JPS5848739B2 - Gastabinhou - Google Patents

Description

DETAILED DESCRIPTION OF THE INVENTION The present invention relates to a method for producing clean fuel gas and a method for combustion thereof in a gas turbine.

More particularly, a method for producing improved fuel gas from hydrocarbonaceous fuels with high ash and sulfur content and the use of the improved fuel gas in gas turbines to generate mechanical power and electrical power in a substantially pollution-free manner. Concerning how to generate it.

The sequence of operating operations in the simplest type of ordinary gas turbine is to compress the air by means of a centrifugal or axial compressor and to burn the fuel with the compressed air of said compressor in the gas turbine combustion chamber so that the resulting product The heated gas is then sent into an expansion turbine.

Some of the turbine power can be used to drive the compressor attached to the same operation.

The remaining turbine output will normally be sent to a generator for the generation of electrical energy.

With the conventional technology described above, it may be economically preferable to directly burn low-grade coal or heavy oil fuel in the combustion chamber of a gas turbine, but such fuels contain large amounts of ash and sulfur. If so, such a thing has never actually been done before.

Solid fuels with such high ash content generally emit solid abrasive and corrosive particles due to incomplete combustion.

When such particles become entrained in the fuel gas, they pass through the expansion turbine and deposit on the turbine blades, corroding the blade surfaces.

This causes the blades to become misshapen and block the gas passages within the turbine.

Furthermore, fine particles adhere to the downstream heat exchange surface and create an insulating state, resulting in a decrease in thermal efficiency.

Similar problems occur when burning petroleum products with a high ash content.

Such ash contains inorganic compounds such as those found in crude oil.

These compounds are concentrated in the residue during the refining process, which also contains silica, iron, and sodium compounds, which must be removed and treated separately.

Vanadium, nickel, sodium, sulfur, and oxygen are the main components of ash.

When burned they form metal oxides, sulfates, sodium vanadates and silicates.

These compounds will corrode the protective oxide film on the high temperature alloy.

Therefore, oxidation is accelerated, especially at temperatures above about 1200''F.

Furthermore, SO2, H2S and COS in the flue gases leaving the expanding gas turbine pollute the atmosphere.

Traditional methods of cleaning fuel gas before entering the gas turbine have been either impractical and/or unreasonably expensive.

The above problems can be substantially avoided by the present invention.

That is, by integrating a gas turbine and a partial oxidation fuel gas generator into a highly efficient process, electric power and mechanical power that does not pollute the atmosphere can be generated.

The method of the present invention relates to generating mechanical power and electrical power by using a gas turbine fueled with an improved fuel gas.

The fuel gas can be produced by non-catalytic partial oxidation of low-cost, sulfur-rich, ash-rich hydrocarbon fuels.

The improved fuel gas produced is approximately 75-350 BTU/
SCF, preferably having a heat of combustion in the range of 75 to 100 BTU/SCF, and having a molar ratio of at least about 0.300 (C
O/H2).

Burning it in a gas turbine causes virtually no environmental pollution.

The method of the present invention is based on the following steps.

(1) In the reaction zone of a non-catalytic free-flow gas generator, in the presence of a temperature regulator, the autogenous temperature range is about 816-189
9℃ (approximately 1500~3500 below) and absolute pressure 10~
Hydrocarbonaceous fuel is reacted with free oxygen-containing gas by partial oxidation under conditions of 180 atmospheres to produce H2, CO, CO
2 and H20 and N2, CH4, COS, H2S
and one or more of the group Ar, and a certain effluent gas stream from a mixture of particulate carbon, the molar ratio of the effluent gas ratio from said gas generator (CO/H2)
(2) cooling the venting gas stream from (1) and introducing the cooled gas into a gas scrubbing purification zone; From there H2 and C
A clean fuel gas consisting of a mixture of O and one or more components in the group N2, CH4, CO2 and H20: a CO2-enriched gas stream; a slurry stream from particulate carbon in a liquid medium; and H2S. and (3) introducing the clean fuel gas stream from (2) into the combustion chamber of the gas turbine to produce a gaseous oxidized stream in (4). (4) The clean flue gas stream from (3) is used as a working fluid to generate power through an expansion turbine, and the clean flue gas stream is combusted in the combustion chamber to provide clean flue gas flow. (3) mixing at least a portion of said clean exhaust flue gas with a free oxygen-containing gas;
This produces a gaseous oxidation flow at

The sensible heat in at least a portion of the clean exhaust flue gas from the expansion turbine in step (4) is then advantageously used to preheat the clean fuel gas entering the combustion chamber of the gas turbine.

A second portion of the waste flue gas may be used to preheat a compressed gaseous oxidation stream comprising air and a portion of the waste flue gas.

This preheated oxidation stream is then introduced into the combustion chamber of the gas turbine.

Optionally, a portion of said gaseous oxidation stream may be introduced into a fuel gas generator.

This gaseous oxidation stream can be compressed by a compressor connected to the expansion turbine.

Optionally, CO2 recovered in the gas purification zone
The enriched gas stream and the effluent gas stream from the gas generator are mixed and the mixed gas stream is subjected to catalyst-free, reversible thermal conversion in a free-flow thermal conversion zone at a temperature of at least 816°C (1500'F). By supplementing the fuel gas stream with the water gas conversion reaction, its molar ratio (CO/H2) can be increased.

Furthermore, the gist of yet another aspect of the present invention is as follows.

(1) At least a portion of the CO2-enriched gas stream from stage (3) as a temperature control agent for the reaction in the reaction zone of a catalyst-free free-stream gas generator; conditions of autogenous temperature range of about 816-1899°C (below about 1500-3500°C) and absolute pressure of 10-180°C in the presence of at least a portion of the road gas and a temperature regulator selected from the group consisting of mixtures thereof; The hydrocarbonaceous fuel is reacted with free oxygen-containing gas by partial oxidation to produce H2,
CO, CO2 and H20 and N2, CH4, COS
, H2S, and a mixture of one or more substances in the group ArO and particulate carbon, the molar ratio (CO/H
(2) producing an effluent gas stream such that the effluent gas flow from (1) is at least 0.30 on a dry basis; (2) cooling the effluent gas stream from (1) by indirect heat exchange with water to produce water vapor; , (3) introducing the cooled effluent gas from (2) into a gas scrubbing purification zone from which H2 and CO and one or more of the group of N2, CH4, H20, and CO2 are introduced. Clean fuel gas consisting of a mixture of precepts:
C02 enriched gas stream; slurry stream derived from particulate carbon in the liquid medium; optionally separated into a gas stream derived from H2S and COS to obtain a clean fuel gas stream; (4) from (3); The clean flue gas stream is combusted with air in the combustion chamber of a gas turbine, and the resulting combustion gas is passed as a working fluid through an expansion turbine to generate power and waste flue gas. .

Also, at least a portion of the exhaust flue gas from the gas turbine is compressed at a pressure slightly greater than the pressure of the gas generator of stage (1), and then into it, at least one portion of the temperature regulating agent is added. Optionally, the part is introduced preferably in admixture with the free oxygen-containing stream.

This invention relates to an improved continuous method for generating thermal, electrical, and mechanical power using gas turbines.

According to this method, hydrocarbonaceous feedstocks containing liquid and solid fuels containing relatively high ash and sulfur content are used.
The fuel gas can be generated in a separate, catalyst-free, free-flow partial oxidation gas generator.

Additionally, the molar ratio (CO/'H2) of the fuel gas can optionally be increased by a reversible thermal conversion reaction.

Furthermore, the composition of the fuel gases can be improved to be combusted downstream of the gas turbine in the process.

That is, it passes through a step of producing steam by cooling through indirect heat exchange with water in a waste heat boiler, and a purification step of washing, removing solid suspended matter, sulfur compounds, etc.

The improved fuel gas is combusted with a gaseous oxidizer in the combustion chamber of the gas turbine to produce clean flue gas.

As discussed further below, electrical power is generated by passing this clean flue gas as a working fluid through an expansion turbine.

The gaseous oxidizing stream as the gaseous oxidizing agent is derived from a mixture of air and a portion of the exhaust flue gas from the expansion turbine.

The shaft power from the expansion turbine operates a generator that compresses the gaseous oxidant for introduction into the combustion chamber of the gas turbine and compresses the CO2 for use in non-catalytic thermal conversion. It can be used for etc.

Sensible heat in the clean flue gas exhausting from the gas turbine can preferably be used to preheat the clean gas and gaseous oxidation streams prior to their introduction into the combustor.

Even if the exhaust gas from the gas turbine is dissipated into the atmosphere after heat exchange, it does not substantially pollute the environment.

This can preferably also be done after passing it through a power generating turbine.

It is suitable for a portion of the exhaust flue gas from the gas turbine to be introduced into the gas generator with or without mixing with air.

The calorific value of this improved fuel gas is approximately 75 to 350 BT.
By maintaining the U/SCF range, the amount of nitrogen oxides (NOx) in the flue gas can be maintained below 10 ppm.

In the method of the present invention, first a continuous stream of fuel gas is produced in a refractory-lined reaction zone of a separate, free-flow, unfilled, uncatalyzed, partially oxidized fuel gas generator.

The gas generator is preferably a vertical steel pressure cooker and is described in U.S. Pat. No. 2,992,906 (F, E. Gu
ptill, Jr. ) is disclosed in the drawings.

Combustible carbon containing a wide range of organic materials can be reacted with free oxygen-containing gas in a gas generator in the presence of temperature regulating gas to produce fuel gas.

The term hydrocarbonaceous, as used herein to refer to various suitable feedstocks, is intended to include gaseous, liquid, and solid hydrocarbons, carbonaceous materials, and mixtures thereof. It is something.

In fact, virtually any combustible carbon containing organic material, or a slurry thereof, falls within the scope of this term.
These are included in the definition of "hydrocarbons".

For example, they include (1) pumpable slugs IJ- of solid carbonaceous fuels such as coal, particulate carbon, petroleum coke, coagulated sludge sludge, and mixtures thereof;
(2) a gas-solid suspension, such as a finely powdered solid carbonaceous fuel dispersed in either a temperature regulating gas or a gaseous hydrocarbon; and (3) a liquid hydrocarbon fuel in atomized form or a temperature regulating gas. There are gas-liquid-solid dispersions such as water and fine carbon particles dispersed in gas.

The sulfur content of these hydrocarbonaceous fuels ranges from about 0 to 10 weight percent and the ash content ranges from 0 to 15 weight percent.

The term liquid hydrocarbons, as used herein to refer to the appropriate liquid feedstocks, includes liquefied petroleum gas, petroleum distillates and residues, gasoline, naphtha, kerosene,
Crude oil, asphalt, gas oil, residual oil, tar sand oil and shale oil, coal oil, aromatic hydrocarbons (Hensen, toluene, xylene fraction, etc.), coal tar, cycle gas oil from fluid catalytic cracking processes, coke gas It is intended to include various substances such as furfural extracted oil, mixtures thereof, and the like.

Gaseous hydrocarbon fuels used in the text to refer to the appropriate gaseous charge include methane, ethane, propane, butane, pentane, natural gas, water gas, etc.
These include coke oven gas, refinery gas, acetylene tail gas, ethylene off-gas, combination gas, and mixtures thereof.

Gaseous and liquid charges can be mixed together and used simultaneously;
And they may contain paraffinic, olefinic, nandene, aromatic, etc. compounds in any proportion.

In addition, the definition of the term hydrocarbons includes carbohydrates,
Oxygenated hydrocarbons, including effluents and by-products from chemical processes containing cellulosic substances, aldehydes, organic acids, alcohols, ketones, oxygenated fuel oils, oxygenated hydrocarbonaceous organic substances, and mixtures thereof, etc. Contains primary organic substances.

The hydrocarbonaceous charge may be at room temperature or between about 316° and
It may be preheated to a temperature range of 649°C (approximately 600°C to below 1200°C), preferably below its decomposition temperature.

The hydrocarbonaceous feedstock can be introduced into the burner in liquid form or in a mixture with a gas as a temperature regulating agent.

Suitable temperature control agents include H20, CO2-enriched gas, a portion of the cooled clean gas from a gas turbine installed downstream of the process, or a mixture thereof with air, an air separation device as further described in the text below. and mixtures with the above-mentioned temperature regulators.

The ability of temperature control agents to be used for temperature control in the reaction zone generally depends on the carbon to hydrogen ratio of the feedstock and the oxygen content of the oxidizing stream.

It is not necessary that the temperature regulator contains some kind of gaseous hydrocarbon fuel, but it is generally substantially liquid hydrocarbon. It will be used together with pure oxygen.

CO2-containing gas stream, e.g. at least about 3 mol% CO2
If (dry base) is used in the absence of supplementary H20 as a temperature modifier, the molar ratio (CO/H2) of the released product gas stream will be enhanced.

As previously mentioned, this temperature control agent can be introduced in admixture with either one or both of the two reactant gas streams.

Alternatively, the temperature regulating agent can be introduced into the reaction zone of the gas generator by a separate conduit in the fuel burner.

According to the present invention, it is possible to arbitrarily increase the molar ratio (Co/H2) of the generated gas used as fuel in the gas turbine.

This allows a higher pressure ratio per turbine stage and thus a reduction in the number of stages.

Therefore, the size of the turbine can be reduced,
Its thermodynamic efficiency increases.

A CO2-containing temperature conditioning gas stream, such as substantially pure CO2 (at least 95 mole % CO2 dry basis) recycle from the gas purification zone described further below, is used to minimize the use of make-up H20. and preferably can be omitted.

The CO2 thus produced in the system can be used as a temperature control agent in a gas generator or in a reversible thermal conversion reaction as further described below.
Alternatively, it has the advantage that it can be used in both of the above locations.

As a temperature control agent, a gaseous stream consisting of 3 mol % or more of CO2 is used at a temperature range of approximately 538 °C (below approximately 1000 °C) and a CO2 to fuel weight ratio of approximately 0 at temperatures and pressures slightly above the generator pressure. It can be introduced into the reaction zone in the range of .3 to 1.0.

When a small amount of H20 is charged to the reaction zone through the burner, for example to cool the burner tip, the H20 can be either a hydrocarbonaceous charge, a free oxygen-containing gas, a temperature control agent, etc., or a combination thereof. Can be mixed with other things.

The weight ratio of water to feed hydrocarbon is in the range of about 0.0 to 1.0, preferably less than 0.0 to 0.2.

As used herein, the term free oxygen-containing gas refers to air, oxygen-enriched air, e.g. 21 mole % or more oxygen,
It is meant to include substantially pure oxygen, eg, 95 mole percent or more oxygen, with the balance being N2 and noble gases.

The free oxygen-containing gas has a temperature range of approximately 982°C (approximately 1800"
F).

The ratio of free oxygen in the oxidizer to carbon in the feedstock (
0/C, atom/atom) is preferably in the range of about 0.7 to 1.5.

The feed stream is introduced into the reaction zone of the fuel gas generator by the fuel burner.

It is preferred to use an annular burner such as that disclosed in US Pat. No. 2,928,460 (Dupois Eastman et al.).

This feed stream is catalyst-free in the reaction zone of the free-flow gas generator and has an autogenous temperature range of approximately 816-1899°C (approximately 15°C).
00-3500'F) and a pressure range of about 10-180 atmospheres absolute by partial oxidation.

This reaction time in the fuel gas generator is approximately 1-10 seconds.

The mixture of discharged fuel gases leaving the gas generator has the following composition (dry basis, mole %), assuming that noble gases are ignored:

CO15-57, H27010, CO2 1.5-5,
CH4 0.0-20, N20-75, H2S zero-2.
0 and COS zero 〇. 1. Unreacted fine particulate carbon (based on the weight of carbon feed) is about 0.2 to 20 weight percent in the case of liquid feed, but is usually negligible in the case of gas feed.

Dry basis molar ratio of gas released from the generator (CO/H2)
is at least 0.30, preferably in the range of 0.30 to 1.5.

The hot discharge fuel gas stream exiting the gas generator preferably has a temperature of about 816-1899°C (about 1
500-3500 below) and a pressure in the same gas generator from 10 to 180 atmospheres absolute, preferably from 15 to 60 atmospheres absolute, into a separate refractory-lined steel chamber.

This can be, for example, a spherical chamber 12 as shown in the drawings and disclosed in US Pat. No. 3,565,588.

This spherical chamber is unfilled and configured so that the gas flow within it is unobstructed.

A portion of the solid material entrained in the discharge stream of fuel gas falls and is removed from the outlet located at the bottom of the bulb chamber and is directed into the closed hopper, ie the flanged outlet 13 in the drawing.

If it is desired to further increase the molar ratio (CO/H2) in the effluent gas stream, the following non-catalytic thermal reverse water gas conversion operation stage can be used.

The supplemental CO2-enriched gas stream that is subsequently recovered in the process is
The gas is simultaneously introduced into the spherical chamber at a temperature within the range of and at a pressure slightly higher than that of the gas generator.

In such cases, approximately 0.1 to 2.5 moles of replenishing CO2 on a dry basis per mole of emitted fuel gas from the gas generator.
is preferably introduced into the sphere chamber.

These gases are mixed and heated to a minimum of 816°C (1500'
F) temperature, preferably about 816°C to 1538°C (about 1
By a non-catalytic thermoreversible water gas conversion reaction at temperatures in the range of 500 T to 2800 Y), CO2 reacts with a portion of the hydrogen in the emitted fuel gas stream from the generator to generate even more CO and H20. It generates.

This step increases the dry basis molar ratio (CO/H2) of the gas generator discharge gas stream by about 10-200%, with an increase of about 15-50% being preferred.

This effluent gas stream will therefore exit the thermal conversion zone with a dry base molar ratio (Co/H2) in the range from 0.3 to 6.0.

However, a molar ratio in the range of about 0.4 to 4.5 is preferred,
Advantageous is a molar ratio of 1.5 or more.

The high temperature adiabatic noncatalytic thermoreversible water gas conversion reaction described above begins in an insulated sphere chamber and continues in an insulated conduit connecting a side outlet of the sphere chamber and a flanged inlet to a waste heat boiler at the bottom. .

See US Pat. No. 3,723,344.

In this way, the fuel gas discharge stream undergoes a non-catalytic thermal conversion while passing through the process steps described above.

The residence time in the water gas conversion zone is approximately 0.1-5
It is in the range of seconds.

The above-described non-catalytic thermoreversible conversion reaction operation takes place in a free-flow, preferably adiabatic reaction zone, unfilled and separate from the fuel gas generator.

The preferred temperature and pressure conditions for carrying out the reversible thermal conversion reaction may be substantially the same as those for the fuel gas generator, but do not result in normal line temperature reduction due to sensible heat and endothermic reactions of the supplemental CO2. Make sure not to let it cool down.

Increasing the CO/H2 ratio of the fuel gas increases the heat of combustion per mole and increases its molecular weight.

Therefore, at 928 °K, Co + 4
0 2 → CO2 + 6 7. 6 4 Kcal /
?・Mole 44 mole weight H2+'r02 →H20 (gas) +5 7.8 0
Kcal/?・Mole 1 becomes 8 mole weight.

This improves the downstream thermal efficiency of the fuel gas and advantageously allows the use of smaller gas turbines.

In the semi-closed cycle gas turbine of the present invention, the combustion power of the combustion chamber is improved when the amount of excess air is less than i, compared to the open cycle gas turbine.

This discharged fuel gas stream then passes through a parallel waste heat boiler that has no contact with the water heat exchange device.

This results in a fuel gas flow of approximately 260-399°C (approximately 50°C).
0 to 750 below).

Here, the by-product water vapor is approximately 232-371℃ (approximately 450-371℃)
700″F) and can be used anywhere in the process of the present invention.

For example, the steam can be used as the working fluid in an expansion turbine for generating electricity, or it can also drive the compressor of a conventional air separation system, for example.

This water vapor is heated to approximately 399-593℃ (approximately 750-1100℃).
It can also be superheated to a temperature in the range of 'F) and this hot superheated steam can also be used as the working fluid of a steam turbine.

Although this high temperature superheating operation can be carried out in a furnace, it is preferable to combust a portion of the clean fuel gas to avoid environmental pollution.

The partially cooled fuel gas stream exiting the waste heat boiler is passed into a gas scrubbing zone where particulate carbon and other entrained solids are removed.

A slurry of particulate carbon in liquid hydrocarbon fuel is created in this washing zone and is recycled to the fuel gas generator as at least a portion of the feedstock.

Any conventional method suitable for removing suspended solids from a gas stream may be employed.

In one embodiment of the invention, the fuel gas stream is introduced into a gas-liquid cleaning zone and is cleaned by a cleaning fluid, such as a liquid hydrocarbon or water.

1 for suitable liquid-gas, tray-type columns.
A detailed explanation is given on page 18, lines 3 to 5 of Perry's Handbook of Chemical Engineers, 4th edition, published by McGraw-Hill in 1996.
Inners Handbook).

In this manner, the process fuel gas stream is passed upwardly through the wash column in direct and countercurrent flow with the appropriate wash fluid or diluted mixture of particulate carbon and countercurrent flow down the column of wash liquid. By contacting, particulate carbon is removed from the fuel gas.

A slurry of particulate carbon and wash liquor is removed from the bottom of the column and sent to a carbon separation or concentration zone.

This can be carried out by conventional equipment, such as sifting, centrifugation, gravity settling, or liquid hydrocarbon extraction (
This can be carried out by any suitable method such as (described in detail in the above-mentioned US Pat. No. 2,992,906).

The clean wash stream or mixture of wash liquid and particulate carbon is recycled to the top of the column for further fuel gas scrubbing.

Other suitable conventional gas cooling and cleaning methods may also be used in conjunction with or in place of the cleaning power ram described above.

For example, the fuel gas flow may be introduced below the surface of the quenching and cleaning fluid pool by an inclined tube arrangement.

Alternatively, the fuel gas stream may be passed through various cleaning stages, such as an orifice type cleaning device, or a penturi or nozzle type cleaning device.

(Chemical Engineers Handbook by Periichi, p. 18, 54-56
In gaseous hydrocarbon fuels such as natural gas or methane, there is virtually no particulate carbon.

In such cases, the gas scrubbing step described above is not necessary.

In the gas purification zone, CO2, H2S, COS, H
20, NH3 and other gaseous impurities can be removed from the cooled and scrubbed gas stream exiting the gas scrubbing zone.

Usual conventional methods such as cooling and physical or chemical absorption with solvents such as methanol, N-methylpyrrolidone, triethanolamine, propylene carbonate, or amines or hot potassium carbonate can be used. .

In the solvent absorption method, the C02 fraction absorbed in the solvent is released by a simple flush.

Remove other items by stripping.

It is economical to use nitrogen for this purpose. The use of conventional air separation equipment to produce substantially pure oxygen (95 mole % O2 or more) for use as oxygen-enriched gas in fuel gas generators is a low cost alternative. Nitrogen is obtained as a product.

The regenerated solvent is then recycled to the absorption column for reuse.

If necessary, the process? The cleaning can be completed by passing the solution through iron oxide, zinc oxide, or activated carbon to remove residual traces of H2S or organic sulfides.

If you need it, about 251. A CO2-enriched gas stream consisting of CO2 in the range of 0 mol %, preferably 98
．． 5% or more can also be produced for use in the catalystless thermal reverse water gas conversion stage of the process.

It is also optional to recirculate the recovered CO 2 stream to the fuel gas generator for use as all or part of the temperature conditioning gas.

In such cases, small amounts of H2S and COS may be included in the CO2 stream.

Similarly, H2S- and COS-containing solvents can be regenerated by flashing and slipping with nitrogen, or alternatively, they can be regenerated by heating and refluxing under reduced pressure without the use of inert gas. You can also.

This H2s and COs can then be converted into sulfur through an appropriate process.

See, for example, Kirk Ozmer Encyclopedia of Chemical Technology, 2nd Edition, Volume 19, Joie Wiley, 1969, 353.
Page (Kirk-Othmer Encycle Op.
ediaof Chemical Technology
y1Second EditionVolume 1
9, John Wiley, 1969, P
Claus (C
elemental sulfur can be produced from H2S using the H2S method.

Kraus' Plant Tilgas can be removed by chemical combination with limestone or by suitable commercial extraction methods.

In general, the composition of clean fuel gas is approximately H2 10-60, CO15-60, CH4 in mole percent (dry basis).
0.0-25, co2 o. o~5, N20.0~7
It is 5.

The heat of combustion is at least 70, suitably from 75 to 3,501 and preferably from 75 to 150, such as 90, in BTU/SCF.

The clean fuel gas stream exiting the gas purification zone has a temperature of approximately 38-4
Range of 27℃ (approximately 100~800℃), absolute pressure 10~
The range is 180 atm, preferably absolute pressure 15~
The pressure is 60 atmospheres.

Most preferably, the pressure of the fuel gas at this point is substantially similar to that produced in a low pressure drop fuel gas generator in a conventional line.

Air is then added to the combustion chamber of the gas turbine to cause combustion.

However, prior to the fuel gas stream being admitted to the combustion chamber of the gas turbine, it is subjected to indirect heat exchange with a portion of the exhaust hot flue gas stream exiting the main expansion turbine downstream in the process (approximately 204-427°C). Approximately 400-800'
Preheating to a temperature within the range of F) is also optional and preferred.

A gaseous oxidation stream of about 1.0 to 3.0 volumes per volume of clean fuel gas is simultaneously introduced into the combustion chamber.

This gaseous oxidation stream, as further detailed below, consists of a free oxygen-containing gas (preferably air) mixed with a portion of the exhaust flue gas from the expansion turbine. Volume to gas ratio is approximately 0.20:2
0, preferably in the range of 0.4 to 1.2.

The preheated clean fuel gas stream is then combusted with the gaseous oxidation stream in a combustion chamber of a gas turbine.

The gaseous oxidation flow is about 204-427℃ (about 400-sooy
When introduced into the combustion chamber of a gas turbine at a temperature within the range of 760-1648°C (about 1400
~3000 below), typically 871-1149°C
(1600-2100T) and about 3.40
~68.05kg/crA (approximately 50~1000ps
ig) or more, preferably 6.80 to 2
7.2 2k9/cJ (100~400psig
) or higher, with typical mole percent analysis values as follows; CO24-10, H20
3-6, N27585, and O2 5-100 Very small amounts of nitrogen oxides (NOx') are found in the flue gas.

This is because the combustion chamber is relatively cool, primarily due to the relatively low temperature adiabatic flame of the improved fuel gas.

Furthermore, the flue gas has zero SO2 content and is virtually free of entrained particulates.

The clean flue gases leaving the combustion chamber are passed as working fluid to at least one power-generating expansion turbine.

A variable speed transmission is connected to the shaft of the turbine, for example,
This may drive at least one generator and at least one turbo compressor.

The gaseous oxidation stream before being introduced into the combustion chamber of the gas turbine and the carbon dioxide leaving the gas purification zone before being recycled to the fuel gas generator or the above-mentioned spherical mixing chamber are brought to a suitable pressure by said turbo compressor, e.g. It can be compressed to 10 to 190 atmospheres.

? Clean exhaust flue gas has a temperature of approximately 427 to 649°C (approximately 800 to
Temperatures within the range of 1200”F and absolute pressures of approximately 1.0
It exits the main expansion turbine at ~7.0 atmospheres.

Approximately 0 to 50 volume percent of this stream is optionally separated and transferred to a heat exchanger for indirect (non-contact) heat exchange with clean flue gas on its way to the combustion chamber of the gas turbine, as previously described. You can also pass through it.

After this heat exchange, the cooled and clean exhaust flue gas can be dissipated into the atmosphere through the chimney.

Therefore, since gaseous impurities have been removed beforehand, virtually no air pollution occurs.

However, in this case it is preferred that the heat-exchanged waste flue gas stream is expanded once more in the power generation turbine before being discharged.

The remainder of the clean exhaust flue gas stream from the main expansion turbine is passed through a heat exchanger for indirect heat exchange with the compressed gaseous oxidation stream.

In this way, the gaseous oxidation stream is introduced into the combustion chamber of the gas turbine at a
800° C.).

Approximately 38 to 149℃ (approximately 10
Approximately 20 to 70 volume percent of the waste flue gas stream cooled to a temperature in the range of 0 to 300 degrees below) can be dissipated into the atmosphere without causing pollution, but should preferably be expanded once again through the power generation turbine. It is preferable to leave it alone.

The remainder of the exhaust flue gas cooling stream mixes with the free oxygen containing gas to produce the gaseous oxidation stream.

The free oxygen-containing gases include air, oxygen-enriched gas (greater than 21 mol % 02), and substantially pure oxygen (95 mol % 0
2 or more).

Thus, it is preferred to introduce it into the charging system of a compressor connected to the shaft of the main expansion turbine at atmospheric temperature and pressure conditions of air.

This mixture of air and waste flue gas is what has been referred to above as the gaseous oxidation stream.

It has the following typical analytical values for mole percent:

CO 3.0-5.0, H20 1.0-4.01N
75-85, 010-20, and Ar2 0.9-1.5 This gaseous oxidation stream is preferably in the range of about 5 to 65 atmospheres absolute pressure in at least one compressor connected to the shaft of the main expansion turbine. Compress to desired pressure.

Typically, this gas stream is cooled before and during its entry into the combustor.

This gaseous oxidation stream is then preheated as described above before entering the combustion chamber.

Optionally, about 0 to 20 volume percent of this gaseous oxidation stream is introduced into the gas generator as at least a portion of the temperature regulating gas.

Further, the present invention is as shown in the second embodiment (FIG. 2) below.
Temperatures within the range of 7-649°C (about SOO-1200 below) and absolute pressures of about i. Sensible heat recovery in the clean flue gas exiting the expansion turbine in the range from 0 to 7.0 atmospheres can be accomplished by heat exchange with water vapor produced downstream of the waste heat boiler from the gas generator.

This results in approximately 399-649℃ (approximately 750-1200℃)
High temperature superheated steam having a temperature in the range of (lower) will be produced.

This hot superheated steam can be used as a working fluid for an expansion turbine.

The axial shaft of the steam turbine can be coupled, for example, to the shaft of the turbo compressor or to the generator or to both by means of a variable drive.

The clean flue gas is then preferably compressed in the turbo compressor to a pressure in the range of 10 to over 180 atmospheres absolute at a temperature in the range of about 204 to 316C (below about 400 to 600C).

This compressed gas can then be recycled to the fuel gas generator as all or part of the temperature regulating gas.

Alternatively, the clean flue gases can optionally be vented to the atmosphere without polluting the atmosphere.

Alternatively, sensible heat in the flue gas exiting the expansion turbine can be selectively removed by preheating the air introduced into the combustion chamber of the gas turbine, thereby generating more high-pressure water vapor. can be recovered by preheating the boiler feed water.

The process fuel gas produced in the gas generator and cooled in the waste heat boiler is e.g. Its use as a working fluid is also optional.

For a more complete understanding of the invention, reference is made to the schematic drawings which illustrate the above process in detail.

Although this drawing illustrates a preferred embodiment of the process of the invention, it is not intended to limit the continuous process to the particular equipment or materials described therein.

According to Figure 1 of the accompanying drawings, a free-flow non-catalytic refractory lined fuel gas generator 1 as described above has an axially aligned inlet 2 with flanges facing upstream and a flanged inlet 2 facing downstream. A flanged outlet 3 is provided.

An annular burner 4 as described above is mounted at the inlet 2 with a central passage 5 parallel to the axis of the gas generator 1.

The passageway 5 has an upstream end 6 and a conical downstream end 7.

A concentric ring-shaped passageway 8 leading to an upstream port 9 and a downstream conical outlet 10 are also provided.

At the outlet 3 of the gas generator 1 there is a refractory-lined free-flow spherical chamber 12.
A flanged head 11 is connected.

The chamber 12 has a downstream normally closed flanged outlet 13 for ash removal, a side flanged port 14, and a fireproof lined side discharge duct 15, etc., the downstream end 16 of which connects to a waste heat boiler 17. has been done.

For example, water in line 18 passes through tubes 19 in boiler 17 for indirect heat exchange with hot gas passing outside the tubes 19.

This water evaporates and exits as water vapor through the pipe 20.

Other suitable boilers can also be used.

A liquid or gaseous hydrocarbonaceous feed as described above is introduced into the system via line 25, valve 26, and lines 27 and 34.

Further, the pump 28 further includes the pipe lines 30, 31, the valve 32,
The concentrated slurry of fine carbon with liquid hydrocarbons or water pumped up from the carbon separation zone 29 via line 33 is injected into line 34 for mixing of the feed streams.

This feed mixture is then preferably preheated in a heat exchanger 220 and introduced via line 221, inlet 9 and annular channel 8 or burner 4 into reaction zone 35 of gas generator 1.

A portion of the steam produced in the waste heat boiler 17 is passed through line 20, lines 36-38, valve 39, lines 40, 41 and the central passage 5 of the burner 4 as a temperature regulating fluid to the reaction zone 35. Pass it inside.

A second portion of the steam leaving the boiler 1T can be used as the working fluid of the steam turbine.

For example, this water vapor flows through the pipes 20, 36, 37, 45
, 46, the expansion turbine 4 via the valve 47 and the line 48.
It passes through the 9th grade.

The discharged water vapor leaves via line 50 (FIG. 2: 186).

The expansion turbine 49 is a turbo compressor 51 (Fig. 2: 50)
to compress the air coming in through the pipe 52,
The compressed air leaves the compressor by line 53.

This compressed air is then passed through the pipe 53, the valve 55, and the pipes 56, 5.
7, is introduced into the reaction zone 35 of the gas generator 1 via the valve 58 and the lines 59, 41 and the central passage 5 of the burner 4.

Alternatively, if two stages of air compression are required, as shown in FIG. 2 of the accompanying drawings, air from line 170 can be compressed in turbo compressor 168 and lines 183, 18
4, 185 and 52 to the compressor 50.

It is also optional that instead of introducing all or part of the air from the turbo compressor 51 (FIG. 2: 50) into the gas generator 1, substantially pure oxygen is introduced.

Oxygen and nitrogen are attached to a normal air separation device A.
It can be produced by SU42, from which pipe 6
Substantially pure oxygen leaves via line 3 and nitrogen leaves via line 64.

Nitrogen is added later in the process of the invention to gas purification zone 65.
used in

A portion of the steam produced in the waste heat boiler 17 can be used to power the steam turbine 69.

In addition, an air compressor 71 used in the air separation device 42
can be used to indirectly provide power.

In such a case, water vapor will flow through pipes 20, 36, 37, 4
5, 66, valve 67, line 68, and steam turbine 69
It passes through as a working fluid and exits through conduit 70.

Air passes via line 72 into a connected turbo compressor 71 .

This air is compressed and passed through the air separation device 4 through the pipe line 73.
2 Go inside.

The oxygen in line 63 is compressed by a steam-driven reciprocating or centrifugal compressor 74 and then passed through line 75, valve 76, lines 77, 78, valve 79, lines 80, 41 to the center of burner 4. Enter aisle 5.

Steam for driving compressor 74 can be obtained from boiler 17 via lines 20 , 36 , 85 , valve 86 , and line 87 .

Alternatively, as shown in FIG. 2, the air sent to air separation device 42 may be a slip stream (not shown) from turbo compressor 168.

Thereby, the dynamic power required for air separation can be minimized by producing a gas containing 60-80% free oxygen.

Preferably, a portion of the steam from waste heat boiler 17 is superheated downstream of the process in heat exchanger 155 by indirect heat exchange with waste flue gas from line 154, as shown in FIG. .

In such case, water vapor enters line 158 through lines 20, 88, valve 89, and line 90.

This high-temperature superheated steam is transferred to the steam turbine 16 as described later.
1 working fluid.

The temperature regulating gas introduced into the reaction zone 35 instead of or in combination with water vapor is a CO2-containing gas, for example air, and in this process the pipes 187 (Fig. 2: 1
00) or a small amount of H2S. A mixture of a CO2-enriched stream with or without COS or a mixture of air and the turbine exhaust gas with a CO2-enriched stream is suitable.

This CO2-enriched stream can be obtained later in the process from the gas purification zone 65, which is the purification step of the discharge flue gas stream produced in the gas generator 1.

It then exits the gas purification zone 65 via the pipe 91 <C
The O2-enriched stream is compressed in a turbo compressor 92 and passed through lines 93,
94, valve 95, pipe line 96, 57, valve 58, pipe line 59, 4
1, and the gas generator 1 via the central passage 5 of the burner 4
is sent to the reaction zone.

A portion of the CO2-enriched stream is connected to line 97, valve 98, line 9.
9 and flanged port 14 into the spherical mixing chamber 12 where a reversible, non-catalytic hydrothermal gas conversion reaction takes place with a portion of the hydrogen in the discharged fuel gas leaving the gas generator 1; The molar ratio of the fuel gas stream for this process (CO/
H2) is preferably increased.

In this way, it is also optional to introduce the compressed gaseous oxidation stream which is subsequently produced in line 187 of the process into the reaction zone 35 of the gas generator 1 as a temperature regulating agent.

For example, the regulator may be present in line 101, valve 102, line 10
3, 78, valve 79, pipe line 80, 41, and burner 4
can be introduced into the reaction zone via a central passage 5.

Substantially pure oxygen from line 77 may be mixed with the oxidizing gas stream in line 78.

Alternatively, a portion of the gaseous oxidation stream can be mixed with the hydrocarbonaceous feed and introduced into the reaction zone.

As mentioned above, in this process, the pipe line 1 shown in FIG.
The clean flue gas produced later in 00 can be passed into the reaction zone 35 of the gas generator 1 as a temperature regulator.

For example, it is line 101, valve 102, line 103, 7
B, valve 79, lines 80, 4L and central passage 5 of burner 4.

Free oxygen containing gas from line 77 is mixed with flue gas in line 78.

Alternatively, the clean flue gas can be mixed with the hydrocarbonaceous charge and sent to the reaction zone.

For example, in FIG. 2, clean flue gas in line 100 passes through line 104 and mixes in line 105 with hydrocarbonaceous material from line 106.

This mixture is heated by a heater 107 and passed as a gaseous raw material through lines 108, 182 and concentric ring-shaped passages 8 into a gas generator.

It is also optional to mix the CO2 gas with the discharged fuel gas produced in the reaction zone 35 in the figure and convert it thermally in the sphere chamber 12 and also in the duct 15 and to cool it in the waste heat boiler 17.

This cooled fuel gas flow flows through lines 111, 112 and valve 1.
13, pipe lines 114, 115, and flanged inlet 11
6 to a commonly used gas scrubbing zone 110.

In this case, a portion of the partially cooled effluent gas stream is sent as a working fluid for one or more expansion turbines located at different points in the system, i.e. to gas washing zone 110 or to gas purification zone 65. Using this before or after entering is also optional.

For example, the discharge flow of the raw material fuel gas from the pipe line 111 is
7 valve 118 and line 119 to expansion turbine 120
can be sent to.

Fuel gas coming out of the turbine 120 is passed through a pipe 121 and a valve 12.
2. Introduce into the pipes 123, 115 and the flanged port 116 of the washing zone.

Turbo compressors 124 and 125, on the other hand, are driven by expansion turbine 120 and can be used to compress other fluids in the system.

For example, nitrogen is introduced into compressor 124 by line 126 and dissipated by line 127.

Air is introduced into compressor 125 by line 128 and dissipated by line 129.

Partially cooled in the waste heat boiler 17, the discharged fuel gas from the fuel gas generator 1 is converted into gas by direct contact with a clean cleaning liquid or a diluted slurry of recirculated particulate carbon and cleaning liquid in a gas cleaning zone 110. Wash zone 11
It is further cooled and cleaned by cleaning at 0.

This clean cleaning fluid can be introduced into the cleaning zone via line 134, valve 135, and lines 136 and 137.

For example, a gas scrubbing zone is a vertical scrubbing tower with a plurality of horizontal shelves.

In such cases, the gas rises through the column and comes into contact with the cleaning liquid, such as water or liquid hydrocarbons, flowing down the column under its own weight at the top of each shelf.

This washes the particulate carbon out of the fuel gas.

The fuel gas becomes progressively cleaner as it moves up the detergent ram, while the particulate carbon condensate in the scrubbing fluid becomes progressively larger as it falls down the column.

This slurry of particulate carbon and cleaning liquid exits the bottom of the cleaning column 110 and enters the carbon separation zone 29 via line 138.

In the carbon separation zone 29, the slurry of particulate carbon and cleaning liquid can be treated by conventional separation methods to separate into a clean cleaning liquid and a slurry stream of particulate carbon in a liquid medium.

In this manner, a fine carbon slurry of approximately 2% by weight water from line 138 of gas scrubbing zone 110 is mixed with naphtha and introduced into a decanter (not shown) of carbon separation zone 29.

A dispersion of particulate carbon and naphtha is now formed, and clean water is recovered from the decanter and recycled as at least a portion of the cleaning liquid to the gas scrubbing zone 110 via line 140, pump 139, W lines 141, 137. .

Fresh heavy liquid hydrocarbon fuel oil from line 43 is introduced into a distillation column (not shown) in carbon separation zone 29 along with a fine carbon-naphtha dispersion from the decanter.

Naphtha is removed from the top of the distillation column and recycled to extract further water from the fine carbon slurry.

The preheated slurry of finely divided carbon and heavy liquid hydrocarbon fuel oil from the bottom of the distillation column is transferred to line 30 by pump 28.
, 31, valve 32, lines 33, 34, preheater 220, line 221, inlet 9 and concentric ring-shaped passage 8 into the reaction zone 35 of the gas generator 1 as described above. Can be put in.

The clean fuel gas stream leaving the gas scrubbing zone 110 is routed through line 14.
2 into a conventional gas purification zone 65.

H2S and COS are removed from the fuel gas and exit separation zone 65 via line 143.

In the Claus device 144, air is sent through a line 145, H2S is combusted, becomes solid sulfur, and exits through a line 146, and water exits through a line 14γ.

Remaining nitrogen and other non-contaminant gaseous impurities are exhausted via line 148.

Also shown in FIG. 2, clean fuel gas in line 149 is introduced into the combustion chamber 150 of the gas turbine and combusted with compressed air from line 151 to produce clean flue gas, which is It exits the combustion chamber 150 via 152.

The clean flue gas passes through the main expansion turbine 153 and then through line 154, heat exchanger 155, line 156, turbo compressor 157, and line 100.

As mentioned above, this compressed clean flue gas in line 100 is optionally recycled to the fuel gas generator 1 as, or as part of, temperature conditioning gas.

Sensible heat in the clean flue gas is also preferably recovered by heat exchange with steam entering heat exchanger 155 via line 158, whereby the water vapor becomes superheated steam and is transferred via line 159. I am leaving.

This superheated steam passes through steam turbine 161 and turbo generator 166 as working fluid.

These devices can be connected by a fluid coupling 160.

Expansion turbine 153 to power turbo generator 167, turbo compressor 92, and turbo compressor 168
can be used.

To link these devices, e.g. fluid coupling 16
A variable speed joint such as 9 can be provided.

Air also enters the turbo compressor 168 in line 170 and the compressed air is passed into the combustion chamber 150 or introduced into the fuel gas generator 1, as previously described.

1, the clean fuel gas stream in line 149 is preheated in heat exchanger 150 and introduced into gas turbine combustion chamber 152 via line 151.

The temperature of the clean fuel gas can be increased by indirect heat exchange with a portion of the exhaust gas from the main turbine 153 in a heat exchanger before dissipating it to the atmosphere.

For example, a portion of the exhaust gas is routed through line 155, valve 156,
Pipe line 157, heat exchanger 150, pipe line 158, Yuichi bottle 1
59 and is discharged from the chimney through a pipe 160.

At the same time, another portion of the exhaust gas from the turbine 153 passes through line 165, heat exchanger 166, lines 167, 168 and 169 where it passes through line 170, the compressor 111,
It is mixed with air entering the system via line 172.

The mixture of air and clean waste flue gas in line 169, hereinafter referred to as the gaseous oxidation stream, is cooled in heat exchanger 173 and passed through line 174, turbo compressor 175, and intermediate cooler 1.
76, Yu-1 Bo compressor 177, pipeline 118, heat exchanger 1
66 and pipes 1γ9 and 180 to the combustion chamber 152.

A portion of the preheated gaseous oxidation stream in line 179 is transferred to line 1.
85, valve 186 and lines 187, 101 into the fuel gas generator 1.

The clean fuel gas is combusted in combustion chamber 152 to become clean flue gas and exits via line 188.

The flue gas then passes through the main expansion turbine 153 as a working fluid.

Turbo compressors 92, 175, 177, and 17i, generator 189, etc. are driven by expansion turbines 153, 159.

These devices can be connected to a single shaft or by a fluid coupling 190, for example.

As mentioned above, the clean hot exhaust flue gas leaves the main expansion turbine 153 via line 154, which is conveniently divided into two streams, lines 155 and 165.

The gas capacity of each stream can be determined by conventional heat and weight balances.

A portion of the exhaust gas from turbine 153 is transferred to heat exchanger 16
It is also optional to remove it before or after 6 and release it into the atmosphere.

For example, the exhaust gas is passed through line 195, valve 196, and line 197.
, turbine 159 , and line 160 .

The clean exhaust flue gas in line 160 may be dissipated into the atmosphere through a chimney without polluting the atmosphere, but is preferably used for work by an expansion turbine 159 before being dissipated.

It is also optional to pass a portion of the clean waste gas in line 160 by line 101 into gas generator 1 at the front end of the process system.

Alternatively, relatively low temperature heat can be recovered from the gas turbine cycle or exhaust gas stream in line 154, as shown in FIG.

The recovered relatively low-temperature heat can also be used as an energy source for absorption refrigerators.

This refrigerator could be used for air separation and CO2 removal by condensation or absorption in cryogenic solvents, the waste gases being used for preheating the gas generator feed stream, preheating the wash fluid entering the gas wash zone, Alternatively, it can also be used to generate water vapor.

This low-temperature heat is CO such as MEA or K2CO3 solution/liquid.
It could also be used to regenerate liquid absorbents for 2.

A turbine-driven generator 189 in FIG. 1 provides the power required to drive the major mechanical and electrical equipment in the process, including the gas regeneration and air separation systems.

The remaining power will be output to the outside.

This design has the great practical advantage that plant operations can continue without dependence on external power sources.

Alternatively, the mechanical force applied to the joint 190 can also be supplied externally.

EXAMPLES The following examples illustrate preferred embodiments of the method of the present invention for producing improved fuel gases and combusting said fuel gases in a gas turbine integrated into the system. .

However, while various preferred modes of operation have been set forth, the examples should in no way be construed as limiting the scope of the invention.

The process is continuous and the flow rate is specified on a time basis for all feed streams.

In a conventional vertical non-catalytic free-flow refractory-lined fuel gas generator, 1,505,6400 standard cubic cubic feet (SCF) of fuel gas is produced by partial oxidation of a hydrocarbonaceous fuel, as described in further detail below. occurred.

A portion of the exhaust flue gas from a gas turbine located downstream of the process, mixed with air, was introduced to regulate the temperature in the reaction zone.

Fuel gas was produced in the generator at an autogenous temperature of about 2180'F and a pressure of about 27 atmospheres absolute.

Its average residence time in the gas generator is approximately 2 seconds.

The composition of the fuel gas exiting the generator is as follows in mole percent.

C015.51, H2 10.17, CO24.55,
H05.12, N63.71, CH40. 0 0,
22 ArO. 80, H2S0.15, coso. oi about 21
Approximately 4800 pounds of unconverted particulate carbon is entrained in the discharged fuel gas stream.

The dry fuel molecular weight after removal of H20 particulates, CO2 and H2S in the downstream gas purification zone is 25.17.
The net heat of combustion or less is 82.6BT
It is U/SCF.

? The above fuel gas is produced by continuously injecting it into a partially oxidized fuel gas generator by means of an annular burner in the following manner.

4 7,638 ky (104,804 lb) of pumpable slurry continues to be produced in this process
A hydrocarbonaceous fuel consisting of

This slurry is preheated to a temperature of about 260° C. (about sooy) and its composition is reduced to 4804 lbs.
00 pounds) is the elemental analysis value (Wt.%) of Togi
Has: C86.1%, H211.0%, S2. O%
, N20.8%, and ash 0.01.

Furthermore, the API specific gravity of this crude crude oil is 10.9, the heat of combustion is 18278 BTU per pound, 50°C (below 122)
Viscosity at 822 Saybolt seconds
ltSecond Furol).

Also, approximately 682,500 OSCF of air and 4 9 8 5
The flue gas of 0 0 O SCF was heated to 260°C (so
oy) and introduced into the reaction zone of the gas generator by the burner.

All hot discharged fuel gas exiting the gas generator passes through a refractory lined spherical free flow chamber located at the downstream outlet of the fuel gas generator.

A portion of the entrained solids falls out of the fuel gas stream and is removed by an outlet located at the bottom of the spherical chamber.

This discharged fuel gas stream is cooled to a temperature of about 427° C. (about sooy) by a waste heat boiler and indirect heat exchange with water as the coolant.

At the same time, the waste heat boiler has a temperature of approximately 427°C (approximately 800'F")
produces steam at a temperature of

In this case, it is optional to operate a compressor in a conventional air separation unit to produce substantially pure oxygen and nitrogen.

It is also optional to introduce the produced oxygen into a gas generator and nitrogen into a gas purification zone located downstream of the process to effect separation of gaseous impurities.

Substantially all particulate carbon and some residual solids are removed from the fuel gas stream in a conventional gas-liquid scrubber column.

A slurry of fine carbon and crude oil is produced here and fed into the gas generator as a feedstock as described above.

CO2, H2S1C from the fuel gas stream in the gas purification zone
OS1 and optionally H20 are removed to produce an improved clean fuel gas stream of substantially the following composition (dry basis): H2 11.37, C017.34, N2
70.39 and Ar0.90 (mol%).

Approximately 1 3 4 6 3 0 0 of this clean fuel gas flow
The OSCF is introduced into the combustion chamber of the gas turbine at a temperature of about 800'F and a pressure of about 20 atmospheres absolute.

At the same time, at substantially the same temperature and pressure as said clean fuel gas, about 11.506 kg (about 25313
lb), and optionally H20, into the combustion chamber where the fuel gas is being combusted.

a temperature of about 1093°C (about 2000'P), and about 15
At atmospheric pressure, mole percent N279.17, CO
27.79, H204.99, Arl. 015 and 0
2 Clean flue gas consisting of 6.784 44,579,000
SCF has been generated.

The clean flue gas was passed through an approximately 338,900 horsepower expansion turbine.

A generator is connected to and driven by the shaft of the turbine, and at least one compressor is connected to compress the gaseous oxidation stream and direct at least a portion thereof to the combustion chamber of the gas turbine. It is what it is.

A temperature of about 945'F and a pressure of about 1
．． Advantageously, the waste flue gas dissipated from the expansion turbine at 5 atmospheres is divided into two streams.

That is, as shown in FIG.
6 7 0 0 O SCF is passed through a heat exchanger 150 for indirect (non-contact) heat exchange with the clean fuel gas from the gas purification zone before being sent to the turbine combustion chamber.

The exhaust flue gas is heated to 316°C (600″F) after the heat exchange.
Although the gas is passed through a turbine at a temperature of 100 mL and then released into the atmosphere, it does not cause air pollution.

This turbine can produce 15,600 horsepower.

The remainder of the residual exhaust flue gas stream from the main expansion turbine 153 is passed to a heat exchanger 166 to provide 2,613,100 OSCF of air and 1,935,400 OSCF of air.
and indirect heat exchange with a gaseous oxidation stream consisting of the exhaust flue gas of F.

Prior to said heat exchange, the gaseous oxidation stream is compressed by at least one compressor.

The compressor is preferably powered by the main expansion turbine and its pressure is slightly greater than that of the fuel gas generator.

As described above, at least a portion of the gaseous oxidation stream preheated to a temperature of about 427° C. (about sooy) is introduced into the combustion chamber of the gas turbine.

To demonstrate an embodiment of the present invention of utilizing a portion of the CO2 recovered in the gas purification zone to improve the composition of the fuel gas by increasing its molecular weight and heat of combustion, CO2-enriched gas containing more than 95 mole % CO2 exiting the zone
The 0 0 O SCF was compressed by a turbo compressor driven by the main gas turbine to a slightly higher pressure than in the fuel gas generator.

This compressed CO2 stream at a temperature of about 800'F was introduced into a free-flow refractory lined vessel, such as spherical vessel 12 in FIG. 1 of the drawings.

and therein about 1 5 0 4 of the discharged fuel gas exiting the gas generator at a temperature of about 1193°C (about 2180'F).
8000 SCF.

At temperatures above about 816°C (about 1500'F), a non-catalytic adiabatic thermoreversible water gas conversion reaction between CO2 and H2 occurs in free-flow refractory-lined chamber 12 and line 15, and The molar ratio (CO/H2) of the flowing process gas stream was increased.

An improved fuel gas was produced having the following mole % composition: CO 16.61, H 2 6.23, CO 2 13.25.
, H207.05, N25 6.0 0, CH40.0
0, ArO. 72, H2S0.13, cos o,
After CO2 and H2S are removed, the molecular weight of the thermally converted dry fuel gas increases to 26.09, and the net heat of combustion per mole is ss. Increased to 3BTU/SCF.

When this fuel gas is combusted in the gas turbine combustion chamber, the expansion power is increased even more than the fuel gas produced in the embodiment described above.

Furthermore, compared to an open cycle process in which all waste flue gases from the expansion turbine are dissipated directly to the atmosphere, the method of the present invention reduces the intake of excess air required for effective combustion by a factor of 10 to 10. It is less than 1/2.

EXAMPLE ■ In a conventional vertical, non-catalytic, free-flow, refractory lined fuel gas generator, the fuel gas improved by the present process involving partial oxidation of a hydrocarbonaceous fuel as further described below is 11
3700 standard cubic feet (SCF) were produced.

Exhaust flue gas from a gas turbine located downstream of the process was introduced into the reaction zone to regulate the temperature therein.

The average residence time in the gas generator in which the fuel gas was produced at an autogenous temperature of about 2575'F and a pressure of about 24 absolute was about 3 seconds.

The composition of the fuel gas exiting the generator in mole percent was as follows:

C023.77, H15.82, CO2 1.44, 2 H202.67, N2 55.38, CH, None, ArO
．． 71, H2S 0.20, COS 0.01 Approximately 45.3 pounds of unconverted particulate carbon was entrained in this fuel gas discharge stream.

The molecular weight of the dry fuel gas after removal of CO2 and H2S is 23.8, and the net heat of combustion or less is 1
It was 24.9 BTU/SCF.

The above-mentioned fuel gas was produced by continuously introducing the following feedstock into a partially oxidized fuel gas generator by means of a ring burner.

A hydrocarbonaceous fuel consisting of 5.3 lbs. of pumpable sluff IJ-10 continues to be produced in this process.

This slurry was preheated to a temperature of about 149°C (about 300'F) to produce 45.3 pounds of particulate carbon and the following final analysis values (Wt, %) C: 86.1%, H2: 11.0
%, 82.0%, N20.8%, and ash 0.01.

Furthermore, this reduced crude oil has an API specific gravity of 10.9,
1s 200 BTU/and 5 per pound of combustion heat
It had a Saybolt-second-Flor viscosity of 822 at 0°C (1221').

Also, the flue gas 6 at a temperature of 316°C (600'F)
5 8 0 Air mixed with SCF 7 4 3 5
0 SCF was introduced through the burner into the reaction zone of the gas generator.

All of the hot discharged fuel gas exiting the fuel gas generator passed through a refractory lined spherical free flow chamber located at the downstream outlet of the fuel gas generator.

A portion of the entrained solids was allowed to fall out of the fuel gas stream and removed by an outlet located at the bottom of the sphere chamber.

The fuel gas stream was cooled to a temperature of about 427° C. (about sooy) by a waste heat boiler and indirect heat exchange with water as the coolant.

At the same time, steam at about 427° C. (about SOO″F) was generated in the waste heat boiler.

A portion of this water vapor can be used to operate a gas compressor in a conventional air separation unit to produce substantially pure oxygen and nitrogen.

Optionally, oxygen is introduced into the gas generator and nitrogen is introduced into a gas purification zone located downstream of the process to effect separation of gaseous impurities.

Substantially all particulate carbon and residual solids were removed from the fuel gas stream in a conventional gas-liquid scrubber column.

A slurry of fine carbon and crude oil was produced and introduced as a charge into the gas generator as described above.

CO2, H2S, COS, and optionally H20 were removed from the fuel gas stream in the gas purification zone to produce an improved clean fuel gas stream having substantially the following composition in mole percent.

H16.53, Co2 4.84, N257.88
O2 and ArO. This clean fuel gas stream was introduced into the combustion chamber of the gas turbine at a temperature of about 75 oy and a pressure of about 20 atmospheres.

At the same time, air and optionally H20 at substantially the same temperature and pressure were passed into the combustion chamber to combust the fuel gas.

A clean flue gas at about 2000'F and a pressure of about 15 atmospheres is produced with a mole percent composition of CO24.7, H20 5.7, N275.4, Ar
l. O and 02 were 13.2.

This clean flue gas is passed through an expansion turbine to approximately 1.546
Generated horsepower hours.

Connected to and driven by the turbine shaft is a generator and a compressor, which compress the air delivered to the gas turbine's combustion chamber and fuel gas generator.

The clean flue gases leaving the expansion turbine at a temperature of about 566°C (below about 1050°C) and a pressure of about 1.5 atmospheres absolute are combined with pre-generated steam and indirect heat in a waste heat boiler downstream of the fuel gas generator. It passes through a heat exchanger as if it were being exchanged.

This produced hot steam that was superheated to a temperature of about 1000'F.

This high-temperature superheated steam was passed through a steam turbine to generate horsepower.

It was connected to a steam turbine which drove a generator and a compressor to compress the waste flue gas to a pressure above the pressure of the fuel gas generator.

6 5 8 O SCF at a temperature of 316°C (6ooy)
H flue gas was mixed with the air and introduced into the fuel gas generator as described above.

Alternatively, the sensible heat of the flue gas stream can also be recovered by preheating the air stream being introduced into the combustion chamber of the gas turbine.

To demonstrate an embodiment of the present invention in which a portion of the C02 recovered in the gas purification zone is utilized to improve the composition of the fuel gas by increasing its molecular weight and heat of combustion, the gas purification zone More than 95 moles of CO from
CO2 enriched gas containing 2 0 2 0 O
The SCF was compressed by a turbo compressor driven by the main gas turbine to a pressure slightly above the pressure in the fuel gas generator.

This compressed CO2 stream is then heated to approximately 316°C (approximately 600'F).
) into a free-flow refractory-lined container, such as sphere container 12 in the drawing (FIG. 2), where it is heated to a temperature of about 1413°C (
The fuel gas was mixed with 1 1 3 7 00 SCF of discharged fuel gas exiting the gas generator at a temperature of about 2575 sf (below).

A non-catalytic, heat-resistant, reversible hydrothermal gas conversion reaction between CO2 and H2 takes place in free-flow refractory lined chamber 12 and line 15;
The molar ratio of the process gas stream flowing through it (Co/H2)
increased.

An improved flue gas was produced having the following mole percent composition:

C025.38, H2 6.23, CO2 1 4.9
1, H20 8.5 3, N24 4.2 1, C
H4 0.0, Ar0.57, H2S'0.16, CO
SO. After removing 0 1CO2 and H2S, the molecular weight of the thermally converted dry fuel gas increased to 25.97.

Furthermore, the net heat of combustion or less per mole is 122. sBTU/SCF.

For purposes of clearly explaining and illustrating the method of the present invention, only hydrocarbonaceous feedstocks and cleaning fluids of specific composition have been described.

However, it should be understood that those skilled in the art will be able to make various modifications to the methods and materials disclosed herein without departing from the spirit of the present invention.

Embodiments of the present invention are listed below.

1. The gaseous oxidation stream from stage gap 4) according to claim 1 is compressed by at least one compressor connected to an expansion turbine, and at least a portion of the gaseous oxidation stream is compressed in stage (3). The claim further comprises a step of preheating the waste flue gas by indirect heat exchange with at least a portion of the exhaust flue gas leaving the expansion turbine of step (4) prior to its introduction into the combustion chamber. The method described in Scope 1.

2. The method of claim 1, further comprising the step of introducing the preheated gaseous oxidation stream into a gas generator as at least a portion of the temperature control agent.

3. 2. The method of claim 1, further comprising the step of dissipating a portion of the cooled clean exhaust flue gas after the heat exchange through a power generating expansion turbine into the atmosphere.

4. Step 3) Prior to combusting the improved combustion gas
A step of preheating by indirect heat exchange a part of the clean exhaust flue gas from step (4), so that the latter clean exhaust flue gas is cooled. The method described in Scope 1.

5. 5. The method of claim 4, further comprising the step of dissipating the cooled clean exhaust flue gas into the atmosphere through a power generating expansion turbine after the heat exchange.

6. In the description of claim 1, step (1)
2. The method according to claim 1, wherein step (3) is carried out at substantially the same pressure as the normal pressure in the pipeline without pressure drop.

7.

characterized in that at least a portion of the temperature regulating agent of step (1) consists of a material selected from the group consisting of H20, the CO2-enriched gas stream obtained from step (2), and mixtures thereof. A method according to claim 1.

8. since the discharged gas stream from stage (1) is cooled and passed to an expansion turbine located upstream of the gas turbine combustion chamber at a substantial pressure with no pressure drop in the normal line of said gas generator; The method according to claim 1, characterized in that:

9. the gas-containing free oxygen in steps (1) and (4) comprises selected from the group consisting of air, oxygen-enriched air (not less than 0.221 mol%) and substantially pure oxygen (not less than 0.2 95 mol%); A method according to claim 1, characterized in that:

10. Hydrocarbon fuels include liquefied petroleum gas: petroleum distillates and residues, gasoline, naphtha, kerosene, crude oil, asphalt, gas oil, residual oil, tar sands oil, shale oil, coal oil: benzene, toluene, xylene fractions , coal tar,
Claim 1, characterized in that the liquid hydrocarbon is selected from the group consisting of cycle gas oil from a fluid catalytic cracking process: furfural extract of coke gas oil, and mixtures thereof. Method described.

11. A method according to claim 1, characterized in that the hydrocarbonaceous fuel consists of a gaseous hydrocarbon.

12. Hydrocarbonaceous fuels are derived from effluents and by-products from chemical processes containing carbohydrates, cellulosic substances, aldehydes, organic acids, alcohols, ketones, oxygenated fuel oils, oxygenated hydrocarbonaceous organic substances and mixtures thereof. A method according to claim 1, characterized in that the oxygen containing liquid hydrocarbonaceous organic material is selected from the group consisting of:

13. Hydrocarbon fuels include coal, fine carbon, petroleum coke,
A pumpable slurry of solid carbonaceous fuel selected from the group consisting of sewage sludge concentrated in a vaporizing medium such as water, liquid hydrocarbon fuels, and mixtures thereof. The method according to claim 1.

14. Prior to introducing the hydrocarbonaceous fuel into the gas generator of step (1), there is a further step of preheating the hydrocarbonaceous fuel to a temperature of about 800'F, but below its decomposition temperature. A method according to claim 1, characterized in that the method comprises:

15. Cooling the discharged gas stream from step (1) by indirect heat exchange with water to produce water vapor, introducing at least a portion of said water vapor into a steam turbine driving a turbo compressor; The air on board is compressed and the compressed air is introduced into an air separation unit that decomposes oxygen and nitrogen from the charge air, compressing at least a portion of the oxygen and converting it into the free oxygen-containing gas. Claim 1 characterized in that it further comprises steps such as introducing the gas into the gas generator as at least a part of the gas generator.
The method described in section.

16. 16. The method of claim 15, further comprising the step of introducing at least a portion of the separated nitrogen into a gas purification zone to facilitate separation of gaseous impurities from the fuel gas stream.

17. 2. A method according to claim 1, characterized in that the power generated in step (4) is utilized to drive a generator gas compressor or a pump.

18. A portion of the CO2-enriched gas stream from step (2) is mixed with the effluent gas stream from step (1) and the mixture is subjected to a catalyst-free reversible hydrothermal gas conversion reaction to form a process gas stream. 2. A method according to claim 1, further comprising the step of increasing the molar ratio (CO/H2) to a value of 1.3 or more.

19. Gasifying hydrocarbon fuel to produce fuel gas,
In a method for generating power by a gas turbine, which comprises combusting this in the combustion chamber of the gas turbine to generate flue gas, and introducing this into a power generating expansion turbine, (1) the presence of a temperature regulating gas; in which a liquid hydrocarbon fuel is reacted by partial oxidation with a free oxygen-containing gas in a noncatalytic free-flow gas generator at a temperature of about 816
℃ (approximately 1500'F) to approximately 1899°C (approximately 3500'F)
) and at a pressure within the range of about 10 to 180 atmospheres absolute, the bulk fraction is H2, CO, CH4, CO2, H20 and H20.
2. A small portion produces an effluent gas stream consisting of COS, H2S, Ar and particulate carbon, and (2) supplementary CO that is subsequently produced in the process.
2. Mixing the enriched gas stream with the effluent gas stream from stage (1) and converting the mixed gas stream into a free-stream thermal conversion zone of at least 81
The dry haze molar ratio (CO/H2) of the effluent gas stream from step (1) is increased by subjecting it to a non-catalytic thermoreversible water gas conversion reaction at a temperature of 6°C (below 1500°C), 2) cooling the effluent gas by indirect heat exchange with water to generate water vapor; and (4) introducing the cooled effluent gas from step (3) into a gas scrubbing and purification zone from which H2 and CO and N2
, a mixture of one or more of the groups CH4, CO2 and H20, a CO2-enriched gas stream, particulate carbon and a liquid carrier, and a clean fuel gas stream consisting of a H2S and COS-enriched gas stream. and (5) stage (4
) at least a portion of the CO2-enriched gas stream from step (4) is introduced into step (2) as said supplementary CO2-enriched gas stream; and (6) during the process with the improved fuel gas from step (4). At least one portion of the gaseous oxidation precipitate subsequently produced
portion is introduced into the combustion chamber of the gas turbine and combusted at a temperature of about 1400-3000'F.
(7) passing the clean flue gas stream from step (6) as a working fluid to said expanding gas turbine to generate power; and producing a clean exhaust flue gas and mixing at least a portion of the clean exhaust flue gas with air;
) of producing a gaseous oxidation stream.

20. The clean fuel gas from step (4) is transferred to step (6).
A portion of the waste flue gas from stage (7) is heated to about 204-427°C by indirect heat exchange prior to combustion at
19, further comprising the step of preheating the waste flue gas to a temperature in the range of about 400 to about 800 degrees Celsius or less before dissipating the waste flue gas through a power generating expansion turbine to the atmosphere. Method described.

21. The gaseous oxidation stream from stage (7) is compressed by a compressor driven by an expansion turbine of stage lv7).
~ 190 absolute pressure and is compressed indirectly with a portion of the exhaust flue gas from stage (7) before at least a portion thereof is introduced into the combustion chamber of stage (6). 20. The method of claim 19, further comprising preheating by heat exchange to a temperature within the range of about 400-800°C.

22. characterized in that it comprises an additional step of introducing a portion of said compressed and preheated gaseous oxidation stream as a portion of said temperature moderating gas into the reaction zone of the gas generator of step (1). 22. The method according to 21 above.

23. step (1) with a portion of the CO2-enriched gas stream from step (4) as at least a portion of said temperature regulating gas;
20. The method according to claim 19, further comprising the step of introducing the gas into a gas generator.

24. compressing air in a compressor driven by the expansion turbine of step (7) to a pressure greater than or equal to the pressure of the gas generator, and using the compressed air as at least a portion of the free oxygen-containing gas of step (1); 20. The method according to claim 19, further comprising the step of introducing into a gas generator.

25. The method of claim 19, wherein the heat of combustion of the improved fuel gas stream separated in step (4) is within the range of about 75 to 350 BTU/SCF.

26. characterized in that the pressure in the system throughout the combustion chamber of stage (6) is substantially the same as the pressure of the gas generator of stage (1), without the usual pressure drop in the lines. 19. The method described in 19 above.

27. The method according to 19 above, characterized in that it comprises an additional step of introducing water vapor into the combustion chamber of stage 6).

28. Step (4) compresses the air to a pressure within the range of about 10 to 180 absolute pressure by a compressor driven by the expansion turbine of step (4) as claimed in claim 2. 3. A method as claimed in claim 2, further comprising the step of introducing as identified air into the combustion chamber of the combustion chamber.

29. compressing the free oxygen-containing gas by a compressor driven by the expansion turbine of stage (4) as claimed in claim 2 to a pressure equal to or higher than the pressure in the gas generator of stage (1); A method according to claim 2, characterized in that the method further comprises the step of introducing the determined free oxygen-containing gas into the gas generator as the specified free oxygen-containing gas. .

30. A method according to claim 2, characterized in that step (4) as claimed in claim 2 comprises driving a generator to generate electricity by means of an expansion turbine.

31. A portion of the CO2-enriched gas stream from stage (3) as claimed in claim 2 is transferred to stage (4) by a compressor driven by an expansion turbine.
The compressed CO2-enriched gas stream is compressed to a pressure above the pressure in the gas generator of step (1) and mixed with the discharged gas stream from step (1), and the resulting mixed gas stream is free-flow type. In the thermal conversion zone, at least 816°C (1500'
F) The non-catalytic thermoreversible water gas conversion reaction is carried out at a temperature of
3. A method according to claim 2, further comprising the step of increasing to a value (dry basis) in the above range.

32. A portion of the discharged gas stream from stage (2) as claimed in claim 2 is heated to a high temperature by indirect heat exchange with the flue gas exhaust from the expansion turbine of stage (4); Claim 2, further comprising the step of passing at least a portion of the hot superheated steam as a working fluid through a steam turbine, the steam turbine driving a compressor or generator. Based on method.

33. The cooled discharge gas stream from stage (2) as claimed in claim 2 is located downstream from said gas turbine at substantially said normal line pressure drop generator pressure. Claim 2 further comprising the step of passing the expanded expansion turbine through the expanded turbine.
Easy way to describe the section.

34 Step (1) stated in claim 2
The free oxygen-containing gases in the air include air, oxygen-enriched air (greater than 21 mol% 02) and substantially pure oxygen (95 mol% 02).
3. A method according to claim 2, characterized in that the method comprises: selecting from the group consisting of:

35. Hydrocarbon fuels include liquefied petroleum gas, petroleum distillates and residues, gasoline, naphtha, kerosene, crude oil, affalut, gas oil, residue oil, tar sands, shale oil, coal oil:
A liquid hydrocarbon selected from the group consisting of aromatic hydrocarbons such as benzene, toluene, xylene fraction coal tar, cycle gas oil from fluid catalytic cracking process, furfural extract of coke gas oil, and mixtures thereof. A method according to claim 2, characterized in that it comprises the following steps:

36. Hydrocarbon fuels are gases selected from the group consisting of methane, ethane, propane, butane, pentane, natural gas, water gas, coke oven gas, refined gas, acetylene table gas, ethylene off gas, and mixtures thereof. A method according to claim 2, characterized in that it consists of a hydrocarbon.

37. Hydrocarbonaceous fuels include effluents and by-products from chemical processes and mixtures thereof that contain carbohydrates, fibrous substances, aldehydes, organic acids, alcohols, ketones, oxygenated fuel oils, oxygenated hydrocarbonaceous organic substances. Claim 2, characterized in that it consists of an oxygenated hydrocarbon organic substance selected from a certain group such as
Easy way to describe the section.

38. Pumping of solid carbonaceous fuels selected from the group consisting of concentrated sewage sludge in vaporized media such as coal, granulated carbon, petroleum coke, water, liquid hydrocarbon fuels and mixtures thereof, etc. 3. A method according to claim 2, characterized in that the slurry comprises a slurry.

39. Prior to introducing the hydrocarbonaceous fuel into the gas generator of step (1), preheating it to a temperature of up to 649° C. (below 120° C.), but below its decomposition temperature. 3. A method according to claim 2, characterized in that the method further comprises providing a.

40. At least a portion of said stream from said step (2) is introduced into a steam turbine, thereby compressing air in a turbo compressor, and the compressed air is introduced into an air separation device, where it is further steps of separating oxygen and nitrogen from the air charge and compressing at least a portion of said oxygen and introducing it into said gas generator as at least a portion of said free oxygen-containing gas; A method according to claim 2, characterized in that the method comprises:

41. At least a portion of the separated nitrogen is passed through a stage (3
41. The method of claim 40, further comprising the step of introducing said stream into a gas purification zone to facilitate separation of said stream.

42. 3. A process as claimed in claim 2, characterized in that it comprises introducing H20 through a burner into the reaction zone of step (1).

43. A method for power generation by a gas turbine comprising gasifying a hydrocarbonaceous fuel to a fuel gas and combusting it in a combustion chamber to produce flue gas, which is introduced into a power generating expansion turbine. (1) At least one part of the C02-enriched gas stream from stage (4), at least one part of the waste flue gas leaving the expansion turbine of stage gap 6), from the group containing H20 and mixtures thereof; In reacting a liquid hydrocarbon fuel by partial oxidation with a free oxygen-containing gas in the presence of a selected temperature regulating gas, the reaction is carried out in the reaction zone of a non-catalytic free flow gas generator at a temperature of about 816-1899
H2, CO, CH4, CO2, H20, and N2 and small amounts of COS, H2S, An effluent gas stream consisting of Ar, and particulate carbon is generated such that the dry basis molar ratio of the effluent gas stream from the generator (CO/H2
) of at least 0.30, and (2) the supplementary CO2 produced in a later step of the process is mixed with the effluent gas stream from the enriched gas stream (1) and its The dry base molar ratio (CO/H2 ), (3) cooling the effluent gas stream from (2) to produce water vapor by indirect heat exchange with water, and (4) introducing the cooled effluent gas from (3) into a gas cleaning purification zone. and from this an improved fuel gas stream consisting of H2, CO, and optionally N2 and CH4: CO
2. Enriched gas stream: separate and obtain streams such as gas streams consisting of fine carbon and liquid carrier, (5) at least a portion of the CO2-enriched gas stream from (4) is used for said replenishment. CO2 as enriched gas stream (2)
(6) combusting the improved fuel gas stream from (4) with air in the combustion chamber and passing the resulting flue gas as a working fluid through the power generating expansion turbine; ) passing a portion of the steam produced in (3) in indirect heat exchange with the exhaust flue gas exiting the expansion turbine of stage (6) to produce hot superheated steam; An improved method comprising the steps of using steam as a working fluid in a power generating steam turbine.

44. A portion of the waste flue gas leaving stage (7) is compressed in a compressor driven by the steam turbine of said stage (7) to a pressure above the pressure in said gas generator, and the compressed flue gas is 44. The method according to item 43, further comprising the step of introducing the temperature-adjusting gas into the gas generator of step (1).

45 of the CO2-enriched gas stream from step (4) above
44. Compressing the part to a pressure equal to or higher than the pressure of the gas generator and introducing the compressed gas as the temperature regulating gas into the gas generator of step (1). How to quickly.

46. Compressing air in a compressor driven by the expansion turbine of step (6) to a pressure equal to or higher than the pressure of the gas generator, and using the compressed air as at least a portion of the free oxygen-containing gas 44. The method according to claim 43, further comprising the step of introducing the gas into the gas generator.

47. The method further comprises the step of compressing air in a compressor sor driven by the expansion turbine of step 6) and introducing the compressed air into the combustion chamber as the specified air of step (6). A method according to the above item 43.

48. Based on paragraph 43, wherein the improved fuel gas stream separated in step (4) has a heat of combustion in the range of about 75 to 350 BTU/SCF. How to save.

49. The pressure in the system, including in the combustion chamber of step (6), is substantially the same as the pressure in the gas generator of step (1), without the usual line pressure drop. 44. The method according to item 43 above.

50. 44. The method of claim 43, comprising adding water vapor to the combustion chamber of step (6).

[Brief explanation of the drawing]

FIG. 1 is a flow sheet diagram illustrating details of Example I of the process of the present invention, and FIG. 2 is a flow sheet diagram illustrating details of Example 2 of the process of the present invention. DESCRIPTION OF SYMBOLS 1...Fuel gas generator, 4...Burner, 5...Central passage, 8...Concentric ring-shaped passage, 10...・・Downstream conical outlet, 1
2...Fireproof lined free-flow spherical chamber, 15...
...Discharge duct, 11... Waste heat boiler, 25.
... Pipe line, 26 ... Valve, 28 ... Curved pump, 29 ... Carbon separation zone, 35 ...
Reaction zone, 49... Expansion turbine, 50...
... Compressor, 51 ... Turbo compressor,
65...Gas purification zone, 69...Steam turbine, 71...Compressor, γ4...
... Compressor, 92 ... Turbo compressor, 107
... Heater, 110 ... Gas cleaning zone, 120 ... Expansion turbine, 124 ...
...Turbo compressor, 125...Compressor, 139
... Pump, 144 ... Claus device, 150 ... Heat exchanger, 152 ... Combustion chamber 153 ... Expansion turbine, 155 ...・・・
... Heat exchanger 159 ... Turbine, 161 ...
...Steam turbine 166 ... Heat exchanger, 167 ... Yuichibo generator 168 ...
・Turbo compressor, 171, 173... Heat exchanger, 176... Intermediate cooler, 177...
Turbo compressor, 189... Generator, 220...
····Heat exchanger.

Claims (1)

[Scope of Claims] 1(1) In the reaction zone of a non-catalytic free-flow gas generator, in the presence of a temperature regulator, the autogenous temperature range is about 816-18
99°C (approx. 1500-3500 below) and absolute pressure 10
Hydrocarbonaceous fuel is reacted with free oxygen-containing gas by partial oxidation under conditions of ~180 atm to produce H2, CO, C.
O2 and H20 and N2, CH4, COS. H2S
, and an effluent gas stream consisting of a mixture of one or more fractions and particulate carbon in the group of (2) cooling the effluent gas stream from step (1) and introducing the cooled gas into a gas scrubbing purification zone and from the H2
a clean fuel gas consisting of a mixture of CO and one or more components in the group of N2, CH4, CO2 and H20; a CO2 enriched gas stream; a slurry stream from particulate carbon in a liquid medium; and (3) introducing the clean fuel gas stream from step (2) into the combustion chamber of the gas turbine, and in step (4) producing a clean fuel gas stream; (4) burning the clean fuel gas stream in the combustion chamber of the gas turbine together with the gaseous oxidation stream to generate a clean flue gas stream; generating power and producing clean exhaust flue gas through an expansion turbine as a gas, and then mixing at least a portion of said clean exhaust flue gas with a free oxygen-containing gas to produce the gas in step (3). Generates an oxidizing stream, ? A method for generating power by means of a gas turbine having a combustion chamber and an expansion turbine, characterized in that the stages (1) to (4) are excavated. 2 (1) in the reaction zone of a catalyst-free free-flow gas generator, at least a portion of the CO-enriched gas stream from stage (3) below and the waste flue gas from stage (4) below; at least 1 of
In the presence of a temperature regulating agent selected from the group consisting of
99°C (approx. 1500-3500 below) and absolute pressure 10
Hydrocarbonaceous fuel is reacted with free oxygen-containing gas by partial oxidation under conditions of ~180 atm to produce H2, CO, C
O2 and H20 and N2, CH4, COS, H2S
, and a mixture of particulate carbon and particulate carbon of one or more in the group of
) is at least 0.30 on a dry basis; (2) cooling the effluent gas stream from step (1) by indirect heat exchange with water to produce water vapor; , (3) introducing the cooled effluent gas from step (2) into a gas scrubbing purification zone from which H2 and CO and N2,
A clean fuel gas consisting of a mixture of one or more components in the group CH, H201 and CO2; CO2
separating into an enriched gas stream; a slurry stream derived from particulate carbon in the liquid medium; and optionally an enriched gas stream from H2S and COS to obtain a clean fuel gas stream; (4) said step (3); ) is combusted with air in the combustion chamber of a gas turbine, and the resulting combustion gas is passed as a working fluid through an expansion turbine to generate power and clean exhaust flue gas. urge A method for generating power by means of a gas turbine having a combustion chamber and an expansion turbine, characterized in that it comprises steps (1) to (4).