JPS608077B2 - Method for producing synthesis gas consisting of H↓2 and CO along with power - Google Patents

Description

DETAILED DESCRIPTION OF THE INVENTION The present invention provides for the production of an effluent gas stream consisting of carbon dioxide and CO in a partial oxidation process in a gas generator, and the direct oxidation of a relaxed mixed gas stream comprising all effluent gas streams. This is a partial oxidation method that produces power through expansion.

Traditionally, the temperature of the effluent gas stream leaving the gas generator in partial oxidation processes has been reduced to a temperature of 177° C. by quenching in a pool of water or by indirect heat exchange with water in a heat exchanger.
The temperature was lowered to ~316C (350-6000F). The above two methods caused the entropy to increase to a large extent and decreased the thermal efficiency. This problem is ``substantially overcome'' by the method of the present invention, namely, expanding and cooling a relaxed mixed gas stream in a turbine.

In U.S. Pat. No. 3,868,817, pure fuel gas is combusted in a gas turbine combustor.

In US Pat. No. 2,660,521, carbon gas or steam is introduced into the combustor of a turbine or into the effluent from the combustor. Adding materials in this manner alters the composition of the product gas and makes purification of the product gas stream costly. The effluent gas stream of the present invention is from a free-flow lower partial oxidation gas generator at a temperature of 982-1649 qo (1800-30000 F);
It comes out at a pressure of 10 to 300k9/c, and the ratio, C○, CQ,
At least 3 of the groups 20 and 20, COS, CH4, N2, and A also consist of one species and accompanying particulate solids.

This exit gas stream is passed through a solid separator zone and mixed with a recirculated portion of the turbine exhaust stream.

The turbine exhaust stream is cooled, cleaned, sometimes subjected to a water gas shift reaction, purified, or both, and then compressed again before the mixing is effected. Alternatively, the recycled gas stream may be mixed with water, steam or both.
In one embodiment, the temperature moderated stream consists of a condensate produced in accordance with the present invention.

The non-recirculated portion of the product gas stream is removed from the system and used as synthesis gas or fuel gas. The volume ratio of the recirculated gas stream to the turbine feed mixed gas stream may range from 0.2 to 0.8. The amounts and temperatures of the recirculated gas stream, steam, water and gas generator effluent stream to be mixed are such that the temperature of the turbine feed mixed gas stream after mixing is between 538 and 1316°C (1000°C).
-24000F) preferably 760-1204C (14
00-22000F) Optimally 1204-1038qo
(1400-19000F). Operating the turbine at high turbine inlet temperatures provides high power recovery. Additionally, the acid gas concentration through the turbine is reduced by removing acid gas from the turbine exhaust prior to gas recirculation. The cost of compressing a gas stream with an auxiliary compressor driven by the expansion turbine described above is much less than the cost of purchasing commercially available electricity to drive the compressor. This is an improved method of gasifying hydrocarbonaceous fuels by continuous partial oxidation to produce synthesis gas or fuel gas.

The effluent gas flow from the gas generator is: day 2, C○, day 20,
It consists of at least one species from the groups C02, S, COS, C, N2, and A, and granular carbon. The method of the present invention is to use the total heat of the gas produced by the partial oxidation process to produce power without drawing it to a high temperature heat exchanger or boiler.

Such heat exchange equipment is expensive and requires lower or higher liquid operating pressures than the high pressure of the generator, at least on the shell side.

High generator temperatures, combined with the generator effluent gas stream, pose metallurgical problems for such heat exchangers. In at least these respects, it should be recognized that heat exchangers that extract high temperature heat from the generator effluent gas stream for use in the power cycle are different from common furnace boilers and superheaters. The increase in molecules is associated with partial oxidation of all hydrocarbonaceous fuels.

In the present invention, power is derived from the increased pressure and sensible heat of the hot partially oxidized effluent gas stream, as well as from this molecular build-up. Although the method of the present invention calculates the power for recompression, direct expansion by transferring heat to a closed Preyton cycle generator
From the energy inherent in the high temperature, high pressure generator exit gas stream,
It is possible to extract more power.

Some of the reasons for this are due to the reduction or elimination of thermodynamic losses. However, the major factor is
The turbine exhaust stream leaving the power section in the inventive method using direct expansion has a low Z energy content. In the present invention, a continuous effluent stream of crude synthesis gas or fuel gas is produced in a refractory-lined reaction zone of a free-flow, unfilled, non-catalytic partially oxidized fuel gas generator.

Preferably, the gas generator J is F.E.Gabutil.
This is a rigid steel container as described in U.S. Pat. No. 2,992,906 invented by F.E. Guptill I Jr. A wide range of combustible carbon, including organic matter, is reacted with a free-oxygen containing gas in a gas generator, sometimes in the presence of a temperature moderating gas,
The effluent gas stream is produced.

When using a gaseous hydrocarbon as a raw material, a temperature moderating agent is not required, but when using solid hydrocarbon dihydrogen as a raw material, a temperature moderating agent is required.

In the present invention, "with a temperature moderator" includes cases where gaseous hydrocarbons are used as raw materials and cases where liquid and solid hydrocarbons are used as raw materials, and therefore, a temperature moderator is used as necessary. 3. "Hydrocarbonaceous material" as used herein as a variety of suitable supplies to a partially oxidized gas generator is meant to include gaseous, liquid and solid hydrocarbons, carbon-containing substances and mixtures thereof. do.

In fact, the term "hydrocarbons" includes almost all carbon-containing organic materials, fossil fuels, or slurries thereof. e.g. tl} of coal, lignite, wood pulp, granular carbon, concentrated sour sludge and mixtures thereof in water or liquid hydrocarbons {2) Temperature-moderating 4 gases or distinct solid carbon dispersed in gaseous hydrocarbons gas-liquid-solid fractions such as water and particulate carbon dispersed in atomized liquid hydrocarbon fuels or tempered gases; The hydrocarbon fuel has a sulfur content of 0 to 1 t% and an ash content of 0 to 15 wt%.
and up to 5% solid hydrocarbon fuel. As shown in the above analysis values, the hydrocarbon fuel may or may not contain sulfur, and depending on the sulfur content, sulfur may be removed from the turbine exhaust gas or its operation may be omitted. In the present invention, the expression "to purify the gas" means both to perform a purification operation or to omit the same operation, and also to subject the gas to a shift conversion reaction and to remove acidic gases as necessary. This means to perform before and after compressing the gas.

Suitable liquid feeds include "liquid hydrocarbons"
Liquefied petroleum gas, petroleum distillates and residues, gasoline, naphtha, kerosene, crude petroleum, asphalt, gas oil, residual oil, tar sands oil and tribute oil, coal derived oil, aromatic hydrocarbons (such as benzene, toluene, xylene, crabmeat), coal tar, recycle gas from fluid catalytic cracking processes, furfural extracts of coker gas oils, and mixtures thereof. The term "gaseous hydrocarbon fuels" as used herein refers to methane, ethane, propane, butane, bentane, natural gas, water gas, coke oven gas, refinery gas, acetylene tail gas, ethylene offgas, synthesis gas, and their means a mixture.

The gaseous and liquid feeds are mixed with each other and used simultaneously and may contain paraffinic, olefinic, naphthenic and aromatic compounds in any proportion. Substances called “hydrocarbons” include carbohydrates, cellulosic substances, aldenoids, organic acids, alcohols, ketones,
Includes oxidized fuel oil, waste liquids or by-products from the performance of chemical processes containing oxidized hydrocarbonaceous organic materials, or mixtures thereof. The hydrocarbonaceous feed may be fed at room temperature but is preferably
12,000F), for example, is heated to 42,700 (8,000F) and supplied.

However, the temperature must be below its decomposition temperature. Sometimes the hydrocarbonaceous feed is preheated indirectly. Indirect preheating is the non-contact heat exchange of the feed in a heat exchanger with the exhaust gas and recycle gas stream from the expansion turbine used in the later steps of the invention. The hydrocarbonaceous fuel is introduced into the burner in liquid phase or in a vaporized mixture with a temperature moderator. Suitable temperature moderating agents include steam, water, CO2-enriched gas, atmospheric nitrogen, generated nitrogen from conventional air separation equipment, and mixtures of the temperature moderating agents described above. The need for the use of a temperature moderator in the reaction zone of a gas generator generally depends on the carbon to hydrogen molar ratio of the V feed and the oxygen content of the oxidant feed stream.
Temperature moderators are not required when using gaseous hydrocarbon fuels, but are necessary when using liquid hydrocarbon fuels and nearly pure oxygen. The temperature moderator is mixed into the burner with one or two of the reactant streams. Or, alternatively, the temperature moderating agent is introduced into the reaction zone of the gas reactor into the burner through a separate conduit to the burner. The total weight ratio of 20 to fuel placed in the reaction zone of the gas generator ranges from 0 to 5.

When a relatively small amount of water is introduced into the reaction zone, for example through the burner to cool the burner chip, the hydrocarbonaceous feed,
Free-oxygen-containing gas, mixed with either a temperature moderating agent or a combination thereof.

In such cases, the weight ratio of water to hydrocarbonaceous feed may range from 0 to
1. For the government, 0 to 0.2 is sufficient. Here, ``free oxygen-containing gas'' refers to air, oxygen-enriched gas, air containing 21 mol% or more of oxygen, and pure oxygen, ie, gas containing 95 mol% or more of oxygen ( The remainder refers to nitrogen (N2 and noble gases).The amount of nitrogen in the effluent gas stream may be reduced since almost pure oxygen or oxygen-enriched air in the gas generator reacts instead of air. The free-oxygen containing gas is admitted to the burner at a temperature ranging from room temperature to 18,000 F. The free-oxygen to carbon ratio (0/C, atom/atom) in the oxidizer in the feed is preferably 0
．． It is in the range of 7 to 1.5. The feed stream is introduced into the reaction zone of the gas generator by a burner.

A suitable burner is DeBois Eastman
This is an annular type burner described in US Pat. No. 2,923,46, invented by John S. The feed stream has an autogenous temperature of 982-1649 qo (1800-300 qo) without catalyst in the reaction zone of the free-flow gas generator.
00F) For example, 1093 to 1593 0 (2000 to 2
9000F), pressure 10~200k9/mass e.g. 40~
100 kg/me is reacted by partial oxidation.

In the present invention, pressure is expressed in absolute pressure.

The reaction time in the gas generator is 1 to 1 sand. The effluent gas flow leaving the gas generator is 2, CO, C02, 20
and at least one of the groups C, 2S, COS, N2, and A, and accompanying solid substances. mole%
The composition represented by is as follows. Day 2 10.0
〜68.0CO 15.0〜68.0CO
2 3.0-30.0 days 20 2.
0~50.0CH4 0~28.0 Day 2S
O~ 5COS O~ 0.7
N2 0-60.0A O-18 Unreacted particulate carbon (based on carbon in the feed by weight) is normally present at 0.2-2x% for liquid feeds, but gaseous carbonization There is almost no hydrogen supply.

The particular composition of the effluent gas stream will depend on the actual operating conditions and the composition of the feed stream. Synthesis gas consists of a mixture of CO2 and CO. The content of C-day may be maximized when a fuel gas with a high calorific value is desired. A continuous stream of hot effluent gas exits the gas generator outlet and then enters the mixing zone at approximately the same temperature and pressure as in the reaction zone.

In the present invention, although the mixer is not specifically illustrated, it is a conventional mixer.

For hydrocarbonaceous fuels containing ash-rich materials such as coal, a solid separation zone is inserted between the gas generator outlet and the mixing zone. Solid separators are used to separate solid materials contained in the heat effluent gas stream, i.e., particulate carbon, ash, metallic constituents, scale, slag, refractories, and mixtures thereof, or materials flowing out of the gas generator, i.e., granular carbon, ash, metal constituents, scale, slag, refractories, and mixtures thereof. In order to remove small pieces of materials, a catchy pot (h-pot for Ca), a slag chamber, a cyclone separator, an electrostatic precipitator (electroS
tatichecjpitor) or a combination thereof. The solid particles are separated from the effluent gas stream and only a small amount is recovered if there is some temperature and pressure drop in the effluent gas stream. The standard slug chamber used is shown in the drawings and is similar to U.S. Pat. No. 3,528,930.
It is shown in Figure 1 of the publication. Turbine erosion and rotor blade alignment can be minimized by removing all solid particles larger than about 12 microns by gravity separation, cyclonic separation, or other physical cleaning methods. The mixed zone has a temperature range of 2 to 1,649 degrees Celsius (1,800 degrees Celsius).
Temperatures range from 177 to 5 with almost all exit gas flow hot from the generator (~30,000F).

Any conventionally used equipment may be used to mix the cooled, cleaned recycle gas stream at 0 (350-100 degrees F).

The volume ratio of the cooled, cleaned recycle gas stream to the mixed gas stream consisting of the effluent gas stream from the generator plus the recycle gas stream is in the range 0.2 to 0.8, e.g. 0.4 to 0.6. It is. The recycle gas stream is produced in a later step of the invention and will be discussed there. A sufficient amount of recirculated gas flow reduces the temperature of the Namiai gas stream from 5 to 131,600 (1,000 to 2,400
0F) For example, 760-1204qo (1400-220
00F) or 1204-1038qo (1400-19
000F) and lower the temperature to above the dew point.
In the mixing zone it is mixed with the effluent gas stream of the gas generator.

At this time, the pressure is 10-200k9/for example, 40-1
00 kg/, so the pressure is preferably only slightly lower than the pressure of the gas in the gas generator. Additionally, the concentration of particulate carbon and acid gases in the mixed gas stream exiting the mixing zone is somewhat reduced. The mixed gas stream is then passed as a working fluid through a power recovery turbine comprising at least one power-producing expansion turbine.

The expansion turbine is paired with at least one gas compressor and sometimes with a generator. The turbine exhaust gas has a temperature of 177 to 538°C (350 to 10,000°C).
F) Exits the power recovery turbine at a pressure of 2 to 15 kg/.

For example, the ratio of pressure entering the turbine to pressure exiting the turbine may range from 6 to 40. Advantageously, the heat of the turbine exhaust gas is almost entirely recovered by indirect heat exchange in a first heat exchanger with the recirculating gas stream on its way to the mixing zone described above. be done. The cooled turbine exhaust gas is then passed through a gas purifier of the type conventionally used to remove all entrained particulate carbon and other entrained solids.

When using gaseous hydrocarbonaceous fuels, very little particulate carbon is produced, so when using gaseous fuels such as natural gas or methane, no gas cleaning step is necessary. If particulate carbon is to be removed, a slurry of particulate carbon dispersed in hydrocarbons is created in the gas clean zone.
At least a portion of the feed stream may be recycled to the generator of fuel gas. Any conventional method suitable for removing cloudy solids from a gas stream may be used. In one aspect of the invention, the expanded turbine exhaust stream after being cooled in a heat exchanger is placed in a gas-liquid scrubbing zone where the exhaust stream is treated with liquid hydrocarbons or water to remove particulate carbon. Washed with a scrubbing fluid such as

A suitable liquid-gas tray type column is clearly described in U.S. Pat. No. 16,382 to C.P. Nbrison. Thus, as the turbine exhaust gas stream passes upwardly through the scrubbing column and a suitable scrubbing stream passes downwardly, the particulate carbon remains in the scrubbing fluid and the particulate carbon is removed. A slurry of particulate carbon and wash fluid is removed from the bottom of the column and sent to a carbon separation or enrichment zone. This can be accomplished by any conventional method: filtration, centrifugation, gravity settling, or liquid hydrocarbon extraction methods such as those described in U.S. Pat. No. 2,992,069. The clean refiner or wash fluid and a dilute mixture of particulate carbon are recycled to the top of the column for further scrubbing of the syngas. Other suitable conventional gas cooling or cleaning methods may be used in conjunction with or in place of the cleaning column described above.

For example, the turbine exhaust gas stream is placed below the surface of a quench pool and the scrubber fluid is placed in a Qip-tu unit. Alternatively, the turbine exhaust gas stream is passed through multiple scrubbing steps including orifice scrubbers or venturi nozzle scrubbers as shown in U.S. Pat. No. 3,618,296. Sometimes, when it is desired to increase the hydrogen content of the product gas while simultaneously decreasing the amount of carbon monoxide present, the soot-free gas stream is introduced into a conventional catalytic water gas shift reaction zone at an inlet temperature range of 177-371°C. (350-700
0F).

CO and CO20 react over a conventional water gas shift catalyst to additionally produce CO2 and C02. A suitable water gas shift reaction catalyst consists of a mixture of iron oxide and chromium oxide, containing 1 to 15 M% of oxides of metals such as potassium, thorium, uranium, beryllium or antimony.
is used as a promoter. The reaction is 260-566 qo (50
0-10500F). Alternatively, cobalt molybdate on alumina can be prepared at a reaction temperature of 260-482°C.
(500-9000F) as a water gas shift catalyst. Cobalt molybdate is COO in tw%
2-5, Earth 038-16, Mg00-20, A〆203
The composition is 59-85. Another shift catalyst is a mixture of /steel and zinc salts or oxides, consisting of 3 parts by weight zinc and 1 part by weight copper. Next, almost all ratio O is removed from the turbine exhaust gas stream.

Water is removed, for example, by cooling the turbine exhaust gas stream below the dew point and then splitting the condensed water. The purified, clean, dry turbine exhaust gas stream is then compressed. After the turbine exhaust gas stream is compressed to a pressure slightly higher than the pressure in the gas generator, sometimes previously condensed water is reintroduced into the recirculated gas stream at a point in the line located before the heat exchanger.

The condensate may be mixed with the recycle gas in a mixing zone or combined with other moderator streams, such as saturated or superheated steam, to moderate the temperature of the effluent gas stream from the gas generator. , may be mixed. This has the following advantages: [
1} The water is evaporated at partial pressures rather than total pressure using lower grade heat, making regeneration to the turbine exhaust more effective.

■The number of heat exchangers can be less than that required for split streams. '3} In situ generation of steam in the recycle gas stream tends to suppress undesirable adverse reactions such as methanation. Depending on the desired pressures of the recycle gas stream and the product gas stream, one or more compressors are operated 3 with the power produced by the expansion turbine. The pressure of the product gas stream may be less than, equal to, or greater than the pressure within the gas generator. The product gas stream and the recycle gas stream may be removed from the same gas compressor or from separate compressors. The recycle gas stream is produced at a pressure slightly higher than the pressure within the gas generator. The product gas stream may be cooled between multiple compressors. Multi-stage turbines and compressors may be used. Sometimes, the free-oxygen-containing gas entering the gas generator is first compressed by another gas compressor operated or paired with said expansion turbine to a pressure above the gas generator pressure. It's fine. sometimes,
A generator is operated by the expansion turbine. In another embodiment of the present invention, the hydrocarbonaceous fuel to the partially oxidized gas generator includes sulfur compounds that appear as QS and COS in the effluent gas stream from the generator.

In such cases, the concentration of 2S and COS in the gas of the power loop (LEOP) is reduced below a concentration that is chemically detrimental to the turbine and gas compressor. The cooled, cleaned turbine exhaust gas stream is purified by removing the acid gases, S, COS and C02, in an absorption zone. Advantageously, this reduces the size and cost of gas compressors and reduces or eliminates chemical attack on them. It also improves the purity of the product gas stream and reduces environmental pollution problems when the product gas stream is used as a fuel gas. It also eliminates the problem of sulfur contamination of the catalyst with which the product gas will later come into contact. Additionally, since the purified recycle gas stream dilutes the gas generator effluent gas stream, a clean recycle gas reduces or eliminates the problem of chemical corrosion in the expansion turbine. Alternatively, the H2S and possibly the C02 can be removed at high pressure.
If it is more economical, the acid gas absorption band can be
It may also be after the bin working gas compressor. Any conventional method may be used to remove gaseous impurities.

Impurities in the gas purification zone include 2S, COS, and CO2. For example, freezing methods, physical methods or chemical absorption methods with solvents such as methanol, n-methylpyrrolidone, triethanolamine, propylene carbonate or alternatively absorption methods with hot potassium carbonate may be used. In the solvent absorption method, most of the C02 absorbed in the solvent is released by one flushing.

The remainder is removed by stripping. This is done most economically with nitrogen. Nitrogen is available as a low cost by-product from conventional air separation equipment. The air separation equipment produces almost completely pure oxygen (95 mol% 0
2 or more). The regenerated solvent is then returned to the absorption column for reuse. If desired, a final cleaning procedure may be performed in which the turbine exhaust gas stream is passed through iron oxide, zinc oxide, or activated carbon to remove any remaining traces of 2S or organic fluids. Similarly, Q
Solvents containing S and COS are regenerated by flushing and stripping with nitrogen or by heating and refluxing without the use of inert gas.

Next, 2S and COS are converted to IO by a suitable method. For example, Kirk-Otmer, Esocyclovesia, Ob, Chemical Chichnology (Kirk-CX)
hmer Encyclo-Pedia of
Chemical Technology) Level 2 Volume 19 John Wifley Publication 1
Elemental sulfur may be produced from Nikko using the Krauss process, as described in 969, p. 353. The excess S02 is either chemically combined with the removed limestone or processed and discarded by suitable conventional extraction methods. The dry, clean, purified turbine exhaust gas stream leaves the gas purification zone at a temperature of 37.8 to 427 oO (100 to 800 oO).
0F) at a pressure of 10 to 180 kg/, preferably in a range of 15 to 60 k9/average %, resulting in a product gas stream, for example, having the following composition in mol %: Day 2
15-98 CO I-750 days 4
0~30N 0~70A
The turbine exhaust gas stream from the O~2.0 acid gas absorption zone is compressed into a product gas stream to a pressure at least slightly higher than the pressure within the gas generator.

As previously mentioned, a portion of the product gas stream is recycled to the mixing zone as the recycle gas stream. The remainder of the dry, clean, purified, compressed product gas stream is removed from the compression zone as product gas, syngas or fuel gas. In an embodiment of the invention, the hot effluent gas stream from the gas generator is cooled simply by introducing solids-free water in liquid phase into the effluent gas stream.

Here, a portion of the recycle gas stream is not recycled for use as a temperature moderator.

If the effluent gas stream contains entrained solids such as ash, refractories, particulate carbon, etc., these are removed in the aforementioned free-flow undergravity zone or cyclone separation zone before admitting cooling water. The temperature and amount of water mixed with the hot effluent gas from the generator as a temperature moderating agent is such that the process gas stream is at a temperature between 982 and 16°C.
4900 (800-30000F) to 538-131
6 qo (1000 to 240 pF) is sufficient to cool the temperature to a temperature above the dew point. The solid-free water may be introduced in the liquid phase as a spray. Boiler feed water or condensate from other steps of the invention may also be used.
The water is heated by indirect heat exchange with the turbine exhaust gas stream before entering the hot effluent gas stream from the generator. The temperature-relieving gas flow is then controlled at an inlet pressure of 10-20
It is placed in an expansion turbine that generates power as a working gas in the range of 0 kg/kg. After expansion in the turbine, the exhaust gas stream has a temperature of 177-53,800 (350-10,000 F).
It leaves the turbine at a pressure in the range of 2 to 15 k9/ground. Conveniently, the heat is recovered by indirect heat exchange with the hydrocarbonaceous fuel feed and or by preheating the water to moderate the temperature of the effluent gas stream from the generator as described above. Ru.

Sometimes, steam is produced by cooling the turbine exhaust gas stream in a gas cooler. The cooled turbine exhaust gas is then, if necessary, cleaned of any remaining entrained solids in a conventional gas clean zone. To remove all particulate carbon,
Cleaning operation is performed. A slurry of liquid hydrocarbon fuel or particulate carbon in water is produced in the gas clean zone and recycled to the gas generator as at least a portion of the feedstock. Suitable gas cooling and cleaning methods have been described above. If the concentration of hydrogen gas in the product gas is desired, sometimes the turbine exhaust gas stream is then entered into a catalytic water-gas shift conversion zone, as described above.

Also, sometimes the process gas stream is entered into a conventional gas purification zone to remove acid-gases as described above.
Moreover, the gas purification zone is installed before or after the next step. The next step involves compressing the product gas stream to a desired pressure that is less than, the same as, or greater than the pressure within the gas generator. The product gas stream is compressed by at least one compressor operated by the expansion turbine. Sometimes, the expansion turbine also drives a turbogenerator. The steps of the present invention will be explained below based on drawings.

A free-flowing non-contact partial oxidation gas generator 1 lined with a refractory 2 as described above comprises an upper flanged inlet 3 concentric with the shaft, a lower flanged outlet 4 concentric with the shaft, and a filler. reaction zone 5.

A ring-shaped burner 6 with a central passage 7 concentric with the axis of the gas generator 1 rests on the inlet 3. The central passage 7 has a flanged upstream inlet 8 and a conical downstream nozzle 9 converging at the burner tip. The burner 6 also has an upstream flanged inlet 10 and a downstream frustoconical discharge channel 11.
Burners designed for pond species may also be used. The continuous flow of free-oxygen containing gas from lion 20 is compressed in compressor 56 and passes through line 22 to flanged inlet 8 of burner 6. For hydrocarbon fuel, line 23
, enters the burner 6 through the inlet 10. Sometimes, the hydrocarbonaceous fuel is passed through lines 25 and 26 to heat exchanger 24.
is preheated. Sometimes the steam in line 27 is used to atomize the hydrocarbon fuel. A flanged ``T'' coupler 30 lined with end fire and separated,
It has a slightly spherical shape and is connected to the outlet 4 of the gas generator 1 by a part 31.

An outlet 32 concentric with the shaft connects with a slug pot 34. The flanged axial outlet 35 is vertical in the closed position and closed by a valve 40. The effluent gas stream from the gas generator 1 passes through the outlet 4. The gas flow then enters the coupler 3 through inlet 31 and then to outlet 37.
and exits coupler 30 through line 38. Connector 30
Any slag, carbon, metal or refractory that separates from the effluent gas stream at the slug pot 34 collects at the bottom of the slug pot 34. Accumulation in the slug pot 34 may be removed through line 39, valve 40, line 41, or a conventional lock-hop system (not shown).
pers$tem). The effluent gas stream from the generator in line 38 is mixed with a temperature moderating agent described below in line 42.

A mixer may be present here, but is not shown here. The gas mixture in line 42 is passed as a working fluid through expansion turbine 50'. Expansion turbines provide the power to compress the gas and sometimes operate a generator. In this way, the expansion turbine 50' has shafts 51, 52 and 53.
It is connected to compressors 54, 55 and 56 by.
Although not shown here, the generator may be rotated by the shaft 57. Although the shafts are shown as straight in the drawings, they may be skewed, connected by flexible joints, or rearranged. Any suitable method may be used to utilize the rotational power provided by expansion turbine 50. The evening bin exhaust gas leaving the expansion turbine 50 may be cooled with a conventional heater or gas cooler or both. For example, turbine exhaust gas in line 60 passes through heat exchanger 24, line 61,
Sometimes it passes through a gas cooler 62. In a gas cooler, water is
Changes to steam and leaves from line 20. The gas stream then enters gas cleaner 63 through line 64 where substantially all particulate carbon and remaining accompanying solids are removed. As previously mentioned, in the gas cleaning step, the gas process is scrubbed with water from line 65 to create a carbon-water dispersion.

This dispersion is redissolved by addition of liquid hydrocarbon. A carbon-liquid hydrocarbon slurry is produced and the slurry is fed to a gas generator as part of the feed.
In this manner, liquid hydrocarbons enter gas clean zone 63 through line 66 and carbon-liquid hydrocarbon slurry exits through line 67. When it is desired to increase the hydrogen content of the product gas while simultaneously decreasing the amount of carbon monoxide, the process gas stream in line 68 enters a water-gas shift conversion zone, not shown in the drawings. The process gas stream or Q-enriched gas stream in line 68 leaving the water gas conversion zone is freed of water and sometimes C02,5S
and purified to remove at least one acid gas from the COS group. For example, line 68 p. The process gas stream may be cooled below the fog point in a cooler 69. The process gas stream then enters a gas-liquid separator 75 via line 76 where water and therefore condensate are removed from line 77. The gases, except for water, are removed from line 78, valve 79 is closed and valve 80 is opened, and the process gas stream passes through lines 81 and 82 and enters acid-gas absorber 83.

The acidic gas is removed by a solvent (absorbent) that has not yet absorbed impurities in the acidic gas absorber 83.

The solvent enters the acid gas absorber 83 via line 84 and exits to line 85 after being saturated with acid gas. Pure gas leaves via line 86. Acidic turbine exhaust gas stream
All or a portion of the process gas stream in line 78 is passed through the acid-gas absorber if it is not necessary to pass it through the gas absorber or if the gas needs to be compressed in compressors 54 and 55 before passing through the gas absorber. 83 will be bypassed. In this case, valve 79 is opened and valve 80 is closed, passing the process gas stream through lines 87, 88, and 89 to compressor 54. The cooled, cleaned, dewatered, and sometimes purified product gas stream enters compressor 54 via line 89. Sometimes, a compressor is used with an additional product gas stream passed through line 90, cooler 91, line 92 and to compressor 55. Water Z
is removed from line 93. In a preferred embodiment,
Open valves 100, 101 and valves 102, 103, 1
04 is closed to recirculate at least a portion of the compressed product gas stream through lines 105, 108, 45, 44, and 43 to the aforementioned mixing zone 4J2.

The remainder of the compressed product gas stream exits compressor 55 as product gas through line 109 and is used as synthesis gas, hydrogen enriched gas, or fuel gas.

Here, the gas containing Day 2 and CO is Line 1 209
product gas flow at Sometimes, solids-free water or steam, such as condensate from line 77, i.e. saturated or superheated steam, is transferred to line 11.
0 valve 104 and line 111 into the recycle gas stream in line 44. In the embodiments described above,
The compressed product gas stream is compressed and then purified.

In this case, valves 80, 101, and 103 are closed, valves 79, 100, and 102 are open, and the compressed product gas stream is transferred to lines 105, 106, 115, and 116.
The gas is then passed through an acid gas absorber 83. At least a portion of the purified gas stream leaving the purification zone is in lines 117, 45, 4.
4 and 44 to enter the mixing zone 42. sometimes line 1
Condensate and steam from 10 are mixed with compressed purified gas in line 44. A portion of the compressed purified gas in line 1 17 is discharged as product gas through line 118, valve 103 and line 119. In other embodiments of the invention, the only solids-free water or condensate in line 110 is used to moderate the temperature of the generator effluent gas stream in line 38.

In this case, valve 100 is closed. The other steps of this method are the same as the preferred embodiment, including other variations, heat exchanger 24, water-gas shifting, and acid-gas absorber 83. When water is heated, such as fog water, by the hot generated gas, a high cooling effect per pound of the cooler can be obtained by the heat absorbed by evaporation. EXAMPLE A hydrocarbonaceous fuel was partially oxidized with oxygen (approximately 98.0 mole percent purity) to produce a continuous effluent gas stream.

Conditions such as temperature and pressure are shown in Table 1 below. The exit gas stream has a temperature of 142900 (26050F) and a pressure of 85k9/
Exit the gas generator in chunks (1215 psla). line 3
The composition of the effluent gas stream at 8 was compared to the vacuum distillation retentate feed oil at 10
Expressed in pounds moles per 0 pounds: day 2 5.
612 days 20 1.365CH4 0
．． 061 C0 6.380C02
0.623 N2 0.018A
O. 065 day 2S O. 136COS
O. 008 Table 1 The cooled and cleaned recycle gas stream from line 43 is:
Expansion turbine 5 is mixed with the effluent gas stream from line 38
Create a gas mixture that goes to 0.

The turbine exhaust gas flow in line 6 is transferred to the heat exchanger 24
It is cooled down and exits to line 67. The turbine 2 exhaust gas stream is scrubbed with water to remove any particulate carbon and is further cooled below the dew point to condense the water. The turbine exhaust gas stream is then purified in an acid gas absorber 83 to provide QS and C
The OS is removed. The product gas stream in line 86 is then compressed in compressors 54, 65 and 56 with additional water removed between the compressors. After compression, the recycle gas stream in line 45 is mixed with condensate in line 110 and in line 44.
generates a recirculated gas stream at This recycle gas stream is heated in heat exchanger 24 to produce a cooled (compared to the effluent gas flow in line 42) and cleaned recycle gas mixture in line 44. In this example,
The expansion turbine 50' produced 83.3 horsepower per 100 pounds per hour of hydrocarbonaceous feed oil entering through line 25. This power, after providing the necessary power to the three compressors 34 and 55, is 26 net per 100 pounds of supplied oil per hour.
．． 4 horsepower left. Since oxygen is supplied at the pressure of the system,
Compressor 56 is omitted. Moreover, the product gas (synthesis gas) in line 109 is 112 k9/area (160 ksi
a) Increased to 4. Using conventional gas generation conditions of 85 k9/ground (1215 psia) and a series of cold carbon scrubbing and acid gas removal, the product gas is
It was 2k9/ground (1170psi).

The amount of useful power provided by the present invention is greater than the amount of power provided by a closed Playton cycle.

The total heat output in a closed Playton cycle is expensive;
This is obtained through indirect gas-gas heat exchange, which is inefficient. In contrast, the present invention utilizes the inherent heat content of the exiting gas stream. The invention has the following advantages:'1}
The present invention provides a significant increase in power production compared to closed playton cycles.

Furthermore, it is possible to eliminate sending hot high pressure gas to a heat exchanger. ■ Compared to some other power systems, large entropy gains associated with large temperature differences between the gas generator and the turbine inlet can be reduced.

The working fluid required for the '3' power cycle is produced in the stave of the present invention, and the working fluid has approximately the same composition as the product gas.

This eliminates the cost, inventory, preparation, contamination and storage problems of separate working fluids. [41] Since another working fluid is removed, the required amount of heat transfer between the multiple streams and the thermodynamic losses caused thereby can be reduced.

■ Acid-if the gas is in the turbine exhaust stream,
Can be removed.

Thus, the life of the compressor and turbine in the system can be extended. The turbine exhaust gas stream is suitable for catalytic reactions in later steps, thus reducing the occurrence of environmental pollution problems. '6} Power can be obtained from large molar increases.

The molar increase is obtained with partial oxidation of the hydrocarbonaceous fuel. In addition, power is derived from the high pressure and sensible heat of the hot partially oxidized effluent gas stream.

[Brief explanation of the drawing]

The drawings illustrate the steps of the invention. 1: Gas generator, 30: “T” coupler, 34: Slug pot, 24: Fusuma heater, 50: Expansion turbine, 62,
69: Gas cooler, 63: Gas purifier, 75: Gas-liquid separator, 83: Acid-gas absorber, 54, 55, 56:
compressor.

Claims (1)

Claims: 1. (a) A hydrocarbon fuel in a reaction zone of a free-flowing gas generator together with a free-oxygen-containing gas and a temperature modifier at a temperature in the range of 982-1649°C (1300-3000°F) and a pressure of 10°C. Partially oxidized in the range of ~200 kg/cm^2, H_2, CO, CO_2, H^2O and H_2
producing an effluent gas stream consisting of at least one of the group S, COS, CH_4, N_2 and A and accompanying particulate carbon and other solids; (b) entrained solids from the effluent gas stream of (a); (c) the effluent gas stream of (b) is mixed with the cooled clean compressed recycle gas stream of (g) in a mixing zone, wherein said effluent gas stream to mixing zone The volume ratio of the mixed gas flow at 0.2:0
．． (d) The mixed gas flow of (c) is heated to a temperature of 538 to 1316°C (1000 to 2
400°F) and temperatures above the dew point
Inflate in the range of ~200 kg/cm^2, (e) (
d) turbine exhaust gas flow at a pressure of 2 to 15 kg/cm
^2 range, temperature 177-538℃ (350-1000℃
(f) (e)
The turbine exhaust gas stream of is purified by cooling, cleaning residual particulate solids, condensing out water,
f) compressing the product gas stream of (a) in at least one gas compression zone operated with the power produced by said expansion turbine to a pressure above the pressure in the gas generator of (a); and compressing a portion of the compressed gas; passing as said recycle gas stream through the mixing zone of (c); and (h) recovering the remainder from the compressed gas stream of (g) as said product gas stream.
A method for producing synthesis gas consisting of H_2 and CO along with power. 2(c), the inlet temperature of the mixed gas stream to the expansion turbine is 760-1204°C (1400-2200°F).
2. The method of claim 1, wherein the effluent gas stream and the recycle gas stream are mixed such that: ). 3. The method of claim 1, wherein water or steam is added to the recycle gas stream of step (g). 4. The purification of (f) is performed by removing all acid-gases from the clean, water-free gas stream in a gas absorption zone before the turbine exhaust gas stream enters the compression zone of (g). 1
The method described in section. 5. The method of claim 1, wherein in the purification of 5(f), the turbine exhaust stream is subjected to a catalytic water-gas shift reaction. 6. The recycle gas stream of (g) is removed in the absorption zone from all acid-
2. The method of claim 1, excluding gas. 7. The method of claim 1, wherein the turbine exhaust gas subjected to the water-gas shift reaction is freed of all acid gases in an acid-gas absorption band. 8. The method of claim 1, wherein the purification of (f) is carried out on the compressed gas of (g). 9. The method of claim 1, wherein a generator is coupled to the power generating turbine to produce electrical energy. 10 Free-oxygen-containing gas is air, oxygen-enriched air (O
21 mol% or more) and almost pure oxygen (O_2
95 mol% or more). 11 The hydrocarbon fuel is liquefied petroleum gas, petroleum distillate and its residual oil, gasoline, naphtha, crude oil, asphalt, gas oil, residual oil, tar sand oil, shale oil, coal derived oil, benzene, toluene, xylene The liquid hydrocarbon selected from aromatic hydrocarbons such as distillates, coal tar, recycle gas oil from fluid catalytic cracking processes, furfural extracts of coked gas oil and mixtures thereof. The method described in section. 12. The method according to claim 1, wherein the hydrocarbonaceous fuel is a gaseous hydrocarbon. 13. Waste liquids and by-products from chemical processes where hydrocarbonaceous fuels include hydrocarbons, cellulosic substances, aldehydes, organic acids, alcohols, ketones, oxidized fuel oils, oxidized hydrocarbonaceous organic substances. 2. The method of claim 1, wherein the oxidized hydrocarbonaceous organic material is selected from the group consisting of: and mixtures thereof. 14(b), wherein the accompanying solids are separated in a slag pot, said solids being selected from particulate carbon, ash, slag scale, refractories, metal components and mixtures thereof. the method of. 15. A patent in which the hydrocarbonaceous fuel is a pumpable slurry of solid hydrocarbonaceous fuel selected from the group consisting of coal, lignite, wood pulp, granular carbon, petroleum coke and concentrated sour sludge and mixtures thereof. The method according to claim 1. 16. The method of claim 1, wherein the product gas streams are synthesis gas and fuel gas. 17 (a) In the reaction zone of a free-flowing gas generator,
The hydrocarbonaceous fuel is heated to a temperature of 982°C to 1649°C (1800°F to 3000°F) with a free oxygen-containing gas and a temperature modifier.
), and at a pressure of 10 to 200 kg/cm^2, at least one of the group H_2, CO, CO_2, H^2O and H_2S, COS, CH_4, N_2 and A and associated granules. (b) removing a portion of the entrained solids from the effluent gas stream of (a); (c)
Water in liquid phase is added to the effluent gas stream of (b), preheated by the turbine exhaust gas stream of (e), and said effluent gas stream is
(d) the mixed gas stream of (c) is cooled to a temperature above the dew point in a temperature range of 316°C (1000-2400°F);
The turbine exhaust gas flow of (e) (d) is expanded by putting it into an expansion turbine at a pressure of 10 to 200 kg/cm^2,
Pressure range 2~15kg/cm^2, temperature 177~53
(f) purifying the turbine exhaust gas stream of (e) by cooling to clean any remaining entrained particulate solids, concentrating and removing water; (g) compressing the product gas stream of (f) in at least one gas compression zone operated with the power produced by the expansion turbine; (h) (g)
recovering the compressed gas stream as a product gas stream. A method for producing synthesis gas consisting of H_2 and CO along with power. Claim 1, wherein a portion of the water used in (c) is produced from the turbine exhaust gas stream of (f).
The method described in Section 7. Claim 17, wherein the purification of the turbine exhaust gas in 19(f) is carried out by a catalytic water-gas shift reaction.
The method described in section. 20. The method of claim 19, wherein the purification of the turbine exhaust gas in step 20(f) is performed by a shift reaction to further remove acid gases in an acid gas absorption zone. 21. The method of claim 17, wherein the purification of the turbine exhaust gas is carried out in (f). 22. The method of claim 17, wherein the purification of turbine exhaust gas is carried out on the compressed gas stream of (g).