Source: https://patents.google.com/patent/US9500362
Timestamp: 2018-04-23 13:48:37
Document Index: 531746462

Matched Legal Cases: ['application No. 61', 'application No. 61', 'application No. 61', 'art. 2', 'art. 1', 'art. 2']

US9500362B2 - Generating steam from carbonaceous material - Google Patents
Generating steam from carbonaceous material Download PDF
US9500362B2
US9500362B2 US13574544 US201113574544A US9500362B2 US 9500362 B2 US9500362 B2 US 9500362B2 US 13574544 US13574544 US 13574544 US 201113574544 A US201113574544 A US 201113574544A US 9500362 B2 US9500362 B2 US 9500362B2
US13574544
US20130200624A1 (en )
Daniel M. Hirson
A system and method of generating steam comprising providing a continuous supply of coal, combusting the coal in a primary processing chamber in the presence of oxygen and water to provide a first product gas stream, recovering heat from the first product gas stream in a first heat recovery steam generator to produce a first steam output, processing the first product gas stream in a secondary processing chamber in the presence of oxygen and water to provide a second product gas stream, recovering heat from the second product gas stream in a second heat recovery steam generator to produce a second steam output, and combining the first steam output and the second steam output. Preferably, the combined steam output is used to drive a steam turbine and the turbine is coupled to a generator.
This application claims benefit of U.S. provisional patent application No. 61/927,251 filed Jan. 21, 2010, U.S. provisional patent application No. 61/927,256 filed Jan. 21, 2010, and U.S. provisional patent application No. 61/330,729 filed May 3, 2010, the entire contents of which are incorporated by reference herein.
Preferred embodiments provide a method of generating steam comprising providing a continuous supply of coal, combusting the coal in a primary processing chamber in the presence of oxygen and water to provide a first product gas stream, recovering heat from the first product gas stream in a first heat recovery steam generator (HRSG) to produce a first steam output, processing the first product gas stream in a secondary processing chamber in the presence of oxygen and water to provide a second product gas stream substantially free of inorganic, organic and particulate contaminants, recovering heat from the second product gas stream in a second heat recovery steam generator (HRSG) to produce a second steam output, and combining the first steam output and the second steam output. In preferred embodiments, the combined steam output is used to drive a steam turbine. In certain preferred embodiments, the steam turbine is operatively coupled to an electric generator to produce electricity. In preferred embodiments, the method further comprises at least one of reducing the temperature of the second product gas stream, treating the second product gas stream by wet scrubbing, separating sulfur from the second product gas stream and collecting the sulfur with a baghouse, using a carbon dioxide recovery system, and discharging a treated gas stream substantially free of contaminants.
Other embodiments of the method comprise providing a continuous stream of thermal waste gas, recovering heat from the thermal waste gas stream in a first heat recovery steam generator (HRSG) to produce a first steam output, processing the thermal waste gas stream in a primary processing chamber in the presence of oxygen and water to provide a product gas stream, recovering heat from the first product gas stream in a second heat recovery steam generator (HRSG) to produce a second steam output, and combining the first steam output and the second steam output. In preferred embodiments, the combined steam output is used to drive a steam turbine. In certain preferred embodiments, the steam turbine is operatively coupled to an electric generator to produce electricity. In preferred embodiments, the method further comprises reducing the temperature of the product gas stream, treating the product gas stream by wet scrubbing, separating sulfur from the second product gas stream and collecting the sulfur with a baghouse, and discharging a treated gas stream substantially free of contaminants.
Certain embodiments provide a method of generating steam comprising providing a continuous supply of a carbonaceous material, combusting the carbonaceous material in a first processing chamber having at least one plasma arc torch in the presence of oxygen and water to provide a first product gas stream; recovering heat from the first product gas stream in a first heat recovery steam generator to produce a first steam output; processing the first product gas stream in a second processing chamber having at least one plasma arc torch in the presence of oxygen and water to provide a second product gas stream substantially free of carbon monoxide and hydrogen, recovering heat from the second product gas stream in a second heat recovery steam generator to produce a second steam output; and using the first steam output and the second steam output. Typically, method comprises using the first steam output and the second steam output to operate a steam turbine. In preferred embodiments, the first steam output and the second steam output operate a steam turbine operatively connected to an electric generator to produce electricity.
In preferred embodiments, the method comprises one or more of the steps of quenching the second product gas, processing the second product gas with a wet scrubber, processing the second product gas with a baghouse, and processing the second product gas with a carbon dioxide removal system.
The foregoing and other objects, features and advantages of the disclosure will be apparent from the following more particular description of preferred embodiments of the disclosure, as illustrated in the accompanying drawings in which like reference characters refer to the same parts throughout the different views. The drawings are not necessarily to scale, emphasis instead being placed upon illustrating the principles of the disclosure.
FIG. 2 is a flow-chart showing an alternative exemplary embodiment of the system of FIG. 1 further comprising an electric generator 110, a quench chamber 50, a wet scrubber 60, a baghouse 70, and a CO2 removal system 120.
FIG. 3 is a flow-chart showing an alternative exemplary embodiment of the system of FIG. 2 further comprising an absorption boiler 15.
FIG. 4 is a flow-chart showing an alternative exemplary embodiment of the system of FIG. 2 in which the baghouse 70 is upstream of the wet scrubber 60.
FIGS. 11A and 11B are schematic diagrams of a non-transferred mode plasma arc torch, 300, and a transferred mode plasma arc torch 350.
FIG. 12 is a schematic diagram of a processing chamber having a transferred mode plasma arc torch 350 and a centrifuge 400.
The present disclosure is directed to a method and system for generating steam from coal for the generation of electricity and other uses. The term “coal,” as used herein, is intended to refer to any carbonaceous feedstock, such as wood chips or organic waste, of adequate carbon density. As used herein, the term “carbonaceous material” refers to any solid, liquid or gaseous carbon-containing material suitable for use as a fuel, i.e. a material which can be combusted to produce energy. Included within the scope of this term are fossil fuels, including coal, oil, natural gas, and oil shale, biomass, i.e. plant materials and animal wastes used as fuel, coke, petroleum coke (“petcoke”), char, tars, wood waste, thermal waste gas, methanol, ethanol, propanol, propane, butane, ethane, etc. In certain preferred embodiments, the coal is a bituminous coal.
The method includes providing a continuous supply of coal, combusting the coal in a primary processing chamber (PPC) that provides circulation of gaseous reactants, recovering the heat that is the result of the combustion in a heat recovery steam generator (HRSG) to produce high-pressure steam Complete combustion of the coal is accomplished by combining the coal with oxygen and water in a high-temperature plasma reactor.
Processes for gasifying coal to produce synthetic gas (“syngas”) are known. The purpose of such gasification processes is to increase or at least maintain the caloric content of the syngas relative to the coal starting material. The syngas is then burned for generate steam to drive a turbine, for electricity generation. However, in the method of the present invention, instead of burning the product gas that results from the combustion of coal in the presence of oxygen and water, the heat from the product gas is used to convert water to steam, which in turn is used, in some preferred embodiments, to drive a turbine operatively linked to an electric generator to produce electricity.
Embodiments of the method may include multiple stages through which the product gas stream passes sequentially, with each stage comprising a processing chamber or reactor and a heat recovery steam generator (HRSG), with the HRSG downstream relative to the processing chamber. The product gas output from the final (furthest downstream) HRSG is processed through further steps comprising quenching, wet scrubbing and baghouse filtration, as needed, which result in a gas stream that is suitable for convenient management. Equipment for the practice of the disclosed method is commercially available from several suppliers. In preferred embodiments, a suitable processing chamber or reactor is a plasma-arc centrifugal treatment (“PACT”) system built by Retech Systems LLC (Ukiah, Calif.), and a suitable heat recovery steam generator (HRSG) system is built by NEM Standard Fasel (Hengelo, Netherlands).
Preferred embodiments of the systems and methods of the present disclosure can process coal in a continuous stream instead of batches, efficiently extract heat from the gas produced by the combustion of the coal in the presence of oxygen and water to create steam to drive a stream turbine, require about fifty (50%) percent less coal than other coal fired power plants to achieve similar electrical power levels; remove contaminant efficiently removal from gas streams, produce and capture a clean carbon dioxide stream ready for EPA approved sequestration.
As shown, combustion section A comprises a primary processing chamber 10 (“PPC 10”), first heat recovery steam generator 20 (“first HRSG 20”), a secondary processing chamber 30 (“SPC 30”), a second HRSG 40. In preferred embodiments, the gas decontamination section C comprises one or more of the following components: a quench chamber 50, a wet scrubber 60, a baghouse 70, and a CO2 removal system 120, all fluidly connected. A source of a treatment gas 80, 90 (such as O2), and source of water 85, 86, are both fluidly connected to each of the primary and secondary processing chambers 10, 30, respectively. The treatment gas 80 and the treatment gas 90 may be the same or different. In certain preferred embodiments, treatment gas 80 and treatment gas 90 comprise 93-95% oxygen and 5-7% argon.
The PPC 10 receives a continuous coal feed 75 as well as the treatment gas input 80 and water input 85, and outlets 16 and 18 for slag and gas, respectively. The PPC 10 is capable of withstanding the processing conditions (i.e., temperature, pressure, corrosion, and the like) under which the combustion of coal in the presence of oxygen and water takes place. One exemplary system is a plasma arc centrifugal treatment (PACT) system available from Retech Systems, LLC, in Ukiah, Calif., which comprise at least one plasma arc torch. For ease of discussion, the terms “torch” or “torches” will be used hereinafter to refer to plasma arc torches. The torches are capable of reaching temperatures ranging of up to about 10,000° F. to about 20,000° F. (about 5,540° C. to about 11,080° C.), or more.
In preferred embodiments, the method involves continuously introducing coal into the PPC 10, with the treatment gas 80 simultaneously supplied to chamber 10 at a predetermined flow rate and concentration to ensure complete combustion of the coal, while the torches heat both the coal and the treatment gas contained in the chamber. The ability to feed and operate the process continuously is an important virtue, improving both efficiency and the continuity of the output electrical power.
During combustion of the coal in the PPC 10, about ninety percent (90%) of the “ash” components of the coal are melted down into a glassy slag 88 by the torches, and the remainder becomes inorganic particulates entrained in the gas stream. The ash combustion product may not be electrically conducting until it is melted. To effect the required melting, a dual-mode plasma torch may be operated initially in non-transferred-arc mode until the work piece is molten and conducting, and then switched to non-transferred mode. The plasma gas may be introduced tangentially so as to produce swirl, thereby stabilizing the flow.
In preferred embodiments, the PPC 10 is configured to produce mixing of the coal feed 75, treatment gas 80 and water 85 to facilitate complete combustion. The slag resulting from combustion of the ash is melted and collects at the bottom of the PPC 10, which acts as a crucible. In preferred embodiments, the crucible is rotated in a centrifuge. The rotation serves to distribute heat from the torch over the molten slag and to hold, by centrifugal force, the molten slag away from the axis of rotation. Rotation of the crucible allows the slag to be removed from the bottom of the crucible by slowing its rotation. When sufficient slag has accumulated in the processing chamber it is removed, cooled and allowed to solidify in a shape convenient for disposal or use as building material. Any heavy metals present in the slag are locked in the leach-resistant glassy slag. An air lock may be used to remove the slag mold and the slag therein.
After combustion of the coal in PPC 10, the resulting gas stream O is discharged into first HRSG 20. The HRSGs are capable of receiving the hot gas stream from the PPCs without suffering appreciable degradation. That is, the HRSGs are capable of withstanding the temperature, pressure, corrosive chemicals, and the like, to which they may be subjected when contacting the hot gas. To assist in accommodating the elevated temperatures, it may be beneficial to line portions of the HRSG with ceramic. One exemplary HRSG is a heat-recovery boiler manufactured by NEM (Leiden, the Netherlands). The first HRSG 20 includes an inlet 22 for receiving the contaminant-containing gas stream O (hereinafter “gas stream O”) discharged from the PPC 10 at a first temperature T1, and an outlet 24 for discharging gas stream O into the SPC 30 at a temperature T2 that is lower than T1. In the first HRSG 20, heat is extracted from gas stream O using a heat exchanger for later use in electricity production, discussed in greater detail below. The amount of heat available for exchange in the first HRSG can vary depending upon various factors including, but not limited to, the configuration of the system, the size of the PPC 10, the rate of coal input, and the processing conditions in PPC 10.
SPC 30 is operated in the same manner as PPC 10. The treatment gas 90 and optionally water 95 are simultaneously supplied to SPC 30 at a predetermined flow rate and concentration, while the gas stream P flows into the chamber inlet 32 from the outlet 24 of the first HRSG 20, and the torches heat the gas. An SPC residence time of two seconds is estimated to suffice for the completion of combustion. The addition of water in the SPC 30 to the gas stream can be used to maintain and/or control the temperature of the gas in the SPC 30. In some embodiments, it may be desirable to maintain a temperature of about 2,400° F. to about 2900° F. (about 1,300° C. to about 1,600° C.).
The HRSGs employed in a multiple-HRSG embodiment may differ from one another. For example, HRSGs 20 and 40 may differ significantly in the density of corrosive and toxic components to which they are subjected, and the HRSGs may have different construction to withstand such differences. When the operating temperature of the processing chamber exceeds the maximum temperature the HRSG can accommodate, FIG. 2 illustrates an embodiment in which an additional heat sink, such as an absorption boiler 15, may be introduced to extract heat from the gas stream between the primarily processing chamber 10 and the HRSG 20. The gas stream resulting from any additional HRSGs is discharged into either the SPC 30 or the quench chamber 50, if needed, depending upon their position. Additional processing chambers and additional heat exchangers may be added either serially or in parallel.
In the quench chamber 50, if needed, the temperature of the treated gas stream R is further reduced to a temperature sufficiently low to prevent the re-formation of contaminants, and to a suitable range to prevent damage to the wet scrubber 60 and/or bag house 70. In the quench chamber 50, water spray is added to the gas stream to rapidly bring the temperature down to roughly 280° F., or just above the saturation temperature. FIG. 9 and Example 5 illustrate an embodiment without a quench chamber.
After treatment in wet scrubber 60, the treated gas U is discharged into baghouse 70, in which the sulfur from the SOx, is collected. Thereafter, a “clean” gas stream T comprising cooled down H2O and CO2 is discharged from the baghouse 70. The water can then be separated and the CO2 stream can then be captured and isolated for EPA approved sequestration or other approved carbon capture and sequestration (CCS) techniques by CO2 removal system 120.
As noted above, the primary and secondary HRSGs are fluidly connected to a steam turbine 100. The heat extracted from the gas streams O, Q in each of the primary, secondary and any additional HRSGs, is combined and used to generate steam to drive the steam turbine 100. After condensation of the steam in the turbine 100, water is recycled back to each of the HRSGs to absorb the heat from the gas streams O, Q. In preferred embodiments, steam 29, 49 produced by HRSG 20 and HRSG 40 drives a steam turbine 100 that drives a generator of electrical power 110 to generate electricity in a manner well known in the art.
Chemical Composition of Input Coal (M)
Dugout Canyon Mine, Price Utah
(http://www.uprr.com/customers/energy/coal/utah/soldier.shtml)
Carbon 72.20 30083 13646
Hydrogen 5.00 2083 945
Oxygen 10.30 4292 1947
Nitrogen 1.40 583 465
Sulfur 0.48 200 91
ASH: 10.62
Silica 6.55 61.7 2730 1238
Alumina 1.75 16.5 730 331
Titania 0.06 0.6 27 12
Ferric oxide 0.32 3.0 133 60
Lime 0.82 7.7 341 155
Magnesia 0.18 1.7 75 34
Potassium oxide 0.10 0.9 40 18
Sodium oxide 0.08 0.8 35 16
Sulfur trioxide 0.53 5.0 221 100
Phosphorus pentoxide 0.07 0.7 31 14
Undetermined 0.15 1.4 62 28
TOTAL 100.00 41,667 18,900
Slag Chemical Composition (N), kg/h
Silica 1,110
Magnesia 30.7
Lime 139
Iron Oxide 54.2
Alumina 298
The treatment gas input 90 to the secondary processing chamber 30 is 21,334 kg/h O2, and the water input 86 to the secondary processing chamber 30 is 820 kg/h H2O. The water input 87 to the quench chamber 50 is 21,467 kg/h H2O. The quench chamber 50 inlet temperature, T5, is 658° F. (328° C.), and the quench chamber 50 outlet temperature, T6, is 260° F. (127° C.). The mercury recovery at the quench chamber 50 is 1.31×10−2 kg/h, and 1.45×10−2 kg/h at the wet scrubber 60.
CO2 3.22 × 104 4.90 × 104 5.00 × 104 5.00 × 104 5.00 × 104 5.00 × 104 5.00 × 104
CO 1.13 × 104 6.00 × 102 0 0 0 0 0
O2 0 0 8.24 × 103 8.20 × 103 8.20 × 103 8.20 × 103 8.20 × 103
N2 1.24 × 103 1.24 × 103 1.24 × 103 1.24 × 103 1.24 × 103 1.24 × 103 1.24 × 103
H2O 4.20 × 104 3.51 × 104 5.03 × 104 5.03 × 104 7.18 × 104 7.18 × 104 1.67 × 103
SOx 1.79 × 102 1.81 × 102 1.82 × 102 2.26 × 102 2.27 × 102 2.27 × 102 2.27 × 101
H2 8.36 × 102 1.61 × 103 0 0 0 0 0
Hg 1.45 × 10−2 1.45 × 10−2 1.45 × 10−2 1.45 × 10−2 1.45 × 10−2 1.45 × 10−2 0
Inorg. Part. 2.01 × 102 2.01 × 102 2.01 × 102 2.01 × 102 2.01 × 102 2.01 × 102 1.005
NOx 1.94 × 10−3 0 15.60 1.55 × 10−3 3.00 × 10−5 3.00 × 10−5 3.00 × 10−5
CO2 2.95 × 104 4.90 × 104 5.00 × 104 5.00 × 104 5.00 × 104 5.00 × 104 5.00 × 104
CO 1.30 × 104 7.19 × 102 0 0 0 0 0
O2 0 0 7.68 × 103 7.64 × 103 7.64 × 103 7.64 × 103 7.64 × 103
N2 1.24 × 103 1.24 × 103 1.24 × 103 1.28 × 103 1.28 × 103 1.28 × 103 1.28 × 103
H2O 3.70 × 104 2.91 × 104 5.03 × 104 4.33 × 104 6.29 × 104 6.29 × 104 1.67 × 103
H2 7.10 × 102 1.60 × 103 0 0 0 0 0
Hg 1.45 × 10−2 1.45 × 10−2 1.45 × 10−2 1.45 × 10−2 1.45 × 10−3 1.45 × 10−3 0
NOx 4.6 × 10−2 0 22.4 1.53 × 10−3 3.00 × 10−5 3.00 × 10−5 3.00 × 10−5
Magnesia 1.63
Lime 7.36
Iron Oxide 2.87
Alumina 15.8
The treatment gas input 90 to the secondary processing chamber 30 is 1,170 kg/h O2, and the water input 86 to the secondary processing chamber 30 is 0 kg/h H2O. The water input 87 to the quench chamber 50 is 1.108 kg/h H2O. The quench chamber 50 inlet temperature, T5 is 658° F. (328° C.), and the quench chamber 50 outlet temperature, T6, is 260° F. (127° C.). The mercury recovery at the quench chamber 50 is 6.9×10−3 kg/h, and 7.7×10−4 kg/h at the wet scrubber 60.
CO2 1.66 × 103 2.59 × 103 2.64 × 103 2.54 × 103 2.54 × 103 2.54 × 103 2.54 × 103
CO 6.25 × 102 3.66 × 101 0 0 0 0 0
O2 0 0 4.74 × 102 4.73 × 102 4.73 × 102 3.46 × 103 3.46 × 103
N2 7.97 × 102 7.97 × 102 7.97 × 102 7.97 × 102 7.97 × 102 7.97 × 102 7.97 × 102
H2O 1.98 × 103 1.6 × 103 2.35 × 103 2.36 × 103 3.46 × 103 3.46 × 103 3.46 × 103
SOx 9.49 × 100 9.59 × 100 9.62 × 100 1.2 × 100 1.2 × 100 1.2 × 100 1.2 × 100
H2 4.22 × 101 8.4 × 102 0 0 0 0 0
Hg 7.67 × 10−3 7.67 × 10−3 7.67 × 10−3 7.67 × 10−3 7.7 × 10−4 7.7 × 10−4 7.7 × 10−4
Inorg. Part. 1.06 × 101 1.06 × 101 1.06 × 101 1.06 × 101 1.06 × 101 1.06 × 101 1.06 × 101
NOx 3 × 10−4 0 1.03 × 100 3 × 10−4 3 × 10−4 3 × 10−4 3 × 10−4
This study assumes that outlet temperatures from both HRSGs are 260° F. (127° C.). T3, only reaches 2568° F. (1409° C.). The mass flow rates in kilograms per hour (kg/h) of all inputs and outputs are shown in Table 2, above, for the slag chemical composition N, and Table 4, below, for the chemical composition of the gas flow at points O, P, Q, R, S, T, and U indicated in the schematic diagram of FIG. 9.
CO2 3.22 × 104 4.90 × 104 5.00 × 104 5.00 × 104 5.00 × 104 5.00 × 104
CO 1.13 × 104 6 × 102 0 0 0 0
O2 0 0 8.17 × 103 8.13 × 103 8.13 × 103 8.13 × 103
N2 1.24 × 103 1.24 × 103 1.23 × 103 1.24 × 103 1.24 × 103 1.24 × 103
H2O 4.20 × 104 3.48 × 104 4.95 × 104 4.95 × 104 4.95 × 104 1.67 × 103
SOx 1.79 × 102 1.81 × 102 1.82 × 102 2.27 × 102 2.27 × 102 2.27 × 101
H2 8.36 × 102 1.65 × 103 0 0 0 0
Hg 1.45 × 10−2 1.45 × 10−2 1.45 × 10−2 1.45 × 10−2 1.45 × 10−3 0
Inorg. Part. 2.01 × 102 2.01 × 102 2.01 × 102 2.01 × 102 2.01 × 100 1.005
NOx 1.94 × 10−3 0 9.06 4 × 10−5 4 × 10−5 4 × 10−5
Primary processing chamber 10 is capable of treating gas stream P such that the majority of contaminants and particulates are removed therefrom. Accordingly, primary processing chamber 10 is capable of withstanding the processing conditions (i.e., temperature, pressure, corrosion, and the like), under which such treatment takes place. In preferred embodiments, the PPC 10 is configured to produce mixing of the coal feed 75, treatment gas 80 and water 85 to facilitate complete combustion. One exemplary system is a plasma arc centrifugal treatment (PACT) system available from Retech Systems, LLC, in Ukiah, Calif.) comprising one or more non-transferred arc plasma torches fitted with gas backflow collars. Non-transferred arc plasma torches house both electrodes inside the torch, and the plasma extends beyond the end of the torch as a result of high gas flow through the torch, even though the electrodes are inside the torch. For ease of discussion, the terms “torch” or “torches” will be used hereinafter to refer to non-transferred arc plasma torches. FIGS. 11A and 11B are schematic diagrams of a non-transferred mode plasma arc torch, 300, and a transferred mode plasma arc torch 350.
In the quench chamber 50, the temperature of the treated gas stream R is further reduced to a temperature sufficiently low to prevent the re-formation of contaminants, and to a suitable range to prevent damage to the wet scrubber 60 and/or bag house 70. After reduction of the temperature to a suitable range, treated gas S is discharged from quench chamber 50 into the wet scrubber 60. In wet scrubber 60, VOCs, SOx and remaining particulate matter are removed from treated gas S, and the treated gas U is discharged into baghouse 70, in which the sulfur from the SOx is collected.
1. A method of generating steam comprising:
providing a continuous supply of a carbonaceous material;
combusting the carbonaceous material in a first processing chamber having a first at least one plasma arc torch in the presence of a first treatment gas and water to provide a first product gas stream comprising CO, CO2, H2, H2O, and byproducts from the combusting the carbonaceous material, wherein combusting the carbonaceous material in the first processing chamber further comprises maintaining the first processing chamber at a negative pressure from 25 to 50 mbar;
processing the first product gas stream in a second processing chamber having a second at least one plasma arc torch in the presence of a second treatment gas and water to provide a second product gas stream free of carbon monoxide, and hydrogen
recovering heat from the second product gas stream in a second heat recovery steam generator to produce a second steam output; and
using the first steam output and the second steam output wherein each of the first plasma torch and the second plasma torch generates heat from 5,540° C. to 11,080° C.
2. The method of claim 1 further comprising the step of using the first steam output and the second steam output to operate a steam turbine.
3. The method of claim 1 further comprising the step of using the first steam output and the second steam output to operate a steam turbine operatively connected to an electric generator to produce electricity.
4. The method of claim 1 further comprising the step of quenching the second product gas using at least one of air, water, steam and a combination thereof.
5. The method of claim 1 further comprising the step of processing the second product gas with a wet scrubber to neutralize acid gases in the second product gas.
6. The method of claim 1 further comprising the step of processing the second product gas with a baghouse.
removing carbon dioxide from the second gas product; and
cooling the removed carbon dioxide.
8. The method of claim 1 wherein the first treatment gas has a composition, the second treatment gas has a composition, and the first treatment gas composition and the second treatment gas composition are different.
9. The method of claim 1 wherein the first treatment gas and the second treatment gas comprise 93%-95% oxygen and 5%-7% argon.
10. The method of claim 1 wherein the first product gas stream has a temperature of 700° C. to 1100° C. and the second product gas stream has a temperature of 1200° C. to 1600° C.
11. The method of claim 1 wherein the first processing chamber and the second processing chamber have different temperatures.
12. The method of claim 1 wherein the first processing chamber comprises a centrifuge portion.
13. The method of claim 12 wherein the centrifuge portion further comprises a centrifuge floor operatively connected to a slag exit.
14. The method of claim 13 further comprising forming a slag bath.
15. The method of claim 14 further comprising the step of rotating the centrifuge portion with a rotational velocity sufficient to exclude the slag bath from the slag exit.
16. The method of claim 15 further comprising the step of slowing the rotational velocity of the centrifuge portion thereby allowing the slag bath to enter the slag exit.
17. The method of claim 1 further comprising extracting heat from the first product gas stream in a heat sink.
18. The method of claim 17 wherein the heat sink comprises an absorption boiler.
19. The method of claim 17 further comprising directing the first product gas stream from the heat sink to the first heat recovery steam generator.
20. The method of claim 1 wherein the first product gas stream and the second product gas stream comprise a composition having a ratio of carbon monoxide to carbon monoxide plus carbon dioxide of 20% to 45%.
US13574544 2010-01-21 2011-01-21 Generating steam from carbonaceous material Active 2033-08-30 US9500362B2 (en)
US29725110 true 2010-01-21 2010-01-21
US29725610 true 2010-01-21 2010-01-21
US33072910 true 2010-05-03 2010-05-03
PCT/US2011/022159 WO2011091327A1 (en) 2010-01-21 2011-01-21 Generating steam from carbonaceous material
US13574544 US9500362B2 (en) 2010-01-21 2011-01-21 Generating steam from carbonaceous material
US20130200624A1 true US20130200624A1 (en) 2013-08-08
US9500362B2 true US9500362B2 (en) 2016-11-22
ID=44626381
US13574544 Active 2033-08-30 US9500362B2 (en) 2010-01-21 2011-01-21 Generating steam from carbonaceous material
US13100160 Abandoned US20110265698A1 (en) 2010-05-03 2011-05-03 System and method for reutilizing co2 from combusted carbonaceous material
US14733588 Active 2032-06-06 US9874113B2 (en) 2010-05-03 2015-06-08 System and method for reutilizing CO2 from combusted carbonaceous material
US15350927 Pending US20170058710A1 (en) 2010-01-21 2016-11-14 Generating steam from carbonaceous material
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