ Reg.: No

Pakistan U UC 001 Index: Dienstst. /Dept. UNID

Rev: 1 Datum /Date

E F PR GT Plant Concept 2009/04/23

Port Qasim Power Station CONCEPTUAL PLANT LAYOUT FOR SGT5-4000F & SST-800

CONFIGURATION 2 X (1+1) TOTAL EXPECTED POWER OUTPUT 800MW

SGT5-4000F

SIEMENS Power Generation

10

21

AC D E

16

13

10

N A

75

50 19 21

200

10

21

AC D E

16

13

10

N A

25

75

175

URA

URD

UHA

ULA

UHN

UM

C

UBA01/02/03

UBA21/21/91/92

UBF

UBE

UR

C

UEN

UMY

SIPEP (Siemens Plant Performance Estimation Program) Version 3.2.3 All performance data refer to LHV. The data are for information purposes only and any warranty and/or liability is excluded. Data to be guaranteed must be submitted in a formal proposal. This sheet contains information proprietary to Siemens. It is submitted in confidence and is to be used solely for the purpose for which it is furnished i.e. evaluation of Siemens products within recipients conduct of business and returned upon request. This information is not to be reproduced, transmitted, disclosed, or used otherwise, in whole or in part, without the written authorization of Siemens. Port Qasim Karatchi SS for Eduard Sinz, Siemens Energy SCC5-4000F Single Shaft (combined cycle turnkey plant, triple pressure with reheat)

PERFORMANCE DATA Design1

Net power MW 379.2Net efficiency % 57.2Net heat rate kJ/kWh 6290 Gross power MW 387.1Gross efficiency % 58.4Gross heat rate kJ/kWh 6162

NOx emissions ppmvd@15%O2kg/h

25.0103

CO emissions ppmvd@15%O2kg/h

10.025

GT EXHAUST GAS Stack exhaust gas mass flow kg/s 627Stack exhaust gas temperature °C 95Gas constant kJ/(kg K) 0.30Composition mass-% / vol-% m-% v-%N2 72.4 72.7O2 13.8 12.1CO2 5.8 3.7H2O 6.8 10.6Ar 1.2 0.9SO2 -0.0 0.0

AMBIENT CONDITIONS Air temperature °C 30Air humidity % 80Air pressure mbar 1007.26

OPERATING DATA Fuel type Std. gas2

Fuel LHV kJ/kg 50012Fuel mass flow kg/s 13.25Water/Steam injection noST back pressure mbar 92.9Power factor - 0.85GT inlet pressure drop (ISO) mbar 7.0

BLOCK CONFIGURATION AND DESIGN PARAMETERS Frequency: 50 Hz Elevation above M.S.L.: 50 m Gas turbine: SGT5-4000F Generator: SGen5-2000H Burner type: DLN Fuel preheating: yes (if gas) GT air inlet system: Standard HRSG system: Standard Steam turbine: SST5-3000 BACK COOLING SYSTEM: Wet type cooling tower (forced circulation) Cold water temperature: 30 °C Cooling range: 11 K Make-up water: 118 kg/s

Cooling water pump 1231 kW Fan Power: 818 kW

Seite 1 von 2Your SIPEP calculation 2009-04-22 17:44:27

23.04.2009file://C:\Documents and Settings\sinz000e\Local Settings\Temporary Internet Files\O...

power:

1 Warning: Suboptimal ST configuration (low LP exhaust velocity). Please contact your sales representative for an optimized solution or mail to administration team.

2 CH4=100%

Your sales representative is SIPEP Admin. SIEMENSJobID: 30635 Erlangen, 2009-04-22

Seite 2 von 2Your SIPEP calculation 2009-04-22 17:44:27

23.04.2009file://C:\Documents and Settings\sinz000e\Local Settings\Temporary Internet Files\O...

SIEMENS AG E F ES EN 11 / stief00g CCGT Qasim, Karatchi SCC5-4000F 1x1 Calculated Heat Flow Diagrams

LOADPOINT

DESCRIPTION

TAMB

°C

REL.

HUMIDITY

%

CWT

°C

LOAD

%

FUEL

POWER OUTPUT

MW GROSS

GROSS

EFFICIENCY

%

HEAT FLOW DIAGRAM

NUMBER

INDEX REV

DATE

YYYY-MM-DD

STATUS

WORKER‘S

INITIALS

Power Plant

30T-80RH-100CC-Gas 30.0 80.0 30.3 1xGas PA10xx-E F ES EN 11-A01 003

L 2009-Apr-23 Working Sheet GS

30T-80RH-60CC-Gas 30.0 80.0 29.7 1xGas PA10xx-E F ES EN 11-A01 004

L 2009-Apr-23 Working Sheet GS

page 1 / 1

CCGT Qasim, KaratchiSCC5-4000F 1x1

30T-80RH-100% CC LOAD

Heat Flow DiagramNo.PA10xx -E F ES EN 11- A01 003 LErlangen, 2009-Apr-23 GS

SIEMENS AGE F ES EN 11Working Sheet

pressure..bar

mass flow..kg/satmospheric humidity..%

enthalpy..kJ/kgtemperature..°C

bar kJ/kgkg/s °C (X)

JOB IDENTIFICATION : C:/Data/Common/0-proj/PA10xx_Qasim_SCC5-4000F-1x1_Apr2009/Thermodynamik/Calculations/A01/A01_Qasim_SCC5-4000F_1x1_2Dr_KM2111.gek; Lp.010; stief00g; 2009-Apr-23 15:20:56; V2.11.1

all pressures are absolute

This document contains information that is proprietary to Siemens AG Power Generation and may not be reproduced or disclosed to any third party or other entity, in whole or in part,

without the express prior written permission of Siemens AG Power Generation.

Water/Steam Property Functions: IAPWS-IF97

F

F

C

C

E

E

D

DG

G

B

B

K H

H K

H

H K

0.000 kg/s

77.85 3528.792.907 552.0

21.67 674.212.522 159.5

6.22 2857.912.389 203.8

96.6 °C Composition Weight-%CO2: carbon dioxide 5.6739

N2: nitrogen 72.4238H2O: water 6.6853O2: oxygen 14.0054

Ar: argon 1.2117

55.0 °C124.385 kg/s

626.366 kg/s588.5 °C

Composition Volume-%CO2: carbon dioxide 3.6282


Ar: argon 0.8536

1.007 PHI = 80.0 %30.0

6.17 bar

6.17 bar

50.00 Hz

25.42 185.8105.429 43.8

21.67 674.2124.385 159.5

0.133 kg/s

0.000 kg/s0.000 kg/s

0.000 kg/s7.54 2766.00.000 168.0

0.0892 2800.00.000 158.8

0.0892 2800.00.000 158.8

21.67 676.60.000 160.1

25.42 185.8105.429 43.8

98.05 685.592.907 161.1

0.000 kg/s

159.5 °C

7.00 2857.912.522 205.7

30.3 °C

Gas LHV = 50012.0 kJ/kg15.0

Composition Mol-%CH4: methane 100.0000

84.1 °C10.912 kg/s

159.9 °C8.045 kg/s

0.0892 2337.8105.379 0.899 x

50.00 Hz

73.96 3528.792.907 550.4

Plant Output (net) = 353.4 MW

Plant Efficiency (net) = 54.85 %

LP-BP

HP-BP

CCGT Qasim, KaratchiSCC5-4000F 1x1

30T-80RH-60% CC LOAD

Heat Flow DiagramNo.PA10xx -E F ES EN 11- A01 004 LErlangen, 2009-Apr-23 GS

SIEMENS AGE F ES EN 11Working Sheet

pressure..bar

mass flow..kg/satmospheric humidity..%

enthalpy..kJ/kgtemperature..°C

bar kJ/kgkg/s °C (X)

JOB IDENTIFICATION : C:/Data/Common/0-proj/PA10xx_Qasim_SCC5-4000F-1x1_Apr2009/Thermodynamik/Calculations/A01/A01_Qasim_SCC5-4000F_1x1_2Dr_KM2111.gek; Lp.011; stief00g; 2009-Apr-23 15:23:51; V2.11.1

all pressures are absolute

This document contains information that is proprietary to Siemens AG Power Generation and may not be reproduced or disclosed to any third party or other entity, in whole or in part,

without the express prior written permission of Siemens AG Power Generation.

Water/Steam Property Functions: IAPWS-IF97

F

F

C

C

E

E

D

DG

G

B

B

K H

H K

H

H K

0.000 kg/s

56.53 3570.666.579 561.1

25.71 661.17.430 156.4

6.74 2841.87.296 197.8

91.0 °C Composition Weight-%CO2: carbon dioxide 5.1376


Ar: argon 1.2141

55.0 °C90.419 kg/s

445.758 kg/s588.5 °C

Composition Volume-%CO2: carbon dioxide 3.2902


Ar: argon 0.8566

1.007 PHI = 80.0 %30.0

5.71 bar

5.71 bar

50.00 Hz

27.63 168.274.010 39.6

25.71 661.190.419 156.4

0.135 kg/s

0.000 kg/s0.000 kg/s

0.000 kg/s7.20 2764.00.000 166.1

0.0709 2800.00.000 158.7

0.0709 2800.00.000 158.7

25.71 664.20.000 157.1

27.63 168.274.010 39.6

74.83 668.466.579 157.4

0.645 kg/s

156.4 °C

7.00 2841.87.430 198.4

29.7 °C

Gas LHV = 50012.0 kJ/kg15.0

Composition Mol-%CH4: methane 100.0000

79.8 °C7.064 kg/s

156.7 °C9.346 kg/s

0.0709 2358.973.959 0.911 x

50.00 Hz

53.71 3570.666.579 560.0

Plant Output (net) = 211.9 MW

Plant Efficiency (net) = 49.78 %

LP-BP

HP-BP




6 Scope of Supply Summary

6.1 Gas Turbine

6.2 Auxiliary Systems 6.2.1 Gaseous Fuel 6.2.2 Liquid Fuel 6.2.3 Hydraulic Oil System 6.2.4 Instrument Air System 6.2.5 Lube Oil System 6.2.6 Rotor Turning Device 6.2.7 Compressor Cleaning System 6.2.8 Compressor Dehumidifier

6.3 Air Intake System

6.4 Exhaust Gas System

6.5 Instrumentation & Control System

6.6 Electrical Systems 6.6.1 Switchgear, Battery System, Protection & Synchronization, PCC 6.6.2 Static Excitation Equipment and Transformer 6.6.3 Starting Frequency Converter and Transformer

6.7 Enclosures

6.8 Electrical Generator 6.8.1 Air-Cooled Generator

6.9 Generator Systems 6.9.1 Generator Cooler

6.10 Options Overview 6.10.1 Major Options 6.10.2 Further Options




6 Scope of Supply Summary

6.1 Gas Turbine

Quantity 50 Hz F-Class SGT5-4000F Gas Turbine, comprising Compressor 1 Combustion system 1 Turbine 1 Bearings 2 Turning gear 1 Hydraulic clearance optimization Insulation 1 set Further equipment Mechanical control and protection system 1 Gas turbine instrumentation and actuation 1 Standard tools 1 set Tools for initial assembly and inspection (option) 1 set Major inspection tools (option) 1 set Additional Tools for inspection (option) 1 set

6.2 Auxiliary Systems

Quantity

6.2.1 Gaseous Fuel

Fuel gas system 1 Fuel gas flow measurement 1 Drainage system 1

6.2.2 Liquid Fuel (option)

Fuel oil system 1 Ignition fuel system 1 Purging water system 1 Sealing air system 1 NOx Water injection system (option) 1




6.2.3 Hydraulic Oil System

System for supply of hydraulic oil for hydraulic valve actuation 1

6.2.4 Instrument Air System

System for supply of compressed air for pneumatic valve actuation 1

6.2.5 Lube Oil System

System for supply of lubrication and lifting oil 1 Lube oil cooler per gas turbine 1 x 100% plate type oil-to-water heat exchangers 1 2 x 100% plate type oil-to-water heat exchangers (option) 1 set 1 x 100% shell and tube type oil-to-water heat exchangers (option) 1 set 2 x 100% shell and tube type oil-to-water heat exchangers (option) 1 set 3 x 50 % Fin-fan type oil-to-air coolers (option) 1 set

6.2.6 Rotor Turning Device

Hydraulic Turning Gear for slow turning of rotor 1

6.2.7 Hydraulic Clearance Optimization Power Unit

System for oil supply for shifting the rotor into optimized position 1

6.2.8 Compressor Cleaning System

Base System Mobile skid for cleaning water supply including hose connection to cleaning water nozzle system

1 set

Advanced Compressor Cleaning System (option) Skid for cleaning water supply including hose connection to cleaning water nozzle system

1 set




6.2.9 Compressor Dehumidifier

Dryer for compressor air during gas turbine standstill 1




6.3 Air Intake System

Quantity Filter House Filter system with pre- and high efficiency filter (multi-stage static filter) 1 Bird screen (option) 1 Weather louver (option) 1 Coalescer (option) 1 Filter system, with pulse filter system (option) 1 Inlet air filter house including weather hood, internal support structure, instrumentation, lighting, power sockets, manhole, access ladders, platforms and doors

1

Anti-icing system (option) 1 Evaporative cooling system (option) 1 Inlet Duct Interconnecting duct work with expansion joint, damper and silencer 1 Cleaning water manifold with nozzle system within the air intake duct opposite to the compressor inlet

1




6.4 Exhaust Gas System

Quantity Diffuser Diffuser with gas turbine expansion joint (between gas turbine and diffuser) 1 Gas Turbine Exhaust Stack (option for simple-cycle) Stack complete with silencer, support frame, expansion joints 1 Aircraft warning lights (option for stack) 1 Diverter Damper and Bypass Stack (option for combined-cycle) Diverter damper complete with shaft, blade, actuators, hydraulic unit, seal-air system

1

Blanking plate (option for diverter damper) 1 Blind plate (option for diverter damper) 1 Stack complete with silencer, support frame, expansion joints 1 Aircraft warning lights (option for stack) 1




6.5 Instrumentation & Control System

Quantity Turbine Functions Turbine Controller Redundant automation processor for closed-loop control functions 1 set I/O modules as per I/O Turbine Failsafe Protection and Trip System Failsafe system for protection and trip functions 1 set Turbine Function Group Automatic and Operational Protection System Redundant automation processor for open-loop, sequence control functions and operational protection functions

1 set

I/O modules as per I/O Operation / Monitoring / Engineering Operator Terminal with 19” LCD monitor, keyboard and mouse (preferable to be located in customer control room)

1 piece

Fault tolerant Application Server for operating, monitoring and engineering functions

1 piece

Printer (A4, Color Laser) (preferable to be located in customer control room) 1 piece Bus System Plant Bus with all necessary network components 1 lot I&C Cables I&C field cables from junction boxes or sensors to I/O modules (option), according to Siemens standard cable types and Siemens standard building and cable tray arrangement

1 lot

Turbine related special I&C cables 1 lot Furniture Operator desk inside of the PCC for installation of the computer equipment and peripherals (not applicable, if Operator Terminal will be located in customer control room)

1

I&C Software I&C software (system and application programs) 1 set Signal Interfaces with Plant Distributed Control system




Signal Interface (hardwired) with Plant DCS Terminal points for exchange of 30 binary signals at most 1 TP per signalTerminal points for exchange of 20 analog signals at most 1 TP per signalTerminal point for exchange of bus clock synchronization signal 1 TP per bus

clock Signal Interface (serial link) with Plant DCS (option) CM communication module 1 piece MODBUS terminal point (Sub-D, RS232 / RS485 / RS422) for exchange of 50 analog and 100 binary signals at most

1 TP

Signal Interface with Plant DCS (option) OPC Server (non-redundant) 1 piece Ethernet terminal point (RJ45 or Sub-D) for exchange of 500 signals at most 1 TP Turbine Diagnostic System Win_TS (Option) Win_TS Analysis System hardware + peripherals 1 set Software for system basic functions Software for Gas Turbine Special Condition Monitoring Software for Gas Turbine Vibration Analysis (option) Software for Gas Turbine Thermodynamic Calculations (option)

Continuous Emissions Monitoring System (CEMS) (Option) Emissions Measurement Cabinet with NOx, CO and O2 multi-component analyzer

1 set

Emissions Evaluation Computer 1 piece




6.6 Electrical Systems

Quantity

6.6.1 Switchgear, Battery System, Protection & Synchronization, PCC

Switchgear and Battery System Low voltage switchgear (AC-Motor Control Centers) 2 DC voltage distribution 2 Battery 1 Battery charger 2 DC/DC-converters 2 Inverter for Siemens supplied turbine DCS in PCC (option) Protection and Synchronization Generator protection cabinet 1 set Main and unit auxiliary transformer protection (option) 1 set Synchronization / Synchro-check equipment 1 set Cabling Cables and cable racks from Siemens supplied equipment to Siemens supplied equipment (option)

1 set

Power Control Centers Containers for electrical and I&C equipment 2

6.6.2 Static Excitation Equipment (SEE) and Transformer 1

Static Excitation Equipment 1 Fully controlled converter bridge type B6C Redundant bridges n+1 (option) Equipment for rapid deexcitation Line side overvoltage protection DC side overvoltage protection 1 manual and 1 automatic controller 2 manual and 2 automatic controller (option) Power System Stabilizer (option) Power factor regulator (option) VAR regulator Rotor temperature signal (calculated, based on ohmic rotor resistance) (option)




SEE transformer with metal enclosure (IP23) 1

6.6.3 Starting Frequency Converter (SFC) and Transformer 1

Starting Frequency Converter 1 Line side and machine side B6C converter bridge DC link between line side and machine side converter Overvoltage protection on line side and machine side Speed control Compressor washing function Boiler purge function (10 minutes) (option) Change over device to allow starting of 2 or 3 GT via two SFC (option) SFC transformer with metal enclosure (IP23) 1




6.7 Enclosures

Quantity Enclosure for Gas Turbine Structural Steel with corrosion protection 1 set Noise abatement panels galvanized (for indoor enclosure) Weather protection and noise abatement panels galvanized (for outdoor enclosure)

1 set

Internal service platforms and ladders galvanized 1 set Doors with safety windows 1 set Internal lighting including emergency escape lighting 1 set Ventilation System for Gas Turbine Enclosure Air intake openings with protective grills, dampers and silencers 1 set Exhaust air openings 1 set Exhaust air handling units, equipped with back draft dampers and silencers behind the fans

1 set

Enclosures for Auxiliary Systems (option) Weatherproof enclosure for outdoor configuration Auxiliaries module for fuel gas (base: fuel gas section ventilation combined with the gas turbine enclosure ventilation system)

1

Auxiliaries module for fuel oil (only if liquid fuel system is installed) 1 CO2-Fire Fighting System for gas turbine enclosure, power control containers and skid enclosures including

Battery of high pressure bottles for CO2 and direction valve station 1 set Piping system from bottle rack to spray nozzles inside the enclosures including supports

1 set

Fire detection and control system with local panel 1 Gas Detection System for gas turbine enclosure and fuel gas system 1 set




6.8 Electrical Generator

6.8.1 Air-Cooled Generator (Static Excitation)

Quantity SGen5-1000A Generator, comprising Bedplate 1 Spring mounted, GVPI, radially cooled stator core 1 Conventionally cooled stator winding with class F insulation 1 Rotor shaft forging including two shaft mounted ventilation fans 1 Radially cooled rotor winding with class F insulation 1 Inner enclosure covering and completing the ventilation circuit 1 High voltage leads at the top and exciter side of the generator 6 Bearings supported in pedestals that are mounted on the bedplate 2 Overhung collector with collector ring assembly and brush holder modules

1

Resistance Temperature Detectors (Platinum, 100 ohms at 0 oC): Duplex Slot RTDs embedded in the armature windings 6 Duplex RTDs in the generator warm air cooler inlet 2 Triplex RTDs in the generator cold air cooler outlet 2 Duplex RTD in the excitation cold air inlet 1 Duplex RTD in the excitation warm air oulet 1 Thermocouples (Type K - chromel alumel): Duplex TC embedded in each bearing metal 1 Rotor grounding brushes 1 set Space heater 1 Further equipment Current transformers, C-400 relaying and 0.3B-1.8 metering accuracy, including:

3 for each of the three phase line leads 9 4 for each of the three neutral leads 12 Grounding equipment including grounding transformer, neutral tie, neutral cable and, grounding resistance.

1 set

All instruments wired to plugs or junction boxes




Weather and sound proof Generator Outer Enclosure including coolers and one liquid detector for a TEWAC unit

1 2

Rotor removal and installation tools (per site per style) 1 set Fixators and grout for fixators 1 set Foundation bolts, nuts and washers 1 set Axial and Transvers Anchors 1 set Generator instruction and installation books (per site per style) 1 set




6.9 Generator Systems

Quantity

6.9.1 Generator forced cooling water system (option)

4 x 33 % Water-to-Air coolers (fin-fan type) 2 x 100% cooling water pumps Cooling water expansion tank Instrumentation and control devices

1 set 1 set

1 1 set




6.10 Options Overview

6.10.1 Major Options Option Type

Gas Turbine • -

Auxiliary Systems • Dual Fuel, Indoor (1x100% fuel oil injection pump) add-on • Water Injection Indoor (1x100% water injection pump) add-on • Advanced Compressor Cleaning System (ACCS) replacement • 3 x 50 % Fin-fan type oil-to-air coolers replacement

Air Intake System • Pulse Filter for Air Intake without compressor replacement • Anti-Icing system add-on • Evaporative Cooler for intake air add-on

Exhaust Gas System • Exhaust stack add-on • Bypass Stack with Diverter Damper add-on

Instrumentation & Control • WIN_TS + Vibration Analysis+ GT Thermodynamic add-on

Electrical Systems • -

Enclosures • -

Generator • -

Generator Systems • 4 x 33 % Fin-fan type water-to-air coolers, 2 x 100% cooling water

pumps add on

Erection, Commissioning, Technical Services • Technical Field Assistance and Performance of Commissioning

(beyond air intake/exhaust TFA that is already in the base scope) add-on




6.10.2 Further Options

Gas Turbine • Fuel gas preheating up to 130°C add-on • 15ppm NOx Fuel Gas only (premix pilot burner without diffusion) replacement

Auxiliary Systems • GT Lube Oil Plate Type Cooler 2x100% replacement • Anti-Freeze agent supply for ACCS add-on • Compressed Air supply for ACCS add-on

Air Intake System • Bird Screen for filter house add-on • Weather Louver for filter house add-on • Coalescer for filter house add-on • Air Compressor system for Air Intake Pulse Filter add-on

Exhaust Gas System •

Instrumentation & Control • Continuous Emissions Monitoring System add-on • Control cables add-on • Additional Operator Terminal add-on

Electrical Systems • Only one Starting Frequency Converter (SFC) for two turbine-

generators take-out

• SFC provided with change over function and provided for connection of starting bus, in case of two turbine-generators add-on

• SFC designed for Boiler purge function (10 minutes) add-on • SFC disconnect cubicle BAB35-38 with voltage transformers, provided

for connection of Isolated Phase Bus Buct (by others) add-on

• SEE provided with Power System Stabilizer add-on • SEE provided with redundant AVR add-on • SEE provided with redundant power bridges n+1 add-on • Inverter 3 kVA for Siemens supplied turbine DCS in PCC add-on • Main and unit auxiliary transformer protection add-on • Electrical Power cable, including cable racks add-on

Enclosures • Skids enclosure, dual fuel, indoor add-on • Skids enclosure, gas only, indoor add-on




Generator • Hydrogen-Cooled Generator, including H2 and seal oil supply

auxiliaries replacement

Generator Systems •

Erection, Commissioning, Technical Services • Erection & commissioning for Air Intake + Exhaust Systems add-on • Erection & Commissioning of Bypass Stack and Diverter Damper add-on



non-binding values / information Application Handbook SGT5-PAC 4000F I Revision 3 I 23.05.2007 I H. Bauer I Appendix A1 I Page 1 of 20

Appendix A1 Requirements on Working Media A1.1: Fuels and Intake Air - Typical Limits for Chemical Contaminants

A1.2.1: Gaseous Fuel - Typical Properties and Conditions of Fuel Gas at Terminal Point A1.2.2: Gaseous Fuel - Typical Properties of Standard Natural Gas A1.2.3: Gaseous Fuel - Checklist for Fuel Gases

A1.3.1 Liquid Fuel - Typical Properties for Fuel Oils per ISO 4261; DIN 51603; ASTM D 396, 975, 2880

A1.3.2: Liquid Fuel - Typical Properties for Standard Liquid Fuels (EL Distillate Fuel Oil, Gas Oil, No. 2 GT Distillate Fuel Oil)

A1.3.3: Liquid Fuel - Typical Properties for Liquid Fuels (Jet A-1, Kerosine, No.1 GT Distillate Fuel Oil)

A1.3.4: Liquid Fuel - Checklist for Liquid Fuels

A1.4.1: Water for NOx Water Injection, Purging, Compressor Cleaning - Requirements A1.4.2: Water for Inlet Air Cooling - Requirements A1.4.3: Cooling Water for Lube Oil and Generator - Requirements

A1.5.1: Lube Oil - Physical and Chemical Properties in the As-supplied Condition

A1.5.2: Hydraulic Oil - Physical and Chemical Properties in the As-supplied Condition




Appendix A1.1: Fuels and Intake Air - Typical Limits for Chemical Contaminants

If the levels of fuel impurities are no higher than the following limits, the gas turbine can be operated without restriction of the permissible output or shortening of the specified maintenance intervals.

As a matter of principle, the total ingress of all impurities with the process media air, fuel, and water is the determining factor for damage to the gas turbine and its individual component parts! The total mass flow rate of a given impurity may therefore be the sum of up to three individual mass flows.

Limits for Chemical Contaminants (Fuel weighting factor f = 1) Fuel downstream of filter Substance Test

Unit Compressor

intake air downstream of filter(empirical values)

Natural gas EL distillate fuel

Dust (with natural gas), Sediments (with EL distillate fuel)

Total d < 2 µm 2 < d < 10 µm d > 10 µm d > 25 µm

ASTM D 3605 ppm(wt) ≤ 0.08 ≤ 0.06 ≤ 0.02 ≤ 0.0002 0

≤ 20 ≤ 18.5 ≤ 1.5 ≤ 0.002 0

≤ 20 ≤ 18.0 ≤ 2.0 0

Vanadium (V) DIN 51790 ASTM D 3605

ppm(wt) ≤ 0.001 ≤ 0.5

Lead (Pb) DIN 51790 ASTM D 3605

ppm(wt) ≤ 0.002 ≤ 1.0

Total of Sodium (Na) + potassium (K)

DIN 51790 ASTM D 3605

ppm(wt) ≤ 0.001 ≤ 0.3 ≤ 0.1 (coastal and industrial sites)

Calcium (Ca) ASTM D 3605 ppm(wt) ≤ 0.02 ≤ 10 Ash DIN 51790

ASTM D 482 ppm(wt) ≤100

Nitrogen (N) (FBN = fuel bound nitrogen)

ASTM D 4629 ppm(wt) Limits prescribed by locally applicable emissions guidelines

Sulphur (S) ASTM D 129 ppm(wt) see max. permissible dust content

Limits prescribed by locally applicable emissions guide lines (100% con- version of S to SOx)

Hydrogen sulphide (H2S) ASTM D 1945 ppm(v) ≤ 10 Mercaptans ASTM D 3227 ppm(wt) ≤10 Acetylene (C2H2) ASTM D 1945 Vol. % ≤0.1 Hydrogen (H2) ASTM D 1945 Vol. % ≤1 Ethane (C2H6) ASTM D 2887 Vol. % ≤15 Higher molecular-weight hydrocarbons CnHm (n ≥ 2) except C2H6

ASTM D 2887 Vol. % ≤10

Limits for fuel impurities are based on a lower heating value (LHV) of 42,000 kJ/kg. The formula "pollutant content at an LHV of 42 MJ/kg x current LHV divided by 42 MG/kg" must be used to correct for deviations in lower heating value. Please refer to explanations on the following page.




Explanations

1) Particulate impurities in compressor intake air and in fuel:

If the stipulated values are exceeded, the permissible limits for fuel impurities shall be lowered by that amount contained in the intake air to ensure that the total mass flow of any given contaminant (intake air + fuel) does not exceed the prescribed limit. The total mass flow rate of a given impurity may therefore be the sum of up to three individual mass flows (air, fuel, H2O).

2) Vanadium: No violations of this limit whatsoever are permissible.

3) Lead: No further violations of the prescribed limit are permissible.

4) Sodium and potassium: The standard limit of 0.3ppm(wt) shall apply to the sum of sodium and potassium.

At coastal and industrial sites, this limit shall be reduced to 0.1ppm(wt), provided that no air analysis has been performed.

5) Ash: The ash fraction is only relevant with liquid fuels.

6) Hydrogen sulfide, acetylene, hydrogen:

These limits absolutely must be observed with gaseous fuels (only present in significant quantities with gaseous fuels).

7) Higher-molecular-weight hydrocarbons:

The tendency of hydrocarbons to decompose increases with increasing chain length. If the permissible fraction exceeds 10vol.%, problems may occur in premix mode (-> flashback).

Lube oils constitute a special problem. Lube oil films on the inner surface of pipes may extend over great distances and thus cause flashback at the burner. If gas compressors are used, they must be absolutely free of lube oil!

Comprehensive evaluation of all available fuels is only possible if a separate analysis is performed for each fuel in accordance with the Checklists given in this appendix.

Suitable analytic methods that correspond to state-of-the-are engineering practice are permissible.




Appendix A1.2.1: Gaseous Fuel - Typical Properties and Conditions of Fuel Gas at Terminal Point

Properties, Condition Condition(s) Limits

Pressure 1)

Design value

Tolerance - at 0 - 15% of the max. fuel flow

± 5.0% of design value

- at 15 - 100% of the max. fuel flow

± 2.5% of design value

Change rate dp/dt ≤0.2bar/s

Temperature 2)

Permissible range min. -10°C

min. 10K above dew point of gas mixture 4)

min. 15K above the dew point of water

Tolerance

See footnote 2)

± 10K from startup and/or design value

Change rate dT/dt ≤1K/s

Heating value 3)

Design range min. 40,000kJ/kg

max. 50,012kJ/kg (100% methane)

Tolerance ± 5.0% of design value

Change rate d LHV/dt ≤0.1%/s

Wobbe index 5)

Design value 46,250kJ/m3 (at 0°C) based on the lower heating value

Tolerance ± 10% of design value (in this range, a gas with a fluctuation range of ±5% may be selected), provided that the Wobbe index limits are not violated!)

Contaminants 6)

Chemical See “Fuels and Compressor Intake Air – Typical Limits for Chemical Contaminants”

T = temperature LHV = lower heating value t = time p = pressure

Please refer to explanations on the following page.




Explanations

1) The required fuel gas pressure at the terminal point of supply of the GT fuel gas system (MBP) is dependent on the fuel gas composition, its temperature and density as well as the ambient conditions (air temperature and elevation of the power plant site). Site-specific parameters are used by Siemens Power Generation PE14 for determination of the required fuel gas pressure (refer to the foregoing) and entered in the List of Control Settings for Open- and Closed-loop Control Equipment (SREL) if a contract is awarded. This pressure is required for various items in the fuel gas system. The fuel gas pressure determined at this time is the “design value” and applies to all gas turbine operating conditions. In other words, it is selected such that operation of the gas turbine at limit output is guaranteed even under the least favorable conditions. The specified tolerances apply to this pressure. In general, the maximum fuel gas pressure is calculated on the basis of the following parameters for the maximum volume flow rate of fuel:

· lowest ambient temperature (with allowance for the permissible limit load) · maximum water injection (e.g., for NOx control) · minimum lower heating value LHV maximum fuel gas temperature.

Allowance is not made for the pressure drop of items in gas supply systems not included the scope of the gas turbine fuel gas system (e.g., gas pressure control station and fuel gas fine filter). An appropriate correction factor must therefore be applied to specify the requisite fuel gas pressure, e.g., at the power plant’s terminal point of supply. If the requisite gas pressure cannot be ensured by the gas supplier, a gas pressure boosting station (gas compressor) must be provided. In such cases it is imperative that only absolutely lube-oil-free gas compressors are used, i.e., all components of the gas compressor in contact with the fuel gas (e.g., pistons of a reciprocating compressor) shall not require oil for lubrication. This requires the use of special materials (e.g., PTFE piston rings).

2) In principle, it is permissible to operate gas turbines on natural gas fuels at ambient temperatures of up to 50°C without consulting Siemens Power Generation. These maximum operating temperatures also apply to the pilot gas. Without exception, fuel preheating to more than 50°C shall be clarified with Siemens Power Generation on a project-specific basis. A special design fuel gas system is required if the range of permissible limits is extended; additional effort (costs, deadline adjustments) must be clarified with Siemens Power Generation PE14. The specified rate of gas temperature change shall not be exceeded, either during operation or in the event of a fault (outage of the fuel preheating system).

3) A “design value” must be selected between the minimum heating value of 40,000kJ/kg and the maximum heating value of 50,012kJ/kg (in line with the respective natural gas analysis, the tolerance stated shall apply to this value). Department PE14 must be consulted if the heating value determined for the fuel gas to be used lies outside the permissible range.

4) The 10K margin to the dew point shall apply to all constituents of the gas, including heavy hydrocarbons. This ensures that the fuel gas does not contain any liquid constituents.

5) The Wobbe index is calculated from the product of the heating value [MJ/kg] and the density of natural gas at standard temperature and pressure [0°C, 1.013bar]. For the standard fuel gas system, the Wobbe index is calculated as 46,250 kJ/m3 (at 0°C) based on the lower heating value. Assuming that standard burners will be used, natural gas with a Wobbe index tolerance range of ±10% can be used (burner design range). In this range, a gas with a fluctuation range of ±5% may be selected), provided that the Wobbe index limits are not violated! In the event of larger Wobbe




index fluctuations, Siemens Power Generation PE14 must be consulted in terms of further details and any requisite modification of parts.

6) To ensure the required degree of purity after filtration, an appropriate filter unit is provided upstream of the terminal point of supply of the gas turbine fuel gas system (MBP). Care must be taken to ensure that entrainment of particles caused by corrosion of the inner walls of the lines downstream of the filtration unit and/or residual soiling in the piping is not possible. Gases with a hydrogen (H2) content greater than 1vol.% and/or an acetylene (C2H2) content greater than 0.1vol.% shall only be combusted in diffusion mode. If such fuels were combusted in premix mode, this would involve the risk of reactions occurring in the premix piping which could completely destroy the burners. Department PE14 shall also be consulted in the case of fuels with higher hydrocarbon (CnHm, n ≥ 2) contents greater than 10vol.% and/or a hydrogen content greater than 10vol.%. Ethane (C2H6) contents of up to a maximum of 15vol.% are permissible and do not require the approval of PE14.




Appendix A1.2.2: Gaseous Fuel - Typical Properties for Standard Natural Gas

Natural gas must meet the following typical requirements if it is to be used in gas turbines equipped with standard fuel gas systems.

The permissible gradients for changes in natural gas pressure, temperature and heating value stipulated in “Typical Properties and Conditions of Fuel Gas at Terminal Point” apply.

The following data must be determined as defined in the respective ASTM, ISO or DIN standard.

Gas constituents Unit (other ISO units are

permitted)

Value

CH4 Vol. % ≥90 (lower contents permissible, provided the specified LHV is complied with) C2H2 Vol. % ≤0.1 C2H6 Vol.% ≤15 CnHm Vol. % ≤10 sum of CnHm with n ≥ 2, excluding C2H6 2) H2 Vol. % ≤1.0 CO Vol. % normally not a constituent of natural gas 2) H2O Vol. % cf. dew point of water CO2 Vol. % ≤5 N2 + Ar + CO2 Vol. % ≤10 O2 Vol. % ≤0.1 Other Vol. % 2)

Properties 2) Lower heating value (LHV)

MJ/kg 40 - 50MJ/kg

Density at 15°C kg/m3 0.8650 Max. permissible natural gas temp. (preheating)

°C 3)

Natural gas dew point* °C T ≥ Tdew point +10 (at design pressure, measured at the terminal point of supply of the gas turbine fuel gas system (MBP))

Dew point of water* °C T ≥ Tdew point +15 * Whichever temperature is higher shall be used in the design.

Contaminants 1) Dust d < 2µm 2 < d < 10 µm d >10 µm

ppm(wt) ≤20 ≤18.5 ≤1.5 ≤0.002

Na + K ppm(wt) ≤0.3 Ca ppm(wt) ≤10.0 V ppm(wt) ≤0.5 Pb ppm(wt) ≤1,0 H2S ppm(vol) ≤10




Important remark: The design fuel may be freely selected among fuels which lie within the above limits, it must, however, be specified; a heating value tolerance of ±5% must be complied with; heating values and ultimate analysis must be individually stated for thermodynamic guarantee calculations! 1) Permissible limits must be corrected using the equation: Xcorr = LHV(MJ/kg/42(MJ/kg) x Xspec. 2) To be specified by Sales & Marketing. 3) The maximum permissible NG preheat temperature shall be clarified with PE14 on a project-specific basis.




Appendix A1.2.3: Gaseous Fuel - Checklist for Fuel Gases

The fuel supplier must fill out the following checklist to permit an unequivocal assessment of customer-specific fuel analyses and thus ensure safe, reliable gas turbine operation:

Gas constituents Unit (other ISO units are permitted)

Value

CH4 Vol. % C2H2 Vol. % C2H6 Vol. % C3H6 Vol. % C3H8 Vol. % C4H8 Vol. % n C4H10 Vol. % iso C4H10 Vol. % n C5H12 Vol. % iso C5H12 Vol. % C6 Vol. % C7 (+) Vol. % H2 Vol. % CO Vol. % CO2 Vol. % H2O Vol. % N2 Vol. % O2 Vol. % Ar Vol. % Other Vol. %

Properties Lower heating value (LHV)

MJ/kg

Density at 15°C kg/m3 Temperature °C Dew point of water °C

Contaminants Dust Mass % Alkali metals (Na + K) ppm(wt) Other metals (V, ...) ppm(wt) NH3 ppm(vol) H2S ppm(vol)

Other specific characteristics:




Appendix A1.3.1: Liquid Fuel - Typical Properties for Fuel Oils per ISO 4261; DIN 51603; ASTM D 396, 975, 2880

Compliance with the limits given below is a prerequisite to reliable and fault-free turbine operation. Actual values shall be specified in the event that an order is placed.

Properties Unit Limits Remarks

Flash point 1) °C As specified in applicable national codes and standards

If explosion protection measures are required, electrical equipment shall be designed in accordance with ElexV and DIN 57165/VDE 0165.

Kinematic viscosity cSt (mm2/s)

≤ 12 (PM)

≤ 28 (DM)

Remark 2

Operating temperature °C ϑ ≥ ϑPP +10

ϑ ≤ ϑFP -5

Remark 3

Pressure upstream of injection pump bar p ≥ 3.0 Remark 4

Solids contained in filtered fuel (up-stream of the terminal point of supply of the gas turbine FO system (MBN))

- Permissible total solids content

- Nominal filter mesh

- Absolute filter mesh

- Particle size 10 - 25µm

- Particle size >25µm

ppm(wt)

µm

µm

%

%

≤ 20

10

25

≤ 10

0

Compliance with the permissible limits ensures that the gas turbine can be operated without the threat of erosion damage.

The use of filters with a mesh size smaller than specified may result in filter clogging after a relatively short operating time.

Water content, bound wt % ≤ 0.1

Lower heating value (LHV) MJ/kg ≥ 42.0

Density (at 15°C) kg/m3 max. 870

ElexV = German industrial ordinance pertaining to electrical equipment in surroundings where there is an explosion hazard

DIN 57165/VDE 0165 = Installation of electrical equipment in areas with explosion hazard

Please refer to explanations on the following page.




Explanations

1) Flash point

Flash point shall be determined and compared with the limits of the national codes and standards applicable at the location where the gas turbine is installed. Applicable explosion protection regulations and guidelines shall be complied with. If fuels must be heated to or above their flash point, additional explosion protection measures are absolutely imperative. This shall also apply if it is not possible to determine the flash point.

2) Kinematic viscosity

The standard fuel oil package design includes a centrifugal pump. Lower viscosity limits are not known for conventional liquid hydrocarbons used with this gas turbine design. If the maximum permissible viscosity is exceeded, atomization of the fuel oil is impaired. Effects: - Less complete combustion - Increased pollutant emissions The maximum permissible viscosity in premix mode is 12cSt and 28cSt in diffusion mode. Viscosity shall be specified in accordance with the "Checklist" (20 and 40°C).

3) Operating temperature (cf. also "Flash point" for explosion protection)

The minimum operating temperature for distillate fuel oils is determined by the maximum viscosity and the solidification of paraffin (ϑPP; pour point). It may be necessary to preheat the fuel oil to meet these viscosity requirements imposed to ensure proper flow and atomization, but fuel oil shall never be heated to above its flash point (ϑFP) to obviate the need for explosion protection measures. If the temperature drops below the minimum operating temperature, paraffin may precipitate out and/or the viscosity may exceed the maximum limit. Effects: - Filter clogging - Shutdown of fuel oil injection pumps due to insufficient pressure in the suction line - See Remark 2. If temperature declines below the pour point, the fuel oil can no longer be pumped. Effects: - Damage to and outage of fuel oil pumps. As a matter of principle, the maximum operating temperature should be 5K below the flash point. Otherwise, additional explosion protection measures must be taken.

4) Pressure

Fuel oil pressure upstream of the injection pump must be at least 3.0bar. Lower pressures require the approval of G214.

5) Solids

If the filter mesh is finer than stipulated and/or the permissible total solids content of the specified particle sizes is exceeded, there is a danger of increased erosion in the fuel oil burner nozzles and on the turbine airfoils. Effects: - Poor atomization - Uneven temperature distribution - Premature replacement of fuel oil nozzles and/or blades.




Appendix A1.3.2: Liquid Fuel - Typical Properties for Standard Liquid Fuels (EL Distillate Fuel Oil, Gas Oil, No. 2 GT Distillate Fuel Oil)

Liquid fuel must meet the following requirements if it is to be used in gas turbines equipped with standard fuel oil systems.

System requirements defined in “Typical Properties for Fuel Oils per ISO 4261; DIN 51603; ASTM D 396, 975, 2880” datasheets must be met.


Constituents 1) Unit (other ISO units are permitted)

Value

C Mass % 85-87 O Mass % ≤ 0.1 S Mass % ≤ 0.2 N Mass % ≤ 0.015 H Mass % 13-15

Properties 1)

Lower heating value (LHV)

MJ/kg ≥ 42

density at 15°C kg/m3 820-870 at ..... Kinematic 20°C cSt 3 - 6 viscosity 40°C 2.3 – 3.9 Flash point °C >55°C Pour point/CFFP °C ≤ -6 (20) True-boiling-point distillation curve

65 % °C ≤ 250 100 % °C ≤ 350

37.7 °C bar ≤ 0.0025 Vapor pressure 65.5 °C bar ≤ 0.008 80.0 °C bar ≤ 0.014 Contaminants 1) Water content Mass % ≤ 0.01 (0.1) Carbon residue Mass % ≤ 0.15 Sediment d < 10 µm 10 ≤ d ≤ 25µm d > 25µm

ppm(wt) ppm(wt) ppm(wt) ppm(wt)

≤ 20 ≤ 18 ≤ 2 0

Ash ppm(wt) ≤ 100 Na + K ppm(wt) ≤ 0.3 V ppm(wt) ≤ 0.5 Pb ppm(wt) ≤ 1.0 Ca ppm(wt) ≤ 10 Mercaptans (organic compounds containing SH groups)

ppm(wt) ≤ 10

1) Other specific characteristics (to be stipulated by Sales & Marketing):




Appendix A1.3.3: Liquid Fuel - Typical Properties for Liquid Fuels (Jet A-1, Kerosine, No. 1 GT Distillate Fuel Oil)

Liquid fuel must meet the following typical requirements if it is to be used for operation of gas turbines with special design fuel oil systems; special design means: due consideration is given to implementation of measures pertaining to explosion protection measures, ventilation, and detection. Additional expenses (extended lead times, increased costs) are generally not covered by the gas turbine F price. Additional documented costs are invoiced to Sales & Marketing at no surcharge. System requirements defined in “Typical Properties for Fuel Oils per ISO 4261; DIN 51603; ASTM D 396, 975, 2880” datasheets must be met.


Constituents 1) Unit (other ISO units are permitted)

Value

C Mass % 84-86 O Mass % ≤ 0.1 S Mass % ≤ 0.2 N Mass % ≤ 0.015 H Mass % 14-16

Properties 1) Lower heating value (LHV)

MJ/kg ≥ 42

density at 15°C kg/m3 775-850 at ..... Kinematic viscosity 20°C

40°C cSt 1.7 – 3.2

1.3 – 2.4

Flash point °C > 37.8 Pour point/filterability (CFPP) °C ≤ -18 (0) True-boiling-point distillation curve

≤ 10vol.% °C ≤ 204.4 ≤ 90 vol.% °C ≤ 288 ≤ 100vol.% °C ≤ 300

37.7°C bar 0.008 Vapor pressure 65.5°C bar 0.028 80.0°C bar 0.047 Contaminants 1) Water content Mass % ≤ 0.01 (0.1) Carbon residue Mass % ≤ 0.15 Sediment d < 10 µm 10 ≤ d ≤ 25µm d >25µm

ppm(wt) ppm(wt) ppm(wt) ppm(wt)

≤ 20 ≤ 18 ≤ 2 0

Ash ppm(wt) ≤ 100 Na + K ppm(wt) ≤ 0.3 V ppm(wt) ≤ 0.5 Pb ppm(wt) ≤ 1.0 Ca ppm(wt) ≤ 10




Mercaptans (organic compounds containing SH groups)

ppm(wt) ≤ 30

1) Other specific characteristics (to be stipulated by Sales & Marketing):




Appendix A1.3.4: Liquid Fuel: Checklist for Liquid Fuels

The fuel oil supplier must fill out the following checklist to permit meaningful evaluation of customer-specific fuel analyses and thus ensure reliable gas turbine operation:

Constituents Unit (other ISO units are permitted)

Value

C Mass % O Mass % S Mass % N Mass % H Mass % Properties

Lower heating value (LHV)

MJ/kg

density at 15°C kg/m3 at ..... Kinematic 20°C cSt viscosity 40°C Flash point °C Pour point °C True-boiling-point distillation curve 10 %

20 % 30 % 40 % 50 % °C 60 % 70 % 80 % 90 % ...................bar at ....... ...........°C Vapor pressure ...................bar at ....... ...........°C ...................bar at ....... ...........°C Contaminants

Sediment Mass % Water content Mass % Wax or paraffins Mass % Carbon residue Mass % Ash ppm(wt) Na + K ppm(wt) V ppm(wt) Pb ppm(wt) Ca ppm(wt) Mercaptans (organic compounds containing SH groups)

ppm(wt)

Other specific characteristics:




Appendix A1.4.1: Water for NOx Water Injection, Purging, Compressor Cleaning - Requirements

NOx, Purge and Cleaning Water

Demineralized Water Test/Check Quality Unit

pH-value ASTM D 1293 5 - 8 -

Conductivity κ < 0.51) µS/cm

Impurities:

Sodium and potassium (Na + K)

Calcium (Ca)

Chlorine and fluorine (Cl + F)

Silicic acid (SiO2)

DIN 51797, ASTM D 3605

ASTM D3605

ASTM D3605

ASTM D895

< 0.05

< 1

< 0.1

< 0.05

ppm(wt)

ppm(wt)

ppm(wt)

ppm(wt)

1) An increase in conductivity of up to 0.8µS/cm is tolerable in the case of compressor washing, provided it is caused by air ingress (CO2) and not by other factors (entrainment of salt, etc.).




Appendix A1.4.2: Water for Inlet Air Cooling - Requirements

Evaporative Inlet Cooling System Water

Potable Water Quality Unit

pH-value 7 - 8.5 -

Conductivity 50 - 450 µS/cm

Total Alkalinity 45 - 170 ppm

Calcium Hardness 45 - 170 ppm

Impurities:

Chlorides (as Cl)

Silica (as SiO)

Iron (as Fe)

Oil and Grease

Total dissolved solids

Suspended solids

< 50

< 25

< 0.2

< 2

< 550

< 5

ppm

ppm

ppm

ppm

ppm

ppm




Appendix A1.4.3: Cooling Water for Lube Oil and Generator - Requirements

The oil-to-water plate-type or shell & tube-type heat exchangers for lube oil and the internal air-to-water coolers of the TEWAC generator require normally demineralized water in a closed cooling water cycle. Nevertheless, the demineralized water may also contain some glycol and rust inhibitor content.

In order to ensure a proper function of all coolers, a project specific analysis of the cooling water has to be performed.




Appendix A1.5.1: Lube Oil - Physical and Chemical Properties in the As-supplied Condition

Property Numeric value Unit Test method DIN/ISO ASTM Kinematic viscosity at 40°C 41.4 – 50.6 mm2/s DIN 51 562-1 ASTM D 445

Air release at 50°C °C°C ≤ 4 min DIN 51 381 ASTM D 3427

Neutralization number ≤ 0.20 mg KOH/g DIN 51 558-1 ASTM D 974

Water content ≤ 100 mg/kg DIN 51 777-1 ASTM D 1744

Foaming characteristics at 25 °C Foam volume Foam stability

≤ 400 ≤ 450

ml s

ISO 6247

(Sequence 1)

ASTM D 892 (Sequence 1)

Water release capability ≤ 300 s DIN 51 589-1 –

Demulsibility ≤ 20 min DIN 51 599 ASTM D 1401

Density at 15 °C ≤ 900 kg/m3 DIN 51 757 ASTM D 1298

Flash point > 185 °C DIN ISO 2592 ASTM D 92

Pour point ≤ – 6 °C ISO 3016 ASTM D 97

Purity ≤ 17/14 – Test: ISO 5884 result: ISO 4406

–

Color ≤ 2 – DIN ISO 2049 ASTM D 1500

Copper strip corrosion ≤ 2 -100 A 3 – DIN EN ISO 2160 ASTM D 130

Corrosion protection of steel ≤ 0 - Pass – DIN 51 585 ASTM D 665

Aging: Increase in neutralization number after 2500 h

≤ 2.0 mg KOH/g DIN 51 587 ASTM D 943




Appendix A1.5.2: Hydraulic Oil - Physical and Chemical Properties in the As-supplied Condition

Property Requirements Unit Test method

DIN/ISO ASTM

Kinematic viscosity at 40°C 41.4 - 50.6 mm2/s DIN 51562-1 ASTM D 445

Air release at 50°C ≤ 10 min DIN 51381 ASTM D 3427

Water content ≤ 100 mg/kg DIN 51777-1 ASTM D 6304

Foaming characteristics at 25°C ≤ 150/0 ml ISO 6247 ASTM D 892 (Sequence 1)

Demulsibility ≤ 40 min DIN ISO 6614 ASTM D 1401

Density at 15°C ≤ 900 kg/m3 DIN 51757 ASTM D 1298

Flash point > 185 °C DIN EN ISO 2592 ASTM D 92

Pour point ≤ -15 °C ISO 3016 ANSI/ASTM D 97

Minimum requirements Class 17/15/12 per ISO 4406Class 6 per SAE AS4059 - ISO 5884 -

Copper strip corrosion pass - DIN EN ISO 2160 ASTM D 130

Steel corrosion resistance pass - DIN ISO 7120 ASTM D 665

Aging: increase in neutralization number after 1000 h ≤ 2.0 mg KOH/g DIN 51587 ASTM D 943

d

Heavy Duty Gas Turbine Generators

History of Berlin plant

First gas turbine, 62.5 MW – 1972

1904 – 1,000 kW

1916 – 50 MW, world‘s largest steam turbine

1926 – 80 MW

1936 – First reheat steam turbine

1947 – First turbine after war1954 – 100 MW

1957 – 150 MW250 MW – 1962

300 MW – 1965

670 MW – 1972(nuclear/steam)

10 turbines V93 – 1973

1978 – World‘s most powerful combustion turbine, 111.5 MW

1980 – 125 MW, world‘slargest GT

1984 – V94.2workhorse

V64.3 First GTof third generation – 1990

V94.3A turbine – 1996

Merger with Westing-house – 1998

First 501 FDs, developed in Orlando,produced in Berlin – 2000

Manufacturing Network Berlin/Hamilton/Orlando – 2000

Manufacturing goes global

Gas Turbine

Steam Turbine

Key data of Berlin plant

Manufacturing of 50-Hz heavy

duty gas turbines from

70 - 270 MW

Approx. 2,000 employees

Area: 125,000 square meters

Over 500 gas turbines delivered,

of those over 90% exported to

customers in 60 countries

Capacity of 100 GW provides

electricity for 100 million people

Global network - fossil power generation

Orlando

CharlotteFt. Payne

Mülheim

Erfurt

Budapest

New-Delhi

Cilegon

Shanghai

FujiHamilton

Offenbach

Berlin

Erlangen

JV

Own site

Evolution of gas turbine technology –turbine blade development

1975 2006

Aerodynamics

Cooling technology

Materials/manufacturing

Anti-corrosion coating

Thermal barrier coating

Film-cooled blade>1400°C gas temperature~ 2 MW output/blade

Non-cooled blade~900°C gas temperature~0.7 MW output/blade

Key disciplines made impressive achievements possible

Heart of a heavy duty gas turbine -proven high-technology blade design

Opened air flow

Detail

Nickel-based super alloys

Single-crystal base material

High-performance airfoils: advanced design for internal and film-cooled hot gas parts

High-temperature corrosion protection with metal coatings

Thermal barrier coating for cooling support with ceramics

Test bed- and field-proven

Best maintenance performance

Driving technology for customer benefit.

We develop advanced technology - based on best-practice air-cooled hot gas parts.

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Gas turbine operating principle

Air

Fuel (natural gas, fuel oil) Firing temperature

Exhaust gas

Combined cycle (gas turbine and steam turbine) power plant operating principle

Steam turbine

ElectricitySteam generator

Steam

Air Fuel

CondensateCondenser

Gas turbine

Saving fuel and keeping emissions low

Examples:

Mainz-Wiesbaden Combined Cycle Power Plant (CCPP),Germany, achieved efficiency of about 58%

BASF Combined Heat and Power (CHP) Plant, Ludwigshafen: fuel efficiency of 90%

Siemens PG develops the world’s largest gas turbine (chart I)

Gas turbine SGT5-8000H

Fuel Gas, oil

Capacity 340 MW

Efficiency 39%

Combined Cycle Power Plant SCC5-8000H

Capacity 530 MW

Efficiency 60%

Siemens PG develops the world’s largest gas turbine (chart II)

1,100 model 911 Turbo Porsche cars

13 jumbo jet engines

An SGT5-8000H gas turbine can supply electricity to around 620,000 three-person households or a city with the size of Hamburg, Germany

Matrixed and multi-location team structure to integrate all global Siemens PG experts

Mülheim, Germany Berlin,

Germany

Erlangen, Germany

Jupiter, FL, USA

Orlando, FL, USA

Developmentteam

Turbinecombustion system

Compressorengine integration

Blades, vanes, secondary air

Manufacturing

Programmanagement,

engine testing, plant design

Gas turbines are high-tech products

Technological challenges for gas turbines

+

High centrifugal forcesHigh temperatures

The blade tips reach sonic speed.

The thermal loading of the blades is almost as high as the melting point of iron (1516°C).

The centrifugal force acting on the blades is 10,000 times the force exerted by the dead weight of the blades.

Great (German) engineering

One gas turbine blade

10 Porsche TurbosDelivers the same power as:

Advanced sensor systems for gas turbines structural health monitoring

New dimension of onlinediagnosis for gas turbinesSmaller clearance gap boosts efficiencyHigh-speed infrared camera records images of red-hot turbine bladesWireless sensors for blades

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June 26, 2006 Power Generation 17Dr.-Ing. Wolf-Dietrich Krueger

Siemens Global Media Summit

Safe harbor statement

This presentation contains forward-looking statements and information – that is, statements related to future, not past, events. These statements may be identified either orally or in writing by words as “expects”, “anticipates”, “intends”, “plans”, “believes”, “seeks”, “estimates”, “will” or words of similar meaning. Such statements are based on our current expectations and certain assumptions, and are, therefore, subject to certain risks and uncertainties. A variety of factors, many of which are beyond Siemens’ control, affect its operations, performance, business strategy and results and could cause the actual results, performance or achievements of Siemens worldwide to be materially different from any future results, performance or achievements that may be expressed or implied by such forward-looking statements. For us, particular uncertainties arise, among others, from changes in general economic and business conditions, changes in currency exchange rates and interest rates, introduction of competing products or technologies by other companies, lack of acceptance of new products or services by customers targeted by Siemens worldwide, changes in business strategy and various other factors. More detailed information about certain of these factors is contained in Siemens’ filings with the SEC, which are available on the Siemens website, www.siemens.com www.sec.govand on the SEC’s website, . Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those described in the relevant forward-looking statement as anticipated, believed, estimated, expected, intended, planned or projected. Siemens does not intend or assume any obligation to update or revise these forward-looking statements in light of developments which differ from those anticipated.

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