Systems and methods for integrating waste heat and blue hydrogen production

Abstract

An integrated hydrogen production (IHP) system including a steam-methane reformer system configured to generate hydrogen via a steam-methane reaction. The steam-methane reformer system is oriented to receive a flue flow from a flue flow source and to use thermal energy from the flue flow in the steam-methane reaction. The system includes a post carbon capture system for capturing carbon from the flue flow discharged from the steam-methane reformer.

Description

SYSTEMS AND METHODS FOR INTEGRATING WASTE HEATAND BLUE HYDROGEN PRODUCTIONTECHNICAL FIELD[1] The field of the disclosure relates generally to hydrogen production and more particularly, to systems and methods for hydrogen production using flue gases recovered from a gas turbine engine.BACKGROUND[2] It is known to produce hydrogen using a steam-methane reformer in which natural gas and steam are reacted to produce hydrogen as well as carbon dioxide as a by-product. Blue hydrogen production refers to the production of hydrogen, using the steam- methane reformer, while capturing and storing the carbon dioxide by-product. Hydrogen production is an endothermic reaction that requires a substantial amount of heat to be supplied to the steam-methane reformer to enable the reaction to take place. C onventionally, the thermal energy is supplied by arch burners, which require a supply of fuel and produce carbon dioxide, and as such, hydrogen production is a relatively inefficient process.[3] Accordingly, a need exists for improved systems and methods for producing hydrogen which overcome the limitations described above.SUMMARY[4] In one aspect, an integrated hydrogen production (IHP) system is provided. The system includes a steam-methane reformer system configured to generate hydrogen via a steam-methane reaction. The steam-methane reformer system is oriented to receive a flue flow from a flue flow source and to use thermal energy from the flue flow? in the steam-methane reaction. The system further includes a post carbon capture system for capturing carbon from the flue flow discharged from the steam-methane reformer.[5] In another aspect, a powder generation integration system is provided. The system includes a gas turbine engine including a turbine exhausting a flue flow and an integration system. The integration system includes a steam-methane reformer systemconfigured to generate hydrogen via a steam-methane reaction, the steam-methane reformer system is oriented to receive the flue flow and to use thermal energy’ from the flue flow in the steam-methane reaction; and a post carbon capture system for capturing carbon from the flue flow discharged from the steam-methane reformer.[6] In another aspect, a method of operating a hydrogen production integration system is provided. The method includes supplying flue flow to a steam-methane reformer system. The flue flow supplies thermal energy to a steam-methane reaction within the steam-methane reformer system. The method further includes supplying the flue flow to a carbon capture system and capturing carbon from the flue flow, after the flue flow supplied thermal energy to the steam-methane reaction.BRIEF DESCRIPTION OF THE DRAWINGS[7] These and other features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying drawings in which like characters represent like parts throughout the drawings, wherein:[8] FIG. 1 is a schematic illustration of an exemplary integrated hydrogen production system.[9] FIG. 2 is a schematic illustration of an alternative integrated hydrogen production system.

[0010] FIG. 3 is a schematic illustration of yet another alternative integrated hydrogen production system.

[0011] FIG. 4 is a flow chart of an exemplary method of operating an integrated hydrogen production system for use with any of the integrated hydrogen production systems shown in FIGs.1-3.

[0012] Unless otherwise indicated, the drawings provided herein are meant to illustrate features of embodiments of the disclosure. These features are believed to be applicable in a wide variety7of systems comprising one or more embodiments of the disclosure. As such, the drawings are not meant to include all conventional features knownby those of ordinary skill in the art to be required for the practice of the embodiments disclosed herein.DETAILED DESCRIPTION

[0013] In the following specification and the claims, reference will be made to a number of terms, which shall be defined to have the following meanings. The singular forms “a,” ‘"an,” and “the” include plural references unless the context clearly dictates otherwise. “Optional” or “optionally” means that the subsequently described event or circumstance may or may not occur, and that the description includes instances where the event occurs and instances where it does not. Furthermore, references to “one embodiment” are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features. Moreover, unless explicitly stated to the contrary, embodiments “including” additional of such elements, but not having that properly7.

[0014] As used herein, the term “real-time” refers to either the time of occurrence of the associated events, the time of measurement and collection of predetermined data, the time to process the data, or the time of a system response to the events and the environment. In the embodiments described herein, these activities and events occur substantially instantaneously.

[0015] Embodiments described herein include an integrated hydrogen production system that uses flue gases, e.g., a flue flow discharged from a gas turbine engine, to supply thermal energy to an endothermic reaction and / or catalyst elements within a steam- methane reformer to produce hydrogen (EL). Because at least a portion of the required thermal energy for the endothermic reaction and / or preheating is supplied by the flue flow, an amount of supplemental thermal energy7, and / or additional fuel, necessary7to be supplied by process burners is facilitated to be greatly reduced, thus improving an overall efficiency of hydrogen production. In some embodiments described herein, the integrated hydrogen production system also includes a carbon capture system that is downstream from the steam- methane reformer and from the flue flow such that carbon dioxide (CO2) generated within the reformer and / or entrained in the flue flow7or burner exhaust, is captured. As such, a need for two separate carbon captures systems, e.g., a first for the flue flow and a second for the steam-methane reformer, is eliminated. In some embodiments, the stream of CO2 exhaustedfrom the combined gas turbine flue flow and steam-methane reformer has a higher resulting concentration, facilitating capturing of the CO2, thus reducing the size, e.g., capacity or footprint, of the carbon capture system.

[0016] In some embodiments described herein, the integrated hydrogen production system produces one or more by-products, in addition to hydrogen, which may be utilized in auxiliary or supplementary processes. For example, in some embodiments, the integrated hydrogen production system may produce methanol (CH3OH). In another example embodiment, the integrated hydrogen production system may produce Ammonia (NH3). Moreover, in some embodiments, the integrated hydrogen production system includes an auxiliary turbine that produces auxiliary power using excess steam produced by a boiler associated with the carbon capture system. In some embodiments, the auxiliary turbine and the steam-methane reformer may both receive steam produced by the boiler of the carbon capture system.

[0017] Referring now to the drawings, FIG. 1 is a schematic illustration of an exemplary integrated hydrogen production (IHP) system 100 that may be used to produce hydrogen (e.g., H2) 102. In the exemplar}' embodiment, the IHP system 100 includes a hydrogen production system 104 including a steam-methane reformer (SMR) system 106, and a hydrogen cleaning and post processing (HCPP) system 108. The IHP system, in the exemplary embodiment, also includes a post carbon capture (PCC) system 110 used to capture carbon (C) or carbon dioxide (CO2). During use, within the SMR system 106, methane reacts with steam to produce hydrogen via an endothermic reaction. More specifically, the reaction in the SMR system 106 requires a significant amount of thermal energy, referred to herein as the required SMR thermal energy. As will be described in additional detail herein, because the IHP system 100 uses waste heat, recovered from a flue flow 112 (e.g., hot exhaust gases), to supply at least a portion of the required SMR thermal energy', the IHP system 100 facilitates producing hydrogen with improved efficiency.

[0018] In the exemplary' embodiment, the SMR system 106 includes at least one first inlet 130 for receiving fuel 132, such as natural gas or methane (CH4), from a fuel source 134. The natural gas may be primarily composed of methane. In some other embodiments, alternative fuels, e.g., propane or ethanol, and / or alternative catalysts may be used. The SMR system 106 also includes at least one second inlet 136 for receiving waterand / or steam 138, and at least a third inlet 140 for receiving the flue flow 1 12. Within the SMR system 106, the steam reacts with the methane to create hydrogen, carbon monoxide (CO), and a relatively small amount of carbon dioxide (CO2). In some embodiments, the steam reacts with the methane in the presence of a catalyst, such as, but not limited to Cu, Pd, Ru, Ni, Zn, and / or any combination thereof. Moreover, the SMR system 106 also includes at least a first outlet 142 for releasing and / or discharging pre-hydrogen, e.g., a hydrogen mixture 144, composed of at least hydrogen and one or more other by-products and / or impurities. In some embodiments, the SMR system 106 is sized, e.g., capacity and / or volume of produced hydrogen, based on the flue flow source, e.g., the mode and / or capacity of the gas turbine engine 162. In some embodiments, the SMR system 106 may be retrofit onto, in fluid connection with, a pre-existing gas turbine engine.

[0019] In some embodiments, the SMR system 106 may include heat exchanging rods (not shown), e g., tubes, pipes, ducts, etc., to facilitate enhanced thermal energy transfer from the flue flow 112 to the mixture of steam and methane contained in the heat exchanging rods. In some embodiments, the rods may be positioned within a transition duct that is positioned to receive flue flow 112, e.g., the transition duct is positioned downstream from the gas turbine engine 162. The fuel 132 and / or steam, or mixture thereof, may flow through the rods and the hot flue flow 112 flows through the transition duct in a crossflow direction relative to the rods. Thermal energy is transferred through the rod walls from the flue flow 112 to the fuel and / or steam mixture contained in the rods. Heat may be transferred from the flue flow 1 12 to the SMR system 106 using any suitable heat exchanging components enabling the system 100 to function as described herein.

[0020] In some embodiments, the SMR system 106 includes one or more primary burners 150 used to supply supplemental thermal energy to the steam-methane reaction. The burners 150 may each include at least one first inlet 152 for receiving fuel, e.g., fuel 132, such as natural gas, and at least one second inlet 154 for receiving air 156. The burners 150 may bum different or alternative fuel. The fuel and / or the air may be combusted in the bumer(s) 150 to generate supplemental thermal energy while also producing exhaust gases 158. In some embodiments described herein, the majority of the required SMR thermal energy is supplied by the flue flow 112 as compared to an amount of thermal energy supplied by the primary burners 150. In some embodiments, greater thanabout 60% of the required SMR thermal energy is supplied by the flue flow 1 12. In other embodiments, at least about 90% of the required SMR thermal energy is supplied by the flue flow 112. In some embodiments, the required SMR thermal energy is all supplied by the flue flow 112 and the burners 150 may be shutoff, and / or fuel 132 is not delivered to the bumer(s) 150.

[0021] In some embodiments, the IHP system 100 may receive a flue flow 112 discharged from an outlet 160 of a gas turbine engine 162. The gas turbine engine 162 may ignite amixture of received fuel, e.g., such as fuel 132 from the fuel source 134, and air 156, to generate a primary power output Pi. The pnmary power output Pi may be between 45 MW and 600 MW. In some embodiments, the primary' power output Pi is approximately 80 MW. In some embodiments, the flue flow 112 may be discharged from an aeroderivative turbine and the primary' power output Pi may be approximately 33 MW.

[0022] In some embodiments, the flue flow 112, e.g., discharged from the gas turbine engine 162, may have a temperature in excess of about 600°C, about 600°C, and / or between 550-750°C. In some embodiments, the flue flow 1 12, e.g.. discharged from the gas turbine engine 162, may have a temperature in the range of 300-750°C, in the range of 300- 500°C, or in the range of 200-400°C. In some embodiments, the temperature of the flue flow 112 may be selectively varied and the temperature of the flue flow 112 may be dependent and / or related to the generated primary power output Pi. In some embodiments, the fuel source 134 may deliver fuel 132 to a combustor (not shown) of the gas turbine engine 162. In some other embodiments, any suitable fuel source may supply fuel to the gas turbine engine 162. In other embodiments, the IHP system 100 may receive hot exhaust gases discharged from any other suitable source or combustion process. In some embodiments, the IHP system 100 includes a supplemental turbine 170 for generating supplemental power P2 from the steam 138. For example, excess high-pressure steam may be generated by a boiler, above SMR system 106 thermal requirements for pre-feed heating, processing, and / or steam-methane reaction or catalyst elements, and the excess steam used to drive the supplemental steam turbine 170 with steam extracted from the steam 138 that is being routed to the CO2 capture amine regeneration, e g., in the PCC system 1 10. For example, the supplemental turbine 170 is downstream from the PCC system 110, and the supplemental turbine 170 receives at least a portion of the steam 138. For example, in some embodiments,the steam turbine 170 is positioned upstream of the PCC 1 10. The PCC 1 10 receives high pressure / high temp steam from a boiler and delivers low pressure / low temperature steam to PCC 110. The supplemental power output P2 generated may be between 10 MW and 500 MW. In some embodiments, the supplemental output power P2 is approximately 30 MW. The produced supplemental power may be used for any suitable process requiring power, e.g., at least one component of the PCC 110 requiring power, at least one component of the HCPP 108 requiring power, CO2 compression, H2 compression, and / or the power may be exported to the grid. The HCPP system 108 includes a water-gas shift reaction (WGSR) system 172, a condenser 174, and a separating system 176. The separation system 176 may be a pressure swing absorber, a membrane system, a cryogenic system, and / or a nitrogen separation system. In WGSR system 172, carbon monoxide and steam are reacted using a catalyst (same comment as above) to produce carbon dioxide and more hydrogen. In Separating system 176 carbon dioxide and other impurities are removed from the gas stream, leaving pure hydrogen 102. As described above, the SMR system 106 produces a mixture of hydrogen, carbon monoxide, and / or a small amount of carbon dioxide, which is delivered to HCPP system 108. The hydrogen mixture 144 may be initially delivered to the WGSR system 172 where the carbon monoxide is reacted with steam to produce carbon dioxide and additional hydrogen, e.g., hydrogen that is produced in addition to the hydrogen produced by the SMR system 106. The WGSR system 172 may use a catalyst(s) to facilitate the reaction therein.

[0023] The condenser 174, downstream from the WGSR system 172, separates at least a portion of the water contained within the mixture received from the WGSR system 172. The remaining mixture is then channeled to the separating system 176 which purifies the hydrogen. In some embodiments, the separating system 176 may use alternating pressure, and / or partial pressure, to facilitate separating the hydrogen (e.g.. pure H2) from other gases and / or contaminates entrained in the mixture. In some alternative embodiments, the Separating system 176 may be integrated with the PCC system 110 to enable the other gases separated from the hydrogen to be captured and stored. The HCPP system 108 may also include additional and / or alternative components that enable the IHP system 100 to post-process the hydrogen mixture 144 discharged from the SMR system 106. In some embodiments, the HCPP system 108 may include a first outlet 177 for releasing hydrogen 102 and a second outlet 178 for releasing a tail gas 180 generated during the post-process. In some embodiments, the tail gas 180 is delivered to the SMR system 106, e.g., via the inlet(s) 152. In some embodiments, the tail gas 180 is composed of N2 and / or H2.

[0024] In some embodiments, fluids (e.g.. liquids and / or gases) of system 100, e.g., fuel, water, steam, air, hydrogen, carbon dioxide, etc. may be channeled between components of the IHP system 100 using conduits, pipes, and / or ducts 182. In some embodiments, the IHP system 100 includes at least one sensor 184. such as, but not limited to, a temperature sensor, a flow rate sensor, and / or a pressure sensor, positioned at various locations within the IHP system 100, e.g., upstream and / or downstream from any and / or all of the components of the IHP system 100, and / or coupled within components, for detecting an operating parameter of the fluid contained therein. In some embodiments, the IHP system 100 includes at least one flow motive device 186, e.g., pumps, blowers, etc. and / or at least one flow control device 188. such as. a valve and / or any other flow metering device that may be used to regulate and / or control the flow of fluid through the ducts 182. The flow motive devices 186 and / or flow control devices 188 may be located at various locations within the IHP system 100, e.g., upstream and / or downstream from any and / or all of the components of the IHP system 100. In some embodiments, fluids may be motivated to move through ducts 182 using pressure differentials and / or gravitational forces.

[0025] In some embodiments, the IHP system 100 includes a controller 190 that is communicatively coupled, e.g.. wirelessly, to the at least one sensor 184, to the flow motive devices 186, and / or to the flow’ control devices 188. In some embodiments, the controller 190 may selectively adjust the supply of thermal energy supplied to the SMR system 106. In particular, the controller 190 may selectively vary the supply of thermal energy delivered from the burners 150 and / or an amount of thermal energy’ supplied by the flue flow 112. For example, the controller 190 may transmit at least one signal to the flow control device 188 to selectively adjust a floyv parameter of the flue floyvl 12, e.g., increase and / or decrease, the flow rate and / or flow' volume, of the flue floyv 112 delivered to the SMR, thereby selectively increasing, or decreasing an amount of thermal energy supplied by the flue flow 112. In another example, the controller 190 may transmit one or more signals to the floyv control deydce 188 to enable a flow' parameter of the fuel 132, to be selectively varied, e.g., increased or decreased, such that the floyv rate or floyv volume of the fuel 132 delivered to the at least one bumer(s) 150 is thereby increased or decreased.

[0026] In some embodiments, the controller 190 may selectively adjust the supply of thermal energy' delivered to the SMR system 106 based on a temperature detected by a sensor 184, such as for example, a temperature sensor. In some embodiments, the controller 190 may selectively adjust the flow control device 188 and / or the flow motive devices 186 to cause the flow of the fuel 132 supplied to the burners 150 to be selectively varied based on a detected temperature of the flue flow 112. For example, if the temperature of the flue flow 112 is detected a predefined threshold, the controller 190 may increase the amount of fuel supplied to the burner 150. In some embodiments, the controller 190 may selectively adjust the flow control device 188 and / or the flow motive devices 186 to enable the flow of the fuel 132 supplied to the burners 150 to be selectively varied based on a detected temperature of the steam-methane reaction within the SMR system 106.

[0027] The PCC system 110 is downstream from the SMR system 106 and includes an inlet 192 for receiving flue flow 1 12 exhausted from the SMR system 106, e.g., flue flow 112 that has supplied thermal energy' to the SMR system 106 and / or the steam- methane reaction and that has been discharged from the SMR system 106. In some embodiments, the flue flow 112 discharged from the SMR system may be combined with the burner exhaust gases 158 generated by the at least one bumer(s) 150, and the resulting combined mixture is discharged from the SMR system 106 through at least one second outlet 194. Accordingly, in the exemplary' embodiments described herein, the IHP system 100 includes a single PCC system 110 used for both the flue flow 112 and the burner exhaust gases 158. In other alternative embodiments, the IHP system 100 may include at least one PCC system 110. In some embodiments, the IHP system 100 may include one or more PCC systems 110 that share one or more components, e.g., one boiler 200 is utilized for both of the one or more PCC systems 110.

[0028] In the exemplary' embodiment, the PCC system 110 includes a boiler 200 for generating steam 138 that may be delivered to the SMR system 106, e.g., via the second inlet 136. The boiler 200 may also generate steam 138 that is delivered to the supplemental turbine 170. In some embodiments, the supplemental turbine 170 exhausts steam and / or water that is recycled and returned to the boiler 200. The PCC system 1 10 also includes an absorber 202 that facilitates removing carbon, a regenerator 204 wherein carbon is released, and a heat exchanger 206 between the absorber 202 and the regenerator 204.The boiler 200 also delivers steam 138 to the regenerator 204. In the exemplary embodiment, the PCC system 110 also includes a condenser 208 downstream from the regenerator 204. The PCC system 110 may also include any other additional and / or alternative components, e.g., pumps, coolers, etc. that enable the PCC system 110 to capture carbon. The PCC 110 exhausts the captured carbon 210 for proper disposal and / or storage.

[0029] FIG. 2 is a schematic of another exemplary integrated hydrogen production (IHP) system 300 including at least one component that is similar to at least one component of the IHP system 100 (shown in FIG. 1). For example, the IHP system 300 includes the SMR system 106, which receives flue flow 112, the HCPP system 108, the PCC system 110, and / or the supplemental turbine 170. The IHP system 300 further includes a methanol production system 250 which includes a first inlet for receiving at least a portion of the captured carbon 210. e.g., captured by the PCC system 110 and a second inlet for receiving hydrogen 102 discharged from the SMR system 106 and / or the HCPP system 108. The methanol production system 250 may produce methanol by reacting the carbon 210 with the hydrogen 102.

[0030] FIG. 3 is a schematic of another exemplary integrated hydrogen production system 400 including at least one component that is similar to at least one component of the IHP system 100 and / or IHP system 300 (shown in Figs 1 and 2). For example, the IHP system 400 includes the SMR system 106, which receives flue flow 112, the HCPP system 108, the PCC system 110, and / or the supplemental turbine 170. The IHP system 400 includes an ammonia production system 260 for producing ammonia (NH3) 262. The ammonia production system 260 includes a separation system 264 and a Haber process (HP) system 266. The separation system 264 may be a pressure swing absorber, a membrane system, a cryogenic system, and / or a nitrogen separation system. The system 264 receives a flue flow (e.g., flue flow 112 and / or burner exhaust gases 158), e.g., discharged from the absorber 202 and creates oxygen (O2) 268 and nitrogen (N2) 270. The oxygen 268 may be released, e.g., to the atmosphere, and the nitrogen 270 is delivered to the HP system 266. The HP system 266 also receives hydrogen 102 discharged from the SMR system 106 and / or the HCPP system 108. The HP system 266 produces ammonia 262 by reacting the nitrogen 270 with the hydrogen 102. The separation system 264 may refer to any suitable N2 separation system (additionally or alternatively referred to as a N2 production system). Forexample, stream 112 or 158 may be N2 'rich' in comparison with the ambient air, and as such, it is easier to separate or produce N2 such that the separation system 264 has improved efficiency.

[0031] FIG. 4 is a flow diagram of an exemplary method 500 for operating any of the IHP systems 100, 300, and / or 400 (shown in Figs 1, 2, and / or 3). In the exemplary embodiment, the method 500 includes receiving 502 a flue flow, such as flue flow 112 exhausted from the gas turbine engine 162, at the SMR system 106. The method 500 further includes the SMR system 106 generating a pre-hydrogen mixture, e.g., hydrogen mixture 144, by supplying thermal energy, extracted from the flue flow 112, to the steam-methane reaction. The method 500 further includes delivering the pre-hydrogen mixture 144 to the HCPP system 108 to generate hydrogen 102.

[0032] The method 500 includes supplying thermal energy via the flue flow 112 to the steam-methane reaction, and / or catalyst elements, within the SMR system 106. The method 500 may include supplementing and delivering additional thermal energy’ to the steam-methane reaction using at least one burner 150. The method 500 may include supplying air and / or fuel to the burners 150 producing exhaust gases 158.

[0033] The method 500 may include delivering 504 the flue flow 112, from the steam-methane reaction to the PCC system 110. The method 500 includes using the PCC system 110 to capture carbon entrained within the flue flow 1 12. In some embodiments, the method 500 also includes delivering 504 both flue flow 112 as well as burner exhaust gases 158 to the PCC system 110 and capturing carbon entrained in both flows 112, 158.

[0034] The method 500 may include directing 506 pre-hydrogen to a hydrogen post processing and cleaning process to produce hydrogen. For example, the method 500 may include delivering the hydrogen mixture 144, discharged from the SMR system 106, into the WSGR system 172 where the carbon monoxide and steam react to produce a second mixture including carbon dioxide and additional hydrogen (H2), then subsequently, the method 500 includes delivering the second mixture to the condenser 174 which produces liquid water, as well as a third mixture including hydrogen, carbon dioxide and / or other impurities. The method includes subsequently delivering the third mixture to the PSA 176 which produces hydrogen 102 and tail gas 180.

[0035] In some embodiments, the method 500 may also include generating 508 methanol, and receiving carbon, captured by the PCC system 110, and receiving the hydrogen discharged from the HCPP system 108. The method 500 includes reacting the carbon with the hydrogen to produce methanol.

[0036] In some embodiments, the method 500 further includes generating 508 ammonia. The method 500 includes receiving flue flow 112 at the system 264 to produce nitrogen. The method 500 includes receiving nitrogen and hydrogen at the HP system 266. The method 500 includes reacting the nitrogen and the hydrogen to produce ammonia.

[0037] Embodiments described herein enable hydrogen to be produced using a system having an improved efficiency, by utilizing waste heat recovered from the exhaust of a gas turbine engine to support the endothermic reaction in a steam-methane reformer. In embodiments described herein, carbon is captured from both the flue flow, after the flue flow has supplied thermal energy to the steam-methane reaction as well as from burner exhaust gases. As such, a single carbon capture system may be used to capture carbon from both the flue flow discharged from a gas turbine engine, and from the steam-methane reformer. Furthermore, one or more by-products of the post carbon capture system may be reacted with the produced hydrogen to create ammonia and / or methanol. The post carbon capture system includes a boiler, for producing steam for use in the PCC, and is also used to supply steam to the steam-methane reformer as well as a supplementary turbine to extract additional power from the steam.

[0038] Further aspects of the present disclosure are provided by the subject matter of the following clauses:

[0039] 1. An integrated hydrogen production (IHP) system comprising: a steam-methane reformer system configured to generate hydrogen via a steam-methane reaction, the steam-methane reformer system is oriented to receive a flue flow from a flue flow source and to use thermal energy from the flue flow in the steam-methane reaction; and a post carbon capture system for capturing carbon from the flue flow discharged from the steam-methane reformer.

[0040] 2. The integrated hydrogen production system according to any preceding clause, wherein the IHP system further comprises: a post processing system configured to receive a mixture including hydrogen discharged from the steam-methane reformer system, the post processing system comprising: a water-gas shift reaction system for reacting carbon monoxide with water vapor to form carbon dioxide and hydrogen; a condenser downstream from the water-gas shift reaction system; and a separation system downstream from the condenser, the separation system used to facilitate separating impurities from the hydrogen.

[0041] 3. The integration system according to any preceding clause, wherein the steam-methane reformer system comprises: an arch burner configured to supply thermal energy to the steam-methane reformer system and to produce burner exhaust, the post carbon capture system captures carbon entrained within the burner exhaust.

[0042] 4. The integration system according to any preceding clause, wherein the post carbon capture system comprises: an absorber; a regenerator in flow communication with the absorber; and a boiler for supplying steam to at least one of the steam-methane reformer system and the regenerator.

[0043] 5. The integration system according to any preceding clause, wherein the integration system further comprises: a steam turbine configured to receive steam generated by the boiler.

[0044] 6. The integration system according to any preceding clause, wherein the integration system comprises: a methanol production system configured to produce methanol using receive carbon captured by the post carbon capture system and hydrogen produced by the steam-methane reformer.

[0045] 7. The integration system according to any preceding clause, wherein the integration system further comprises: an ammonia production system for producing ammonia, wherein the ammonia production system comprises: a separation system configured to produce nitrogen using the flue flow; and a Haber Process system configured to produce ammonia using the produced nitrogen and hydrogen.

[0046] 8. The integration system according to any preceding clause, wherein the integration system comprises: a gas turbine engine exhausting the flue flow.

[0047] 9. The integration system according to any preceding clause, wherein the integration system comprises: a temperature sensor configured to detect a temperature within the steam-methane reformer system; a flow control valve between the flue flow source and the steam-methane reformer system; and a controller communicatively coupled to the temperature sensor and the flow control valve, the controller configured to adjust the flow control valve based on a received temperature from the temperature sensor.

[0048] 10. A power generation integration system comprising: a gas turbine engine including a turbine exhausting a flue flow; and an integration system comprising: a steam-methane reformer system configured to generate hydrogen via a steam- methane reaction, the steam-methane reformer system is oriented to receive the flue flow and to use thermal energy from the flue flow in the steam-methane reaction; and a post carbon capture system for capturing carbon from the flue flow discharged from the steam-methane reformer.

[0049] 11. The power generation system according to any preceding clause, wherein the system further comprises: a post processing system configured to receive a mixture including hydrogen discharged from the steam-methane reformer system, the post processing system comprising: a water-gas shift reaction system for reacting carbon monoxide with water vapor to form carbon dioxide and hydrogen; a condenser downstream from the water-gas shift reaction system; and a separation system downstream from the condenser, the separation system used to facilitate separating impurities from the hydrogen.

[0050] 12. The powder generation system according to any preceding clause, wherein the steam-methane reformer system comprises: an arch burner configured to supply thermal energy to the steam-methane reformer system and to produce burner exhaust, the post carbon capture system captures carbon entrained within the burner exhaust.

[0051] 13. The power generation system according to any preceding clause, wherein the post carbon capture system comprises: an absorber; a regenerator in flow communication with the absorber; and a boiler for supplying steam to at least one of the steam-methane reformer system and the regenerator.

[0052] 14. The power generation system according to any preceding clause, wherein the integration system further comprises: a steam turbine configured to receive steam generated by the boiler.

[0053] 15. The power generation system according to any preceding clause, wherein the integration system comprises: a methanol production system configured to produce methanol using receive carbon captured by the post carbon capture system and hydrogen produced by the steam-methane reformer.

[0054] 16. The power generation system according to any preceding clause, wherein the integration system further comprises: an ammonia production system for producing ammonia, wherein the ammonia production system comprises: a separation system configured to produce nitrogen using the flue flow; and a Haber Process system configured to produce ammonia using the produced nitrogen and hydrogen.

[0055] 17. The power generation system according to any preceding clause, wherein the integration system comprises: a temperature sensor configured to detect a temperature within the steam-methane reformer system; a flow control valve between the gas turbine engine and the steam-methane reformer system; and a controller communicatively coupled to the temperature sensor and the flow control valve, the controller configured to adjust the flow control valve based on a received temperature from the temperature sensor.

[0056] 18. A method of operating a hydrogen production integration system, the method comprising: supplying flue flow to a steam-methane reformer system, wherein the flue flow supplies thermal energy to a steam-methane reaction within the steam- methane reformer system; supplying the flue flow to a carbon capture system; and capturing carbon from the flue flow, after the flue flow supplied thermal energy to the steam-methane reaction.

[0057] 19. The method according to any preceding clause, wherein the method further comprises: supplying fuel to an arch burner to supply thermal energy' to the steam-methane reformer sy stem within the steam-methane reformer system, the arch burners producing burner exhaust; supplying the burner exhaust to the carbon capture system; and capturing carbon entrained in both the flue flow and the burner exhaust.

[0058] 20. The method according to any preceding clause, wherein the method further comprises: supplying a mixture including hydrogen produced by the steam- methane reformer to a water-gas shift reactor to produce additional hydrogen.

[0059] The above description is meant to be exemplary' only, and one skilled in the art will recognize that changes may be made to the embodiments described without departing from the scope of the invention disclosed. Modifications, which fall within the scope of the present invention, will be apparent to those skilled in the art, in light of a review of this disclosure, and such modifications are intended to fall within the appended claims.

[0060] Although specific features of various embodiments of the disclosure may be shown in some drawings and not in others, this is for convenience only. In accordance with the principles of the disclosure, any feature of a drawing may be referenced and / or claimed in combination with any feature of any other drawing.

[0061] This written description uses examples to disclose the embodiments of systems and methods, including the best mode, and also to enable any person skilled in the art to practice the systems and methods, including making and using any devices or systems and performing any incorporated methods. The patentable scope of the systems and methods is defined by the claims, and may include other examples that occur to those skilled in the art. Such other examples are intended to be within the scope of the claims if they have structural elements that do not differ from the literal language of the claims, or if they include equivalent structural elements with insubstantial differences from the literal languages of the claims.

Claims

WHAT IS CLAIMED IS:

1. An integrated hydrogen production (IHP) system comprising: a steam-methane reformer system configured to generate hydrogen via a steam-methane reaction, the steam-methane reformer system is oriented to receive a flue flow from a flue flow source and to use thermal energy from the flue flow in the steam-methane reaction; and a post carbon capture system for capturing carbon from the flue flow discharged from the steam-methane reformer.

2. The integrated hydrogen production system of Claim 1, wherein the IHP system further comprises: a post processing system configured to receive a mixture including hydrogen discharged from the steam-methane reformer system, the post processing system comprising: a water-gas shift reaction system for reacting carbon monoxide with water vapor to form carbon dioxide and hydrogen; a condenser downstream from the water-gas shift reaction system; and a separation system downstream from the condenser, the separation system used to facilitate separating impurities from the hydrogen.

3. The integration system of claim 1. wherein the steam-methane reformer system comprises: an arch burner configured to supply thermal energy to the steam-methane reformer system and to produce burner exhaust, the post carbon capture system captures carbon entrained within the burner exhaust.

4. The integration system of claim 1, wherein the post carbon capture system comprises: an absorber;a regenerator in flow communication with the absorber; and a boiler for supplying steam to at least one of the steam-methane reformer system and the regenerator.

5. The integration system of claim 4, wherein the integration system further comprises: a steam turbine configured to receive steam generated by the boiler.

6. The integration system of claim 1, wherein the integration system comprises: a methanol production system configured to produce methanol using receive carbon captured by the post carbon capture system and hydrogen produced by the steam-methane reformer.

7. The integration system of claim 1, wherein the integration system further comprises: an ammonia production system for producing ammonia, wherein the ammonia production system comprises: a separation system configured to produce nitrogen using the flue flow; and a Haber Process system configured to produce ammonia using the produced nitrogen and hydrogen.

8. The integration system of claim 1, wherein the integration system comprises: a gas turbine engine exhausting the flue flow.

9. The integration system of claim 1, wherein the integration system comprises: a temperature sensor configured to detect a temperature within the steam- methane reformer system; a flow control valve between the flue flow source and the steam-methane reformer system; anda controller communicatively coupled to the temperature sensor and the flow control valve, the controller configured to adjust the flow control valve based on a received temperature from the temperature sensor.

10. A power generation integration system comprising: a gas turbine engine including a turbine exhausting a flue flow; and an integration system comprising: a steam-methane reformer system configured to generate hydrogen via a steam-methane reaction, the steam-methane reformer system is oriented to receive the flue flow and to use thermal energy from the flue flow in the steam-methane reaction; and a post carbon capture system for capturing carbon from the flue flow discharged from the steam-methane reformer.

11. The power generation system of claim 10, wherein the system further comprises: a post processing system configured to receive a mixture including hydrogen discharged from the steam-methane reformer system, the post processing system comprising: a water-gas shift reaction system for reacting carbon monoxide with water vapor to form carbon dioxide and hydrogen; a condenser downstream from the water-gas shift reaction system; and a separation system downstream from the condenser, the separation system used to facilitate separating impurities from the hydrogen.

12. The power generation system of claim 10, wherein the steam-methane reformer system comprises: an arch burner configured to supply thermal energy to the steam-methane reformer system and to produce burner exhaust, the post carbon capture system captures carbon entrained within the burner exhaust.

13. The power generation system of claim 10, wherein the post carbon capture system comprises: an absorber; a regenerator in flow communication with the absorber; and a boiler for supplying steam to at least one of the steam-methane reformer sy stem and the regenerator.

14. The power generation system of claim 13, wherein the integration system further comprises: a steam turbine configured to receive steam generated by the boiler.

15. The power generation system of claim 10, wherein the integration system comprises : a methanol production system configured to produce methanol using receive carbon captured by the post carbon capture system and hydrogen produced by the steam-methane reformer.

16. The power generation system of claim 10, wherein the integration system further comprises: an ammonia production system for producing ammonia, wherein the ammonia production system comprises: a separation system configured to produce nitrogen using the flue flow; and a Haber Process system configured to produce ammonia using the produced nitrogen and hydrogen.

17. The power generation system of claim 10, wherein the integration system comprises: a temperature sensor configured to detect a temperature within the steam- methane reformer system; a flow control valve between the gas turbine engine and the steam-methane reformer system; and a controller communicatively coupled to the temperature sensor and the flow control valve, the controller configured to adjust the flow control valve based on a received temperature from the temperature sensor.

18. A method of operating a hydrogen production integration system, the method comprising: supplying flue flow to a steam-methane reformer system, wherein the flue flow supplies thermal energy to a steam-methane reaction within the steam-methane reformer system; supplying the flue flow to a carbon capture system; and capturing carbon from the flue flow, after the flue flow supplied thermal energy to the steam-methane reaction.

19. The method of claim 18, wherein the method further comprises: supplying fuel to an arch burner to supply thermal energy to the steam-methane reformer system within the steam-methane reformer system, the arch burners producing burner exhaust; supplying the burner exhaust to the carbon capture system; and capturing carbon entrained in both the flue flow and the burner exhaust.

20. The method of claim 19, wherein the method further comprises: supplying a mixture including hydrogen produced by the steam-methane reformer to a water-gas shift reactor to produce additional hydrogen.

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