Classifications

• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10K—PURIFYING OR MODIFYING THE CHEMICAL COMPOSITION OF COMBUSTIBLE GASES CONTAINING CARBON MONOXIDE
  • C10K1/00—Purifying combustible gases containing carbon monoxide
  • C10K1/04—Purifying combustible gases containing carbon monoxide by cooling to condense non-gaseous materials
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
  • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
  • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
  • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
  • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
  • F01K23/067—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle the combustion heat coming from a gasification or pyrolysis process, e.g. coal gasification
• • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
  • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
  • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
  • F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
  • F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
• • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
  • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
  • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
  • Y02E20/00—Combustion technologies with mitigation potential
  • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
  • Y02E20/18—Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]

Definitions

• This invention relates to a process for cooling, in particular for cooling by allowing an endothermic chemical reaction to occur (“chemical cooling”) , of a hot gas stream and in particular a synthesis gas stream, to a process for increasing the efficiency of the electricity production utilizing a synthesis gas stream, as well as to a process for regulating the cooling process of a synthesis gas stream in such a manner that peaks in the electricity demand can be accommodated.
• electricity can be generated with different resources.
• the fossil fuels oil, gas and coal are employed on a large scale for electricity production. These fossil fuels are burned for driving gas turbines, optionally in combination with steam turbines.
• the present invention relates to processes in which fossil fuels, but also other hot combustible gasses, can be employed.
• Natural gas burns efficiently in the sense that the overall efficiency for the conversion of natural gas into electricity (efficiency approximately 55% based on the net heating value) is higher than the overall efficiency for the conversion of other fossil fuels to electricity (efficiency for coal approximately 43% based on the net heating value) .
• the net heating value is the calorific lower value or Lower Heating Value of the gaseous fuel stream to the gas/steam turbine system.
• natural gas produces the least amount of CO per kWh electric energy generated.
• the use of natural gas in contrast with the use of coal, does not lead to the formation of large amounts of fly ash.
• coal, other heavy fossil fuels and other carbonaceous raw materials are not burned without more, but are gasified first.
• the gasification of th heavy or heavier fuels which may or may not be carbonaceous couples the advantages of the use of natural gas to a large arsenal of available and relatively cheap starting materials
• coal or oil gasification whereby fuel gas is produced, has an advantage in gas cleaning over coal and oil combustion, whereby flue gas is formed. More in particular, during the gasification in the upstream gasifier, heating ga or fuel gas is formed; as contrasted with pulverised coal plants, where the solid pulverised coal serves as fuel.
• the cleaning thereof is simpler than the cleaning of flue gas of low pressure. Due to the higher pressure of fuel gas relative to the flue gas, smaller equipment will suffice for the cleanin of fuel gas.
• the sulphur components in the form of hydrogen sulphide can be removed elementary as sulphur with a sulphur recovery percentage of 97-99%, while in the case of flue gas cleaning sulphur components mainly in the form of sulphur dioxide hav to be removed as gypsum, with a recovery percentage of only 85-90%.
• the us of the gasification technology moreover leads to a lower NO x and fly ash emission.
• Gasification installations generally comprise a gasifyi unit, a cooling section, a gas cleaning section and gas and/ steam turbines.
• a gasifying unit the fossil fuel is partially oxidized with oxygen or an oxygenous gas.
• synthesis gas Gasification of coal, oil, cracked residues, residues remaining after hydroconversion of atmospheric residues and vacuum residues, etc., leads to the formation of so-called synthesis gas.
• this synthesis gas comprises a complex mixture of hydrogen, carbon monoxide, carbon dioxide, steam, nitrogen, nitrogen oxides, hydrogen sulphide and other compounds formed from the constituents of the starting material.
• An example of a gasification process for heavy hydrocarbons is described in European patent application 0,497,425 (Shell); for an example of a coal gasification process reference is made to European patent application 0,423,401 (The Dow Chemical Company), which application will be further discussed hereinbelow.
• Gasification occurs at a relatively high temperature.
• Oil (residue) gasification typically takes place at a temperature of 800-1500°C.
• Coal is usually gasified to synthesis gas at even higher temperatures of 1300-1650°C.
• This cooling section comprises, for instance, a synthesis gas cooler (syngas cooler) .
• the syngas cooler is in fact a conventional convective heat boiler, a standard heat exchanger.
• the synthesis gas is introduced at the top of this cooler and flows from the top down. Heat is exchanged with the water in the boiler, whereby steam is generated.
• the syngas coolers employed heretofore usually operate at a temperature of "only" about 900°C at a maximum. This temperature is essentially determined by the presence of fly ash in the hot gas phase.
• fly ash particles is present in the hot synthesis gas. It happens that approximately half of the total amount of ash formed upon the gasification of coal ends up in the hot synthesis gas in the form of fly ash.
• ash is heated to above its melting point.
• the fly ash particles thus formed have to be removed from the synthesis gas or brought into the solid state before the synthesis gas reache the syngas cooler, the purpose being to avoid clogging or other inconveniences caused by deposition of solid fly ash i the cooler, such as a delayed or insufficient heat transfer between the gas to be cooled and the cooling medium.
• a suitable manner of removing fly ash is rapid cooling of the synthesis gas to below the melting point of the fly ash, whi means, in practice, that rapid cooling to approximately 900° is required. In this way the ash particles do not become sticky, so that the fouling behaviour of the pipe surfaces i the syngas cooler is controllable. For that matter, the soli fly ash particles are not removed from the synthesis gas unt after the cooling section.
• the cooling of the hot gas nearly always takes place in two steps.
• the first step which comprises cooling from, for instance, 1600°C to 900°C, can be carried out by quenching with already cooled synthesis gas or water or by cooling wit a radiation cooler. Because a radiation cooler is a very costly apparatus on account of the very high standards which its construction and material are required to meet, cooling generally effected by recirculation of already cooled synthesis gas or water. When cooling is effected with water, the resultant gas contains very much water vapour.
• the second cooling step will be carried with the syngas cooler already mentioned.
• the pre-cooling step is carried o by cooling or quenching the hot synthesis gas which has a temperature of 1500-1650°C with synthesis gas which has already passed the syngas cooler and which has a temperature of about 250°C.
• hot and cooled synthesis gas in a ratio of about 1:1, a synthesis ga stream of a temperature of about 900°C is obtained.
• the just discussed cooling step with cooled synthesis gas has a number of disadvantages, the most important of which will presently be discussed briefly.
• recirculating cooled synthesis gas requires a number of mechanical adaptations. For instance, a relatively large recirculation compressor is necessary to recirculate the cooled synthesis gas into the hot gas stream before it reaches the syngas cooler.
• Another, major mechanical adaptation is connected with the fact that a volume of gas which is approximately twice as large as the volume of synthesis gas produced must pass the synthesis gas cooler, since both the hot synthesis gas and the amount of cooled synthesis gas added thereto have to be cooled in the syngas cooler. Accordingly, a relatively high duty syngas cooler which is relatively large for the synthesis gas stream produced by gasification is required.
• cooling section may also be constituted by a "radiant heat water tube boiler” in combination with a convective cooler.
• a cooling apparatus is used in the Texaco coal gasification installation and is described in the brochure "Technology available for licence from Texaco", Texaco Development Corporation, Artwork &
• a hot gas in particular a hot synthesis gas
• a hot gas stream is injected Into the hot (synthesis) gas stream is injected a relatively small amount of a hydrocarbon or hydroxylated hydrocarbon and optionally water (preferably in the form of steam) and/or carbon dioxid
• a hydrocarbon or hydroxylated hydrocarbon and optionally water (preferably in the form of steam) and/or carbon dioxid
• th hydrocarbon will rapidly react with the water (see reaction and/or the carbon dioxide (see reaction 2) to form substantially carbon monoxide and hydrogen gas.
• the reaction between the hydrocarbon and carbon dioxide is composed of the so-called “shift reaction” (see reaction 3) and the reaction between hydrocarbon and water (reaction 1) .
• the invention relates to a process f chemically cooling a hot gas stream, in particular a hot synthesis gas stream, of a temperature above 900°C, in which gaseous hydrocarbon, and optionally water and/or carbon dioxide, is introduced directly into the hot gas stream.
• gaseous hydrocarbon is also understood to refer to liquid hydrocarbons which upon introduction into the hot gas stream pass into the gas phase
• the invention relates to a process for increasing the efficiency of electricity production, utilizing a synthesis gas stream from a gasification plant, wherein a gaseous hydrocarbon, and optionally water and/or carbon dioxide, is introduced directly into the synthesis gas stream, before the product stream is supplied to electricity- generating plants.
• the process according to the invention is especially of advantage for chemically cooling synthesis gas produced by the gasification of coal or oil (residues) .
• This gas has a temperature of about 1000-1650°C at a pressure between about 25 and 70 bara.
• further cooling can be effected by means of a physica cooling or by recirculation of gas cooled in the cooling section or by direct injection of additional gaseous hydrocarbon and/or water and/or carbon dioxide.
• the chemical and physical quench can be carried out simultaneously in the same reaction vessel. Since additional water has an adverse effect on the efficiency and since additional carbon dioxide gives an impoverishment of the syntnesis gas mixture, preferably only additional hydrocarbon is injected. In the manner just described, a cooling process in two parts is obtained, in which initially a chemical quenc is carried out and subsequently a physical quench.
• the cold gas stream is preferably supplied on or along the wall. This prevents fly ash particles in the gas to be cooled from solidifying and thereby causing problems.
• the composition of the hot gas has relatively little influence on the effect of the endothermic reaction to be carried out in accordance with the process of the invention.
• the decrease in temperature is a result of the removal of sensible heat.
• the heat capacities of the different hot (synthesis) gas components ar approximately the same. Only the presence of water vapour and carbon dioxide in the hot gas stream influence the process control to some extent because these gasses participate in th endothermic cooling reaction.
• the hot offgas from the gas turbine is thereafter employed for the production of steam under high pressure.
• This steam is thereafter expanded in the steam turbine, whereby likewise electricity is produced.
• the total energetic efficiency of a STEG installation an apparatus which is known from the prior art, is normally around 55% based on the net heating value.
• the processes according to the invention have the following advantages with regard to efficiency.
• a conversion of a gaseous hydrocarbon to synthesis gas takes place.
• the synthesis gas gives a higher efficiency as far as the electricity production in a gas turbine is concerned than does the gaseous hydrocarbon starting product.
• a second advantage resides in the fact that less steam is produced in the cooling section.
• the total gas stream through the cooling section is reduced compared with the known physical cooling process such as it is employed, for instance, in the gasification installation in Buggenum.
• the overall efficiency for electricity production from steam (40% on an enthalpy basis) is much lower than is the overall efficiency of electricity production from synthesis gas (> 50% based on the net heating value) .
• a third advantage results from the fact that the chemical exergy loss in the quench by means of a chemical reaction is lower than in a physical quench.
• the amount of cold gas supplied is much lower, so that the loss of physical exergy is greatly limited.
• the endothermic reaction takes place at the bulk temperature of the gas, so that only a limited exergy loss arises as a result of the progress of the chemical reactions during chemical cooling.
• the heat released upon cooling of the hot synthesis gas is stored, as it were, in t form of chemical energy.
• the products formed are products which are already demonstrable in the hot gas.
• the gas stream through the syng cooler decreases, since in volume much less gaseous hydrocarbon and optionally water or steam and/or carbon dioxide needs to be supplied than the amount of cooled synthesis gas to be admixed to arrive at a desired synthesis gas temperature. All this leads to reduced capital outlay. O the one hand, a smaller syngas cooler will suffice, on the other, a smaller recirculation compressor for the feedback of cooled synthesis gas will be needed, or none, ideally.
• a syngas cooler of a capacity of 70-80% of that of the conventional synthesis gas cooler will suffice.
• coke of coal, coal tar, petroleum coke, but also coaly material obtained from shale oil, tar sand, pitch, concentrated sewage sludge, rubber, etc. can be added.
• As liquid phase preferably water is used.
• This heavy "cooling material” leads to the formation of a relatively large number of different reaction products compared with the products formed from the gaseous hydrocarbons and water and/or carbon dioxide, the reactants in the processes according to the invention. This implies that additional gas cleaning steps or in any case more extensive gas cleaning steps are needed.
• the method according to EP-A-0,423,401 requires very complex equipment for introducing the "cooling material".
• Dutch patent application 7903522 discloses a method for recovering hydrogen- and carbon monoxide-containing gas mixtures by partial oxidation of organic compounds with steam and/or carbon dioxide. However, no link with the generation of electricity is made.
• hydrocarbons which are, or the mixture of hydrocarbons which is, introduced into the hot synthesis gas in accordance with the present invention must meet the requirement that they react endothermically with water molecules and/or carbon dioxide molecules, substantially without entering into any reactions with other components present in the synthesis gas.
• Suitable hydrocarbons that mee these criteria are C 1 - 4 alkanes, as well as mixtures of such alkanes and hydroxylated derivatives thereof.
• higher hydrocarbons can be used as well.
• natural gas, refinery gas, and/or LPG are used as hydrocarbon component.
• refinery gas is intended to refer to t light hydrocarbon fractions formed as by-products in crackin distillation, platforming, etc. of oil or oil residues. Ligh cracked products of other organic material, such as biomass, wood and refuse can also be used. Since the process line of gasification installation includes gas purification apparatu it is no problem if slightly polluted gaseous hydrocarbons, such as unpurified or "sour" natural gas or refinery gas, ar used. As stated hereinabove, hydroxylated hydrocarbons can al be used. These compounds substituted with hydroxyl groups al react endothermically with water and/or C0 2 .
• hydrocarbon-containing gasses formed in the (anaerobic) biological degradation of organic material in unpurified form.
• gasses are formed, for instance, upon fermentation or anaerobic composting of the organic part of waste, in particular household refuse or vegetable refuse, fruit refuse and garden refuse, in anaerobic water purification and in the processing of manure.
• the hot synthesis gas may or may not necessary to inject, in addition to the hydrocarbon stream, additional water, usually in the form of steam, and/or carbo dioxide.
• additional water usually in the form of steam, and/or carbo dioxide.
• the endothermic reaction requires one wate molecule or one carbon dioxide molecule per carbon atom of t hydrocarbon compound; if hydroxylated hydrocarbons are used, fewer water and/or carbon dioxide molecules are needed.
• the ratio of gaseous hydrocarbon to water and/or carbon dioxide is not critical. The supply of an excess of gaseous hydrocarbon or an excess of water and/or carbon dioxide will provide for a physical cooling.
• a synthesis gas is produced in which as little C0 as possible is present.
• This embodiment can be realized by adding so much hydrocarbon gas that substantially all carbon dioxide is consumed in the reaction with hydrocarbon.
• coal gas coming from a dry gasification installation contains approximately 2% C0 2 and 3% H 2 0. In a wet gasification process, these values are considerably higher, for instance 11% C0 2 and 13% H 0.
• a skilled person can determine the composition of the gas to be cooled in a relatively simple manner by known techniques. On the basis of these data, he can determine the supply of the reactants to be injected, depending on the gaseous hydrocarbon to be used and the water and/or carbon dioxide gas to be injected. Usually it is sufficient to introduce about 5-10% methane directly into the hot gas stream.
• reaction product of the endothermic reaction employed for cooling the synthesis gas stream consists for a considerable part of carbon monoxide and hydrogen gas. This product mixture provides for an enrichment of the synthesis gas stream, which leads to a higher efficiency in the STEG installation.
• the stream through the syngas cooler ma even become smaller.
• the overall efficiency is less in comparison with the separate generation of energy from th synthesis gas stream on the one hand and the hydrocarbon gas stream on the other.
• the chemical and physical quenches can be effected simultaneously and in the same reactor vessel.
• the gaseous hydrocarbon to be used for the purpose of chemical cooling will react effectively with water and/or carbon dioxide molecules only a particular minimum temperature. It may be that, depending the conditions in the hot synthesis gas, the endothermic reaction proceeds with a high conversion of about 80% above, for instance, 1200°C and has a low equilibrium conversion of only 30% at a temperature of, for instance, 900°C. More particularly, at a lower temperature the endothermic reactio will shift to the side of the hydrocarbon. Moreover, as the temperature decreases, the rate of reaction decreases too.
• the invention further relates to a process for regulating the cooling process of a synthesis gas stream, in such a manner that peaks in the electricity demand can be accommodated, with an increased electricity production being obtained in that the cooling step of the synthesis gas, depending on the increased energy demand, is carried out by injecting a gaseous hydrocarbon and optionally water and/or carbon dioxide stream in combination with the recirculation of already cooled synthesis gas" or with physical cooling with a gaseous hydrocarbon, water or carbon dioxide stream.
• cooling can be effected by the use of the chemical cooling process according to the invention in combination with a second cooling step, in which recirculation gas is utilized. If the electricity demand increases at a particular time of the day, it is possible, in accordance to the invention, to switch from the recirculation cooling in the second cooling step to a cooling process in which a cold gaseous hydrocarbon stream is injected directly into the synthesis gas stream. Thus, in the second cooling step a physical cooling with a gaseous hydrocarbon stream is employed.
• Methanol in particular has advantages in the day/night power control. During the nightly off-peak hours, coal gas can be used for synthesizing methanol. This methanol can subsequently be used in the chemical quench during peak-hours and as fuel for generating electricity.
• a very suitable cooling agent by means of which the chemical and physical cooling can be carried out is an unpurified hydrocarbon gas stream, for instance a sour natural gas stream or an unpurified refinery gas stream.
• a gaseous methane stream of 0.047 kmol/s and a temperature of 25°C was injected together with an amount of steam of 0.047 kmol/s and a temperature of 250°C into a coal gas stream of l kmol/s and a temperature of 1614°C.
• the coal gas stream had the following composition: 27.8 mol.% hydrogen 63.1 mol.% carbon monoxide, 1.6 mol.% carbon dioxide, 5.1 mol.% nitrogen, 0.3 mol.% hydrogen sulphide and 2.1 mol.% water.
• the pressure at the point of injection was approximately 27 bara.
• This gas stream was further cooled to 900°C by admixture of coal gas, cooled in the synthesis gas cooler, of 0.58 kmol/s and a temperature of 247°C, which, of course, had the same composition as the gas described in the preceding paragraph.
• the result was a gas stream of 1.76 kmol/s.
• This gas stream was cooled to 235°C in the syngas cooler, whereby 0.72 kmol/s steam of 250°C and 27 bar was generated. This steam was converted to electricity in a steam turbine with an exergetic efficiency of 90%.
• a gas stream of 0.58 kmol/s was recirculated, after recompression, to the point of admixture for the physical quench.
• the product gas stream of 1.18 kmol/s was passed to a STEG installation. This gas stream was converted to electricity in the STEG installation with an efficiency of 57.51% based on the net heating value.
• the net electricity production in the steam turbine and the STEG installation was 180.5 MW.
• the methane stream of 0.047 kmol/s and a temperature of 25°C was burned in the STEG installation, whereby 20.9 MWe electricity was generated with an efficiency of 55.97% based on the net heating value.
• the coal gas stream (l kmol/s; 27 bara; 1614°C) was presently brought to a temperature of 900°C (2.2 kmol/s) entirely with recirculated cooled gas (1.20 kmol/s; 247°C) .
• This gas stream was cooled to 235°C in a syngas cooler, whereby 0.91 kmol/s steam of 250°C and 27 bar was generated.
• a gas stream of 1.2 kmol/s was recirculated for the physical quench.
• the product stream of 1.0 kmol/s was passed to the STEG installation.
• Example 2 The method as described in Example 1 was repeated with the modification that now the physical cooling step was not carried out with recirculated cooled coal gas but with a stream of 0.24 kmol/s methane of 25°C.
• a gas stream of temperature of 900°C of the following composition was obtained: 28.5 mol.% hydrogen, 47.6 mol.% carbon monoxide, 1.2 mol.% carbon dioxide, 3.6 mol.% nitrogen, 0.2 mol.% hydrogen sulphide, 1.7 mol.% water and 17.0 mol.% methane.
• this gas stream was cooled to a temperature of 235 in the syngas cooler, whereby 0.68 kmol/s steam of 27 bar an 250°C was generated.
• the product gas was fed to a STEG installation where it was converted to electricity with an efficiency of 57.15% based on the net heating value.
• the gaseous methane stream of 0.28 kmol/s and a temperature of 25°C was used in a STEG installation for the production of electricity.
• the conversion to electricity occurred with an efficiency of 55.97% based on the net heati value, which yielded 126.5 MWe electricity.
• the efficiency increase resulting from the use of the process according to the invention is 0.5% based on the net heating value.
• Example 3 in this example it is demonstrated that the use of chemical cooling by means of injection of methane and carbon dioxide in combination with physical cooling with recirculation gas in accordance with the invention leads to a higher efficiency in electricity generation in comparison with separate generation of electricity in accordance with the prior art.
• a gaseous methane stream of 0.040 kmol/s and a temperature of 25°C was injected together with an amount of carbon dioxide of 0.040 kmol/s and a temperature of 25°C into a coal gas stream of 1 kmol/s and a temperature of 1614°C.
• the coal gas stream contained 27.8 mol.% hydrogen, 63.1 mol.% carbon monoxide, 1.6 mol.% carbon dioxide, 5.1 mol.% nitrogen, 0.3 mol.% dihydrogen sulphide and 2.1 mol.% water.
• the pressure of het gas at the point of injection was approximately 27 bara.
• Injection resulted in a gas stream of 1.15 kmol/s of a temperature of 1200°C, which contained 30.2 mol.% hydrogen, 61.1 mol.% carbon monoxide, 1.6 mol.% carbon dioxide, 4.4 mol.% nitrogen, 0.3 mol.% dihydrogen sulphide, 2.0 mol.% water and 0.4 mol.% methane.
• This gas stream was cooled to 900°C by physical admixture of a recirculation stream of already cooled gas of the same composition of 0.57 kmol/s and a temperature of 247°C. This resulted in a gas stream of 1.72 kmol/s of unchanged composition. Then further cooling to 235°C took place in a syngas cooler, whereby 0.71 kmol/s steam of 250°C and 27 bar was generated. A gas stream of 0.57 kmol/s was recirculated, after recompression, to the physical quench point. The product gas stream was 1.15 kmol/s.
• a gaseous methane stream of 0.040 kmol/s and a temperature of 25°C was burned in a STEG installation for th production of electricity.
• the conversion to electricity occurred with an efficiency of 55.97% based on the net heati value, resulting in an electricity production of 18.0 MWe.
• a gaseous methane stream of 0.09 kmol/s and a temperatur of 25°C was injected into a coal gas stream of l kmol/s and a temperature of 1614°C.
• the coal gas stream contained 27.8 mol.% hydrogen, 63.1 mol.% carbon monoxide, 1.6 mol.% carbon dioxide, 5.1 mol.% nitrogen, 0.3 mol.% dihydrogen sulphide and 2.1 mol.% water.
• the pressure at the point of injection was approximately 27 bara.
• a gaseous methane stream of 0.032 kmol/s and a temperature of 25°C was injected into a coal gas stream of 1 kmol/s and a temperature of 1474°C.
• the coal gas stream contained 29.4 mol.% hydrogen, 43.5 mol.% carbon monoxide, ll.l mol.% carbon dioxide, 2.0 mol.% nitrogen, 0.2 mol.% dihydrogen sulphide and 13.8 mol.% water.
• the pressure at the injection point was approximately 40 bara.
• a gaseous methane stream of 0.032 kmol/s and a temperature of 25°C was burned in a STEG installation for th production of electricity.
• the conversion to electricity occurred with an efficiency of 55.97% based on the net heati value, resulting in an electricity production of 14.5 MWe.
• the product gas stream was 1.0 kmol/s.

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Cited By (8)

Citations (5)

• 1994
  • 1994-08-26 NL NL9401387A patent/NL9401387A/nl not_active Application Discontinuation
• 1995
  • 1995-08-25 AU AU32318/95A patent/AU3231895A/en not_active Abandoned
  • 1995-08-25 WO PCT/NL1995/000282 patent/WO1996006901A1/en active Application Filing

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