Liquid natural gas (LNG) regasification systems and combined cycle power plants including same

Abstract

A regasification system includes a first cooling apparatus in flow communication with a liquid natural gas conduit for receiving liquid natural gas (LNG), and a second cooling apparatus in flow communication and downstream from the first cooling apparatus. The second cooling apparatus is in flow communication with a cooling assembly including cooling water. The cooling assembly facilitates cooling a carbon dioxide stream flowing through a compression train of a carbon capture system included in a combined cycle power plant. The regasification system also includes a heat exchanger in flow communication and downstream from the second cooling apparatus. The heat exchanger is in flow communication with a combustor of a gas turbine assembly for the combined cycle power plant.

Description

LIQUID NATURAL GAS (LNG) REGASIFICATION SYSTEMS AND COMBINEDCYCLE POWER PLANTS INCLUDING SAMETECHNICAL FIELD

[0001] The disclosure relates generally to regasification systems for use with combined cycle power plants, and more particularly, to regasification systems that facilitate reducing the temperature of cooling fluids used in the combined cycle power plants.BACKGROUND

[0002] Combined cycle power plants, including known gas turbine systems and steam turbine systems, utilize a single fuel source to power the gas turbine system, which in return generates an exhaust gas that is processed and subsequently used by the steam turbine system. Each turbine assembly within the power plant drives at least one generator that produces power for an external system (e.g., power grid). To maintain operational life and / or improve operational efficiencies of the power plant, a variety of components forming the power plant are cooled to withstand the heat or exposure generated during operation. For example, various coolers or heat exchangers throughout the power plant cool components and / or fluids (e.g., exhaust gases) during operation to facilitate maintaining and / or improving efficiencies and reliability of the components, and while also improving the subsequent processing or byproducts that require cooling. In one example, a compression train within a carbon capture system included in power plants compresses carbon dioxide extracted from an exhaust product of the steam turbine system, such that the carbon dioxide can be more easily transported, stored, and / or repurposed when removed from the pow er plant. To facilitate improving the compression of the carbon dioxide within the compression train, the carbon dioxide is cooled, via an independent cooling assembly, in each stage of compression.

[0003] Additional cooling and / or heat exchanges take place with the fuel delivered to the gas turbine system. More specifically, in such an example, although the gas turbine system utilizes natural gas (NG) in its combustor to generation combustion fluid (e.g., working fluid), natural gas (NG) is typically transported over long distances (e.g., overseas) and / or stored within the power plant in liquid form or as liquid natural gas (LNG) until it is ready to be supplied to the gas turbine system during operation. Liquid natural gas (LNG) iseasier to transportation, and / or can be stored in high quantity in the liquid phase than in its gaseous state. To store and maintain the liquid natural gas (LNG) in its liquid state, liquid natural gas (LNG) must be cooled to a relatively low temperature (e.g., -160°C). Before being used within the gas turbine system, conventional regasification systems are used to convert the liquid natural gas (LNG) to natural gas (NG). Known conventional systems often use sea or natural water to exchange heat with the liquid natural gas (LNG) until it is vaporized to form natural gas (NG) that is subsequently supplied to the combustor of the gas turbine system. The liquefied natural gas (LNG) undergoes vaporization by the use of a heating media such as sea water, a typical cooling water system, or any suitable heating medium. The liquefied natural gas (LNG) is heated and transformed into vapor, while the heating medium is simultaneously cooled, extracting cooling energy from the LNG stream. This extracted cooling energy is not utilized and might be seen as w asted.BRIEF DESCRIPTION

[0004] A first aspect of the disclosure provides a regasification system, including: a first cooling apparatus in flow communication with a liquid natural gas (LNG) conduit for receiving liquid natural gas (LNG); a second cooling apparatus in flow communication and downstream from the first cooling apparatus, the second cooling apparatus in flow communication with a cooling assembly that uses cooling water to facilitate cooling a carbon dioxide stream flowing through a compression train of a carbon capture system; and a heat exchanger in flow communication and downstream from the second cooling apparatus, the heat exchanger in flow communication with a combustor of a gas turbine assembly.

[0005] A second aspect of the disclosure provides a combined cycle powder plant system including: a gas turbine assembly including: a combustor; and a turbine in flow communication with the combustor, wherein the turbine discharges a first exhaust gas stream; a heat recovery steam generator (HRSG) in flow communication with the turbine for receiving the first exhaust gas stream and discharging a second exhaust gas stream; a carbon capture system in flow communication with the HRSG for receiving the second exhaust gas stream, the carbon capture system including: a compression train receiving and compressing a generated carbon dioxide stream; and a cooling assembly in flow communication with the compression train, the cooling assembly using cooling water tofacilitate cooling the carbon dioxide stream compressed by the compression train; a regasification system in flow communication with the cooling assembly, the regasification system including: a first cooling apparatus in flow communication with a liquid natural gas (LNG) conduit for receiving liquid natural gas (LNG); a second cooling apparatus in flow communication and downstream from the first cooling apparatus, the second cooling apparatus in flow communication with the cooling assembly; and a heat exchanger in flow communication and downstream from the second cooling apparatus, the heat exchanger in flow communication with the combustor of the gas turbine assembly.

[0006] The illustrative aspects of the present disclosure are designed to solve the problems herein described and / or other problems not discussed.BRIEF DESCRIPTION OF THE DRAWINGS

[0007] These and other features of this disclosure will be more readily understood from the following detailed description of the various aspects of the disclosure taken in conjunction with the accompanying drawings that depict various embodiments of the disclosure, in which:

[0008] FIG. 1 is a schematic illustration of an exemplary combined cycle power plant including a gas turbine system, a steam turbine system, a carbon capture system, and a regasification system.

[0009] FIG. 2 is a schematic illustration of the regasification system shown in FIG. 1.

[0010] FIG. 3 is a schematic illustration of a combined cycle power plant shown in FIG. 1 and including a gas turbine system, a steam turbine system, a carbon capture system, and a regasification system.

[0011] FIG. 4 is a schematic illustration of the regasification system shown in FIG. 3.

[0012] FIG. 5 is a schematic illustration of the regasification system show n in FIG. 1.

[0013] FIG. 6 is a schematic illustration of another embodiment of a regasification system that may be used with the combined cycle power plant shown in FIG. 3.

[0014] It is noted that the drawings of the disclosure are not to scale. The drawings are intended to depict only typical aspects of the disclosure, and therefore should not be considered as limiting the scope of the disclosure. In the drawings, like numbering represents like elements between the drawings.DETAILED DESCRIPTION

[0015] The embodiments described herein relate to combined cycle power plant systems that utilize heat exchange within a regasification system to cool working fluids for use in various portions of the power plant system. Although heat exchange is typically used to vaporize liquid natural gas (LNG) to natural gas (NG) using an open (sea) water system, distinct from any other system of the power plant, the regasification systems described herein use that heat exchange to provide additional cooling of working fluid used within the power plant, thus facilitating improving operating efficiencies of the power plant as the single use sea water system is eliminated, such that the heat exchange can take place between the regasification system and another component, system, or assembly (e g., cooling assembly). Additionally, because of the relatively low temperature of the liquid natural gas (LNG) being exchanged within the regasification system, working fluids cooled in the regasification system can be reduced to a lower temperature than typical systems, and ultimately can facilitate improving the operation of each component, apparatus, and / or system the working fluid is channeled through during operation.

[0016] At least some benefits of the regasification system used to cool additional components or systems within a power plant include: a) more efficient and effective use of heat exchanges within the power plant; b) improved cooling to a cooling assembly of a compression train of a carbon capture system; c) improved cooling for exhaust gas recirculation (EGR) loops or assemblies; and d) improved cooling to distinct heat exchangers within the carbon capture system and / or other portions of the power plant. Additional benefits realized by the compression train may include reducing a number of compression stages within the compression train and / or a reducing power demand necessary’ to compress a carbon dioxide stream flowing therethrough.

[0017] Unless otherwise indicated, approximating language, such as ‘‘generally,'’ “substantially,” and “about,” as used herein indicates that the term so modified may apply to only an approximate degree, as would be recognized by one of ordinary skill in the art, rather than to an absolute or perfect degree. Accordingly, a value modified by a term or terms such as “about,” “approximately,” and “substantially” is not to be limited to the precise value specified. In at least some instances, the approximating language may correspond to the precision of an instrument for measuring the value. Additionally, unlessotherwise indicated, the terms “first / ’ “second,” etc. are used herein merely as labels, and are not intended to impose ordinal, positional, or hierarchical requirements on the items to which these terms refer. Moreover, reference to, for example, a “second” item does not require or preclude the existence of, for example, a “first” or lower-numbered item or a “third” or higher-numbered item.

[0018] In addition, several descriptive terms may be used regularly herein, and it should prove helpful to define these terms at the onset of this section. These terms and their definitions, unless stated otherwise, are as follows. As used herein, '’downstream" and “upstream” are terms that indicate a direction relative to the flow of a fluid, such as the working fluid through the turbine engine or. for example, the flow of air through the combustor or coolant through one of the turbine's component systems. The term ’’dow nstream" corresponds to the direction of flow of the fluid, and the term “upstream” refers to the direction opposite to the flow. The terms “forward” and “aft.” without any further specificity, refer to directions, with “forward” referring to the front or compressor end of the engine, and “aft” referring to the rearward or turbine end of the engine. It is often required to describe parts that are at differing radial positions with regard to a center axis. The term “radial” refers to movement or position perpendicular to an axis. In cases such as this, if a first component resides closer to the axis than a second component, it will be stated herein that the first component is “radially inw ard” or “inboard” of the second component. If, on the other hand, the first component resides further from the axis than the second component, it may be stated herein that the first component is “radially outward” or “outboard” of the second component. The term “axial” refers to movement or position parallel to an axis. Finally, the term “circumferential” refers to movement or position around an axis. It will be appreciated that such terms may be applied in relation to the center axis of the turbine.

[0019] FIG. 1 is a schematic illustration of an exemplary combined cycle power plant 100 (hereafter, “power plant 100”). In the exemplary embodiment, power plant 100 includes a gas turbine assembly 102 and a steam turbine 104. Gas turbine assembly 102 includes a compressor 106, a combustor 108, and a turbine 110 coupled together in a serial flow' relationship. In operation, combustor 108 receives air from compressor 106 and fuel (e.g., liquid natural gas) from a fuel supply (e.g., regasification system 200) and mixes the fuel and air to create a fuel-air mixture that is combusted to generate combustion gases. Thefuel is supplied to combustor 108 via a fuel supply conduit 109. Combustion gases are channeled through turbine 1 10 and discharged from turbine 1 10 as a first exhaust gas stream 112. In the exemplary' embodiment, power plant 100 also includes a steam cycle arrangement including a heat recovery steam generator (HRSG) 114 and steam turbine 104. In some embodiments, the steam cycle arrangement may also include other components, including a condenser 116 and at least one circulation pump 117. Moreover, in other embodiments, the steam cycle arrangement may also include at least one additional HRSG 114.

[0020] In the exemplary embodiment, HRSG 114 includes an inlet 118 that receives first exhaust gas stream 112 from gas turbine assembly 102. Heat is extracted from first exhaust gas stream 112, and a second exhaust gas stream 120 is discharged from a first outlet 122. Second exhaust gas stream 120 is at a lower temperature than a temperature of first exhaust gas stream 112 entering inlet 118. HRSG 114 also includes a second outlet 124 that discharges a first steam stream 126. Steam turbine 104 receives first steam stream 126 and subsequently discharges an interstage extraction flow 128 therefrom. Any steam not extracted with flow 128 continues expansion to condensation within condenser 116. In some embodiments, steam turbine 104 may include additional steam admissions from HRSG 114. In the exemplary’ embodiment, gas turbine assembly 102 and steam turbine 104 are both coupled to a generator 132 that produces power using working fluids flowing through each. Alternatively, turbine assembly 102 and steam turbine 104 may be on separate shafts, with each coupled to a separate generator.

[0021] In the exemplary embodiment, power plant 100 also includes a carbon capture system 134. During operation, carbon capture system 134 produces a carbon dioxide stream 138. Carbon capture system 134 may include one or more separators, either used alone, or in combination with other separation processes, such as carbon dioxide selective membrane technologies, absorption processes, diaphragms, and the like. An exhaust stream or carbon depleted exhaust stream 140 may be discharged from carbon capture system 134 to the ambient environment. Exhaust stream 140 may also be further processed prior to discharge to the environment or elsewhere. At least a portion of carbon dioxide stream 138 may be increased to supercritical pressure for transport and / or storage, for example.

[0022] Carbon capture system 134 generally includes an absorber 142, a stripper 144, and a stripper reboiler 146. In operation, second exhaust gas stream 120 discharged fromHRSG 114 is channeled towards absorber 142. The exhaust gas may be pretreated for removal of particulates and impurities such as SOx and NOx before entry into absorber 142. In addition, in the exemplary embodiment, a first cooler 148 is coupled between HRSG 114 and carbon capture system 134. Alternatively, carbon capture system 134 may include at least one booster blower (not shown) to pressurize flow channeled towards carbon capture system 134. First cooler 148 may be, but is not limited to only being, a quench tower. First cooler 148, with the aid of heat exchanger 139, cools a portion of second exhaust gas stream 120 to be channeled towards carbon capture system 134. A solvent 152, rich in carbon dioxide, is discharged from absorber 142 and is then channeled, via a pump 154, to stripper 144. A solvent 156, lean in carbon dioxide, is discharged from stripper 144 and is channeled back to an upper portion of absorber 142 via reboiler 146, a pump 166, and heat exchanger 158. Absorber 142 may be of any construction typical for providing gas-liquid contact and absorption. Absorber 142 and stripper 144 may incorporate a variety of internal components, such as trays, packings, and / or supports, for example. In one embodiment, absorber 142 absorbs carbon dioxide via a countercurrent flow from the entering exhaust gas. Stripper 144 removes carbon dioxide from solvent 152. Absorber 142 and stripper 144 may be variably sized based on an amount of carbon dioxide to be removed, and may be sized according to various engineering design equations. Furthermore, a single stripper 144 may serve and be coupled to multiple absorbers 142.

[0023] The solvent may be a solution or dispersion, typically in water, of one or more absorbent compounds. More specifically, the solvent may be any compound which when mixed with water creates an absorbent fluid that, as compared to water alone, increases the ability of the fluid to preferentially remove carbon dioxide from exhaust gas. For example, the solvent may be, but is not limited to only being, monethanolamine (MEA). Inhibitors may be included in the solvent to facilitate inhibiting degradation of the solvent.

[0024] In the exemplary embodiment, solvent 152 is preheated in a counter-current heat exchanger 158 against solvent 156, and is subsequently channeled to stripper 144. Moreover, in the exemplary embodiment, stripper 144 is a pressurized unit in which carbon dioxide is recovered from solvent 152. Stripper 144 generally incorporates reboiler 146 which receives a portion of solvent 156 exiting stripper 144. Reboiler 146 vaporizes solvent 156 and channels solvent vapor 160 back to stripper 144 to facilitate increasedcarbon dioxide separation. A single stripper, such as stripper 144. may be coupled to more than one reboiler 146. Reboiler 146 receives steam, such as from steam turbine 104 via flow 128, to provide heating duty in reboiler 146.

[0025] Carbon dioxide (CO2) vapor 162 exiting stripper 144 is partially condensed in a condenser 136. The condensed portion of carbon dioxide (CO2) vapor 162 is returned to stripper 144 as reflux 164. Reflux 164 may be transferred through an accumulator (not shown) and a pump (not shown) before entry into stripper 144. A distinct, condensed portion of carbon dioxide (CO2) vapor 162 forms carbon dioxide stream 138, which is removed from condenser 136 for transport and / or storage after compression.

[0026] As shown in FIG. 1, carbon capture system 134 includes a carbon dioxide (CO2) compression train 170 (hereafter, "compression train 170”) that receives carbon dioxide stream 138. Compression train 170 includes a plurality of compressors 172 coupled in series for compressing carbon dioxide stream 138 prior to the carbon dioxide stream 138 being discharged, transported, and / or removed and stored from carbon capture system 134. Carbon capture system 134 and / or compression train 170 also includes a cooling assembly 174 coupled in flow communication with compression train 170. Cooling assembly 174 carries, contains, and / or includes a cooling fluid (e.g., cooling water) that facilitates cooling carbon dioxide stream 138 as it is compressed within compression train 170. In an example, cooling water flows from inlet conduit(s) 176 of cooling assembly 174 to a plurality of heat exchanger 178 coupled between each compressor 172 and an adjacent final stage compressor 172 of compression train 170. Each heat exchanger 178 of cooling assembly 174 is fluidly coupled and / or in fluid / flow communication with carbon dioxide stream 138 flowing between compressors 172 of compression train 170. As such, heat exchanger 178 utilizes cooling w aler to facilitate cooling or reducing the temperature of carbon dioxide stream 138 as it flows through, and / or is compressed by, compression train 170. Cooling water is subsequently discharged or flow s from heat exchanger 178 via outlet conduit(s) 180.

[0027] Power plant 100 can also include an exhaust gases recirculation (EGR) system 182 (hereafter, “EGR system 182”). EGR system 182 is in flow communication with the HRSG 114. More specifically, an inlet conduit 184 of EGR system 182 is downstream from and in flow communication with HRSG 114 for receiving and / or supplying at least a portion of the exhaust gas stream 120 expelled from HRSG 114 to EGR system 182. EGR system 182processes exhaust gas stream 120 (e.g., reduces temperature, removes / reduces impurities, reduces moisture content, etc.) and recirculates the processed, exhaust gas stream 120 back to compressor 106 of gas turbine assembly 102, via outlet conduit 186.

[0028] In the exemplary embodiment, power plant 100 also includes a liquid natural gas (LNG) regasification system 200 (hereafter, “regasification system 200?’). As shown, and as discussed herein with respect to FIGs. 2 and 4-6, at least a portion of regasification system 200 is in flow communication with cooling assembly 174 of carbon capture system 134. More specifically, in the exemplary embodiment, inlet conduit(s) 176 and outlet conduit(s) 180 are in flow communication and / or fluidly coupled to regasification system 200 and / or at least one apparatus of regasification system 200 (see. e.g., FIG. 2).

[0029] Regasification system 200 receives liquid natural gas (LNG), fuel for gas turbine assembly 102, and subsequently vaporizes the liquid natural gas (LNG) to form natural gas (NG). The (vaporized) natural gas (NG) is then provided to combustor 108 of gas turbine assembly 102, via fuel supply conduit 109 in flow communication with regasification system 200. In the exemplary embodiment, power plant 100 includes an LNG storage tank 202 coupled in flow communication with regasification system 200. LNG storage tank 202 stores the fuel (e.g., LNG / NG) in its liquid state, and provides liquid natural gas (LNG) to regasification system 200 via a liquid natural gas (LNG) conduit 204.

[0030] Although shown and discussed herein as including storage tank 202, it is understood that regasification system 200 can receive liquid natural gas (LNG) from any suitable component, apparatus and / or system capable of transporting, storing, and / or delivering liquid natural gas (LNG) to power plant 100. For example, liquid natural gas (LNG) conduit 204 can be fluidly coupled to and / or in flow communication with a storage ship or a railway tanker containing liquid natural gas (LNG) that provides liquid natural gas (LNG) to regasification system 200, as discussed herein.

[0031] In addition to being in flow7communication with cooling assembly 174. regasification system 200 can be fluidly coupled to and / or in flow communication with distinct portions of power plant 100. In the exemplary embodiment shown in FIG. 1, and as discussed herein with respect to FIGs. 2 and 4-6, at least a portion of regasification system 200 is also fluidly coupled to and / or in flow communication with heat exchanger(s) 137, 139 of carbon capture system 134 and / or condenser 136 of carbon capture system 134. Regasification system 200, and more specifically at least one apparatus or component ofregasification system 200, is fluidly coupled to condenser 136 and / or heat exchanger(s) 137, 139 of carbon capture system 134 via inlet conduit 206 (shown in phantom) and outlet conduit 208 (shown in phantom)(see also, FIG. 2), respectively. Additionally, or alternatively, at least a portion of regasification system 200 is fluidly coupled to and / or in flow communication with EGR system 182. as discussed herein. Regasification system 200, and more specifically at least one apparatus or component of regasification system 200, is fluidly coupled to EGR system via inlet conduit 210 (shown in phantom) and outlet conduit 212 (shown in phantom)(see also, FIG. 2), respectively.

[0032] FIG. 2 is a schematic illustration of an exemplary regasification system 200 included in power plant 100 (shown in FIG. 1). It is understood that similarly numbered and / or named components may function in a substantially similar fashion. Redundant explanation of these components has been omitted for clarity.

[0033] In the exemplary embodiment, regasification system 200 includes a plurality of cooling apparatuses 218. 220 coupled in flow communication with LNG conduit 204. Specifically, in the exemplary embodiment, regasification system 200 includes a first cooling apparatus 218 fluidly coupled to and / or in flow communication with LNG conduit 204. First cooling apparatus 218 receives liquid natural gas (LNG) from LNG conduit 204 and subsequently increases the temperature of liquid natural gas (LNG) flowing / interacting therewith. In a non-limiting example, first cooling apparatus 218 is formed as a first refrigerant cycle that includes a first evaporator 222 coupled in flow communication with LNG conduit 204, and a first compressor 224 coupled in flow communication with first evaporator 222. The first refrigerant cycle of first cooling apparatus 218 also includes a first condenser 226 coupled in flow communication with first compressor 224. and a first expansion valve 228 between and in flow communication with both first condenser 226 and first evaporator 222. First condenser 226 is also coupled in flow communication with cooling assembly 174. As shown in FIG. 2, outlet conduit(s) 180 of cooling assembly 174 are in flow communication with and / or fluidly coupled to first condenser 226 of first cooling apparatus 218.

[0034] The first refrigerant cycle of first cooling apparatus 218 also includes a first working fluid 230 flowing therethrough. More specifically, the first refrigerant cycle includes a first working fluid 230 continuously flowing between first evaporator 222, first compressor 224, first condenser 226, and first expansion valve 228 to facilitate transferringheat to the liquid natural gas (LNG) flowing through first refrigerant cycle / first cooling apparatus 218. That is, cooling water previously used to cool carbon dioxide stream 138 being compressing in compression train 170 flows from outlet conduit(s) 180 to first condenser 226, wherein heat is transferred from the cooling water to working fluid 230. The working fluid 230 in turn flows to first evaporator 222 where it transfers the heat to liquid natural gas (LNG) channeled to first refrigerant cycle / first cooling apparatus 218 via LNG conduit 204. Subsequently, the energy / heat exchange in first evaporator 222 cools and / or facilitates reducing the temperature of working fluid 230, which returns to first condenser 226 to subsequently facilitate cooling the cooling water before flowing from first condenser 226 to inlet conduit(s) 176 of cooling assembly 174.

[0035] In the exemplary embodiment, liquid natural gas (LNG) is subsequently channeled to second cooling apparatus 220. That is, regasification system 200 includes a second cooling apparatus 220 fluidly coupled to and / or in flow communication with first cooling apparatus 218. As shown in FIG. 2, second cooling apparatus 220 is downstream from first cooling apparatus 218 and is fluidly coupled to first cooling apparatus / first refrigerant cycle via first intermediate conduit 232. As discussed herein, the temperature of liquid natural gas (LNG) is increased after the liquid natural gas (LNG) flows through first cooling apparatus 218. As such, the temperature of liquid natural gas (LNG) flowing through first intermediate conduit 232 is higher than the temperature of the liquid natural gas (LNG) flowing through LNG conduit 204.

[0036] In the exemplary embodiment shown in FIG. 2, similar to first cooling apparatus 218, second cooling apparatus 220 is formed as a second, distinct refrigerant cycle. The second refrigerant cycle of second cooling apparatus 220 includes a second evaporator 234 that is coupled in flow communication with first intermediate conduit 232, and a second compressor 236 coupled in flow7communication with second evaporator 234. The second refrigerant cycle of second cooling apparatus 220 also includes a second condenser 238 coupled in flow communication with second compressor 236. and a second expansion valve 240 between, and in flow communication with both, second condenser 238 and second evaporator 234. Second condenser 238 is also in flow communication with cooling assembly 174 of carbon capture system 134. As shown in FIG. 2, outlet conduit(s) 180 of cooling assembly 174 are in flow communication with and / or fluidly coupled to second condenser 238 of second cooling apparatus 220.

[0037] The second refrigerant cycle of second cooling apparatus 220 also includes a second working fluid 242 flowing therethrough. More specifically, the second refrigerant cycle includes a second working fluid 242 continuously flowing between second evaporator 234, second compressor 236, second condenser 238, and second expansion valve 240 to facilitate transferring heat to the liquid natural gas (LNG) flowing through second refrigerant cycle / second cooling apparatus 220. Similar to first refrigerant cycle, cooling water previously used to cool carbon dioxide stream 138 being compressed in compression train 170 of carbon capture system 134 flows from outlet conduit(s) 180 towards second condenser 238, wherein heat is transferred from the cooling water to second working fluid 242. Second working fluid 242 in turn flows to second evaporator 234 wherein it transfers the heat to liquid natural gas (LNG) channeled to second refrigerant cycle / second cooling apparatus 220 via first intermediate conduit 232. Subsequently, the energy / heat exchange in second evaporator 234 cools and / or facilitates reducing the temperature of second working fluid 242, which is subsequently returned to second condenser 238 to facilitate cooling the cooling water before it enters inlet conduit(s) 176 of cooling assembly 174.

[0038] In the exemplary embodiment, the first working fluid 230 of first cooling apparatus 218 and the second working fluid 242 of second cooling apparatus 220 are distinct materials. For example, the first working fluid 230 can be formed as carbon dioxide (CO2), and the second working fluid 242 can be formed as R400 cooling fluid. However, it is understood that first working fluid 230 and second working fluid 242 can be formed from the same material. Additionally, first working fluid 230 and second working fluid 242 can be formed as any suitable working fluid utilized within refrigerant cycles including, but not limited to, carbon dioxide (CO2), R290, R134, or any other suitable hydrocarbon refrigerant. The material make-up of first working fluid 230 and second working fluid 242 can be dependent on. at least in part, the desired temperature of liquid natural gas (LNG) exiting the respective refrigerant cycle and / or the amount of heat / energy transfer taking place within first evaporator 222 / second evaporator 234, as discussed herein.

[0039] The heat exchange that takes place in the first condenser 226 of first cooling apparatus 218 and second condenser 238 of second cooling apparatus 220 facilitates reducing the temperature of the cooling water, before the cooling water is returned to inlet conduit(s) 176 of cooling assembly 174. The cooled or reduced temperature cooling waterflows through the inlet conduit(s) 176 back to compression train 170 to facilitate cooling carbon dioxide stream 138 as it is compressed. In the exemplary embodiment, and because of the temperature range in which liquid natural gas (LNG) flows through first cooling apparatus 218 and second cooling apparatus 220 (e.g.. approximately -160°C to approximately -50°C), the cooling water of cooling assembly 174 is returned to compression train 170 at a predetermined temperature to facilitate increasing the efficiency in the cooling of carbon dioxide stream 138. For example, in one embodiment, the cooling water of cooling assembly 174 flows and / or is returned to compression train 170 via inlet conduit(s) 176) at a temperature between approximately zero degrees Celsius (0°C) and approximately ten degrees Celsius (10°C). The cooling water can be cooled to and subsequently flow from first cooling apparatus 218 / first refrigerant cycle and second cooling apparatus 220 / second refrigerant cycle between approximately zero degrees Celsius (0°C) and approximately ten degrees Celsius (10°C). Alternatively, the cooling water can be cooled to two distinct temperatures in each of first cooling apparatus 218 / first refrigerant cycle and second cooling apparatus 220 / second refrigerant cycle, before being combined in inlet conduit(s) 176. Once combined, the aggregate temperature of cooling water is between approximately zero degrees Celsius (0°C) and approximately ten degrees Celsius (10°C) before the cooling water reaches compression train 170. As discussed herein, the working fluid 230, 242 within first cooling apparatus 218 / first refrigerant cycle and second cooling apparatus 220 / second refrigerant cycle can be distinct. As such, the amount of heat exchange between working fluid 230 and the cooling water withing first cooling apparatus 218 / first refrigerant cycle can be different than the amount of heat exchange between working fluid 242 and the cooling water within second cooling apparatus 220 / second refrigerant cycle. As such, the temperature in which the cooling water exits or flows from first cooling apparatus 218 / first refrigerant cycle can differ from the temperature in which the cooling water exits or is discharged from second cooling apparatus 220 / second refrigerant cycle.

[0040] Liquid natural gas (LNG) is discharged from second cooling apparatus 220. That is, regasification system 200 includes a second intermediate conduit 244 that is coupled in flow communication with second cooling apparatus 220 / second refrigerant cycle. The temperature of liquid natural gas (LNG) is facilitated to be increased after flowing through second cooling apparatus 220. As such, the temperature of liquid natural gas (LNG)flowing through second intermediate conduit 244 is higher than the temperature of liquid natural gas (LNG) flowing through first intermediate conduit 232.

[0041] In the exemplary embodiment, regasification system 200 also includes a heat exchanger 246. Heat exchanger 246 is fluidly coupled to and is downstream from second cooling apparatus 220 / second refrigerant cycle. Heat exchanger 246 is in flow communication with second intermediate conduit 244 for receiving liquid natural gas (LNG), and subsequently raising its temperature to enable the liquid natural gas (LNG) to be vaporized and / or converted to natural gas (NG). In non-limiting examples, heat exchanger 246 of regasification system 200 is in flow communication with condenser 136, heat exchanger, 137 and / or heat exchanger 139 of carbon capture system 134 via outlet conduit 208 and inlet conduit 206, respectively (see, FIG. 1). That is, in the exemplary embodiments, heat exchanger 246 is in flow communication with condenser 136, heat exchanger 137. heat exchanger 139, or any combination of condenser 136, heat exchanger 137 and heat exchanger 139 via inlet conduit(s) 206 and outlet conduit(s) 208. Similar to the heat exchange taking place in condensers 226, 238 discussed herein, heat exchanger 246 of regasification system 200 can facilitate increasing the temperature of liquid natural gas (LNG) passing therethrough to vaporize and / or convert the liquid natural gas (LNG) to natural gas (NG), while simultaneously cooling or decreasing the temperature of a working fluid used by condenser 136, heat exchanger 137, and / or heat exchanger 139 during operation of power plant 100.

[0042] In other exemplary embodiments, heat exchanger 246 of regasification system 200 is also, or alternatively, in flow communication with EGR system 182 via outlet conduit 210 and inlet conduit 212, respectively (see. FIG. 1). Similar to the heat exchange taking place in condensers 226, 238 discussed herein, heat exchanger 246 of regasification system 200 can facilitate increasing the temperature of liquid natural gas (LNG) passing therethrough to vaporize and / or convert the liquid natural gas (LNG) to natural gas (NG), while simultaneously cooling or decreasing the temperature of a working fluid used by EGR system 182 during operation of power plant 100. For example, EGR system 182 includes a heat exchanger (not shown) to facilitate the cooling of exhaust gas stream 120 from HRSG 114, before recirculating exhaust gas stream 120 back to compressor 106 of gas turbine assembly 102. The working fluid used by the heat exchanger in the EGR system 182 to cool exhaust gas stream 120 can be in flow communication with heatexchanger 246 of regasification system 200. via outlet conduit 210 and inlet conduit 212, to cool and subsequently provide the working fluid back to EGR system 182.

[0043] Additionally as shown in FIG. 2, heat exchanger 246, in the exemplary embodiment, is fluidly coupled to and / or in flow communication with fuel supply conduit 109 of power plant 100. As discussed herein, heat exchanger 246 of regasification system 200 facilitates increasing the temperature of liquid natural gas (LNG) to vaporize and / or convert liquid natural gas (LNG) to natural gas (NG). After exiting heat exchanger 246, natural gas (NG) is channeled to combustor 108 of gas turbine assembly 102 via fuel supply conduit 109 to create the fuel-air mixture discussed herein w ith respect to FIG. 1.

[0044] In the exemplary embodiment shown in FIG. 2, regasification system 200 can also include a pump 248 (shown in phantom in FIG. 2). Pump 248, in the exemplary embodiment, is in flow communication with and / or fluidly coupled to LNG conduit 204. Additionally, pump 248 is downstream from storage tank 202 and upstream from first cooling apparatus 218. In a non-limiting example, pump 248 provides or flows liquid natural gas (LNG) through LNG conduit 204 from storage tank 202 to first cooling apparatus 218 so liquid natural gas (LNG) can be vaporized to form natural gas (NG), as discussed herein. Additionally, or alternatively, pump 248 can be used to pressurize liquid natural gas (LNG) within LNG conduit 204 as it flows to first cooling apparatus 218. Pressurizing liquid natural gas (LNG) can, for example, alter (e.g., increase) an amount of heat / energy exchanged within first cooling apparatus 218 between liquid natural gas (LNG), w orking fluid 230, and cooling w ater of cooling assembly 174 within first cooling apparatus 218. As such, optimizing the pressure of liquid natural gas (LNG) can ensure regasification system 200 can convert liquid natural gas (LNG) to natural gas (NG) prior to the natural gas being channeled to combustor 108, while simultaneously ensuring the cooling w ater of cooling assembly 174 is cooled within regasification system to a predetermined and desired temperature (approximately 0°C to approximately 10°C). In another non-limiting example (see, FIG. 5), optimizing the pressure of liquid natural gas (LNG) using pump 248, as similarly discussed herein, can ensure the w orking fluid of condenser 136, heat exchanger 137, and / or heat exchanger 139 is cooled within regasification system, as discussed herein.

[0045] FIG. 3 is a schematic illustration of another exemplary power plant 100. It is understood that similarly numbered and / or named components may function in a substantially similar fashion. Redundant explanation of these components has been omitted for clarity.

[0046] In the exemplary embodiment, additional portions of carbon capture system 134 are in flow communication with and / or fluidly coupled to regasification system 200. Specifically, carbon dioxide stream 138, exhausted from stripper 144, is channeled to both compression train 170 , as well as to regasification system 200. As shown in FIG. 3, carbon dioxide stream 138 is provided to regasification 200 via carbon dioxide conduit 250.

[0047] FIG. 4 is a schematic illustration of regasification system 200 included in power plant 100 of FIG. 3. It is understood that similarly numbered and / or named components may function in a substantially similar fashion. Redundant explanation of these components has been omitted for clarity.

[0048] As shown in FIG. 4, first cooling apparatus 218 includes an apparatus or component that uses carbon dioxide stream 138 to facilitate increasing the temperature of liquid natural gas (LNG) within regasification system 200. For example, first cooling apparatus 218 includes and / or is formed as a dry ice box 252 that is in flow communication with stripper 144 of carbon capture system 134 via carbon dioxide conduit 250 (see also, FIG. 3). Dry ice box 252 of first cooling apparatus 218 receives and processes carbon dioxide stream 138 exhausted by stripper 144. For example, in the exemplary embodiment, carbon dioxide stream 138 exhausted from stripper 144 is channeled to dry ice box 252 at a temperature that is higher than that of the liquid natural gas (LNG) flowing through dry ice box 252 via LNG conduit 204. As such, the liquid natural gas (LNG) flowing through dry ice box 252 is facilitated to be heated and / or increased in temperature prior to flowing to second cooling apparatus 220 (e.g., second refrigerant cycle) via first intermediate conduit 232.

[0049] Additionally, during the heat exchange within dry ice box 252, carbon dioxide stream 138 can absorb and / or be cooled by liquid natural gas (LNG) flowing through dry ice box 252. The rapid cooling of carbon dioxide stream 138 and / or the exposure to liquid natural gas (LNG) results in an output or creation of dry ice 254. Dry ice 254 produced within and / or by dry ice box 252 can be utilized by other portions or components of power plant 100, or alternatively can be removed from power plant 100 and utilized or sold for use in any suitable means associated with dry ice 254 (e.g., food packaging / shipping).

[0050] FIG. 5 is a schematic illustration of an exemplary regasification system 200 included in power plant 100 of FIG. 1 . In the exemplary embodiment, first cooling apparatus 218 is in flow communication with and / or fluidly coupled to a distinct portion or component of power plant 100. For example, and similar to heat exchanger 246 of regasification system 200, first cooling apparatus 218 (e.g., first refrigerant cycle) is in flow communication with condenser 136 and / or heat exchanger(s) 137, 139 of carbon capture system 134 via outlet conduit 208 and inlet conduit 206, respectively (see, FIG. 1). In an exemplar}7embodiment where first cooling apparatus 218 is fluidly coupled with heat exchanger 137 of carbon capture system 134, heat exchanger 246 can be fluidly coupled to heat exchanger 139. In other non-limiting examples, an opposite configuration can be formed, and / or first cooling apparatus 218 and / or heat exchanger 246 can also or alternatively be fluidly coupled to condenser 136. As similarly discussed herein with respect to heat exchanger 246, first cooling apparatus 218 shown in FIG. 5 can facilitate increasing the temperature of liquid natural gas (LNG) passing therethrough, while simultaneously cooling or decreasing the temperature of a working fluid used to cool heat exchanger(s) 137, 139 and / or condenser 136 during operation of power plant 100. It is understood that first cooling apparatus 218 of regasification system 200 can be in flow communication to one or any combination of heat exchangers 137, 139 and condenser 136 for cooling the working fluids of each respective component during operation of power plant 100.

[0051] Additionally, or alternatively, first cooling apparatus 218 (e.g., first refrigerant cycle) can be in flow communication with EGR system 182 (e.g., working fluid of heat exchanger) of power plant 100 via outlet conduit 210 and inlet conduit 212, respectively (see, FIG. 1). In exemplar} embodiments, first cooling apparatus 218 can be in flow communication and / or fluidly coupled with only EGR system 182 or can be in flow communication with EGR sy stem 182, as well as condenser 136 and / or heat exchanger(s) 137, 139. As similarly discussed herein, first cooling apparatus 218 shown in FIG. 5 can facilitate increasing the temperature of liquid natural gas (LNG) passing therethrough, while simultaneously cooling or decreasing the temperature of a working fluid used by EGR system 182 during operation of power plant 100.

[0052] In another non-limiting example, heat exchanger 246 can also (or alternatively) be in flow communication with EGR system 182 via outlet conduit 210 and inlet conduit 212, as similarly discussed herein with respect to FIG. 2. It is understood that first cooling apparatus 218 of regasification system 200 and / or heat exchanger 246 can be in flow communication with one or any combination of heat exchangers 137. 139, condenser 136, and / or EGR system 182 for cooling the working fluids of each respective component during operation of power plant 100.

[0053] FIG. 6 is a schematic illustration of an exemplary7regasification system 200 included in power plant 100 of FIG. 3. In the exemplary embodiment, second cooling apparatus 220 is in flow communication with and / or fluidly coupled to cooling assembly 174, as well as distinct portions or components of power plant 100. That is, second cooling apparatus 220 (e.g., second refrigerant cycle) is in flow communication with cooling assembly 174 for reducing the temperature of cooling water, as similarly discussed herein with respect to FIGs. 1 and / or 4. Additionally as shown, second cooling apparatus 220 (e.g., second refrigerant cycle) is also in flow communication with condenser 136 and / or heat exchanger(s) 137, 139 of carbon capture system 134 via outlet conduit 208 and inlet conduit 206, respectively (see, FIG. 1). In an exemplary embodiment where second cooling apparatus 220 is fluidly coupled with heat exchanger(s) 137, 139 , heat exchanger 246 can be fluidly coupled to condenser 136. In other non-limiting examples, an opposite configuration can be formed, or alternatively second cooling apparatus 220 and / or heat exchanger 246 can be coupled to one of or any combination of heat exchanger(s) 137, 139 and / or condenser 136. As discussed herein with respect to heat exchanger 246, second cooling apparatus shown in FIG. 6 can facilitate increasing the temperature of liquid natural gas (LNG) passing therethrough, while simultaneously cooling or decreasing the temperature of a working fluid used to cool heat exchanger(s) 137, 139 and / or condenser 136 during operation of power plant 100, as well as reducing the temperature of the cooling water flowing included within cooling assembly 174. It is understood that second cooling apparatus 220 of regasification system 200 can be in flow communication to one or any combination of heat exchanger(s) 137, 139 and condenser 136 for cooling the working fluids of each respective component during operation of power plant 100. while also being in flow communication with cooling assembly 174, as discussed herein.

[0054] In other non-limiting examples, and as similarly discussed herein, second cooling apparatus 220 (e.g., second refrigerant cycle) and / or heat exchanger 246 can also (or alternatively) be in flow communication with EGR system 182 via outlet conduit 210 and inlet conduit 212. It is understood that second cooling apparatus 220 of regasification system 200 and / or heat exchanger 246 can be in flow communication with one or any combination of heat exchangers 137, 139, condenser 136, and / or EGR system 182 for cooling the working fluids of each respective component during operation of power plant 100.

[0055] Although carbon capture system 134 shown and discussed herein is formed as a solvent-based system, it is understood that carbon capture system 134 of power plant 100 can alternatively be formed as a sorbent-based system, a cryogenic-based system, a membrane-based system, or any other suitable system or assembly capable of extracting and / or isolating carbon from the exhaust gas generated within power plant 100.

[0056] At least one technical effect is to provide regasification systems of a combined cycle power plant that utilizes heat exchange in the regasification process to cool working / cooling fluids (e.g., cooling water) used to cooling distinct components, apparatuses, and / or systems within the power plant.

[0057] The foregoing drawings show some of the processing associated according to several embodiments of this disclosure. In this regard, each drawing or block within a flow diagram of the drawings represents a process associated with embodiments of the method described. It should also be noted that in some alternative implementations, the acts noted in the drawings or blocks may occur out of the order noted in the figure or, for example, may in fact be executed substantially concurrently or in the reverse order, depending upon the act involved. Also, one of ordinary skill in the art will recognize that additional blocks that describe the processing may be added.

[0058] The terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the disclosure. As used herein, the singular forms ’‘a”, “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise. It will be further understood that the terms “comprises” and / or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and / or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations.elements, components, and / or groups thereof. “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.

[0059] Approximating language, as used herein throughout the specification and claims, may be applied to modify any quantitative representation that could permissibly vary without resulting in a change in the basic function to which it is related. Accordingly, a value modified by a term or terms, such as “about,” “approximately” and “substantially,” are not to be limited to the precise value specified. In at least some instances, the approximating language may correspond to the precision of an instrument for measuring the value. Here and throughout the specification and claims, range limitations may be combined and / or interchanged, such ranges are identified and include all the sub-ranges contained therein unless context or language indicates otherwise. “Approximately” and / or “substantially” as applied to a particular value of a range applies to both values, and unless otherwise dependent on the precision of the instrument measuring the value, may indicate + / - 10% of the stated value(s).

[0060] The corresponding structures, materials, acts, and equivalents of all means or step plus function elements in the claims below- are intended to include any structure, material, or act for performing the function in combination with other claimed elements as specifically claimed. The description of the present disclosure has been presented for purposes of illustration and description but is not intended to be exhaustive or limited to the disclosure in the form disclosed. Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the disclosure. The embodiment was chosen and described in order to best explain the principles of the disclosure and the practical application, and to enable others of ordinary skill in the art to understand the disclosure for various embodiments with various modifications as are suited to the particular use contemplated.

[0061] Exemplary systems and methods that use a gasification system for providing heat exchange (e g., cooling) with cooling assemblies of a pow er plant are described herein. Moreover, the systems and methods described herein facilitate increasing the overall plant efficiency to a level that is higher than possible with traditional regasification systems and / or cooling methods for various components of a combined cycle power plant system. The exemplary systems and methods as described herein provide several advantages overconventional designs and processes, including increasing the efficiency and performance of regasification (e.g., evaporating) of liquid natural gas (LNG), while simultaneously increasing the efficiency and performance of cooling various components of the power plant using the heat exchanges that take place during the regasification process. For example, the above-described systems and methods facilitate the use of the low temperatures of liquid natural gas (e.g., -160°C) and the heat exchange that occurs within the regasification system to more effectively and efficiently cool working / cooling fluids of cooling assemblies within the power plant. Moreover, the above-described systems and methods enable multiple cooling assemblies for multiple components of the power plant to utilize the heat exchange within the regasification system to more effectively and efficiently cool working / cooling fluids. Furthermore, the above-described systems and methods facilitate the regasification system to produce secondary7marketable byproducts (e.g., dry ice) while simultaneously providing the increased efficiency and performance for the power plant, as discussed herein.

[0062] 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. The systems described herein are not limited to the specific embodiments described herein, but rather portions of the various systems may be utilized independently and separately from other systems described herein.

[0063] Although specific features of various embodiments of the invention may be shown in some drawings and not in others, this is for convenience only. Moreover, references to “one embodiment” in the above description are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features. In accordance with the principles of the invention, any feature of a drawing may be referenced and / or claimed in combination with any feature of any other drawing.

[0064] Further aspects of the invention are provided by the subject matter of the following clauses:

[0065] A regasification system, comprising a first cooling apparatus in flow communication with a liquid natural gas (LNG) conduit for receiving liquid natural gas (LNG), a second cooling apparatus in flow communication and dow nstream from the first cooling apparatus, the second cooling apparatus in flow communication with a cooling assembly that uses cooling water to facilitate cooling a carbon dioxide stream flowing through a compression train of a carbon capture system, and a heat exchanger in flow communication and downstream from the second cooling apparatus, the heat exchanger in flow communication with a combustor of a gas turbine assembly.

[0066] The regasification system of in accordance with any of the preceding clauses, wherein the first cooling apparatus includes a first refrigerant cycle including a first evaporator in communication with the LNG conduit, a first compressor in flow communication with the first evaporator, a first condenser in flow communication with the first compressor, wherein the first condenser is in flow communication with at least one of the cooling assembly, a carbon capture condenser, a carbon capture heat exchanger, and a cooler betw een a heat recovery steam generator (HRSG) and the carbon capture system, and a first expansion valve betw een the first condenser and the first evaporator.

[0067] The regasification system in accordance with any of the preceding clauses, wherein the heat exchanger is in flow communication with at least one of the carbon capture condenser, the carbon capture heat exchanger, and the cooler between the HRSG and the carbon capture system.

[0068] The regasification system in accordance with any of the preceding clauses, wherein the second cooling apparatus includes a second refrigerant cycle including a second evaporator, a second compressor in flow communication with the second evaporator, a second condenser in flow communication with the second compressor, the second condenser in flow communication with the cooling assembly, and a second expansion valve between the second condenser and the second evaporator.

[0069] The regasification system in accordance with any of the preceding clauses, wherein the second condenser is in flow communication with one of the carbon capture condenser, the carbon capture heat exchanger, and the cooler between the HRSG and the carbon capture system.

[0070] The regasification system in accordance with any of the preceding clauses, wherein the cooling water of the cooling assembly flows from at least one of the first refrigerant cycle or the second refrigerant cycle at a temperature between approximately zero degrees Celsius (0°C) and approximately ten degrees Celsius (10°C).

[0071] The regasification system in accordance with any of the preceding clauses, wherein the first refrigerant cycle further includes a first working fluid flowing between the first evaporator, the first compressor, the first condenser and the first expansion valve, and wherein the second refrigerant cycle further includes a second working fluid flowing between the second evaporator, the second compressor, the second condenser and the second expansion valve, the second working fluid being distinct from the first working fluid.

[0072] The regasification system in accordance with any of the preceding clauses, wherein the first cooling apparatus includes a dry ice box in flow communication with the carbon capture system, the dry ice box receiving a carbon dioxide stream discharged from the carbon capture system.

[0073] The regasification system in accordance with any of the preceding clauses, further comprising a pump in flow communication with and downstream from the liquid natural gas conduit, the pump selectively adjusting a pressure of the LNG flowing through the liquid natural gas conduit.

[0074] The regasification system in accordance with any of the preceding clauses, wherein the liquid natural gas conduit is in flow communication with a storage tank.

[0075] A combined cycle power plant, comprising a gas turbine assembly including: a combustor, and a turbine in flow communication with the combustor, wherein the turbine discharges a first exhaust gas stream, a heat recovery steam generator (HRSG) in flow communication with the turbine for receiving the first exhaust gas stream and discharging a second exhaust gas stream, a carbon capture system in flow communication with the HRSG for receiving the second exhaust gas stream, the carbon capture system including: a compression train receiving and compressing a generated carbon dioxide stream, and a cooling assembly in flow communication with the compression train, the cooling assembly using cooling water to facilitate cooling the carbon dioxide stream compressed by the compression train, a regasification system in flow communication with the cooling assembly, the regasification system including: a first cooling apparatus in flowcommunication with a liquid natural gas (LNG) conduit for receiving liquid natural gas (LNG), a second cooling apparatus in flow communication and downstream from the first cooling apparatus, the second cooling apparatus in flow communication with the cooling assembly, and a heat exchanger in flow communication and downstream from the second cooling apparatus, the heat exchanger in flow communication with the combustor of the gas turbine assembly.

[0076] The combined cycle power plant in accordance with any of the preceding clauses, wherein the first cooling apparatus of the regasification system includes a first refrigerant cycle including a first evaporator in communication with the LNG conduit, a first compressor in flow communication with the first evaporator, a first condenser in flow communication with the first compressor, wherein the first condenser is in flow communication with at least one of the cooling assembly, a carbon capture condenser of the carbon capture system, a carbon capture heat exchanger of the carbon capture system, and a cooler between the HRSG and the carbon capture system, and a first expansion valve between the first condenser and the first evaporator.

[0077] The combined cycle power plant in accordance with any of the preceding clauses, wherein the heat exchanger is in flow communication with at least one of the carbon capture condenser, the carbon capture heat exchanger, and the cooler between the HRSG and the carbon capture system.

[0078] The combined cycle power plant in accordance with any of the preceding clauses, wherein the second cooling apparatus of the regasification system includes a second refrigerant cycle including a second evaporator, a second compressor in flow communication with the second evaporator, a second condenser in flow communication with the second compressor, the second condenser in flow communication with the cooling assembly, and a second expansion valve between the second condenser and the second evaporator.

[0079] The combined cycle power plant in accordance with any of the preceding clauses, w herein the second condenser is in flow communication with one of the carbon capture condenser, the carbon capture heat exchanger, and the cooler between the HRSG and the carbon capture system.

[0080] The combined cycle power plant in accordance with any of the preceding clauses, wherein the first refrigerant cycle further includes a first working fluid flowing between the first evaporator, the first compressor, the first condenser and the first expansion valve, and wherein the second refrigerant cycle further includes a second working fluid flowing between the second evaporator, the second compressor, the second condenser and the second expansion valve, the second working fluid being distinct from the first working fluid.

[0081] The combined cycle power plant in accordance with any of the preceding clauses, wherein the cooling water of the cooling assembly flows from at least one of the first refrigerant cycle or the second refrigerant cycle at a temperature between approximately zero degrees Celsius (0°C) and approximately ten degrees Celsius (10°C).

[0082] The combined cycle power plant in accordance with any of the preceding clauses, wherein the first cooling apparatus includes a dry ice box in flow communication with the carbon capture system, the dry ice box receiving a portion of the carbon dioxide stream.

[0083] The combined cycle power plant in accordance with any of the preceding clauses, wherein the regasification system further includes a pump in flow communication with and downstream of the liquid natural gas conduit, the pump selectively adjusting a pressure of the LNG flowing through the liquid natural gas conduit.

[0084] The combined cycle power plant in accordance with any of the preceding clauses, further comprising an LNG storage tank in flow communication with the liquid natural gas conduit of the regasification system.

Claims

CLAIMSWhat is claimed is:

1. A regasification system, comprising: a first cooling apparatus in flow communication with a liquid natural gas (LNG) conduit for receiving liquid natural gas (LNG); a second cooling apparatus in flow communication and downstream from the first cooling apparatus, the second cooling apparatus in flow communication with a cooling assembly that uses cooling water to facilitate cooling a carbon dioxide stream flowing through a compression train of a carbon capture system; and a heat exchanger in flow communication and dow nstream from the second cooling apparatus, the heat exchanger in flow communication with a combustor of a gas turbine assembly.

2. The regasification system of claim 1, wherein the first cooling apparatus includes a first refrigerant cycle including: a first evaporator in communication with the LNG conduit; a first compressor in flow communication with the first evaporator; a first condenser in flow communication with the first compressor, wherein the first condenser is in flow communication with and cools a w orking fluid used by at least one of: the cooling assembly, a carbon capture condenser, a carbon capture heat exchanger, and an exhaust gases recirculation (EGR) system in flow' communication with a heat recovery steam generator (HRSG) ; anda first expansion valve between the first condenser and the first evaporator.

3. The regasification system of claim 2, wherein the heat exchanger is in flow communication with and cools the working fluid used by at least one of the carbon capture condenser, the carbon capture heat exchanger, and the EGR system in flow communication with the HRSG.

4. The regasification system of claim 2, wherein the second cooling apparatus includes a second refrigerant cycle including: a second evaporator; a second compressor in flow communication with the second evaporator; a second condenser in flow communication with the second compressor, the second condenser in flow communication with the cooling assembly; and a second expansion valve between the second condenser and the second evaporator.

5. The regasification system of claim 4, wherein the second condenser is in flow communication with and cools the working fluid used by at least one of: the carbon capture condenser, the carbon capture heat exchanger, and the EGR system in flow communication with the HRSG.

6. The regasification system of claim 4, wherein the cooling water of the cooling assembly flows from at least one of the first refrigerant cycle or the second refrigerant cycle at a temperature between approximately zero degrees Celsius (0°C) andapproximately ten degrees Celsius (10°C).

7. The regasification system of claim 4, wherein the first refrigerant cycle further includes a first working fluid flowing between the first evaporator, the first compressor, the first condenser and the first expansion valve, and wherein the second refrigerant cycle further includes a second working fluid flowing between the second evaporator, the second compressor, the second condenser and the second expansion valve, the second working fluid being distinct from the first working fluid.

8. The regasification system of claim 1, wherein the first cooling apparatus includes a dry ice box in flow communication with the carbon capture system, the dry ice box receiving a carbon dioxide stream discharged from the carbon capture system.

9. The regasification system of claim 1, further comprising: a pump in flow communication with and downstream from the liquid natural gas conduit, the pump selectively adjusting a pressure of the LNG flowing through the liquid natural gas conduit.

10. The regasification system of claim 1, wherein the liquid natural gas conduit is in flow communication with a storage tank.

11. A combined cycle power plant comprising: a gas turbine assembly including: a combustor; and a turbine in flow communication with the combustor, wherein the turbinedischarges a first exhaust gas stream; a heat recovery steam generator (HRSG) in flow communication with the turbine for receiving the first exhaust gas stream and discharging a second exhaust gas stream; a carbon capture system in flow communication with the HRSG for receiving the second exhaust gas stream, the carbon capture system including: a compression train receiving and compressing a generated carbon dioxide stream ; and a cooling assembly in flow communication with the compression train, the cooling assembly using cooling water to facilitate cooling the carbon dioxide stream compressed by the compression train; and a regasification system in flow communication with the cooling assembly, the regasification system including: a first cooling apparatus in flow communication with a liquid natural gas (LNG) conduit for receiving liquid natural gas (LNG); a second cooling apparatus in flow communication and downstream from the first cooling apparatus, the second cooling apparatus in flow communication with the cooling assembly; and a heat exchanger in flow communication and downstream from the second cooling apparatus, the heat exchanger in flow communication with the combustor of the gas turbine assembly.

12. The combined cycle power plant of claim 11, wherein the first cooling apparatus of the regasification system includes a first refrigerant cycle including: a first evaporator in communication with the LNG conduit;a first compressor in flow communication with the first evaporator; a first condenser in flow communication with the first compressor, wherein the first condenser is in flow communication with and cools a working fluid used by at least one of: the cooling assembly, a carbon capture condenser of the carbon capture system, a carbon capture heat exchanger of the carbon capture system, and an exhaust gases recirculation (EGR) system in flow communication with the HRSG; and a first expansion valve between the first condenser and the first evaporator.

13. The combined cycle power plant of claim 12, wherein the heat exchanger is in flow communication with and cools the working fluid used by at least one of: the carbon capture condenser, the carbon capture heat exchanger, and the EGR system in flow communication with the HRSG.

14. The combined cycle power plant of claim 12, wherein the second cooling apparatus of the regasification system includes a second refrigerant cycle including: a second evaporator; a second compressor in flow7communication with the second evaporator; a second condenser in flow communication with the second compressor, the second condenser in flow communication with the cooling assembly; and a second expansion valve between the second condenser and the second evaporator.

15. The combined cycle power plant of claim 14, wherein the second condenser is in flow communication with and cools a working fluid used by at least one of: the carbon capture condenser, the carbon capture heat exchanger, and the EGR system in flow communication with the HRSG.

16. The combined cycle power plant of claim 14, wherein the first refrigerant cycle further includes a first working fluid flowing between the first evaporator, the first compressor, the first condenser and the first expansion valve, and wherein the second refrigerant cycle further includes a second working fluid flowing between the second evaporator, the second compressor, the second condenser and the second expansion valve, the second working fluid being distinct from the first working fluid.

17. The combined cycle power plant of claim 14, wherein the cooling water of the cooling assembly flows from at least one of the first refrigerant cycle or the second refrigerant cycle at a temperature between approximately zero degrees Celsius (0°C) and approximately ten degrees Celsius (10°C).

18. The combined cycle power plant of claim 11 , wherein the first cooling apparatus includes a dry ice box in flow communication with the carbon capture system, the dry ice box receiving a portion of the carbon dioxide stream.

19. The combined cycle power plant of claim 11, wherein the regasification system further includes: a pump in flow communication with and downstream of the liquid natural gas conduit, the pump selectively adjusting a pressure of the LNG flowing through the liquid natural gas conduit.

20. The combined cycle power plant of claim 11, further comprising: an LNG storage tank in flow communication with the liquid natural gas conduit of the regasification system.

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