The combustion of the hydrocarbon gas to produce a reformed gas

 

The invention relates to a system and a method for converting hydrocarbon gas in the reformed gas containing hydrogen and carbon monoxide. The method is carried out by compression of the air supplied to the primary compressor for receiving the primary air, followed by separation into two parts, the first part of which is a primary combustion air. The primary hydrocarbon gas before it enters the mixing chamber is divided into two parts. The first part of the burn with the primary combustion air in the primary combustion zone of the combustion chamber with the formation of the primary gas combustion, and the second part of the primary hydrocarbon gas is fed to the reforming zone, followed by reacting it with a primary gas combustion with the formation of the reformed gas. Reformed gas drives the primary energoterminal and the compressor. Part of the primary air is supplied together with the secondary hydrocarbon gas into the secondary combustion chamber, producing a flue gas, resulting in the effect of the secondary energoterminal and a compressor for compressing gas. In the second implementation of the system is almost identical to the first run, but the compressor and power turbines reconfigured and the system is the receiving of the reformed gas and the actuation of the primary power turbines and compressors. The exhaust gas drives the secondary energoterminal, however, secondary energoterminal actuates the auxiliary primary compressor that compresses the air in front of the primary compressor is energetically self-sufficient way. The exhaust gas is additionally actuates the auxiliary secondary energoterminal to provide additional energy for alternative energy consumers. The system and method of converting uglevodorodnogo gas in the reformed hydrogen-containing gas are more cost-effective compared to conventional systems conversions of hydrocarbon gas due to reduced investment in equipment and operations costs, and also due to the increased product yield. 4 S. and 2 C.p. f-crystals, 3 ill.

Technical field the Present invention relates in General to a system and method for converting hydrocarbon gas in a hydrogen-containing gas and citesti, to a system and method of combustion of hydrocarbon gas in the presence of air to generate a reformed gas containing hydrogen and carbon monoxide.

Information about the counterparts.

Long ago, there is a need to transform the available coal is useful hydrocarbon products, such as liquid hydrocarbon fuels, petrochemicals and the like. For example, one such carbonaceous substances is coal, readily available in some areas. U.S. patent 3986349 addresses the process of coal gasification in an intermediate synthetic gas, which can then be hydrogencarbonates to provide valuable liquid hydrocarbon fuel. This fuel is used for energy production by relatively clean combustion in a gas turbine open cycle.

Natural gas is another carbon material, which is found in abundance in many regions, however, it is uneconomical to develop due to the lack of local markets gas or high costs of transporting gas to other markets. One solution is to produce natural gas and convert it to a field in a more practical liquid hydrocarbon fuel or other liquid product. The transformation product can be used in local conditions or cost-effective to be transported to other markets. Methods of conversion of light hydrocarbon gases such as natural gas, heavier hydrocarbon liquids are known from the prior art. Takanyi connection moreover, methane is first converted to an intermediate synthetic gas containing hydrogen and carbon monoxide. The resulting syngas is then converted into liquid synthetic paraffin hydrocarbon compounds by the reaction of the Fischer-Tropsch process. Unconverted synthesis gas, residual gas remaining in the process after the reaction of the Fischer-Tropsch process, usually catalytically restored to methane by reaction of ketanazii and returns to the input of the process to increase the overall efficiency of the conversion process.

The conversion of methane into syngas is often accomplished by using high-temperature steam reforming, in which methane and steam react endothermically on the catalyst contained in many heated from the outside of the tubes mounted in a large observou oven. Alternative methane is converted into synthetic gas by technolo oxidation, in which the methane reacts exothermically with purified oxygen. Partial oxidation using purified oxygen requires the installation for the separation of oxygen with the possibility of a significant and compression, respectively, with significant energy needs. The production of synthesis gas with methane in paraffin hydrocarbons.

Autothermal reforming is less expensive means of converting methane into syngas. Autothermal reforming uses a combination of partial oxidation and steam reforming. The heat required to activate the reaction endothermic steam reforming, is obtained from the exothermic partial oxidation. In contrast, however, from the above reaction, partial oxidation, as the source of oxygen for the reaction of partial oxidation air is used. In addition, the synthetic gas obtained by autothermal reforming, contains significant amounts of nitrogen from the air inlet. Therefore, it is impossible to re-process the unprocessed components contained in the residual gas of the process, without unwanted accumulation in the process of excess nitrogen. The production of synthesis gas with dissolved nitrogen by autothermal reforming or partial oxidation with air, followed by conversion of synthesis gas by the reaction of the Fischer-Tropsch process, as discussed in U.S. patent 2552308 and 2686195 are, however, a useful tool for the production of synthetic liquid hydrocarbon products from methane.

Patd reacts with air in the presence of recirculating carbon dioxide and steam for the production of synthetic gas. Synthetic gas obtained in the presence of a hydrocarbon synthesis catalyst containing cobalt, forming a residual gas stream and the liquid stream containing heavier hydrocarbons and water. These heavier hydrocarbons are separated from the water and recovered as product. The residual gas is catalytically combusted with additional air to obtain carbon dioxide and nitrogen, which are separated. At least part of the carbon dioxide re-served on the step autothermal reforming.

Known from the prior art methods of converting hydrocarbon gas can meet the requirements of the conversion of hydrocarbon gases in the reformed gases such as synthesis gas, is used as intermediate products in the production of the desired end products. However, it is found that such methods are not cost-effective due to the significant investment in equipment and energy required to compress the inlet air. The energy required to compress the air inlet is a significant part of the mechanical energy required in the process, and much of this energy is lost in the form of non-renewable energy pressure premiato the fuel in the form of unconverted compounds and unrestored products often remains in the residual gases downstream. In General strongly rarefied nature of the residual gas downstream and its low calorific value are not effectively recover energy from the fuel. As a result, often the fuel energy is lost or restored with great difficulty and expense.

Another disadvantage present in the known methods of converting hydrocarbon gas, particularly when the autothermal reforming or partial oxidation, is the limited output of the desired intermediate product resulting from that process. Despite the fact that the reaction autothermal reforming or partial oxidation reach equilibrium at high temperatures, during the subsequent step of cooling/damping is significant reverse reaction, reducing the net output of intermediate products. Thus, it is obvious that there is a need for a more efficient method of converting hydrocarbon gas to overcome the above disadvantages of the known methods.

Accordingly, an object of the present invention is the provision of an efficient way of converting hydrocarbon gas in the reformed hydrogen-containing gas. Also olypropylene hydrocarbon gas in the reformed hydrogen-containing gas. In particular, an object of the present invention is the provision of such system and method of converting hydrocarbon gas, which has a much lower energy requirement. Another object of the present invention is the provision of such system and method of converting hydrocarbon gas, which has a much lower investment in equipment. Another object of the present invention is the provision of such system and method of converting hydrocarbon gas, which makes efficient use of the energy of the leaving gas pressure and/or energy of the residual fuel gas downstream. Another object of the present invention is the provision of such system and method of converting hydrocarbon gas, which would have increased yield of desired products. These and other objects are achieved in accordance with the invention described below.

Disclosure of the invention the Present invention is a system and method for converting hydrocarbon gas in the reformed hydrogen-containing gas. In the first implementation of the invention is provided by the first system to perform a first method of converting hydrocarbon gas. Einem compressor and a primary combustion chamber with the combustion zone and the reforming zone. The first method is done by starting the supply of the first system containing the air and the primary hydrocarbon gas separated in the first part and the second part. The feed air is compressed in the primary compressor for receiving primary air, shared on a much greater first part and a much smaller second part. The first part of the primary air is supplied from the first part of the primary hydrocarbon gas and, optionally, with water or steam into the combustion zone of the primary combustion chamber so that the combustion zone was almost stoichiometric ratio of primary air primary hydrocarbon gas. Primary air primary hydrocarbon gas, optionally in the presence of water or steam, is burned in the combustion zone for receiving the primary combustion gas.

Primary combustion gas flowing downstream of the primary combustion zone of the reformer, where it is combined with the second part of the primary hydrocarbon gas introduced into the primary combustion chamber downstream of the combustion zone. The mixture of primary combustion gas and the second part of the primary hydrocarbon gas is in the area of the endothermic reforming reaction of the reformer that the rate of primary air primary hydrocarbon gas, supplied into the primary combustion chamber is substochiometric, by maintaining a nearly stoichiometric ratio of primary air primary hydrocarbon gas in the combustion zone is maintained flammable and stable self-sustaining combustion reaction without the formation of soot. The flow of water or steam into the combustion zone by request increases the ratio of hydrogen to carbon monoxide in the subsequent reformed gas, diluting and cooling at the same time, the primary combustion gas and suppressing the formation of soot in the zone of the reformer.

The reformed gas exits the reforming zone of the primary combustion chamber and very quickly expanded in primary Energoservice. The rapid expansion and, as a consequence, the cooling of the reformed gas effectively reduces the reforming reaction, providing a high yield of the desired hydrogen and carbon monoxide in the reformed gas. The expansion of the reformed gas actuates the primary energoterminal, which is connected to the primary shaft with the primary compressor, thereby operate the primary compressor. Then the reformed gas is removed from the system for subsequent use. The second use in other applications external to the system.

In the second implementation of the invention provides an alternative second system, to provide an alternative to the second method of converting hydrocarbon gas having a considerably better performance than the first method. This second system contains substantially the same components as the first system, acting pretty much the same as in the first method. However, the second system further comprises a second turbine-compressor installation with the secondary energotrans and secondary compressor and a secondary combustion chamber having a flame zone and a burnout zone. There are additional components to compress the reformed gas using the fuel, which is available from secondary hydrocarbon gas as described below. The second method is performed by starting the supply of the second system containing the air and the primary hydrocarbon gas separated in the first part and the second part. The feed air is compressed in the primary compressor for receiving primary air, shared the first part and the second part. The first part of the primary air is supplied with the first part of the primary uglevodorodnaya. Primary combustion gas reacts with the second part of the primary hydrocarbon gas in the reforming zone of the primary combustion chamber, producing a reformed gas, which is rapidly expanding in the primary Energoservice, thereby causing the primary energoterminal and respectively powering the primary compressor.

Unlike the first method, the second part of the primary air remains in the second system, where it is preheated by the heat exchanger using emerging from the primary turbine reformed gas, forming the secondary air, which is divided into a first part and a second part. The supply system further comprises a secondary hydrocarbon gas, preferably exhaust gas with low calorific value from an external source, which is preheated by the heat exchanger by using the reformed gas downstream from the step of pre-heating the air. Pre-heated secondary hydrocarbon gas is fed from the first part of the secondary air into the flame zone of the secondary combustion chamber and burned therein for receiving the secondary combustion gas. The second part of the secondary air is supplied together with the secondary combustion gas is full of hydrocarbons, hydrogen, carbon monoxide and other products of combustion in the secondary gas combustion to carbon dioxide and water. The secondary combustion gas is also diluted and cooled in the area of burnout, suppressing the formation of nitrogen oxides in exiting the secondary combustion chamber exhaust gas. The resulting exhaust gas is expanded in the secondary Energoservice, thereby powering the secondary energoterminal and accordingly the secondary compressor means connected to the output shaft before exiting exhaust gas from the system.

After cooling the reformed gas heat exchanger with the second part of the primary air and secondary hydrocarbon gas reformed gas is further cooled almost to ambient temperature in a conventional cooling means and enters the water separator where condensed water is removed from the reformed gas and is removed from the system. Then the reformed gas is compressed in the secondary compressor and is discharged from the system under relatively high pressure for subsequent use.

In the third implementation of the invention provides an alternative third system to perform alternative rubs the process. This third system contains substantially the same components as the second system, acting almost as a second way. The third system, however, changes the configuration of the two turbine-compressor units so that the second turbine-compressor unit replaces the secondary compressor auxiliary primary compressor, which works together with the primary compressor. The third system is provided for supporting the secondary energoterminal working together with the secondary energotrans. Reconfigured and additional components are provided for compression of the air supplied to the primary air in two stages and to produce energy for consumers variable energy external to the method as described below. The third way is by starting the supply of the third system, containing the air and the primary hydrocarbon gas separated in the first part and the second part. The feed air is compressed in the auxiliary primary compressor for receiving the intermediate air. Intermediate air is supplied to the primary compressor and optionally compressed therein for receiving the primary air section is knogo hydrocarbon gas and, optional, water or steam, into the primary combustion zone of the combustion chamber, where it turns out the primary combustion gas. Primary combustion gas reacts with the second part of the primary hydrocarbon gas in the reforming zone of primary combustion chamber for receiving the reformed gas, which is rapidly expanding in the primary Energoservice, thereby powering the primary energoterminal and, therefore, a primary compressor.

The second part of the supplied air is preheated by a heat exchanger using the reformed gas leaving the primary turbine, forming the secondary air, which is divided into a first part and a second part. The supply system further comprises a secondary hydrocarbon gas is pre-heated by the heat exchanger by using the reformed gas downstream from the step of pre-heating the air. Pre-heated secondary hydrocarbon gas is fed together with the first part of the secondary air into the flame zone of the secondary combustion chamber and burned therein for receiving the secondary combustion gas. The second part of the secondary air is supplied together with the secondary gas combustion and, optionally, water or steam, in the area of burnout secondary Kama gas combustion to suppress the formation of nitrogen oxides in the area of burnout. The resulting exiting the secondary combustion chamber exhaust gas expands in the secondary Energoservice.

In contrast to the second process, the secondary energoterminal connected auxiliary primary shaft with the auxiliary primary compressor, thereby leading to the action of this auxiliary primary compressor. The exhaust gas discharged from the secondary power turbines, is fed to the auxiliary secondary energoterminal, where it further expands before exiting the system. Energy of the shaft with the auxiliary secondary power turbines can be used external to the system energy consumers, such as a generator. After cooling the reformed gas heat exchanger with the second part of the primary air and secondary hydrocarbon gas reformed gas is discharged from the system under a relatively low pressure for subsequent use.

It is found that the present system and method for converting hydrocarbon gas in the reformed hydrogen-containing gas in each of the multiple executions is more cost-effective compared to conventional systems conversion of hydrocarbon gas because of the reduced to Traiana gas turbine cycle in the conversion system eliminates the high cost of providing electric or steam air compressors for compressing air, supplied in one or more combustion chambers. This system also has the practical advantage of opportunities to use Gastronom cycle of commercially available modules gastroline engines. Commercial modules for gas turbine engines are available in many designs and sizes and are produced in a wide range to achieve a high degree of profitability, as well as heavy and reliable service.

The cost of the work of the United gastroline cycle is significantly lower than the cost of the work fed from the outside air compressors, because one or more gas turbines are driven by the reformed gas produced as an intermediate product for the production of desirable products, such as liquid hydrocarbon fuels or petrochemicals. The injection of steam or water into the primary combustion chamber is also advantageous moderates temperature and increases the rate of mass transfer to energotrans, thereby ensuring the use of standard metallurgy in the manufacture Energoservis without significant loss of thermal efficiency. The net effect of these improvements is to maintain the capital cost of the system n is a quick description of the drawings Fig.1 is a diagram of the first implementation of the system and method according to the present invention.

Fig. 2 is a diagram of an alternative second execution system and method according to the present invention.

Fig. 3 is a diagram of an alternative third run of the system and method according to the present invention.

Description of the preferred executions of the Present invention relates to a method for converting hydrocarbon gas to produce a hydrogen-containing reformed gas. The invention further relates to a system connected with way of equipment for carrying out the method of converting hydrocarbon gas. The implementation of the system and method according to the present invention is described below first in Fig.1, which system generally designated position 10. The system 10 is characterized by the inclusion of a single gas turbine-compressor unit, as will be described below. The system 10 illustrates a preferred configuration of the equipment carried out by a method for relatively small applications, in which the conditions of the working pressure is comparable with commercially available gas turbine-compressor units. For professionals, however, from here the description it is obvious that the system 10 can be modified in Headerget the input 12 of the air, which delivers the air into the primary compressor 14 at a speed ranging from approximately 5,000 to approximately 5400 m3/h, a pressure of from about 75 to about 150 kPa and a temperature of from about -30 to about 40oC. the air is preferably air from the surrounding atmosphere under normal pressure and normal temperature conditions. The primary compressor 14 compresses the air to primary air having a pressure of from about 1000 to about 1050 kPa and a temperature of from about 300 to about 350oC. the Primary air is discharged from the primary compressor 14 in the primary air line 16, which supplies it to the primary air manifold 18. Primary air is divided into primary air manifold 18 on the first part and the second part. The first part of the primary air is the primary combustion air, comprising the majority of the primary air. Primary combustion air is discharged from the primary air collector 18 through line 20 primary combustion air and fed into the primary mixer 22 of the burner, such as mixing manifold or other known mixing sredstava manifold 18 through line 24 of bleed air at a speed of from about 1000 to about 1500 m3/h and goes from the system 10 through the valve 26 to control the flow of bleed air for alternative uses.

The system 10 further comprises an input 28 of the primary hydrocarbon gas, which delivers primary hydrocarbon gas from a remote source (not shown) in the system 10. The primary hydrocarbon gas is preferably natural, non-synthetic hydrocarbon gas produced from the subsurface formation. Among the most preferred of such gases natural gas, although you may be used and other hydrocarbon gases, including associated gas, containing nitrogen and/or carbon dioxide gas from coal mines and gas extracted from oceanic hydrates. The primary hydrocarbon gas is taken through the inlet 28 of the primary hydrocarbon gas with a speed of from about 1000 to about 12003/h, a pressure of from about 1500 to about 2500 kPa and a temperature of from approximately 10 to approximately the 50oC. Note that the rate of flow of primary combustion air through line 20 primary combustion air is substochiometric in relation to the flow velocity of the primary hydrocarbon gas through the inlet 28 particlization 45% oxygen, required for complete combustion of the primary hydrocarbon gas. The input 28 of the primary hydrocarbon gas supply manifold 30 primary hydrocarbon gas, which divides the primary hydrocarbon gas on the first part and the second part. The first part of the primary hydrocarbon gas is the primary gas burner comprising from about 25 to about 50% of the total primary hydrocarbon gas. The first part of the primary hydrocarbon gas is fed through line 32 of the primary gas burner in the primary mixer 22 of the burner.

Line 34 primary water/steam also leads to the primary mixer 22 of the burner, optional delivering into the system 10 or the primary water, or primary steam from a remote source (not shown). If the contractor selects the flow of water into the primary mixer 22 of the burner, feedwater enters the system 10 with a speed of from about 250 to about 1000 kg/h through the inlet 36 of the water/steam. Feedwater is usually under a pressure of from about 100 to about 300 kPa and at a temperature of from approximately 10 to approximately the 50oC. feedwater turns in the primary water through the in-line pump 38, which re is positive 2500 kPa and a temperature of from approximately 10 to approximately the 50oC.

If the contractor chooses the steam flow in the primary mixer 22 of the burner, the steam used in almost the same money supply that water. However, from the system 10 eliminates built-in pump 38. Primary steam is supplied directly to the primary mixer burner 22 through line 34 primary water/steam at approximately the same speed and pressure as that of water, but at a higher temperature from about 200 to about 250oC.

Primary combustion air, primary gas burner and optional, primary water or primary steam completely mixed in the primary mixer burner 22 for the formation of the primary mixture of the burner, preferably with a molar composition of from about 70 to about 75% of the air from approximately 5 to approximately 15% of the hydrocarbon gas and from about 11 to about 28% of steam or water, while the remainder is carbon dioxide and traces of other compounds. The molar ratio of primary combustion air to the primary gas burner in the primary mixture of the burner is nearly stoichiometric, ranging from about 7.5:1 to about 12:1. The primary mixture of the burner preferably sod hydrocarbons in the primary mixture of the burner. The primary mixture of the burner is fed directly from the primary mixer burner 22 in the node 40 of the primary burner, where the primary mixture of the burner is ignited for combustion in the zone 42 of combustion associated with the node 40 of the primary burner. The primary mixture of the burner is under pressure from about 1000 to about 1050 kPa and at a temperature of from about 95 to about 300oWith node 40 primary burner before moving into the area 42 of the combustion speeds of from about 5000 to about 6000 m3/PM

Area 42 of combustion is one of the two zones in the primary combustion chamber 44 of combustion, while another zone, located downstream than the area 42 of the combustion area is 46 refirming. Primary chamber 44 of the combustion boiler is a continuous action of high temperature and high pressure, usually supported at a pressure of from about 1000 to about 1500 kPa. The temperature in the zone 42 of combustion is maintained in the range from about 1200 to about 1700oWith providing primary combustion of the mixture of the burner to the state of the primary gas combustion. The primary gas of combustion flowing from the zone 42 of the combustion zone 46 refirming.

The second part of the primary hydrocarbon gas separated the cooling gas, comprising from about 50% to about 75% of the total primary hydrocarbon gas. This second part is injected into the area 46 of the reformer through line 48 primary cooling gas having its valve 50 controls the flow of primary cooling gas. The second part of the primary hydrocarbon gas is completely mixed with the primary gas combustion, forming in the zone 46 reforming reformingof mixture. Area 46 reforming may contain a catalyst to promote walking in her endothermic reforming reactions, but preferably primary chamber 44 of the combustion free from any kind of catalyst, since the catalyst is not necessary for the effective operation of the system 10.

During the endothermic reforming reactions in the zone 46 refirming there is a significant cooling reformirovat mixture, but the high temperature zone 42 of the combustion due to the nearly stoichiometric composition of the raw mix burner supports reformingof the mixture at a very high temperature to activate the subsequent endothermic reforming reactions and to achieve thermodynamic equilibrium zone 46 reforming. Accordingly, in the zone 46 reforming achieved significant change is in the desired ratio. Example the molar composition desirable reformed gas: approximately 42% of nitrogen, 26% hydrogen, 8% carbon monoxide, 6% carbon dioxide and 17% water.

Specific conditions of temperature, pressure and quantitative composition in the primary combustion chamber can be selected within the above ranges in accordance with the present invention in conjunction with theory, known in the art, to achieve a predetermined ratio of hydrogen and carbon monoxide in the reformed gas, depending on the desired end use of the reformed gas. For example, if the desired end use of the reformed gas is synthesis gas for the production of liquid hydrocarbons or petrochemicals, the specific conditions of the primary combustion chamber are selected so that the molecular ratio of hydrogen and carbon monoxide in the reformed gas ranged from an estimated 1.9:1 to approximately 2.2:1, preferably about 2:1. On the contrary, if the desired end ispolschovaniem reformed gas is a hydrogen-containing regenerating gas for the recovery of metallurgical ore or hydrogenation of heavy oils or is ookii carbon in the reformed gas was in the range of around 1.8:1 to about 3.6:1, preferably at least about 3:1. Note further that the presence of water or steam in the zone 42 of the combustion in the desired manner moderates combustion temperature reduces the formation of coal/carbon and increases the production of hydrogen by reaction of the water-gas shift, thereby increasing the ratio between hydrogen and carbon monoxide.

The reformed gas is moved from zone 46 reforming primary combustion chamber 44 and is transferred via line 52 of the reformed gas to the primary Energoservice 54 with a speed of from about 7500 to about 8500 m3/h under a pressure of from about 1000 to about 1050 kPa and at a temperature of from about 750 to about 1000oC. the Reformed gas is partially expanded in the primary Energoservice 54 and then is returned from the primary power turbines 54 through the output 56 of the reformed gas to the desired end use. Primary energoterminal 54 is mechanically connected to the primary compressor 14 through a rotating shaft 58, providing the energy requirements for actuation of the primary compressor 14. It is obvious that the system 10 shows the energy self-sufficiency to the extent that h is isoamsa in the primary compressor 14 for compressing air, supplied to the primary chamber 44 of combustion. The system 10 also provides a significant number coming under excessively high pressure air, which can be used in any number of alternative applications, including combustion exhaust gases formed by the processes using the reformed gas.

Alternative second execution of the second system and the second method according to the present invention is described below with reference to Fig.2, where the second system is generally indicated by the position 100. The second system 100 is almost identical to the first system 10, however, the second system 100 further comprises a second gas turbine-compressor unit for processing the stream of secondary hydrocarbon gas, as will be described below, associated with the first gas turbine-compressor unit, the processing flow of the primary hydrocarbon gas. Components of the second system 100, the corresponding components of the first system 10, are denoted by three-digit reference position in which the first digit is the unit, and the second two digits are identical to the reference positions of the corresponding components of the first system.

System 100 has an input 112 of the air, delivering supplied vosd from about 75 to about 150 kPa and at a temperature of from about -30 to about 40oC. Supplied air is preferably air from the surrounding atmosphere at normal pressure and temperature. The primary compressor 114 compresses the air to primary air having a pressure of from about 900 to about 1100 kPa and a temperature of from about 300 to about 350oC., the Primary air is discharged from the primary compressor 114 in line 116 of the primary air, which supplies it to the collector 118 of the primary air. Primary air is separated in the collector 118 of primary air for the first part and the second part. The first part of the primary air is the primary combustion air, comprising the bulk of the total primary air. Primary combustion air is withdrawn from the collector 118 of the primary air line 120 primary combustion air and fed into the primary mixer 122 burner with a speed of from about 35,000 to about 40,000 m3/H. the Second part of the primary air is bleed air, which is discharged from the collector 118 of primary air through the line 124 of bleed air with the valve 126 control of bleed air. The ratio of the volume of primary combustion air and strategic input 128 of the primary hydrocarbon gas, which delivers to the system 100 of the primary hydrocarbon gas from a remote source (not shown). The primary hydrocarbon gas is preferably a naturally occurring non-synthetic hydrocarbon gas produced from subsurface formations, such as natural gas, associated gas, containing nitrogen and/or carbon dioxide gas from coal mines and gas extracted from oceanic hydrates. The primary hydrocarbon gas is taken through the inlet 128 of the primary hydrocarbon gas with a speed of from about 11,000 to about 12000 m3/h under a pressure of from about 900 to about 1100 kPa and at a temperature of from approximately 5 to approximately 40oC. Note that the flow rate of combustion air is substochiometric in relation to the flow velocity of the primary hydrocarbon gas through the inlet 128 of the primary hydrocarbon gas. In particular, the primary combustion air contains only from about 35 to about 45% of the oxygen required for complete combustion of the primary hydrocarbon gas. The input 128 of the primary hydrocarbon gas leads to the collector 130 of the primary hydrocarbon gas, separating the primary hydrocarbon plate, comprising from about 25 to about 50% of the total primary hydrocarbon gas. The first part of the primary hydrocarbon gas is fed through line 132 of the primary gas burner in the primary mixer 122 burner.

Line 134 primary water/steam also leads to the primary mixer 122 burner, optional feeding system 100 or the primary hearth or primary steam from a remote source (not shown). If the contractor selects the flow of primary water in the primary mixer 122 burner supplied hearth is accepted into the system 100 with a speed of from about 6000 to about 7000 kg/h through the inlet 136 of water/steam. Feedwater is usually under a pressure of from about 75 to about 150 kPa and at a temperature of from approximately 5 to approximately the 50oC. feedwater is maintained at high pressure by means of a built in pump line 138, which moves the first part of the feed water as the primary water line 134 primary water/steam with a speed of from about 800 to about 1100 kg/h under a pressure of from about 1000 to about 2500 kPa and at a temperature of from about 5 to about 50oC.

If the contractor is of the feed means, as for water. However, from the system 100 eliminates built-in pump 138. Primary steam is supplied directly to the primary mixer 122 burner through line 134 primary water/steam at approximately the same rate and under the same pressure as the primary water, but at a higher temperature from about 200 to about 250oC.

Primary combustion air, primary gas burner and optional, primary water or primary steam completely mixed in the primary mixer 122 burner to form a primary mixture of the burner, preferably with a molar composition of from about 85 to about 90% of the air from about 5 to about 10% hydrocarbon gas and from about 0 to about 5% of steam or water, while the remainder is carbon dioxide and traces of other compounds. The molar ratio of primary combustion air and the primary gas burner in the primary mixture of the burner is nearly stoichiometric, being in the range from about 7.5:1 to about 12: 1. The primary mixture of the burner preferably contains from about 20% shortage to about 20% excess oxygen required for complete combustion uglevodoroda 140 primary burner, where the primary mixture of the burner is ignited for combustion in the zone 142 combustion associated with the node 140 of the primary burner. The primary mixture of the burner is under pressure from about 950 to about 1050 kPa and at a temperature of from about 150 to about 300oWith node 140 primary burner before moving into the zone 142 burning speeds ranging from approximately 40,000 to approximately 50,000 m3/PM

Area 142 combustion is one of the two zones in the primary combustion chamber 144, the second zone is the zone 146 reforming located downstream than the area 142 of combustion. The primary combustion chamber 144 is a boiler continuous action, usually supported at a pressure of from about 850 to about 1000 kPa. The temperature in the zone 142 combustion is maintained in the range from about 1700 to about 2000oWith providing primary combustion of the mixture of the burner to the primary gas combustion.

The second part of the primary hydrocarbon gas separated from the first part of the primary hydrocarbon gas in the manifold 130 primary hydrocarbon gas, is the primary cooling gas comprising from about 50% to about 75% of the total primary uglevodorodnyi valve 150 controls the flow of the primary refrigerant gas in the primary combustion chamber 144 downstream zone 142 combustion and upstream zone 146 reforming. The second part of the primary hydrocarbon gas is completely mixed with the primary gas combustion, forming reformingof mixture, which flows into the zone 146 reforming. Area 146 reforming may contain a catalyst going there endothermic reforming reactions, but preferably the primary combustion chamber 144 practically free of any catalysts, because catalysts are not required for effective operation of the combustion chamber.

In the area of 146 reforming is a significant cooling reformirovat mixture during the endothermic reforming reactions, but high due to almost stoichiometric composition of the raw mix burner temperature zone 142 burning supports reformingof mixture at a sufficiently high temperature to activate the subsequent endothermic reforming reactions and to achieve in the area of 146 reforming thermodynamic equilibrium. Accordingly, in the zone 146 reforming achieved a significant transformation reformirovat mixture generating a reformed gas containing hydrogen and carbon monoxide in a desirable ratio. Prima is erode, 3% carbon dioxide and 7% water and less than 1% hydrocarbon. The specific conditions of the primary combustion chamber temperature, pressure and quantitative composition can be selected within the above ranges in accordance with the present invention and in accordance with theory, well-known specialist, to achieve a predetermined ratio between hydrogen and carbon monoxide in the reformed gas, depending on the desired end use of the reformed gas.

The reformed gas is moved from the zone 146 reforming primary combustion chamber 144 and is transferred via line 152 of the reformed gas in the primary energoterminal 154 speeds ranging from approximately to approximately 60000 65000 m3/h under a pressure of from about 800 to about 1000 kPa and at a temperature of from about 850 to about 950oC. the Reformed gas is partially expanded in the primary Energoservice 154, which is mechanically linked to the primary compressor 114 by rotating the shaft 158, providing the energy requirements for actuation of the primary compressor 114. After partial expansion of the reformed gas is transferred via line 202 ohlazhdeniya reformed gas upstream from the water separator 204, acting as described below for cooling the reformed gas to a temperature of from about 40 to about 50oC and a pressure from about 200 to about 300 kPa for the attainment of the water separator. Under these conditions, in the reformed gas is condensed water, which is separated from the reformed gas in the water separator 204 and is output from the system 100 via the outlet water line 212.

Bleed air is supplied through line 124 of bleed air through the valve 126 controls the flow of bleed air in the heat exchanger 206 of bleed air, where the reformed gas from line 202 cooling the reformed gas pre-heats bleed air, forming a secondary air with temperatures ranging from approximately 500 to approximately 600oC and a pressure of from about 250 to about 350 kPa. The reformed gas, respectively, leaves the heat exchanger 206 of bleed air at a temperature of from about 550 to about 650oC and a pressure of from about 250 to about 300 kPa. The secondary air is supplied via line 214 secondary air into the reservoir 216 secondary air, the secondary air is divided into the usual collector 216 secondary air line 218 secondary air flame and served in a secondary mixer 220 burner speeds ranging from approximately to approximately 12500 13500 m3/PM

The system 100 further includes an input 222 of the secondary hydrocarbon gas, which delivers secondary hydrocarbon gas from a remote source (not shown) in system 100. Secondary hydrocarbon gas is preferably exhaust gas not associated with the how of the process, containing unconverted hydrogen and carbon monoxide and unused hydrocarbons. For example, secondary hydrocarbon gas may be a gaseous waste product of the process using the reformed gas according to the present method. The approximate molar composition of desirable secondary hydrocarbon gas constitutes from about 85 to about 90% nitrogen, from about 1 to about 3% hydrogen, from about 1 to about 3% carbon monoxide, from about 4 to about 5% carbon dioxide, about 3% water and from about 1 to about 3% methane and other hydrocarbons. Usually secondary hydrocarbon gas has a relatively low calorific value, much lower than the calorific value of the primary hydrocarbon gas, and contains only from about 4 to about 10% of flammable compounds.3/h under a pressure of from about 300 to about 400 kPa and at a temperature of from approximately 5 to approximately the 50oC. Secondary hydrocarbon gas is fed through the inlet 222 of the secondary hydrocarbon gas in the heat exchanger 208 secondary hydrocarbon gas, where the reformed gas from line 202 cooling the reformed gas pre-heats the secondary hydrocarbon gas to a temperature of from about 300 to about 400oC and a pressure from about 250 to about 350 kPa. Accordingly, the reformed gas leaves the heat exchanger 208 secondary hydrocarbon gas at a temperature of from about 400 to about 500oC and a pressure of from about 250 to about 350 kPa. Secondary hydrocarbon gas is supplied via line 226 secondary hydrocarbon gas in the secondary mixer 220 burners.

The secondary air to the flame and secondary hydrocarbon gas is completely mixed in the secondary mixer 220 burner for forming the secondary mixture burner, preferably with a molar composition of from about 80 to about 90% nitrogen, from about 5 to about 10% oxygen, about 5% non-flammable componenti and secondary hydrocarbon gas in the secondary mixture burner ranges from approximately 0.3:1 to about 0.5:1. Secondary mixture burner is supplied directly from the secondary mixer 220 burners in the node 228 of the secondary burner, where the secondary mixture burner is ignited for combustion in zone 230 flame associated with the node 228 of the secondary burner. Secondary mixture burner is under pressure from about 250 to about 350 kPa and at a temperature of from about 350 to about 450oWith node 228 of the secondary burner before moving into the zone 230 flame speeds ranging from approximately 40,000 to approximately 50,000 m3/PM

Area 230 of the flame is one of the two zones in the secondary combustion chamber 232, while the other area is the area 234 oxidation downstream from the zone 230 of the flame. The secondary combustion chamber 232 is a boiler continuous actions supported under a pressure of from about 200 to about 300 kPa. The temperature in zone 230 of the flame is maintained in the range from about 1000 to about 1300oWith, providing there is secondary combustion of the mixture of the burner and receiving secondary gas burning.

The second part of the secondary air, which is separated from the first part of the secondary air, a secondary air oxidation, which is available from the collector 216 of the secondary air on the and oxidation, and served in a secondary mixer 240 oxidation. Line 22 secondary water/steam with the valve 244 to control the flow of secondary water/steam, devotes the second part of the feedwater or steam as a secondary water or steam in the secondary mixer 240 oxidation. Secondary steam or water is the quantity of supplied water or steam remaining after removal of the primary water or steam line 134 primary water/steam. The secondary air oxidation and secondary water or steam are mixed in the secondary mixer 240 oxidation for the formation of secondary pre-mix and injection into the secondary combustion chamber 232 downstream from the zone 230 flame and upstream from the zone 234 oxidation. Secondary pre-mixture is completely mixed with the secondary gas burning, forming a mixture of oxidation, which flows into the zone 234 oxidation.

Temperature zone 234 of oxidation is maintained in the range from approximately 700 to approximately 1000oFor complete oxidation of the mixture of oxidation, thus produces exhaust gas that is discharged from the secondary combustion chamber 232 at speeds from approximately to approximately 60000 65000 kg/h and fed to the output line 246 exhaust gas under devenir>oC. an Example of the exhaust gas consists of approximately 74% nitrogen, 20% water, 5% carbon dioxide, 1% oxygen and traces of carbon monoxide and oxides of nitrogen. The secondary combustion chamber 232 may be provided with a catalyst to promote on-going reactions or may be free of any catalysts. In any case, the operating parameters of the secondary combustion chamber 232 are selected within the competence of a specialist so that combustion filed there gases formed as much carbon dioxide and water while minimizing the formation of oxides of nitrogen and the almost complete oxidation of any organic contaminants contained in the feed water or steam within the system 100 through the inlet 136 of water/steam.

Exhaust gas is fed through the output line 246 exhaust gas in the secondary energoterminal 248 and extends it to actuate the secondary power turbines 248. Secondary energoterminal 248 mechanically connected with the secondary compressor 250 by rotating the output shaft 252, thereby providing the energy requirements for actuation of the secondary compressor 250. Advanced flue gas is withdrawn from the secondary power turbines 248 and peredvigaetsya in the atmosphere at nearly atmospheric pressure and a temperature of from approximately 500 to approximately 600oC.

The reformed gas discharged from the water separator 204, is supplied via line 258 suction reformed gas in the secondary compressor 250, where the reformed gas is compressed and then is returned through the output 156 of the reformed gas from the secondary compressor 250 for the desired end use. The reformed gas exits the system 100 via the reformed gas under pressure from about 700 to about 800 kPa and at a temperature of from about 150 to about 225oC.

Alternative third execution of the third system and the third method according to the present invention is described below with reference to Fig.3, where the third system generally indicated by the position 300. The third system 300 is almost identical to the second system 100, however, the third system 300 modifies the configuration of the first and second gas turbine-compressor units for joint processing of primary and secondary hydrocarbon gas, as will be described below. Components of the third system 300, the corresponding components of the first system 10, are denoted by three-digit reference position, where the first digit of the number is three, and the remaining two figures identical reference position cosystem 100, are denoted by three-digit reference position, where the first digit of the number is four, and the remaining two digits are identical to the reference positions of the respective components of the second system.

The system 300 has an input 312 of air that delivers supply air in the auxiliary primary compressor 502 with a speed of approximately 350000 to 360000 m3/h under a pressure of from about 75 to about 150 kPa and at a temperature of from about -30 to about 40oC. the air is preferably air from the surrounding atmosphere at normal pressure and normal temperature. Auxiliary primary compressor 502 compresses the air to an intermediate air having a pressure from about 200 to about 300 kPa and a temperature of from approximately 100 to approximately 150oC. Intermediate air is displaced from the primary auxiliary compressor 502 in-line 504 intermediate air, which leads to the primary compressor 314. The primary compressor 314 compresses the intermediate air to primary air having a pressure of from about 2500 to about 2600 kPa and a temperature of from about 500 to about 550oC. Peror 318 primary air.

In the reservoir 318 primary air primary air is divided into a first part and a second part. The first part of the primary air is the primary combustion air, forming a large mass of the total primary air. Primary combustion air is withdrawn from the reservoir 318 primary air line 320 of the primary combustion air and is served primary mixer 322 burner with a speed of from about 255000 to about 265000 m3/H. the Second part of the primary air is bleed air, which is discharged from manifold 318 primary air line 324 of bleed air with the valve 326 control the flow of bleed air. The volumetric ratio of primary combustion air and bleed air is in the range from about 2:1 to approximately 3.3:1.

The system 300 further includes an input 328 of the primary hydrocarbon gas, which delivers primary hydrocarbon gas from a remote source (not shown) in the system 300. The primary hydrocarbon gas is preferably a naturally occurring non-synthetic hydrocarbon gas produced from subsurface formations, such as natural gas, associated gas is Ignatov. The primary hydrocarbon gas is taken through the inlet 328 primary hydrocarbon gas with a speed of from about 75,000 to about 80000 m3/h under a pressure of from about 2500 to about 2600 kPa and at a temperature of from approximately 5 to approximately 40oC. Note that the rate of flow of primary combustion air through line 320 of the primary combustion air is substochiometric in relation to the flow velocity of the primary hydrocarbon gas through the inlet 328 primary hydrocarbon gas. In particular, the primary combustion air contains only from about 35 to about 45% of the oxygen required for complete combustion of the primary hydrocarbon gas. Input 328 of the primary hydrocarbon gas leads to the manifold 330 primary hydrocarbon gas, which divides the primary hydrocarbon gas on the first part and the second part. The first part of the primary hydrocarbon gas is the primary gas burner, comprising from about 25 to about 50% by volume of all the primary hydrocarbon gas. The first part of the primary hydrocarbon gas is supplied via line 332 primary gas burner in the primary mixer 322 burner.

Line 334 primary the primary pairs from a remote source (not shown). If the contractor selects the flow in the primary mixer 322 burner primary water supplied water is taken into the system 300 with a speed of from about 10,000 to about 40,000 kg/h through the inlet 336 water/steam. Feedwater is usually under a pressure of from about 75 to about 150 kPa and at a temperature of from approximately 5 to approximately the 50oC. feedwater is under pressure by means of a built in pump line 338, which moves the first part of the feed water as the primary water line 334 primary water/steam at speeds from approximately 10,000 to approximately 13000 kg/h under a pressure of from about 2500 to about 3000 kPa and at a temperature of from approximately 5 to approximately the 50oC.

If the contractor selects the flow of primary steam into the primary mixer 322 burner for a couple uses almost the same money supply that water. However, system 300 eliminates built-in pump 338. Primary steam is supplied directly to the primary mixer 322 burner on line 334 primary water/steam with almost the same speed as that of water, but under pressure from about 1500 to about 2500 kPa, and when tempera, optional, primary water or primary steam completely mixed in the primary mixer 322 burner to form a primary mixture of the burner, preferably with a molar composition of from about 85 to about 90% of the air from about 5 to about 10% hydrocarbon gas and from about 5 to about 10% hydrocarbon gas and from about 0 to about 5% of steam or water, the remainder is carbon dioxide and traces of other compounds. The molar ratio of primary combustion air and the primary gas burner in the primary mixture of the burner is almost stoichiometric and is in the range from about 7.5:1 to about 12:1. The primary mixture of the burner preferably contains from 20% shortage 20% excess oxygen required for complete combustion of the hydrocarbons in the primary mixture of the burner. The primary mixture of the burner is fed directly from the primary mixer 322 burner in the node 340 primary burner, where the primary mixture of the burner is ignited for combustion in the zone 342 combustion associated with the node 340 of the primary burner. The primary mixture of the burner is under pressure from about 2500 to about 3000 kPa and at a temperature of from priblisitelno approximately 250,000 to approximately 350000 m3/PM

Area 342 burning is one of the two zones in the primary combustion chamber 344, while the other area is the area 346 reforming, located downstream from the zone 342 burning. The primary combustion chamber 344 is a boiler continuous action, usually supported at a pressure of from about 2500 to about 2100 kPa. The temperature in the area 342 combustion is maintained in the range from about 1200 to about 2100oWith providing the combustion of there primary mixture burner accessing primary gas combustion.

The second part of the primary hydrocarbon gas separated from the first part of the primary hydrocarbon gas in the manifold 330 primary hydrocarbon gas, is the primary cooling gas comprising from about 50 to about 75% by volume of all the primary hydrocarbon gas. This second part is injected through line 348 primary cooling gas having its valve 350 control the flow of the primary refrigerant gas in the primary combustion chamber 344 downstream from the zone 342 burning, but upstream from the zone 346 reforming. The second part of the primary hydrocarbon gas is completely mixed with the primary gas combustion, is conducive to reaching it endothermic reforming reactions, however, preferably the primary combustion chamber 344 is free from any kind of catalysts, as is usually the catalysts are not required for its effective action.

In the area of 346 reforming is a significant cooling reformirovat mixture during the endothermic reforming reactions, however, the high temperature zone 342 combustion due to an almost stoichiometric composition of the raw mix burner supports reformingof mixture at a substantially high temperature to activate the subsequent endothermic reforming reactions and to achieve thermodynamic equilibrium in the zone 346 reforming. Accordingly, in the area 346 reforming achieved a significant transformation reformirovat mixture with the formation of the reformed gas containing hydrogen and carbon monoxide in a desirable ratio. Example the molar composition desirable reformed gas is approximately 45% nitrogen, 30% hydrogen, 15% carbon monoxide, 3% carbon dioxide and 7% water, and less than 1% of hydrocarbons. Specific conditions of temperature, pressure and quantitative composition in the primary combustion chamber can be selected within the above ranges in accordance with the present invention nookie carbon in the reformed gas, depending on the desired end use of the reformed gas.

The reformed gas is moved from the zone 346 reforming primary combustion chamber 344 and fed through line 352 of the reformed gas in the primary energoterminal 354 with a speed of from about 400,000 to about 500000 m3/h under a pressure of from about 2500 to about 3000 kPa and at a temperature of from about 900 to about 1000oC. the Reformed gas is partially expanded in the primary Energoservice 354, which is mechanically linked to the primary compressor 314 through the rotating shaft 358, providing the energy requirements for actuation of the primary compressor 314. After partial expansion of the reformed gas flows through the cooling line 402 reformed gas through a pair of heat exchangers 406 and 408, operating below the method for cooling the reformed gas to a temperature of from about 400 to about 550oC and a pressure from about 500 to about 600 kPa. The reformed gas then exits through the output 356 of the reformed gas to the desired end use.

Bleed air is supplied via line 324 of bleed air with the valve 326 control the flow of bleed in the spent gas pre-heats bleed air, forming a secondary air having a temperature of from approximately 500 to approximately 600oC and a pressure from about 200 to about 300 kPa. The reformed gas leaves the heat exchanger 406 of bleed air, respectively, at a temperature of from about 650 to about 700oC and a pressure of from about 600 to about 650 kPa. The secondary air is supplied via line 414 secondary air into the reservoir 416 secondary air, the secondary air is divided into a first part and a second part. The first part of the secondary air secondary air to the flame that is produced from the collector 416 secondary air line 418 secondary air flame and served in a secondary mixer 420 burner with a speed of from about 80,000 to about 85000 m3/PM

The system 300 further has an input 422 of the secondary hydrocarbon gas supplied to the system 300 secondary hydrocarbon gas from a remote source (not shown). Secondary hydrocarbon gas is, preferably, the exhaust gas of unrelated data by way of the process containing unconverted hydrogen and carbon monoxide and nonconvertible hydrocarbons. For example, vtorichnyi, obtained in this way. The approximate molar composition of desirable secondary hydrocarbon gas is in the range of from about 85 to about 90% nitrogen, from about 1 to about 3% hydrogen, from about 1 to about 3% carbon monoxide, from about 4 to about 5% carbon dioxide, about 3% water and from about 1 to about 3% methane and other hydrocarbons. Usually secondary hydrocarbon gas has a relatively low calorific value, significantly lower than the primary hydrocarbon gas, and contains only from about 4 to about 10% combustible substances.

Secondary hydrocarbon gas is taken through the inlet 422 of the secondary hydrocarbon gas with a speed of from about at 225,000 to about 250000 m3/h under a pressure of from about 200 to about 300 kPa and at a temperature of from approximately 5 to approximately the 50oC. Secondary hydrocarbon gas is fed through the inlet 422 of the secondary hydrocarbon gas in the heat exchanger 408 secondary hydrocarbon gas, where the reformed gas from the cooling line 402 reformed gas pre-heats the secondary Lu is but 200 to about 300 kPa. Accordingly, the reformed gas leaves the heat exchanger 408 secondary hydrocarbon gas at a temperature of from about 450 to about 550oC and a pressure of from about 500 to about 600 kPa. Secondary hydrocarbon gas is supplied via line 426 secondary hydrocarbon gas in the secondary mixer 420 burner.

The secondary air to the flame and secondary hydrocarbon gas is completely mixed in the secondary mixer 420 burner for forming the secondary mixture burner, preferably with a molar composition of from about 80 to about 90% nitrogen, from about 5 to about 10% oxygen, about 5% incombustible solids and from about 3 to about 5% combustible substances. As such, the molar ratio of secondary air to the flame and secondary hydrocarbon gas in the secondary mixture burner is in the range from approximately 0.3:1 to about 0.5:1. Secondary mixture burner is supplied directly from the secondary mixer 420 burner secondary burner 428, where the secondary mixture burner is ignited for combustion in the zone 430 flame associated with the secondary burner 428. Secondary mixture burner is under pressure from priblizeni burner 428 before moving into the zone 430 flame speeds of from about 300,000 to about 350000 m3/PM

Area 430 flame is one of the two zones in the secondary combustion chamber 432, while the other area is the area 434 oxidation, located downstream from the zone 430 flame. The secondary combustion chamber 432 is a boiler continuous action, usually supported under a pressure of from about 150 to about 250 kPa. The temperature in the zone 430 flame is maintained in the range from about 950 to about 1300oWith providing secondary combustion of the mixture of the burner with a secondary gas burning.

The second part of the secondary air, which is separated from the first part of the secondary air, a secondary air oxidation, which is available from collector 416 secondary air line 436 secondary air oxidation, with its valve 438 to control the flow of secondary air oxidation, and served in a secondary mixer 440 oxidation. Line 442 secondary water/steam with its valve 444 control the flow of secondary water/steam, devotes the second part of the feedwater or steam as a secondary water or steam in the secondary mixer 440 oxidation. Secondary steam or water is the quantity of supplied water or steam remaining after udata or steam are mixed in the secondary mixer 440 oxidation to secondary education pre-mix and injection into the secondary combustion chamber 432 downstream from the zone 430 flame and upstream from the zone 434 oxidation. Secondary pre-mixture is completely mixed with the secondary gas burning, forming a mixture of the oxidation current in the area 434 oxidation.

The temperature in the area 434 of oxidation is maintained in the range from approximately 700 to approximately 1000oFor complete oxidation of the mixture of oxidation with the production of exhaust gas that is discharged from the secondary combustion chamber 432 with a speed of from about 400,000 to about 450000 kg/h and fed to the output line 446 exhaust gas, under pressure from about 150 to about 250 kPa and at a temperature of from about 700 to about 1000oC. an Example of the exhaust gas has a molar composition of about 78% nitrogen, 16% water, 5% carbon dioxide, 1% oxygen and traces of carbon monoxide and oxides of nitrogen. The secondary combustion chamber 432 may be provided with a catalyst that promotes walking in her reactions or may be free of any catalysts. In any case, the operating parameters of the secondary combustion chamber 432 is selected within the competence of the specialist in order to achieve almost complete combustion of gases filed in the combustion chamber, with the formation of water and carbon dioxide with simultaneous minimization of the I in the feed water or steam, included in the system 300 via the input 336 of water/steam.

Exhaust gas is fed through the output line 446 of the exhaust gas in the secondary energoterminal 448 and partially extends it to bring the secondary power turbines 448 in action. Secondary energoterminal 448 mechanically connected with the auxiliary primary compressor 502 by rotating the auxiliary shaft 506, thereby providing the energy requirements for driving the auxiliary primary compressor 502. Partially extended beyond the gas is discharged from the secondary power turbines 448 with a speed of from about 400,000 to about 500000 kg/h and transferred by the auxiliary line 508 of the exhaust gas in the auxiliary secondary energoterminal 510, under pressure from approximately 100 to approximately 200 kPa and at a temperature of from about 600 to about 900oC. the Exhaust gas is additionally expanded in the auxiliary secondary Energoservice 510 and then removed from the system 300 through the exhaust line 454, which preferably leads to the atmosphere. Auxiliary secondary energoterminal 510 has an auxiliary output shaft 512 to supply energy alternative Energo is subramania many possible alternatives for the selection of a single component, used in described here combined gas turbine-compressor units. In particular, the most practical to use commercially available modules for gas turbine engines. Commercially available modules for gas turbine engines are typically used to generate electricity or for actuation of industrial compressors and pumps. Commercially available modules for gas turbine engines are also used in applications such as supply ships. As such, commercial sites available in many designs and different sizes. Mainly you should choose a design and size which most closely meet the private needs of a specific application. Thus, in the systems 10, 100, and 300 size gas turbine modules preferably is selected based on the volume of gas available for processing into products. Also note that different versions of the commercial components of gas turbine engines operate at significantly different pressures and with different efficiency. Accordingly, the advantages of such a choice of operating conditions of pressure, which makes the best use of specific dimensions and design of the modules is clear, in the framework of the present invention can be made of alternative execution and modification, such as the one suggested here and other.

Claims

1. Method of reforming hydrocarbon gas, including compression of the air supplied to the primary compressor for receiving the primary air, followed by separation into two parts, the first part of which is a primary combustion air, water or steam, the primary combustion air and the primary hydrocarbon gas into the primary combustion chamber having a combustion zone located downstream zone of the reformer, the response referred to the primary combustion air and the primary hydrocarbon gas in the primary combustion chamber for producing reformed gas containing hydrogen and carbon monoxide, and the primary hydrocarbon gas before it enters the mixing chamber is divided into two parts, the first part of the burn with the primary combustion air in the primary combustion zone of the combustion chamber with the formation of the primary gas combustion, and the second part of the primary hydrocarbon gas is fed to the reforming zone, followed by reacting it with a primary gas combustion with the image of the th power turbines, and with the last of the primary compressor, the supply of the second part of the primary air as secondary air into the secondary combustion chamber with secondary hydrocarbon gas, reacting it with said secondary air in the secondary combustion chamber having a flame zone and located downstream of the oxidation zone, to produce flue gas containing carbon dioxide and water, and before feeding into the secondary combustion chamber secondary air is divided into two parts, the first part and the said secondary hydrocarbon gas is burned in the flame zone of the secondary combustion chamber with secondary gas burning, and the second part of secondary hydrocarbon gas is fed to the zone of oxidation of the secondary combustion chamber with subsequent reaction with the second part of the secondary air to obtain the aforementioned exhaust gas actuation by means of the aforementioned exhaust gas secondary power turbines, and using the last - secondary compressor.

2. The method according to p. 1, characterized in that the ratio of primary combustion air and hydrocarbon gas in the primary combustion zone of the combustion chamber is supported within 7.5:1.0 to 12,0:1,0.

3. Speciesare for intermediate air then the intermediate air is compressed in the primary compressor for receiving the primary air, followed by separation into two parts, the first part of which is a primary combustion air, water or steam, the primary combustion air and the primary hydrocarbon gas into the primary combustion chamber having a combustion zone located downstream zone of the reformer, the response referred to the primary combustion air and the primary hydrocarbon gas in the primary combustion chamber for producing reformed gas containing hydrogen and carbon monoxide, and the primary hydrocarbon gas before it enters the mixing chamber is divided into two parts, the first part of the burn with the primary combustion air in the primary combustion zone of the combustion chamber with the formation of the primary gas combustion, and the second part of the primary hydrocarbon gas is fed to the reforming zone, followed by reacting it with a primary gas combustion with the formation of the reformed gas, the actuation by the aforementioned reformed gas primary power turbines, and using the last of the primary compressor, the supply of the second part of the primary air as a secondary is by secondary air in the secondary combustion chamber, having the flame zone and located downstream of the oxidation zone, to produce flue gas containing carbon dioxide and water, and before feeding into the secondary combustion chamber secondary air is divided into two parts, the first part and the said secondary hydrocarbon gas is burned in the flame zone of the secondary combustion chamber with secondary gas combustion, and the second part of secondary hydrocarbon gas is fed to the zone of oxidation of the secondary combustion chamber with subsequent reaction with the second part of the secondary air to obtain the aforementioned exhaust gas actuation by means of the aforementioned exhaust gas secondary power turbines, and with the last - primary auxiliary compressor for receiving the intermediate air, the subsequent actuation of the auxiliary secondary power turbines through the aforementioned exhaust gas after actuation of the mentioned secondary power turbines.

4. The method according to p. 3, characterized in that the ratio of primary combustion air and hydrocarbon gas in the primary combustion zone of the combustion chamber is supported within 7.5:1.0 to 12,0:1,0.

5. A device for reforming pleodorina, having at least one input of the primary hydrocarbon gas, water or steam and primary combustion air and an outlet for output of the reformed gas is connected by a line reformed gas inlet of the reformed gas primary power turbines to bring it into effect, and the primary energoterminal associated with the primary compressor by rotating the shaft to compress the supplied air with the primary air, a secondary combustion chamber with flame zone and located downstream of the oxidation zone to produce exhaust gas, having at least one input secondary hydrocarbon gas, the secondary combustion air and the exit of the exhaust gas, connected to the output line of the exhaust gas from the secondary energotrans connected through the secondary shaft with the secondary compressor.

6. A device for reforming hydrocarbon gas containing a primary combustion chamber with a combustion zone located downstream of the reforming zone having at least one input of the primary hydrocarbon gas, water or steam and primary combustion air and an outlet for output of the reformed gas is connected by a line reformed gas I is Binah is associated with the primary compressor by rotating the shaft to compress the supplied air with the primary air, the secondary combustion chamber with flame zone and located downstream of the oxidation zone to produce exhaust gas, having at least one input secondary hydrocarbon gas, the secondary combustion air and the exit of the exhaust gas directly connected to the output line of the exhaust gas from the secondary energotrans to bring her into action, and secondary energoterminal mechanically connected through a rotatable auxiliary shaft with the auxiliary primary compressor for receiving the intermediate air and connected to the auxiliary line of the exhaust gas from the auxiliary secondary energotrans having an auxiliary output shaft for supplying energy alternative to the consumer.

 

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FIELD: inorganic chemistry, chemical technology.

SUBSTANCE: invention relates to a method for preparing chlorine dioxide from chlorate ions and hydrogen peroxide in small scales. Chlorate ions, sulfuric acid and hydrogen peroxide are fed into reactor as aqueous solutions wherein they are mixed. Chlorate ions are reduced to chlorine dioxide. Chlorine dioxide-containing product flow is formed in reactor. Flowing water is fed into ejector fitted by jet by spiral or helically. The product flow from reactor passes into ejector and mixed with water and chlorine dioxide diluted solution is formed. Invention provides preparing chlorine dioxide aqueous solution of high concentration and high output.

EFFECT: improved preparing method.

18 cl, 3 dwg, 1 tbl, 1 ex

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