Marzieh 2002

Proceedings of ASME TURBO EXPO2002 2002 ASME TURBO EXPO June 2002, Amsterdam

June 3-6, 2002, Amsterdam, The Netherlands

GT-2002-30108 THE ALSTOM GT13E2 MEDIUM BTU GAS TURBINE Frank Reiss / ALSTOM Power Ltd, CH-5401 Baden, Switzerland

Timothy Griffin / ALSTOM Power Technology Ltd, CH-5401 Baden, Switzerland

Karl Reyser / ALSTOM Power Ltd, CH-5401 Baden, Switzerland

ABSTRACT ALSTOM Power’s GT13E2 gas turbine has been successfully commissioned in a refinery residual oil gasification process (api Energia, Italy) operating on Medium Btu gas (GT13E2-MBtu). The modification of the standard GT13E2 to operate with MBtu fuel has resulted in an improvement in the performance of the GT13E2 to exceed 192 MW and 38% efficiency (simple cycle) at ISO conditions. The GT compressor has been upgraded to incorporate an extra-end stage to boost the pressure ratio to 17:1 and improve performance. Syngas from residual oil gasification has a typical volumetric composition of 45% H2, 48% CO and 7% CO2 and a lower heating value of 13.9 MJ/kg. This syngas has been diluted with N2 to reduce the heating value to 7 MJ/kg lowering reactivity and allowing partially premixed operation. In order to operate with syngas a redesign of the standard EV burners was necessary to deal with the associated high flame velocities and volume fluxes. The fuel injection for syngas operation was placed at the burner end and the gas injected radially inward to obtain inherently safe operation. The gas turbine demonstrated successful operation with both syngas and oil No. 2 fuels. At the standard dilution of 7MJ/kg NOx emissions are in the 20-25 vppm range and the CO emissions are below 5 vppm independent of load. The modified burners demonstrated safe operation on syngas with and without dilution of nitrogen in a tested LHV range from 6.8 to 14 MJ/kg. This behavior allows high flexibility of the entire power plant. Changeover from oil no. 2 to syngas and vice versa can be done between 50 and 100% load. The gas turbine

components have been inspected several times during the commissioning period and shown to be in good condition. INTRODUCTION Low emissions and high efficiency are the major requirements for the current power generation market. Due to the significant increase in gas turbine and combined cycle efficiency and the very low emissions of gas turbines burning clean fuels (i.e. no fuel bound nitrogen or sulfur components), complex gasification combined cycle processes are becoming economically feasible. The hydrocarbons used for the gasification can be residual oils, coal, pet coke, visbroken tar or industrial waste. To achieve low emissions with these fuels, modern high temperature gas turbines, designed for natural gas and oil no. 2, have to be modified, especially with respect to the combustion technique used. The ALSTOM combustion technique for fuels from gasification processes is premix combustion which requires only moderate dilution of syngas for low NOx control. With this technique, no air extraction is required from the gas turbine due to a sufficient surge margin. This fact and the ability of the burners to burn un-diluted syngas guarantees the gas turbine both high flexibility and availability within the gasification process. Major modifications of the 13E2 gas turbine are restricted to the premix EV burners and the fuel distribution system. Compared to diffusion burner techniques, much smaller volume flows have to be controlled for the operation of the gas turbine and no water is used for NOx control.

11

Copyright Copyright © © 2002 2002 by by ASME ASME

Downloaded From: http://proceedings.asmedigitalcollection.asme.org/ on 02/05/2016 Terms of Use: http://www.asme.org/about-asme/terms-of-use

The api Energia IGCC of Falconara is based on use of a single ALSTOM GT13E2-MBtu gas turbine. The following describes the required modifications of the MBtu gas turbine and combustion technique, the operation concept and the initial results regarding performance and combustion behavior.

FROM THE GT13E2 TO THE GT 13E2 - MBTU The GT13E2 is the latest member of the GT13E product family with a turbine inlet temperature of 1100°C (according to ISO definition) and a pressure ratio of 15:1, which gives a power output of 165.1 MW and an efficiency of 35.7% in single cycle application (ISO at base load conditions with natural gas fuel, see /1/, /2/). The GT13E2 follows in direct line from the successful aerodynamic and mechanical design features of the GT13 product family, with a single shaft concept with two bearing sections, a welded monolithic rotor, a subsonic compressor, a highly efficient turbine, efficient cooling systems for turbine rotor, vane carrier and front stages and one combustion chamber. Since launching the GT13E2, 57 are operating in the field, with over 1,000,000 fired operating hours. Fig. 1 shows the turbogenerator group of the GT13E2 and GT13E2-MBtu.

Table 1: Performance data of the GT13E2 (natural gas fuel, ISO conditions) Power Output 165.1 MW Thermal 35.7% Efficiency Turbine Inlet Temperature 1100 oC (ISO 2314 Definition) Exhaust Gas Flow 532kg/s Exhaust Temperature 525 oC NOX Emissions Gas (Dry) 25 vppm (Corrected to 15% O2) NOX Emissions Oil (Wet) 42 vppm (Corrected to 15% O2)

Performance of the GT13E2-MBtu The machine performance testing on syngas on the GT13E2 started on July 1, 2000. On August 20, 2000 the GT reached full load on syngas for the first time. At the beginning of the official performance test on February 19, 2001 the GT reached 4800 operating hours (OH). The evaluation of the process measurements for the GT13E2MBtu prototype at API showed very good agreement with expectations with guarantee values being successfully demonstrated. This together with the long experience of the large GT13E2 fleet shows that the GT13E2-MBtu is very well suited for the combustion of hydrogen-containing syngas in large-scale industrial applications. Syngas operation without any air extraction after the compressor leads to an increased compressor pressure ratio and an increased mass flow rate through the turbine. Increased power and efficiency are the consequence. To minimize the load of the turbine, the turbine inlet temperature has been reduced to 1080 °C (ISO) compared to the standard natural gas fired GT13E2 (1100°C). Typical performance data for a syngas with a heating value of 7 MJ/kg are:

Figure 1: GT13E2 Thermal Block

The combustion system of the GT13E2 is a single annular combustor design (no cans) with 72 lean premix EV burners, arranged symmetrically in four rings around the turbine (see Figure 1). This symmetrical arrangement gives a homogeneous mixture of hot gas and, therefore, an excellent temperature pattern factor in front of the first stage vane. The annular combustor was designed with respect to optimized combustion with low NOx emissions (see /4/, /5/, /6/). Table 1 summarizes the performance data of the GT13E2 at ISO conditions in base load operation.

Table 2: GT13E2-MBtu Performance with Syngas (diluted syngas fuel, ISO conditions.) Power Output 192 MW Thermal Efficiency 38.1 % Turbine Inlet Temperature ~ 1080 oC (ISO 2314 Definition) Exhaust Gas Flow 587 kg/s Exhaust Temperature 500 oC NOX Emissions Gas (Dry) < 25 vppm (Corrected to 15% O2) NOX Emissions Oil (Wet) < 42 vppm (Corrected to 15% O2)

The basic design of the GT13E2 compressor with its high surge margin allows operation with the increased pressure ratio without air extraction. Therefore, no delivery of compressor discharge air to an air separation unit is foreseen. Instead the ASU is supplied with a separate compressor, designed for the optimal gasification conditions (non-integrated GCC). Figure 2 shows this basic power plant concept. The advantage of the non-integrated GCC is the de-coupled operation of the gas

2

Copyright © 2002 by ASME


turbine from the ASU, which requires the gas turbine to also operate without nitrogen dilution. This gives the gas turbine a high flexibility for start up, shut down and load shedding operation. Another consequence of the non-integrated GCC is that the combustion system must be able to run in a low NOx mode with relatively low N2 dilution. AIR OXYGEN DEMI WATER TAR

Gasification

NITROGEN Air Separator

Gas Cooling

Acid Gas Removal

POWER

POWER

GAS TURBINE

STEAM TURBINE

HOT EXHAUST

Sulphur Recovery

Soot Recovery STEAM WASTE WATER

DEMI WATER

EXHAUST STEAM

HEAT RECOVERY STEAM GENERATOR STEAM TO REFINERY

SULPHUR

STEAM

AUXILIARY BOILER

SMPP

CCPP+BOP

Figure 2: Gasification Combined Cycle Plant Concept

Compared to the standard GT13E2 the required fuel mass flow for the MBtu application is 6-7 times higher in order to reach the same heat input into the GT. Therefore, in total the exhaust mass flow of the GT is increased by approx. 10%. Using the standard turbine this leads to a significantly increased pressure ratio of the gas turbine process. In order to realize this increased pressure ratio the compressor design was modified by adding an additional compressor stage. This 22nd stage is a repeating stage derived from the existing 21st stage but with a shorter span. As mentioned the main change in the GT configuration is restricted to the combustion system. Thus, the focus of the initial part of the paper is on modifications of the burner.

COMBUSTION OF MBTU SYNGAS Specification of syngas fuel properties Residual oil gasification syngas is the most challenging syngas composition as far as premix burner technology is concerned. Residual oil gasification fuel from oxygen-blown processes can be represented by a typical volumetric composition of 45% H2, 48% CO and 7% CO2 and a lower heating value of 14 MJ/kg. The H2/CO ratio is about 1. The first ALSTOM application of a GT13E2 to hydrogen-based syngas fuel (api Energia, Falconara, Italy) was for residual oil gasification syngas.

Reliable premixed combustion systems for gas turbines are difficult to apply to hydrogen-containing MBtu fuels, due to their basic combustion properties. Peak laminar flame speeds of syngas are about an order of magnitude higher than the laminar flame speed of methane. Another property of these synthesis gases is their wide ignition limits. Additionally, reaction times for syngas are one fifth of that for natural gas. The time scale of the premixing process must be faster than the chemical time scale. Flashback can only be avoided if no low speed flow regions exist within the mixing zone. Syngas can be diluted with an inert gas (such as nitrogen) to reduce its chemical reactivity, making low NOx combustion possible. By diluting syngas with only 55% (Vol.) N2, the flame speed can be approximately halved, while the maximum flame temperature drops to values comparable to natural gas. This effect can be exploited to delay ignition until further downstream. In practice, the effect of moderate dilution is very strong, since rich combusting zones, which are most critical for flame stabilization and NOx production, are no longer present if the shift of the ignition point downstream is sufficiently large. Burner adaptation to syngas fuel The EV burner is also known as the Double Cone Burner because it consists of two half cones shifted perpendicular to their centerlines thus forming two inlet slots of constant slot width. Air entering through these slots is mixed with gaseous fuel emerging from a large number of holes along each of the slots. With a suitably selected ratio of slot width to burner length a central recirculation zone is formed on the centerline at the end of the burner and serves as an aerodynamic flame holder. Due to the central recirculation zone, stable combustion is possible, even at conditions close to extinction with flame temperatures well below 1500°C, without the need for piloting flames. This guarantees a minimum of NOx emissions. The burner is inherently safe against flashback since the fuel is injected and mixed in the inlet slots where the flow velocities are high and no fuel is present upstream of the burner. An appropriate injection method for MBtu gases has to take the critical properties of these fuels into account. Injection of these MBtu fuels along the air inlet slots is no longer appropriate due to the high flame velocities of hydrogencontaining fuels and the higher volume flux, which distorts the incoming air profile. A simple and effective injection design for the MBtu fuel has been developed. Instead of fuel injection along the slots, a number of circular holes close to the burner end inject fuel radially inward enabling inherently safe operation of the burner, even with high hydrogen content fuels (Figure 3). No fuel is found inside the burner and care has been taken to keep the outer recirculation zone free from unmixed fuel. Due to the high velocity of the fuel injection, the flame stabilizes downstream of the burner. Here the fuel jets reach the hot recirculation zone (see Figure 3). The air leaving

3



the

burner

Vortex Breakdown

is

entrained

into

the

fuel

jets

thus

Gas Injection Holes Combustion Air

Flame Front

MBTU - Fuel

Figure 4: Numerical simulation of flame stabilization in the MBtu EV burner.

Figure 3: Schematic of the MBtu EV burner.

premixing the fuel and air. The standard EV burner has been shortened to increase the air velocity at the burner exit where the syngas injector holes are located. This acts to enhance mixing thereby lowering NOx emissions and is an additional step to prevent flashback into the burner. The optimization of the hole geometry and distribution requires appropriate numerical tools. A three-dimensional flow field simulation including a k−ε turbulence model and species transport was used to study different injection geometries (see /7/). With the knowledge of the local equivalence ratio and the temperature in the fuel air mixing zone as well as information on the turbulent properties of the flow field, local flame velocities could be determined (see /8/, /9/). A comparison of this turbulent flame velocity with the local convective velocity yields the zones where flame stabilization is most likely to occur. These are indicated as surfaces in a three-dimensional plot (see Figure 4). Only those flames, which stabilize far enough downstream of the fuel injection, will allow the fuel to premix with sufficient quantities of air. Two principle modes of flame stabilization were found for various types of fuel injection geometries. With appropriate fuel injection, flame stabilization is found far downstream of the fuel injection holes where the jets reach the hot recirculation zone. The very low NOx values which can be achieved with premixed combustion of MBtu fuels need such suitable flame injection which delay flame stabilization until the fuel and air are mixed (as shown in Figure 4). Such a design has been employed in the burner development.

Due to these modifications the combustion system is capable of burning undiluted syngas safely and fulfilling NOx requirements with relatively small N2 dilution to only 7 MJ/kg heating value. This system is based on the proven EV burner and is also operable with oil no. 2. In contrast to the standard EV burner design the fuel distribution channels are now located near to the hot end of the burner. To prevent build up of thermal stresses caused by temperature gradients between the cold fuel channels and the burner shells, the two have been mechanically and thermally isolated in the current design (Figure 5).

Syngas

Oil Water Emulsion

Main Air Syngas injection

Figure 5. Design drawing of MBtu Burner. Note, the separation of fuel injection channel and the burner cone to reduce thermal stresses.

4



API - GT13E2MBtu - Syngas Operation - LHV Variation 1000 NOx@15%O2, dry [vppm] CO@15%O2, dry [vppm]

The GT13E2-MBtu burner mechanical design has been analyzed with full three-dimensional finite element techniques in order to check its operational reliability. The finite element predictions indicated that stress levels are well below the material’s inherent strength and yield the required lifetime in terms of creep and low cycle fatigue. In addition, the burner has been instrumented with thermocouples during full load testing and the results indicated that burner material temperatures are below thermal limits, corroborating the finite element stress analysis computations.

nominal, standard LHV (diluted)

100

Prel 70% NOx 80% NOx 90% NOx baseload NOx 70% CO 80% CO 90% CO baseload CO

10

undiluted

1

Extensive tests on this gas turbine in Falconara (api) with different boundary condition and with -

oil no. 2, mixed fuel (oil and syngas) pure syngas and diluted syngas

were performed during the commissioning process.

7

8

9

10

11

12

13

14

15

LHV [MJ/kg]

Figure 6: GT 13E2-MBtu, pure and diluted Syngas operation, NOx-Emission as a function of LHV (Prel is the relative power).

The NOx performance of the GT13E2-MBtu is excellent and meets all guaranteed values. In the required syngas operation range between 50% and 100% load, measured NOx values were below 25 vppm @ (15% O2, dry) – see Figure 7. The measured CO values are also very low and stay below 3 vppm @ (15% O2, dry). API - GT13E2MBTU - Syngas Operation Concept 7.5

80 NOx

70

CO

60

LHV in MJ/kg

7.3

50 40

7.0

30 20

LHV [MJ/kg]

Combustion Performance At the end of the full scale DLR combustion tests, the final design of the MBtu burner was fixed and a full set of 72 burners were manufactured for use in the prototype MBtu gas turbine.

6

NOx@15%O2, dry [vppm] CO@15%O2, dry [vppm]

To reduce the risk of the use of syngas fuel in the first machine application, a series of high-pressure combustion tests at simulated gas turbine conditions were performed to confirm performance. The conditions of these tests were chosen to reflect the entire operating window with both fuels (oil and diluted and un-diluted syngas) and with fuel mixed operation of the api Energia machine. To enable the greatest range of testing possibilities at lowest possible cost, the DLR (German Aerospace Research Center) test facility in Cologne, Germany was chosen.

6.8

10

Emissions on syngas operation Generally it can be stated that the NOX-emissions (see Figure 6) increase with increasing LHV more or less independently from the operated load. The measured NOxemissions can be summarized as follows: • • •

20 - 25 vppm operating with a standard LHV of 7 MJ/kg, approx. 50 vppm with 9 MJ/kg and approx. 200 vppm with 14 MJ/kg (undiluted syngas).

For a relative load greater than 70% the CO-emissions stay consistently below 5 vppm over the entire GT-Load range.

0

6.5 50

60

70

80

90

100

relative Load [%]

Figure 7: GT 13E2-MBtu pure Syngas operation, NOX-Emission as a function of GT-Load

The standard GT13E2 has permanently installed pressure sensors to monitor the RMS values of the combustion-induced pulsations. The standard monitored frequency bands are based on broad experience with the standard GT13E2 burner. The pulsations for syngas operation with the normal, standard LHV (7 MJ/kg) showed nearly the same levels as the standard GT13E2.

5



As a result of the tests with the gas turbine on syngas it was found that the frequencies monitored for pulsation protection need to include two additional frequency bands in the high frequency range (2 kHz, 4 kHz). Variation of pulsations at 4 kHz for syngas operation with the nominal LHV over the load range of syngas operation is shown in Figure 8, indicating inherent combustion stability.

•

These high frequency pressure pulsations were monitored with the extended range sensors during the entire test and commissioning phase. In order to make this protection available for the regular MBtu-operation concept, two additional filters designated for the 2 and 4 kHz ranges were installed.

are fulfilled in the prototype GT13E2-MBtu machine.

As a result of the detailed measurement with syngas it was found that pulsations in all frequency ranges were very low as in the GT13E2 on natural gas. The pulsations in the high frequency range increase with higher LHV peaking at an intermediate value between 7 and 14 MJ/kg. In this case the implemented pulsation protection will prevent the GT from running with critical values. The measured values of pulsation on pure syngas (at 14 MJ/kg LHV) are again well below the protection limits.

GT13E2MBTU - Syngas Operation Concept, LHV = 7MJ/kg Normalized Pulsations as a function of Load Normalized Pulsations [-]*

3 Peak@4kHz at 50-100%

7MJ/kg

* Normalized with GT13E2 Standard Value

ability to burn mixed (syngas + oil) fuel over a wide mixing ratio wide operation range regarding H2/CO ratio and fuel heating value low emissions of NOx and CO low levels of pressure pulsations high mechanical thermal reliability

• • • •

OPERATION CONCEPT An operating concept has been established providing maximum flexibility and optimal performance. This is due to the fact that the burners can handle both mixed syngas-oil operation (within the individual burners) as well as undiluted syngas (with up 14.4 MJ/kg heating value). The operating concept is illustrated schematically in Figure 9. In this figure the allowed fuel compositions are indicated as a function of gas turbine load. It can be seen that full flexibility is possible at greater than 50% load. Oil # 2 is used for ignition of the gas turbine (GT). Ignition on syngas is not foreseen. Only minor adjustments have to be made to the starting sequence compared with the GT13E2 standard concept. To optimize start up of the machine variations were done with acceleration ramp and the variable inlet guide vane position. Additionally variations with water injection1 were done during commissioning tests.

2

1

0 50

60

70 80 relative Load [%]

90

100

Figure 8. Combustion-induced pressure pulsations during syngas operation as a function of GT load.

The MBtu unit at API has proven its stability in oil operation where performance is similar to that of a standard GT13E2 dual burner. The emissions and pulsation values are equal or slightly reduced compared to the standard burner over the complete load range.

Load operation tests on oil # 2 consisted of adjustment of the water injection, adjustment of burner group activation points and measurement of base load performance. The required level of water injection had to be moderately increased as compared to the GT13E2-standard. Additionally, activation points had to be varied slightly. The burner group switching points were optimized for emissions and flame stability. The same loading and de-loading gradients were used as for the standard. After optimization operation on oil # 2 was possible from 0% to 100% load. If syngas is available to the plant from the gasification process, then at greater than 50% relative load, fuel switchover to syngas can be performed and carried out with the implemented concept (see Figure 9).

Commissioning tests have thus confirmed the single burner DLR tests showing that the following design requirements: • •

ability to burn syngas and oil no. 2 as a backup fuel, safe operation with pure syngas and with diluted syngas

1

Water Injection is realized with the injection of water through the burner lances

6



GT 13E2-MBtu Operation Window 100% Syngas (diluted and un-diluted) 1

80

0.9

60

Fuel Change Over, Emergency case

0.5 0.4 0.3 0.2 0.1

50

Mixed Operation, Allowed for Stationary Operation (oil and diluted/un-diluted syngas)

40

30

20 Fuel Change Over; Fuel Change Over Only Allowed for Transient Operation

Burner in Syngas Operation

0.6

Fuel Change Over; Only Allowed for Transient Operation

Fuel Change Over

0.7

Beta_Gas

70

Fuel Change Over, Emergency case

0.8

10

100%Oil 0 0

10

20

30

40

50

60

70

80

90

0 100

P_rel [%] Beta_Gas min

Beta_Gas max

Beta_Mixed max

Burner in Operation (Syng.--> Oil)

Figure 9: GT13E2-MBtu, Operation Concept. Beta is the proportion of energy from syngas in fuel (BetaGas=1 Å pure syngas, BetaGas=0 Å pure oil)

From 50% to 100% relative load the gas turbine can operate with diluted and un-diluted syngas. In the load range between 50% to 100% fuel change over from oil to syngas and vice versa has been demonstrated and is available as an easy-to-use standard operational feature. Operation with pure syngas was successfully tested over a wide range of Lower Heating Values (LHV) from 6.8 MJ/kg to 14 MJ/kg. The LHV of the syngas produced in the gasification process is about 14 MJ/kg, with an exact value depending on the used feedstock. For low NOx emissions the syngas must be diluted with nitrogen prior to use in the GT. The specified regular, standard LHV of the syngas to be in used for combustion in the GT is 7 MJ/kg. The important ratio of H2/CO in the syngas, which affects the reactivity of the syngas and thus, the risk for flashback, was also tested in a range from 0.96 to 1.1 and shown to not affect burner performance. In the load range between 50% and 100% load it is also possible to operate the GT with mixed fuel (oil and syngas simultaneously in each burner). A changeover from oil to mixed operation is only allowed above 50% relative power. The fuel mixing ratio syngas to oil (expressed in terms of the energy obtained from syngas, “Beta” in Figure 9) can be chosen in a range between 0.3 to 0.7 for stationary operation.

For the whole range of mixed operation the lower heating value (LHV) of the syngas has to be 8 MJ/kg. The mixed fuel ratios (syngas to oil) from >0 to 0.3 and 0.7 to <1 are only allowed for transient operation (see Figure 9). In case of insufficient syngas production it is necessary to changeover to 100% oil # 2 - operation. This case is regarded as an emergency case and therefore the necessary fuel switch must be performed very quickly. To meet this requirement a specialized operation procedure was successfully tested and implemented.

CONCLUSION The modification of the standard ALSTOM GT13E2 to operate with Medium Btu (MBtu) syngas from a residual oil gasification process has resulted in a unit where main performance parameters are improved to exceed 192 MW and 38% (simple cycle) at ISO conditions. The compressor module of the unit has been upgraded to incorporate an extra end compressor stage boosting the pressure ratio to 17:1 and improving performance. The unit can be used in the gasification process without the requirement for air extraction of the GT. The residual oil gasification syngas (typical volumetric composition of 45% H2, 48% CO and 7% CO2 and lower

7



heating value of 14 MJ/kg) has been diluted with N2 to allow partially premixed operation. An effective fuel injection design has been developed to allow the use of a modified EV burner and standard oil no. 2 operation. Syngas fuel injection has been placed at the burner end to ensure inherently safe operation. The fuel distribution channels at the end of the burner are both thermally and mechanically isolated from the main burner assembly. The modified EV burners can handle • oil as back up fuel, • mixed syngas-oil operation (within the individual burners), • diluted and undiluted syngas (14 MJ/kg heating value)

/6/

/7/

/8/

/9/

Thus, it is possible to operate the gas turbine independent of the nitrogen production of the air separation unit. An operating concept has been established providing maximum flexibility, availability and optimal performance.

Klohr, M., Schmidtke, J., Tschirren, S., Rihak, P., 1995, “Initial Operation Experience and test results of ABB’s Gas Turbine GT13E2”, ASME Paper 95-GT-248. Döbbeling, K, Knöpfel, H. P., Polifke, W., Winkler, D., Steinbach, C., and Sattelmayer, T, “Low NOx Premixed Combustion of MBtu Fuels Using the ABB Double Cone Burner (EV Burner)”, Transactions of the ASME, 118: 4653. Andrews, G.E., Bradley, D. and Lwakabanba, S.B., "Turbulence and Turbulent Flame Propagation-A Critical Appraisal", American Elsevier Publishing Company, 1975. Liu, Y., Lenze, B. and Leuckel, W., 1989, "Investigation on the Laminar and Turbulent Flame Velocity of Premixed Lean and Rich Flames of CH4-H2 Mixtures," presented at the 12 Int. Coll. on the Dynamics of Explosions and Reactive Systems (ICDERS), Ann Arbor MI.

The gas turbine demonstrated successful operation with both syngas and oil no. 2 fuels. At the standard dilution of 7 MJ/kg NOx emissions are in the 20-25 vppm range independent of load; they increase to around 50 vppm at 9 MJ/kg and to about 200 vppm at 14 MJ/kg with CO emissions below 5 vppm. The modified burners can handle syngas in the premix mode from 35 to 100% GT load. Changeover from oil no. 2 to syngas and vice versa can be done between 50 and 100% load. The gas turbine components have been inspected several times during the commissioning period and shown to be in good condition. The GT13E2 gas turbine has been successfully commissioned at the residual oil gasification process of api Energia in Falconara, Italy. On April 24, 2001, ALSTOM was awarded the Provisional Acceptance Certificate (P.A.C.) by the customer api Energia for the GT13E2-MBtu unit.

REFERENCES /1/

/2/

/3/

/4/

/5/

Viereck, D. 1992, “Die ABB Gasturbine GT13E2 – ein Gasturbinenkonzept für die Zukunft”, XXiV Kraftwerkstechnisches Kolloquium, TU Dresden, Germany. Viereck, D. Wettstein, H.E., Aigner, M. Kiesow, HJ. 1992, “GT13E2, the Cleanest Gas Turbine for Combined Cycleand Cogeneration Application”, ASME Cogen-Torbo, IGTIVol.7, pp.231-237. Aigner, M., Müller, G. 1992, “Second-Generation LowEmission Combustor for ABB Gas Turbines; Field Measurements with GT 11N – EV”, ASME Paper 92-GT022. Senior P., Lutum, E, Polifke, W., and Sattelmayer, T., 1993,”Combustion technology of the ABB GT 13E2 Annular Combustor”, CIMAG Conference, London. Tschirren, S., Aigner, M.,1993 “The Design of a Single Annular Combustor with EV-burners,” CIMAC Conference, London.

8



Marzieh 2002

Recommend Documents