Systems and methods for power production with integrated production of hydrogen

Abstract

To provide systems and methods useful for power production.SOLUTION: A power production cycle comprising a first combustor (102) and a turbine (103) and utilizing CO2 as a working fluid may be configured for simultaneous hydrogen production in an additional hydrogen production unit. Substantially all carbon generated from combustion in power production and hydrogen production is collected in the form of carbon dioxide. Further, produced hydrogen (optionally mixed with nitrogen (160) received from an air separation unit) can be input as fuel in a gas turbine combined cycle unit for additional power production therein without any atmospheric CO2 discharge.SELECTED DRAWING: Figure 1

Description

[Technical field]

[0001] This disclosure relates to 2 An electrical power production system and method is provided in which an electrical power production cycle utilizing a circulating fluid can be configured for the co-production of hydrogen. [Background technology]

[0002] Hydrogen has long been considered a desirable energy source due to its clean interconversion with stored energy sources, such as for use in fuel cells. For example, hydrogen can be used as a fuel to power electric vehicles that use fuel cells advantageously coupled to large capacity batteries. The use of hydrogen as a fuel reduces CO 2 It would be beneficial to eliminate emissions of NOx, CO, and hydrocarbons, resulting in a significant reduction in air pollution. However, the path to implementation of a hydrogen-based global economy would require very large hydrogen production capacities. Furthermore, such hydrogen production methods would reduce CO emissions from the fossil fuels used. 2 It will be necessary to simultaneously achieve nearly 100% recovery of carbon dioxide and low-cost hydrogen production.

[0003] Beneficially, the use of hydrogen as a fuel source can also reduce or eliminate carbon dioxide emissions associated with traditional power production processes. For example, hydrogen can be diluted with nitrogen and / or steam and used as a fuel in a gas turbine combined cycle power generation system.

[0004] Gas turbine combined cycle power generation systems are the primary source of electricity generation worldwide in terms of their ability to produce electricity from natural gas with efficiencies in the range of 60% on a lower heating value (LHV) basis. Despite their desirable efficiency, such systems still suffer from problems because the carbon in the fuel is emitted to the atmosphere as carbon dioxide. To solve this problem, turbine exhaust CO 2 The gas is recycled and subsequently cooled to produce the product CO 2to the inlet of the gas turbine compressor section, replacing air as the working fluid. 2 It is possible to operate a gas turbine with 100% oxygen. The fuel must be burned with pure oxygen, and the only combustion product is CO. 2 This method is also problematic because only CO and water are produced and because it requires the addition of an air separation plant, which acts as a process efficiency reducer. Chemical and / or physical solvent cleaning processes treat gas turbine exhaust and remove CO 2 However, such processes can provide mixed products and again reduce process efficiency due to the added expense and maintenance of the exhaust treatment system. As discussed above, it is possible to eliminate carbon emissions by utilizing hydrogen as fuel in gas turbines. However, such approaches have the associated CO 2 A steady source of hydrogen is required, which is provided preferentially without generation. The desire to use hydrogen as a fuel source reduces CO emissions to the atmosphere. 2 There remains a need for a means to provide hydrogen fuel that is virtually emission-free and at low cost. Summary of the Invention

[0005] The present disclosure relates to systems and methods for combined power and hydrogen production. In particular, power production (e.g., electrical power) and hydrogen production can be accomplished simultaneously by combustion of a hydrocarbon fuel. More particularly, the hydrocarbon fuel can be combusted to provide combustion products that include and / or are converted to hydrogen. Furthermore, hydrogen can be produced with substantially zero carbon emissions, and hydrogen can be utilized as a fuel for power production.

[0006] In some embodiments, the present disclosure further provides a method for the partial oxidation of hydrocarbon fuels in catalytic and / or non-catalytic reactions using oxygen, hydrogen (H 2The present invention relates to systems and methods for the generation of natural gas (NG) and carbon monoxide (CO). For example, a partial oxidation non-catalytic reactor (POX) or a catalytic autothermal reactor (ATR) can be used. Following partial oxidation of a hydrocarbon fuel, a gas-heated reformer (GHR) can be used in either series or parallel mode with the POX or ATR reactor to generate additional H by utilizing the sensible exhaust heat in the POX and / or ATR reactor system to provide heat for the endothermic catalytic steam plus natural gas reforming reaction occurring in the GHR. 2 and CO (i.e., synthesis gas).

[0007] In one or more embodiments, the systems and methods of the present invention can utilize excess heat (e.g., temperature levels below 400° C.) generated in the hydrogen plant to provide additional heat input to the power production system and method. This added heat can be beneficial in helping to achieve high electricity generation efficiencies.

[0008] In another embodiment, the present disclosure provides a method for producing a fuel cell comprising: 2 +CO synthesis gas generation reactor. Providing the heat required to superheat one or both of the steam feed streams to the synthesis gas generation reactor. Providing the heat can be accomplished, for example, by using heat from a turbine discharge stream from the power production system and process.

[0009] In another embodiment, the systems and methods of the present invention may utilize a pressure swing adsorption (PSA) system to separate pure high pressure hydrogen from a cooled crude hydrogen stream. The use of a pressure swing adsorption system may include, for example, the separation of H2O from a catalytic shift reaction using steam. 2 This can be carried out following the conversion of CO to

[0010] In additional embodiments, the present disclosure can provide for the capture of substantially all of the carbon present in the fuel for a hydrogen plant. For example, carbon capture can be achieved by compressing the waste gas from the PSA and extracting CO 2This can be accomplished by using the compressed waste gas as part of the fuel gas for the power production cycle system and method in which a cooled turbine exhaust stream is extracted.

[0011] If desired, some or all of the oxygen used in the power production cycle system and method can be provided in a low pressure feed from a cryogenic air separation plant or an oxygen ion transport membrane (ITM) oxy-fuel combustor. The hydrogen plant can receive substantially pure H from the PSA at up to 95 bar. 2 A high pressure gaseous oxygen stream at a pressure of up to 105 bar can be utilized as a feed to the POX and / or ATR producing . A cryogenic air separation plant providing high pressure oxygen can be particularly useful in providing oxygen.

[0012] In addition, if desired, the gas turbine exhaust may be heated to produce H 2 A second fuel oxy-combustor may be used to provide preheat for one or more of the plant fuel, oxygen, and steam supply streams. The second fuel oxy-combustor may be provided with a gaseous oxygen stream at turbine discharge pressure, the gaseous oxygen stream being O 2 CO in the burner injection system 2 The natural gas is preferentially diluted with oxygen to control the adiabatic flame temperature. A second alternative is to use an ITM combustor supplied with preheated low pressure air to preheat the turbine exhaust using a preheated natural gas stream mixed with the gas turbine exhaust combusted with diffusing oxygen to provide the necessary superheat of the natural gas and steam feed streams for the syngas reactor.

[0013] In one or more embodiments, the present disclosure can provide an electrical power production system or unit that can be configured for simultaneous electrical power and hydrogen production. In particular, the system can include a combustor, a turbine, a recuperator, a water separator, a compressor, and an integrated hydrogen production system or unit.

[0014] In one or more embodiments, the present disclosure may provide a method for producing electrical power. In particular, the method includes: Combustion Pressure Recirculating CO 2 A carbonaceous fuel is combusted in a first combustor with an oxidizer in the presence of a CO 2 providing a combustion product stream comprising: Expanding the combustion product stream through a turbine to produce electricity and CO 2 forming a turbine discharge flow comprising: CO 2 cooling the turbine discharge flow comprising the turbine in a recuperative heat exchanger; CO from other components of the turbine discharge stream 2 Separation and recirculation of CO 2 Providing a flow recirculating CO 2 compressing the stream to substantially combustion pressure; recirculating CO 2 CO from the combustion of carbon in a hydrocarbon or carbonaceous fuel 2 and Recirculated CO compressed with heat drawn from the turbine exhaust stream and / or with external heat provided at a temperature below about 400°C. 2 heating the stream in a recuperative heat exchanger; The optionally preheated carbonaceous fuel (and optionally oxygen and / or steam) is passed through a POX or ATR, optionally followed by a GHR, and in particular H 2 and forming a synthesis gas stream, which may include CO. cooling the synthesis gas to generate high pressure steam; CO and H 2 O to H 2 and CO 2 passing the synthesis gas through one or more catalytic shift reactors effective to convert H from the syngas stream 2 and H from the syngas stream 2 passing the remaining fuel gas through one or both of the first combustor and the second combustor following the separation of the first combustor and the second combustor; may include.

[0015] It should be understood that not all of the recited steps in the foregoing methods must be performed in every possible embodiment. Rather, one or more of the above steps may be optional, and one of ordinary skill in the art with knowledge of this disclosure will be able to recognize that various possible combinations of steps may be performed in separate embodiments.

[0016] In addition to the foregoing, the systems and methods of the present disclosure may be further defined with respect to additional components and configurations. For example, one or more of the following may apply:

[0017] Hydrogen production may be carried out using at least two reactors, specifically a partial oxidation reactor and a gas-heated reforming reactor.

[0018] The high temperature heating of the hydrocarbon and / or steam feed streams for use in syngas production can utilize heat from the power production cycle. In particular, the heat can be from at least a portion of the power production cycle turbine exhaust.

[0019] Hydrogen can be separated from one or more waste components in a multi-bed pressure swing adsorption section.

[0020] One or more of the waste components separated from the hydrogen can be compressed and used as part of the fuel in the power production cycle.

[0021] Substantially all of the carbon from the hydrocarbon fuels used as fuel feed in the hydrogen production system and method is converted to high pressure CO 2 CO 2 It is adaptable for introduction into a pipeline.

[0022] H 2 Substantially all of the low temperature heat removed from the plant (ie, heat at temperatures above ambient temperature but below about 400° C.) can be extracted for heat input into the power production cycle.

[0023] In one or more embodiments, the present disclosure provides a method for integrating hydrogen production from fuels (e.g., from natural gas), CO from carbon in the fuel, and 2 It is possible to provide effective integration of heat between the power system and hydrogen production, with high efficiency (e.g., >60% LHV) and low CO emissions to the atmosphere. 2 Near-zero emissions and partial or complete CO2 emissions 2 It would be desirable to be able to achieve production of electrical power from fuels that is substantially similar to the costs incurred by current processes that do not provide recovery.

[0024] In some embodiments, the present disclosure provides a system for producing electricity, comprising: 2 CO 2 a power production section configured for successively compressing, heating, expanding, cooling, and recirculating a working fluid; a partial oxidation combustor configured to form a syngas stream and a H 2 a hydrogen production system or hydrogen production unit including a separator configured to separate H from the hydrogen production system or hydrogen production unit; 2 and a gas turbine combined cycle portion configured to receive and combust the

[0025] In some embodiments, the present disclosure provides a method for producing and processing electricity using an integrated H 2 A production process comprising: In the combustor, recirculating heated CO 2 At elevated pressure, in the presence of essentially pure O 2 combusting a gaseous fuel with the expanding the combustion product stream to a low pressure in a turbine to produce shaft power and form a turbine exhaust stream; In the recuperator, recirculating CO 2 Heat the flow and recycle the heated CO 2 cooling the turbine exhaust flow while forming a cooled turbine exhaust flow; In some cases, recycled CO from an external source 2applying heat to the stream at a temperature level of less than about 400° C.; Separating condensate from the cooling turbine exhaust stream and recirculating CO 2 Providing a flow recirculating CO 2 compressing the stream to a pressure suitable for injection into a combustor; Including, H 2 one or both of the hydrocarbon or carbonaceous fuel stream and the steam stream supplied to the synthesis plant reactor are heated utilizing heat transferred from the turbine exhaust stream; Increasing the turbine combustor fuel inlet flow rate and turbine inlet temperature increases the amount of power generated from the turbine as well as the amount of H 2 Provides the heat required to preheat the hydrocarbon or carbonaceous and steam feed to the plant synthesis reactor, and the turbine inlet temperature to the recuperator heat exchanger is independent of the CO 2 the condition being substantially the same as in the power cycle; H at a temperature level below approximately 400°C 2 The excess heat from the synthesis plant is used to 2 Recycled CO from synthesis plants 2 The condition that the information is transmitted in a stream, H in one or more CO catalytic shift reactors 2 followed by the conversion of CO to H 2 Impure total H in synthesis plants 2 separating hydrogen from the production stream followed by cooling to about ambient temperature and removing liquid water; H 2 H in synthesis plants 2 The condition is that the waste fuel gas remaining after separation is compressed to a pressure suitable for injection into the combustor; H 2 H in synthesis plants 2 The separation is carried out in multiple stages; H 2 H in synthesis plants 2 Separation of the intermediate CO 2 Removal of H and catalytic 2 and the proviso that the CO shift conversion to In addition to substantially pure oxygen and fuel gas, at least a portion of the turbine exhaust is used to 2 the provision of utilizing a second combustor to provide at least a portion of the heat required to preheat the hydrocarbon or carbonaceous and steam feed to the plant synthesis reactor; Provide a heated and pressurized water and / or steam flow at a temperature of less than about 400° C. and convert excess heat into H 2 Recycled CO from synthesis plants 2 The condition of carrying it in the flow, H 2 H produced from a synthesis plant 2 N 2 and / or in combination with steam to produce a fuel gas suitable for combustion in a gas turbine to produce electricity; One or more of the following applies to power production, processing and integrated H 2 Regarding production processing.

[0026] In one or more embodiments, the present disclosure may provide, inter alia, a system for combined power and hydrogen production comprising a power producing section that expands pressurized carbon dioxide for power production, a hydrogen producing section that partially oxidizes a hydrocarbon fuel to produce a synthesis gas from which hydrogen is separated, and one or more flow members configured for passage of one or more flows between the power producing section and the hydrogen producing section.

[0027] In another embodiment, the mentioned system for combined power and hydrogen production can be further defined with respect to one or more of the following statements, which can be combined in any order or number:

[0028] The power production section may include a combustor configured to receive a hydrocarbon fuel and oxygen and output a heated stream comprising at least compressed carbon dioxide; a turbine configured to receive the heated stream comprising compressed carbon dioxide from the combustor and expand it to produce power and form an expanded heated stream comprising carbon dioxide; a recuperative heat exchanger configured to receive the expanded heated stream comprising carbon dioxide and form a cooling stream comprising carbon dioxide; a separator configured to receive the cooling stream comprising carbon dioxide from the recuperative heat exchanger and provide a carbon dioxide stream; and a compressor configured to receive the carbon dioxide stream from the separator and compress the carbon dioxide.

[0029] The hydrogen production section can include a partial oxidation combustor configured to receive a portion of the hydrocarbon fuel and oxygen and to output a synthesis gas, a reformer in fluid communication with the partial oxidation combustor and configured to receive the synthesis gas from the partial oxidation combustor and to receive a portion of the hydrocarbon fuel, a shift reactor in fluid communication with the reformer, a shift stream heat exchanger in fluid communication with the shift reactor, a separator in fluid communication with the shift stream heat exchanger, and a pressure swing adsorption section in fluid communication with the separator, the pressure swing adsorption section configured to output a substantially pure hydrogen stream.

[0030] Hydrocarbon fuel may be provided to the partial oxidation combustor and reformer from a hydrocarbon fuel line that passes through a shift flow heat exchanger.

[0031] The hydrocarbon fuel line may pass through an auxiliary heat exchanger configured to receive and cool the heated stream comprising the expanded carbon dioxide exiting the turbine of the power production section.

[0032] The system may further include a water line that may be configured to pass water to the reformer.

[0033] The water line may pass through a shift flow heat exchanger.

[0034] The water line may pass through an auxiliary heat exchanger configured to receive and cool the heated stream comprising expanded carbon dioxide exiting the turbine of the power production section.

[0035] The pressure swing adsorption section may be configured to produce a waste stream that is separated from the substantially pure hydrogen stream, the waste stream comprising one or more of carbon monoxide, carbon dioxide, hydrogen, methane, argon, and nitrogen.

[0036] The one or more flow members configured for passage of one or more flows between the power producing section and the hydrogen producing section may include a line for passage of at least a portion of the waste stream from the pressure swing adsorption section to a combustor of the power producing section.

[0037] The power producing section may further comprise an additional heat exchanger in contact with one or more compressed streams from the power producing section and configured to heat the substantially pure carbon dioxide stream.

[0038] The additional heat exchanger may be further configured to contact the stream from the hydrogen production section and to heat the substantially pure carbon dioxide stream.

[0039] In one or more embodiments, the present disclosure provides, inter alia, a method for combined power and hydrogen production, comprising: 2 combusting a first hydrocarbon fuel in a first combustor with an oxidizer at a combustion pressure in the presence of a CO 2 providing a combustion product stream comprising CO 2 The combustion product stream including the 2 forming a turbine discharge flow comprising CO 2 cooling the turbine discharge stream containing CO in a recuperator heat exchanger and extracting CO from another component of the turbine discharge stream. 2 Separation and recirculation of CO 2 and providing a stream comprising recirculating CO. 2 compressing a stream containing the gas to substantially combustion pressure; and compressing the compressed recirculated CO using heat extracted from the turbine exhaust stream. 2The stream is heated in a recuperator and recycled CO 2 providing a heated stream comprising recirculating CO 2 and producing hydrogen in a hydrogen production section including passing a heated stream comprising the first hydrocarbon fuel into a first combustor, and passing a second hydrocarbon fuel stream into a partial oxidation reactor to form a synthesis gas stream, and processing the synthesis gas to provide a substantially pure hydrogen stream and a waste stream comprising at least carbon monoxide.

[0040] In another embodiment, the mentioned method for combined power and hydrogen production can be further defined with respect to one or more of the following statements, which can be combined in any order or number:

[0041] The method may further include passing at least carbon monoxide from the exhaust stream to a first combustor.

[0042] Processing the syngas may include passing the syngas through a reformer that is also configured to receive a second hydrocarbon fuel gas stream and a hot water stream.

[0043] One or more of the second hydrocarbon fuel stream passing through the partial oxidation reactor, the second hydrocarbon fuel stream received by the reformer, and the hot water stream received by the reformer are fed to a CO 2 The turbine discharge flow may be heated by an auxiliary heat exchanger utilizing heat transferred from the turbine discharge flow including

[0044] Processing of the syngas may include passing the reformed syngas from the reformer through a shift reactor followed by a shift stream heat exchanger.

[0045] A hydrocarbon fuel stream may be provided to one or both of the partial oxidation combustor and the reformer via a hydrocarbon fuel line that passes through a shift stream heat exchanger.

[0046] A stream of hot water received at the reformer may be provided through a water line that passes through a shift stream heat exchanger.

[0047] The process may further include passing the stream exiting the shift stream heat exchanger through a water separator to remove water and form a crude hydrogen stream comprising hydrogen and impurities.

[0048] The method may further include passing the crude hydrogen stream through a pressure swing adsorption section that produces substantially pure hydrogen and a waste stream.

[0049] The waste stream may be compressed to a pressure suitable for input to the power producing section's combustor and then passed through the power producing section's combustor.

[0050] The power production section is in contact with one or more compressed streams from the power production section and is configured to generate a recirculated CO 2 may include an additional heat exchanger for heating the stream.

[0051] The method is such that heat from the hydrogen production section is recycled to 2 The method may further include passing the heated stream from the hydrogen-producing section through an additional heat exchanger so as to be transferred to the stream of

[0052] Recirculated CO from hydrogen production section 2 The heat transferred to the stream may be at a temperature level of less than about 400°C.

[0053] The first hydrocarbon fuel is burned to produce CO 2 to provide additional heat to at least a portion of the turbine discharge flow including 2 At least a portion of the turbine discharge stream including the first hydrocarbon fuel and the oxygen stream may be passed through the second combustor.

[0054] CO 2 At least a portion of the additional heat provided to at least a portion of the turbine discharge stream including may be provided to one or more streams in the hydrogen-producing section.

[0055] The method may further include producing electrical power in a gas turbine separate from the electrical power production section, where at least a portion of the substantially pure hydrogen is combusted in the gas turbine to produce electrical power.

[0056] In one or more embodiments, the present disclosure provides a system for producing electricity, comprising: 2 CO 2 A system may further be provided that includes a power production section configured for sequentially compressing, heating, expanding, cooling, and recirculating a working fluid; a hydrogen production section including a partial oxidation combustor configured to form a syngas stream, and one or more additional components configured to process the syngas to form a substantially pure hydrogen stream and a waste stream; and a gas turbine combined cycle section configured to receive and combust at least a portion of the substantially pure hydrogen from the hydrogen production section.

[0057] Having thus described the disclosure in general terms above, reference is now made to the accompanying drawings, which are not necessarily drawn to scale, and in which: [Brief description of the drawings]

[0058] [Figure 1] 1 is a flow chart of an exemplary system and method for producing power using a CO2 working fluid and including a cryogenic oxygen plant. [Diagram 2] 2 is a flow chart of a hydrogen production facility including components for integration with power production systems and methods as illustrated in FIG. 1. [Diagram 3] 1 is a flow chart illustrating a combined system in which nitrogen gas from an air separation section and hydrogen gas from a hydrogen generation section are input to a gas turbine combined cycle section. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0059] The subject matter of the present invention will now be described more fully hereinafter with reference to exemplary embodiments thereof. These exemplary embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the subject matter to those skilled in the art. Indeed, the subject matter may be embodied in many different forms and should not be construed as limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will satisfy applicable legal requirements. As used in this specification and the appended claims, the singular forms "a," "an," and "the" include the plural forms unless the context clearly dictates otherwise.

[0060] The present disclosure provides systems and methods for achieving simultaneous power and hydrogen production. Previous efforts have been made to provide simultaneous power and hydrogen production, and one or more components from such previous attempts may be incorporated into the systems and methods of the present disclosure. For example, U.S. Patent No. 6,534,551 to Allam et al. describes a combination of 1) a hydrocarbon fuel gas reaction with steam and / or oxygen, and 2) a power system utilizing compressed oxidant gas, in which the fuel gas is burned with the product of a combustor that produces power by working expansion, the expanded combustion product gas is used to superheat steam used in a hydrogen synthesis reaction, and an oxygen production section is powered by at least a portion of the power produced by the expansion of the combustion product gas. U.S. Patent No. 6,534,551 to Allam et al. is incorporated herein by reference.

[0061] In one or more embodiments, the systems and methods of the present invention recover substantially all of the carbon produced, in particular the CO 2It would be beneficial to be able to recover substantially all of the hydrogen produced by the hydrogen plant and provide hydrogen production in combination with electricity production. The combination can be a single system having a suitable combination of components to achieve simultaneous production of hydrogen and electricity. In some embodiments, the hydrogen production system or section can operate in parallel with the electricity production system or section with appropriate spanning of components such that the two systems or sections function as a single, integrated system. Thus, the present disclosure may relate to a hydrogen plant, which refers to the combination of components necessary to form the hydrogen production system or section utilized herein.

[0062] A useful power production cycle according to the present disclosure is 2 (Especially supercritical CO 2 - or sCO 2 ) is used in the working stream. As a non-limiting example, U.S. Patent No. 8,596,075 to Allam et al., incorporated herein by reference, describes a method for producing recycled CO 2 A system and method are described in which a stream is directly heated and used in power production. Specifically, a recirculated CO 2 The stream is provided at high temperature and pressure to a combustor where a carbonaceous fuel is burned with oxygen, expanded into a turbine to produce power, cooled in a heat exchanger, purified to remove water and other impurities, pressurized, reheated using heat captured from the turbine exhaust, and passed through the combustor again to repeat the cycle. The system and method removes all fuel and combustion-derived impurities, excess CO 2 Beneficially, the system and method removes CO2, sulphate, and water as gas or supercritical fluid, liquid or solid (e.g., ash), resulting in virtually zero atmospheric emissions for all streams. 2 After the stream is repressurized and before combustion, heat input at low temperature levels (i.e., below 500°C) (i.e., recuperated heat from the turbine exhaust stream plus recirculated CO 2 High efficiency is achieved by using low temperature levels of heat added to the CO 2It should be understood that this illustrates a power production cycle utilizing a working fluid and a combination of the components and method steps described herein and in the incorporated documents.

[0063] Useful power production cycles according to the present disclosure may include more or fewer steps than those described above, and typically include high pressure recirculating CO 2 The term "high pressure recycled CO" may include a cycle in which the stream is expanded for power production and recycled again for further power production. 2 The stream may have a pressure of at least 100 bar (10 MPa), at least 200 bar (20 MPa), or at least 300 bar (30 MPa). In all instances, the upper pressure limit may be determined by the limitations of the equipment available at the time of implementing the systems and / or methods according to the present disclosure. High Pressure Recycled CO 2 The stream may have a pressure of about 100 bar (10 MPa) to about 500 bar (50 MPa), about 150 bar to about 450 bar (45 MPa), or about 200 bar (20 MPa) to about 400 bar (40 MPa) in some embodiments. Thus, the high pressure recycled CO 2 The term flow refers to the CO2 concentration at pressures within the ranges mentioned above. 2 The pressure may be 2 The term also applies to other high pressure stream expressions described herein, such as high pressure working streams including: (a) a high pressure working stream comprising: (i) a high pressure working stream including: (a) a high pressure working stream comprising: (b) a high pressure working stream including: (c) a high pressure working stream including: (d) a high pressure working stream including: (e) a high pressure working stream including: (i) a high pressure working stream including: (c) a high pressure working stream including: (a) a high pressure working stream including: (c ... 2 The outlet temperature of the first combustor after mixing with the above gas can be about 400°C to about 1,500°C, about 500°C to about 1,200°C, or about 600°C to about 1,000°C.

[0064] In some embodiments, a power production cycle, such as those described above, integrated with a hydrogen production facility can utilize the excess low temperature levels of heat produced by the hydrogen plant to increase the efficiency of power production. For example, superheating of steam and hydrocarbon feeds in the turbine exhaust stream can be performed in power production systems and methods to increase turbine electrical output. Additionally, the hydrogen plant can be used to reduce CO from carbon present in the hydrocarbon fuel feed to the hydrogen plant or system. 2 Virtually all of the CO captured, and in some cases, from electricity production cycle plants 2 The integrated system can be combined with the power production cycle to achieve zero air emissions and reduce the power plant and H 2 CO produced from both plants 2 Recover up to 100%.

[0065] Hydrogen production plants for use in accordance with the present disclosure can incorporate various components known to be suitable in conventional hydrogen production plants. For example, a hydrogen production plant may use partial oxidation of hydrocarbons with oxygen, possibly with the addition of steam, to convert a hydrocarbon feed to CO+H 2 The partial oxidation (POX) of the natural gas feed with pure oxygen can be carried out at an outlet temperature of about 1300° C. to about 1500° C. and a typical pressure of about 30 bar to about 150 bar. The autothermal reformer (ATR) can add steam and extra hydrocarbons, typically natural gas, after the partial oxidation burner so that the hot gas is then further converted into H 2 +CO and the gas mixture is cooled to an outlet temperature of about 1000 °C to about 1100 °C at a pressure of about 30 bar to about 150 bar. The second stage reactor is used to obtain the total H from both reactors. 2A steam / hydrocarbon catalytic reformer may be used that uses the +CO gas product (e.g., at temperatures above about 1000° C.) and provides the endotherm of the reforming reaction in the convection heated shell side flow with a catalyst in the tubes. In some cases, the two reactors may be operated in series or parallel mode. A preferred configuration has open-ended tubes filled with catalyst that hang from a single tube plate at the top of the vessel, and a product H 2 +CO leaves the reformer tubes and is mixed with the product gas from the POX reactor or ATR at the bottom of the GHR, resulting in a total product of H 2 A vertical gas-fired reformer (GHR) is used where the +CO stream passes through the shell side and is cooled, typically from about 1050°C to 550°C-800°C.

[0066] The advantage of the two reactor configuration is that it reduces the amount of H from the hydrocarbon feed. 2 +CO yield is maximized, and all CO formed in the reactor 2 is contained in the high pressure system. Products CO + H 2 The gas is further cooled in a waste heat boiler (WHB) which produces steam, and an added benefit is that the amount of this steam can be reduced by 2 times the amount of H 2 + It is sufficient only to provide the required amount of steam to the CO reactor. The by-product of steam production in the system is not significant.

[0067] To generate hydrogen, the WHB leaves the reactor at a typical temperature of about 240°C to about 290°C, and typically contains about 20% to about 40% (molar) steam. 2 +CO product is CO reacting with steam, CO 2 and further H 2 The mixture passes through one or more catalytic shift converters that produce H 2 The overall reaction sequence for the production process is shown below (CH is the hydrocarbon). 4 ). CH 4 +1 / 2O 2 → CO+2H 2 Partial oxidation CH 4 +2O 2 → CO 2+2H 2 O Heat generation CH 4 +H 2 O → CO+3H 2 Modification CH 4 +CO 2 → 2CO+2H 2 Modification CO+H 2 O → CO 2 +H 2 CO shift

[0068] Total CO+H passing through the CO shift reactor 2 The product is cooled and a significant amount of heat is released due to gas cooling and steam condensation, usually at temperature levels below about 290° C. This heat is not released at a single temperature level, but over a range of temperatures down to about ambient temperature. Some of this heat release can be used to preheat boiler feed water, but there is a large surplus available at lower temperature levels and only at a certain temperature range.

[0069] H in the two reactors 2 The efficiency of +CO generation can be significantly increased by preheating the hydrocarbon and steam feed, typically to about 400°C to about 550°C, preferably to about 500°C to about 550°C. This is because H 2 +This is preferably done by using an external heat source since there is no excess heat at these temperature levels available within the WHB in addition to the CO generating reactor.

[0070] Cooling H 2 The rich gas stream is then passed through a cooler (e.g., an ambient temperature cooler) that removes condensed water. The gas stream then passes through a separator that can isolate substantially pure hydrogen. For example, the gas stream typically has about 10 ppm to about 50 ppm total impurities and is separated from the feed to produce product H 2 The crude H can be passed through a conventional multi-bed pressure swing adsorber which typically separates about 85% to about 90% (molar) of the hydrogen as a pure stream with a pressure drop of typically about 1 bar to about 2 bar. 2Any impurities in the feed stream are separated into a waste fuel gas stream and the waste stream is H 2、 CO, CO 2 , C.H. 4 , N 2 , argon, and a small amount of vapor phase H 2 The exhaust gas may contain any combination of components such as H, O, etc. The pressure is typically about 1.1 bar to about 1.5 bar. This exhaust gas typically has about 20% of the lower heating value (LHV) of the total hydrocarbon feed to the hydrocarbon reactor, so its effective use is limited by the addition of H 2 There are benefits to the overall economics of production. The waste gas converts all the carbon from the total hydrocarbon feed into CO 2 +CO and pure CO when pipeline pressure is high 2 This extraction of carbon as fuel similarly has the advantage of meeting climate change emissions targets.

[0071] CO 2 The integration of a high pressure, two reactor hydrogen generation system with a power production cycle utilizing the working stream can achieve various benefits. The turbine exhaust from the power production cycle is typically in the range of about 700°C to about 800°C. The steam and hydrocarbon feed to the two reactors can be preheated to the range of about 500°C to about 550°C utilizing a portion of the turbine exhaust flow in a separate heat exchanger. This simply requires an increase in fuel to be burned in the turbine combustor, requiring more heat than necessary. This increase raises the turbine inlet temperature and flow rate, providing significant additional power output from the turbine. The turbine exhaust can be cooled to a typical temperature of about 700°C to about 800°C before entering the recuperative heat exchanger, while the steam and hydrocarbon or carbonaceous fuel can be heated to a typical temperature of about 400°C to about 550°C.

[0072] As an alternative arrangement, a second combustor may be provided to preheat at least a portion of the turbine exhaust stream and deliver the heat required to preheat the fuel and steam required for the generation of synthesis gas in the two-stage reactor system. 2 Diluted with virtually pure O 2 An oxidizing agent containing 20% ​​to 30% molar O 2The second combustor arrangement produces an oxidizer containing H 2 and adding substantially pure O2 from a preheated low pressure air stream to at least a portion of the turbine exhaust to which a regulated portion of the fuel has been added to raise the temperature as required by the plant preheat conditions. 2 Diffuse O 2 An ion transport membrane reactor is used.

[0073] The waste gas from the PSA is typically compressed to about 200 bar to about 400 bar, mixed with the feed hydrocarbons and can be used very effectively as fuel gas in the power production cycle. Carbon from the hydrocarbon reactor feed is converted into CO in the power production cycle system. 2 Another advantage is that it can be recovered as CO + CO, typically at a high concentration of about 50% to about 70% (mol). 2 A further advantage is that the mass flow of the waste gas is high due to its content, allowing additional turbine power to be generated. Alternatively, the waste gas from the PSA can be compressed to the inlet pressure of the first PSA and the CO 2 can be removed by one of many known processes, CO 2 The depleted gas stream is sent to a second PSA to produce more H 2 Separate and separate total H 2 It can be added to the production stream. In some cases, the waste gas can be preheated in an economizer heat exchanger and steam can be added to produce more H 2 can be produced in an additional catalytic CO shift reactor. The gas is then converted to more H in the second PSA. 2 The refrigerant may be cooled in an economizer heat exchanger before being processed to separate the refrigerant.

[0074] Cooling H 2 The significant amount of low grade heat available from the +CO stream provides low temperature level heat that can be added to the power production cycle and is ideally suited to increase heat recovery from the turbine exhaust, thereby achieving high efficiency. 2 The "low" heat from the +CO stream may be at a temperature level of about 200°C to about 400°C, about 220°C to about 350°C, particularly about 240°C to about 290°C.2 Depending on the output, this could be the main air compressor of the power production cycle oxygen plant, which is a conventional intercooled compressor, rather than an insulated section, where the reduction in parasitic power in the power production cycle is significant. It would be a hot CO2 compressor, with further reduction in parasitic power. 2 The availability of this extra heat over the temperature range mentioned above (down to near ambient) will allow for the use of high pressure recirculated CO2 over a similar temperature range. 2 The defined integrated system is equally applicable to power production cycles utilizing conventional cryogenic oxygen production and the addition of an oxy-fuel combustor, or to systems utilizing an oxy-ion combustor.

[0075] The integrated power and hydrogen production according to the present disclosure is described below in conjunction with the various figures. In particular, Figure 1 illustrates a power production cycle system having a cryogenic oxygen plant and using natural gas fuel. The system is described below in conjunction with operating parameters corresponding to an exemplary embodiment, however, it should be understood that the power production cycle may be as otherwise defined herein. Additionally, the power production cycle may incorporate components and / or operating parameters as otherwise described in U.S. Pat. No. 9,068,743 to Palmer et al., U.S. Pat. No. 9,062,608 to Allam et al., U.S. Pat. No. 8,986,002 to Palmer et al., U.S. Pat. No. 8,959,887 to Allam et al., U.S. Pat. No. 8,869,889 to Palmer et al., U.S. Pat. No. 8,776,532 to Allam et al., and U.S. Pat. No. 8,596,075 to Allam et al., the disclosures of which are incorporated herein by reference.

[0076] In one or more embodiments, the power production cycle according to the present disclosure includes 2 In particular, in some embodiments, the CO2 can transition between supercritical and liquid and / or gaseous states, whereas CO 2 may be supercritical through at least some of these stages. In various embodiments, a power production cycle that can improve efficiency includes: ·Recirculating CO 2 combusting a carbonaceous fuel with an oxidizer in the presence of the stream to provide a combustion product stream at a temperature of at least about 500° C. or at least about 700° C. (e.g., from about 500° C. to about 2000° C. or from about 600° C. to about 1500° C.) and a pressure of at least about 100 bar (10 MPa) or at least about 200 bar (20 MPa) (e.g., from about 100 bar (10 MPa) to about 500 bar (50 MPa) or from about 150 bar (15 MPa) to about 400 bar (40 MPa)); High pressure recirculating CO into the turbine for power production 2 expanding the stream (e.g., to a pressure as mentioned above); High temperature recirculated CO, especially at the turbine discharge 2 cooling the stream (e.g., pressure as mentioned above) in a recuperative heat exchanger; - condensing one or more combustion products (e.g. water) present in the expanded and cooled combustion product stream, in particular in a recuperative heat exchanger and an ambient temperature cooler, Water and / or CO 2 Separating and recycling different substances from CO 2 forming a stream; Recirculating CO, possibly in multiple stages with intermediate cooling 2 compressing the stream to a high pressure (e.g., the pressures mentioned above) to thicken the stream; In the recuperator, compressed recirculated CO 2 heating the stream, particularly against a cooled turbine exhaust stream; and In some cases, recirculated CO in addition to heat recovery from the cooled turbine exhaust stream 2 adding heat to the stream, the heat being from another source, such as low grade heat obtained from a hydrogen production system or hydrogen producer as described herein; may include a combination of:

[0077] With more particular reference to FIG. 1, an electrical power production unit suitable for combination with a hydrogen production unit is illustrated. It should be understood that the electrical power production unit is intended to encompass any combination of individual components that, when operated together, are effective in producing electrical power, and thus is intended to be synonymous with an electrical power production system. Similarly, it should be understood that the hydrogen production unit is intended to encompass any combination of individual components that, when operated together, are effective in producing hydrogen, and thus is intended to be synonymous with a hydrogen production system. Although the illustrated electrical power production unit is described in relation to specific operating parameters, it should be understood that the electrical power production unit can be operated over a range of parameters consistent with the entire disclosure herein. In the electrical power production unit illustrated in FIG. 1, 304 bar of CO2 heated to 715° C. in heat exchanger 101 is heated to 715° C. in heat exchanger 102. 2 Stream 107 enters combustor 102 where it is mixed with combustion products from methane stream 112 compressed to 305 bar (251° C.) in compressor 105 driven by electric motor 106 to produce a mixture of about 25% oxygen and about 75% CO 2 and is burned in oxidant stream 108 which is heated to 715° C. in heat exchanger 101. The resulting mixed stream 110 enters turbine 103 at 1150° C. and 300 bar, expands to 30 bar and 725° C., and exits as stream 109 to generate electricity in generator 104. The 30 bar stream is cooled in heat exchanger 101 and converts the heat into high pressure CO 2 The stream is cooled further in a direct contact water cooler 115, which includes a packing section 114 and a circulating water section with a pump 116 and an indirect chilled water heat exchanger 117 directing water streams 119, 120, and 121 to the top of the packing section. 4 Excess liquid water produced from the combustion, stream 118, is removed from the bottom of the water cooler 115. Substantially pure CO 2 The cooling stream 122 of substantially pure CO is split into multiple streams. 2A first portion 123 of stream 122 is a net CO2 that is discharged for external or other use. 2 The product stream 161 and the dilution stream 163 are mixed with a 29 bar combustor oxygen flow 150 to form a combustor oxidant stream 151 containing 25% (molar) oxygen. 2 The main part of the 124 is a two-stage internally cooled CO 2 The CO enters the compressor (comprising a first compressor stage 159, an intercooler 160, and a second compressor stage 125) where it is compressed to 67.5 bar and exits as stream 162. 2 The stream is substantially pure and contains less than 3 mol%, less than 2 mol%, less than 1 mol%, less than 0.5 mol%, less than 0.1 mol%, or less than 0.01 mol% impurities.

[0078] The power production cycle is carried out at a temperature level below 400°C using high pressure CO 2 This requires a significant amount of additional heat to be provided to the stream. In the embodiment illustrated here, the heat comes from two sources that provide the heat of compression. The first source is an adiabatically compressed cryogenic oxygen plant supply air stream 142 at 5.6 bar and 226°C from air compressor 140 driven by electric motor 141 which compresses air stream 139. The second source is 29.3 bar of CO taken from heat exchanger 101 at a temperature of 135°C and adiabatically compressed in compressor 136 to produce stream 137 at 226°C. 2 These two streams are the 304 bar CO2 stream 135 split from the discharge stream 130 taken directly from the multi-stage pump 129. 2 The additional heat from the additional heat exchanger 134 converts the CO from 50° C. in stream 131 to 221° C. in stream 133. 2 Increase the temperature of the cooled CO 2 Flow 138 and CO 2 The recirculated compressor discharge stream 162 is combined and cooled in the cooling water heat exchanger 126 to produce a CO2 Total CO producing recycle stream 128 2 Forming stream 127. High density CO 2 This stream of liquid is compressed to 305 bar in multi-stage pump 129. The discharge stream 130 at 50°C is split into a main portion 132 which enters recuperative heat exchanger 101 and a minor portion 131 which is heated in heat exchanger 134 against the cooling of adiabatic compressed streams 137 and 142 to 221°C to produce stream 133 as mentioned above. Stream 133 is converted in heat exchanger 101 to high pressure CO 2 The recirculated CO 2 is then recombined with the main portion of the flow 132. In this manner, in order to achieve a high level of operating efficiency, 2 The side stream 179 provides additional heating (i.e., in addition to the heat recuperated from the turbine discharge stream 109). 2 A major portion 132 of the flow can be taken and directed to the turbine 103 as turbine blade cooling flow.

[0079] The cooled air stream 143 at 56°C enters a cryogenic air separation system that includes an air cleaning section 144 with a direct contact air cooler, a water chiller, and a switched dual bed thermally regenerated adsorption section to produce dry CO from the air at 5.6 bar and 12°C. 2 A portion of this air (stream 145) is compressed to 70 bar in compressor 146 driven by electric motor 178, and air streams 148 and 147 enter pumped liquid oxygen cycle air separation and refrigeration system 149. The products from the air separator are waste nitrogen stream 164 and 30 bar product oxygen stream 150, which is converted to direct contact CO 2 CO leaving the cooler 115 2 The oxidant stream 151 is mixed with a cooled portion of the dilution stream (dilution stream 163) to produce the oxidant stream 151. The oxidant stream 151 is 2 / O 2In the compression mechanism, the oxidant stream 151 is compressed to 304 bar. Specifically, oxidant stream 151 is compressed in compressor 152 driven by electric motor 153, exits as stream 155, is cooled in intercooler 154, exits as stream 156, and is further compressed in pump 157. The resulting compressed oxidant stream 158 is heated to 715° C. in heat exchanger 101, exits as stream 108, and enters combustor 102.

[0080] The power production cycle requires a separate cryogenic air separation plant to produce oxygen, which is typically preheated to above 700 °C at a regulated concentration of about 20% to about 30% molar CO 2 must be delivered to the combustor diluted with 2 / CO 2 This requires a compressor mechanism or a more complex cryogenic air separation plant with significantly higher power consumption. 4 The fuel 111 is compressed to 305 bar in the high pressure compressor 105 as discussed above.

[0081] The integration of a hydrogen plant with an electricity production cycle system (fueled with natural gas in the illustrated embodiment) is shown in Figure 2. The system is powered by 99.5% pure O2 at 270°C, both at a pressure of 85 bar. 2 The POX reactor 201 has a feed stream 221 of 1,000 sq. m. and a natural gas stream 246 at 500° C. The POX reactor 201 produces a product H 2 +CO stream 222 (which may be optionally quenched and cooled to 1350° C. by the addition of saturated steam stream 223), and 2 +CO stream 222 enters the bottom 203 of the gas heated reforming (GHR) reactor 202. 2 +CO stream 222 is the reformed H 2 +CO product stream, total product CO+H 2The stream passes up the shell side providing heat for the endothermic reforming reaction and exits as stream 224 at 600°C. The tubes are free to expand downward at operating temperature, with negligible pressure differentials at the hot end and therefore stresses on the tube walls. The tubes as well as exposed metal parts are fabricated from alloys such as INCONEL® 693, which are resistant to metal dusting corrosion caused by the Boudouard reaction which precipitates carbon. Additionally, the metal surfaces can be further protected with an alumina coating.

[0082] Stream 224 is cooled by passing through waste heat boiler 236 and exits as product gas stream 254 at 320° C. Product gas stream 254 passes through two catalyst loaded CO shift reactors 207 and 208 in series. Exit streams 226 and 228 enter shift stream heat recovery heat exchangers 209 and 210 where heat is used to preheat the boiler feed water and the natural gas stream. Specifically, stream 226 exiting CO shift reactor 207 passes through shift stream heat exchanger 209 and exits as stream 227 and enters CO shift reactor 208. Stream 228 exiting CO shift reactor 208 passes through water cooler 235 and through shift stream heat exchanger 210 before exiting as stream 229. Boiler feed water streams 256 and 257 are heated in shift stream heat exchangers 210 and 209, respectively, to provide warm water stream 258. Natural gas streams 241 and 242 are heated in shift stream heat exchangers 210 and 209, respectively, to provide natural gas stream 243 at 290° C. Boiler feed water stream 258 is split into waste heat boiler feed stream 260 and surplus stream 259 at 290° C., which is cooled to 60° C. in heat exchanger 134 (see FIG. 1 ) and has its heat transferred to the recycle high pressure CO2 for the power production cycle. 2 The mixture is discharged into a part of the streams 131 to 133 (see FIG. 1).

[0083] Crude H exiting heat exchanger 210 2 Stream 271 (water vapor and traces of CO, CH 4 , N 2 , and CO from the combustion of carbon from the hydrocarbon or carbonaceous feed, along with Ar. 2The resulting water (containing substantially all of the above) is cooled to about ambient temperature in water chiller 235. Condensate is separated from stream 229 in separator 212. Water stream 262 leaving separator 212 and cooling water stream 253 leaving heat exchanger 134 enter water treatment section 214 which produces purified water 255 and excess water stream 261. Purified water 255 serves as the boiler feed water stream and is pumped by pump 213 to a pressure of about 87 bar. Pressurized boiler feed water stream 256 leaving pump 213 enters heat exchanger 210.

[0084] Waste heat boiler feed stream 260 is heated in waste heat boiler 236 and exits as saturated steam stream 249, which is split into steam stream 250 and quench stream 223. Saturated steam stream 250 and preheated natural gas stream 243, both at 290° C., enter auxiliary heat exchanger 237 where they are heated to 500° C. against stream 247, which corresponds to turbine exhaust stream 109 in FIG. 1. Exit stream 248 enters recuperative heat exchanger 101 (in the power production section of FIG. 1) at approximately 725° C. In this case, the inlet temperature of turbine 103 in the power production section of FIG. 1 is increased, providing the necessary heat transferred in heat exchanger 237, and the power output of the turbine is increased. Thus, auxiliary heat exchanger 237 is configured to provide supplemental heating to saturated steam stream 250 and natural gas stream 243, which supplemental heating is provided by streams from the power production section.

[0085] Hot natural gas stream 244 exiting heat exchanger 237 is split between providing a 500° C. feed to POX reactor 201 as stream 246 and to GHR reactor 202 as stream 245, which is mixed with steam stream 251 to form total GHR feed stream 252. Total GHR feed stream 252 fed to GHR reactor 202 provides, in this case, a 6:1 steam to carbon ratio (carbon combined with hydrogen in the GHR reactor feed). This high ratio results in a high total product H 2 +CO stream 224 with a small amount of unconverted methane and H 2 + Allow the CO product pressure to reach 80 bar.

[0086] The crude hydrogen product stream 230 exiting the water separator 212 contains 88% of the hydrogen present in stream 230 and has an impurity level of 50 ppm and is substantially pure H 2 It then passes through a multi-bed pressure swing adsorption section 215 which produces a product stream 239. Thus, substantially pure H 2 The product stream may contain less than 500 ppm impurities, less than 250 ppm impurities, less than 100 ppm impurities, or less than 75 ppm impurities (e.g., down to an impurity content of 0). 2 In addition, CO, H 2 , C.H. 4 , Argon, N 2 A 1.2 bar pressure waste stream 232, containing various inclusions such as sulphur dioxide and traces of water vapour, is compressed to 30 bar in compressor 216 driven by electric motor 219 and exits as stream 238. Discharge stream 238 is cooled to near ambient temperature in cooler 217 and added as part of inlet stream 111 (see FIG. 1) to the power production system's natural gas compressor 105 (see FIG. 1). The 320 bar compressor discharge stream 112 (see FIG. 1) provides feed to the power production section's combustor 102 (see FIG. 1). An 85 bar natural gas feed stream 241 can also be produced from a separate natural gas compressor stage that is part of compressor 105 in FIG. 1.

[0087] performance Both are pure CH 4 or 246,151 Nm with a power production cycle system having a natural gas feed and producing 290.3 MW of power; 3 The integration of a hydrogen production section operating at 1000 rpm / hr results in the following calculated performance data: H 2 is produced at a total impurity level of 50 ppm and a pressure of 74 bar. Power production from integrated system = 234.23 MW. CH for hydrogen production 4 =92,851.2Nm 3 / hour (equivalent to 923.2 Mw). 43,773.9Nm 3 / hour (equivalent to 435.2 Mw) of electricity production CH 4 . CH to hydrogen plants and power plants 4 CO of carbon from the feed 2 The take-out rate as such is 100%. CO from integrated systems 2 Production was 6,437.1 MT / D. CO 2 is generated at a pressure of 150 bar.

[0088] In the systems and methods as described herein, the use of substantially pure oxygen in the combustor can have the concomitant benefit of providing large quantities of substantially pure nitrogen. Nitrogen can be provided at relatively high pressure directly from an air separation section, which may be associated with a power production section, to provide the required stream of substantially pure oxygen. At least a portion of this nitrogen can be mixed with hydrogen, which may be produced as described herein. The end product is H2O suitable for use in a conventional gas turbine combined cycle power generation system. 2 +N 2 This is illustrated in Figure 3, where nitrogen gas 160 from the air separation section (see Figure 1) and hydrogen gas 239 from the hydrogen production facility (see Figure 2) are input to a gas turbine combined cycle section 300.

[0089] H 2 +N 2 The fuel gas may be utilized in any gas turbine combined cycle power generation system. Known systems may otherwise use CO 2may be modified as necessary to remove, discontinue, or otherwise abandon the use of components that would be required for the removal of the Known gas turbine combined cycle power generation systems that may be utilized in accordance with the present disclosure are described in U.S. Pat. No. 8,726,628 to Wichmann et al., U.S. Pat. No. 8,671,688 to Rogers et al., U.S. Pat. No. 8,375,723 to Benz et al., U.S. Pat. No. 7,950,239 to Lilley et al., U.S. Pat. No. 7,908,842 to Eroglu et al., U.S. Pat. No. 7,611,676 to Inage et al., U.S. Pat. No. 7,574,855 to Benz et al., U.S. Pat. No. 7,089,727 to Schutz, U.S. Pat. No. 6,966,171 to Agematsu et al., and U.S. Pat. No. 6,474,069 to Smith, the disclosures of which are incorporated herein by reference.

[0090] The present disclosure provides a combination of systems, which 2 The combination of the system, in which hydrogen and nitrogen gases are provided from a combustion power system that burns a hydrocarbon fuel, with substantially no atmospheric emissions of CO2, offers distinct advantages over conventional operation of gas turbine combined cycle systems. In particular, the combination of the system of the present invention eliminates the natural gas fuel normally required for the gas turbine and reduces the amount of CO2 emitted during combustion. 2 Thus, in some embodiments, the present disclosure provides a method for replacing 1) an oxygen-based hydrogen producer; 2) a fuel that does not generate CO 2 The combined system provides a combination of a power generation section that recovers substantially all of the CO2 emissions from the turbine and a conventional gas turbine combined cycle power generation section that provides additional power generation. The combined system as described herein provides surprisingly high efficiency, low cost power generation, and nearly 100% CO2 emissions. 2 Therefore, the result is approximately 100% CO 2 and 100% CO 2This represents a heretofore unknown approach to providing natural gas fired power production at operating costs below the costs of known power production methods that do not provide capture.

[0091] The combination of systems can be implemented in a variety of ways. In some embodiments, existing combined cycle power stations use all CO 2 It can be converted to increase power generation capacity while eliminating emissions. 2 Production of electricity and H using circulating fluids 2 +N 2 It may include the addition of other system components as described herein for the production of fuel gas.

[0092] performance The performance calculations for the combined system as described above may be based on a GE PG9371(FB) gas turbine cogeneration system designed to produce 432.25 Mw of power at ISO conditions. 100% CO 2 Recovery, H 2 generation, N 2 Generation of H in gas turbines 2 +N 2 Considering a combination of natural gas fired power producers with combustion of fuel gas, values ​​calculated according to embodiments of the present disclosure are provided below. The total net electricity production from the combined system is 697Mw. The fuel for the gas turbine is 50% H 2 +50%N 2 Assume that (moles). The total methane feed is 1,368.6 Mw (LHV). The required oxygen is 4979 MT / day. CO produced at 150 bar pressure 2 is 6,437Mt / day. The overall efficiency is 50.9% (LHV standard).

[0093] Many modifications and other embodiments of the subject matter disclosed herein will come to mind to one skilled in the art having the benefit of the teachings presented in the foregoing descriptions and the accompanying drawings. It is to be understood, therefore, that the disclosure is not limited to the specific embodiments described herein, and that modifications and other embodiments are intended to be included within the scope of the appended claims. Although specific terms are employed in the specification, they are used in a generic and descriptive sense only and not for purposes of limitation.

Claims

1. 1. A method for combined power and hydrogen production, the method comprising: Producing electricity in a power producing section including a combustor, a turbine, at least one power producing section heat exchanger, and a compressor, wherein a working fluid is circulated through the combustor, the turbine, the at least one power producing section heat exchanger, and the compressor; Producing hydrogen in a hydrogen production section comprising a partial oxidation combustor, a reformer, a shift reactor, at least one hydrogen production section heat exchanger, and a pressure swing adsorption section; Equipped with The method of claim 1, wherein at least one stream of compressed working fluid in the power production section is heated in a heat exchanger in contact with at least one heated stream from the hydrogen production section.

2. The method of claim 1 , wherein producing the electrical power includes using heat extracted from a flow exiting the turbine to heat a recirculation flow exiting the combustor prior to passage into the combustor.

3. The method of claim 1 , wherein excess heat extracted from the hydrogen production section is formed at least in part during processing of syngas from the partial oxidation combustor.

4. The method of claim 3 , wherein processing the synthesis gas is configured to provide a substantially pure hydrogen stream and a waste stream comprising at least carbon dioxide.

5. The method of claim 4 , wherein processing the synthesis gas comprises processing in one or more shift reactors.

6. The method of claim 4 further comprising passing at least the carbon dioxide from the waste stream to a combustor of the power producing section.

7. 4. The method of claim 3, wherein processing the syngas comprises passing the syngas through a reformer that is also configured to receive a fuel stream and a hot water stream.

8. The method of claim 1 , wherein at least one stream in the hydrogen producing section is heated using heat transferred from a stream exiting a turbine of the power producing section.

9. 10. The method of claim 8, wherein at least one stream within the hydrogen producing section to be heated comprises one or more of a fuel stream for use in the partial oxidation combustor, a fuel stream for use by the reformer, and a water stream for use by the reformer.

10. 10. The method of claim 1, wherein the at least one hydrogen production section heat exchanger comprises a shift stream heat exchanger arranged to draw heat from a stream exiting the shift reactor.

11. 11. The method of claim 10, wherein heat in the shift stream heat exchanger is transferred to one or more of fuel for use in the partial oxidation combustor, fuel for use by the reformer, and water for use by the reformer.

12. The method of claim 1 , wherein the pressure swing adsorption section is configured to produce a substantially pure hydrogen stream and a waste stream.

13. The method of claim 12 , further comprising passing at least a portion of the waste stream to a combustor of the power producing section.

14. The method of claim 1 , wherein the power production section comprises a second combustor.

15. 15. The method of claim 14, wherein at least a portion of the flow exiting a turbine of the power producing section is passed through the second combustor along with the fuel flow and the oxidant flow such that fuel is combusted to provide additional heat to at least a portion of the flow exiting the turbine.

16. The method of claim 15 , wherein at least a portion of the additional heat is used to heat one or more streams in the hydrogen producing section.

17. 2. The method of claim 1, wherein the excess heat extracted from the hydrogen producing section is at a temperature level below 400°C.

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