HIGH TEMPERATURE GAS COMPRESSOR, SYSTEMS, AND METHODS THEREOF

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to U.S. Provisional Patent Application No. 63/701,249, filed September 30, 2024, and titled “Small Modular Reactor Driven Utilization to Support Net-Zero Carbon Dioxide Emission,” which is incorporated herein by reference in its entirety.

BACKGROUND

A third of the total energy produced in the United States is used for industry. The largest portion of the energy used by industry is used in the form of heat produced by combustion of fossil fuels, which causes the generation of greenhouse gases that are hard to abate.

Currently, nuclear power plants are capable of providing steady supplies of superheated steam at approximately 300°C. Presently, compressor technology may be used to provide superheated steam at approximately 400°C. However, a number of industrial applications, including petrochemical processing industries, require supplies of steam and/or heat at even higher temperatures (e.g., 500°C or more). Accordingly, new technology is required to provide a steady superheated steam supply for industrial processes.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 schematically illustrates a Small Modular Nuclear Reactor (SMR) system integrated with an industrial process, according to an embodiment of this disclosure.

FIG. 2 schematically illustrates an SMR system integrated with an auxiliary heater and an industrial processing plant, according to an embodiment of this disclosure.

FIG. 3 schematically illustrates an SMR system integrated with an industrial processing plant, according to an embodiment of this disclosure.

FIG. 4 schematically illustrates a side cross-sectional view of a compressor, according to an embodiment of this disclosure.

FIG. 5 schematically illustrates a side cross-sectional view of a compressor, according to an embodiment of this disclosure.

FIG. 6 is a partial schematic, partial cross-sectional view of a nuclear reactor system configured in accordance with embodiments of the present technology.

FIG. 7 is a partial schematic, partial cross-sectional view of a nuclear reactor system configured in accordance with additional embodiments of the present technology.

FIG. 8 is a schematic view of a nuclear power plant system including multiple nuclear reactors in accordance with embodiments of the present technology.

DETAILED DESCRIPTION

Overview

The Detailed Description is set forth with reference to the accompanying figures. In the figures, the left-most digit(s) of a reference number identifies the figure in which the reference number first appears. The use of the same reference numbers in different figures indicates similar or identical items. Furthermore, the drawings may be considered as providing an approximate depiction of the relative sizes of the individual components within individual figures. However, the drawings are not to scale, and the relative sizes of the individual components, both within individual figures and between the different figures, may vary from what is depicted. In particular, some of the figures may depict components as a certain size or shape, while other figures may depict the same components on a larger scale or differently shaped for the sake of clarity.

Illustrative Embodiments

FIG. 1 schematically illustrates a Small Modular Nuclear Reactor (SMR) system 100 (“system 100”) integrated with an industrial process 102.

In an embodiment, the system 100 may include a primary loop 104 (e.g., first loop, reactor loop, etc.). In an embodiment, the primary loop 104 may include a power plant system 106, a boiling heat exchanger 108 (e.g., first heat exchanger, etc.), a recovery heat exchanger 110 (e.g., second heat exchanger, etc.), and a feedwater system 112.

In an embodiment, the power plant system 106 may produce steam that is directed to the boiling heat exchanger 108. The boiling heat exchanger 108 may convert the main steam into primary condensate that is directed to the recovery heat exchanger 110. The primary condensate entering the recovery heat exchanger 110 may transfer heat to the recovery heat exchanger 110 and exit as cooled primary condensate. The cooled primary condensate may be directed to a feedwater system 112. In an embodiment, the feedwater system 112 may include multiple components (e.g., pump(s), valve(s), heat exchanger(s), etc.), and may include multiple feedwater systems and/or sub-systems (e.g., turbine exhaust condensate, external feedwater source, etc.), collectively referred to as feedwater system 112. The cooled primary condensate may exit the feedwater system 112 as feedwater. The feedwater may enter the power plant system 106 and be converted into the main steam.

In an embodiment, the system 100 may include a secondary loop 114 (e.g., second loop, steam loop, etc.). In an embodiment, the secondary loop 114 may include the boiling heat exchanger 108, the recovery heat exchanger 110, a steam compressor 116, and the industrial process 102. In an embodiment, the secondary loop 114 may include auxiliary heater 118. While described in this disclosure as singular, one or more components of system 100 may include more than one component (i.e., auxiliary heater 118 may include more than one auxiliary heater, etc.).

In an embodiment, supply steam may enter the steam compressor 116. The steam compressor 116 may pressurize the supply steam and produce pressurized steam. As the steam is pressurized, the temperature of the steam will increase as the pressure of the steam increases. In an embodiment, the pressurized steam may be directed to the industrial process 102 (e.g., petrochemical plant, chemical production plant, etc.) without additional, or augmented, heat. In an embodiment, the pressurized steam may be directed to the auxiliary heater 118 for heat augmentation in order to produce heat-augmented pressurized steam. For example, the industrial process 102 may require pressurized steam at a particular temperature for a specific process in excess of the steam temperature when the pressurized steam is produced by the steam compressor 116. In an embodiment, the heat-augmented pressurized steam may be directed to the industrial process 102.

The industrial process 102 may utilize the pressurized steam and/or the heat-augmented pressurized steam, as required, and discharge secondary condensate. The secondary condensate may exit the industrial process 102 and be directed to the recovery heat exchanger 110. The recovery heat exchanger 110 may be configured to transfer heat from the primary condensate into the secondary condensate. In an embodiment, the heat transferred from the primary condensate may be transferred, via the recovery heat exchanger 110, into the secondary condensate to generate the heated secondary condensate. The secondary condensate may enter the recovery heat exchanger 110 and exit as heated secondary condensate that may be directed to the boiling heat exchanger 108.

In an embodiment, the heated secondary condensate may enter the boiling heat exchanger 108 and receive, via the boiling heat exchanger 108, heat from the main steam. The heat from the main steam may cause the heated secondary condensate to boil within the boiling heat exchanger 108. The resulting supply steam may be directed to the steam compressor 116.

FIG. 2 schematically illustrates an SMR system 200 (“system 200”) integrated with an auxiliary heater 202 and an industrial processing plant 204. In an embodiment, the system 200 may include a first loop 206 (e.g., primary loop, primary steam loop, first steam loop, etc.) and a second loop 208 (e.g., secondary loop, secondary steam loop, second steam loop, etc.). In an embodiment, the first loop 206 may include a power plant system 210, a first heat exchanger 212 (e.g., boiling heat exchanger, etc.), a second heat exchanger 214 (e.g., recovery heat exchanger, pre-heat heat exchanger, etc.), and a pump 216 (e.g., first pump, primary feedwater pump, first feedwater pump, first feed pump, first condensate pump, etc.). The primary feedwater pump 216 may be a centrifugal pump, a positive displacement pump, a single-stage pump, a multi-stage pump, steam-driven, electrically driven, or may have any other operating characteristics as required.

In an embodiment of the first loop 206, the power plant system 210 may produce first steam 218 (e.g., primary steam, main steam, etc.) that is directed to the first heat exchanger 212. The primary steam 218 may transfer sufficient heat to the first heat exchanger 212 to be condensed into warm feedwater 220 (i.e., feedwater that is warmer than ambient temperature water, but not warm enough to become steam, at the operating pressure) within the first heat exchanger 212. The warm feedwater 220 (e.g., primary condensate, primary feedwater, etc.) may be directed to the second heat exchanger 214.

In an embodiment, the warm feedwater 220 may transfer heat to the second heat exchanger 214 such that the warm feedwater 220 may be converted to cooled feedwater 222 (i.e., feedwater that is cooler than the warm feedwater 220) that is directed to the primary feedwater pump 216. In an embodiment, the primary feedwater pump 216 may receive that cooled feedwater 222 and discharge pressurized feedwater 224. In an embodiment, the primary feedwater pump 216 may be adjusted such that the pressurized feedwater 224 has a specific pressure and/or range of pressures, as required. The power plant system 210 may receive the pressurized feedwater 224 and produce the primary steam 218.

In an embodiment, the second loop 208 may include a steam compressor 226, the auxiliary heater 202, the industrial processing plant 204, a pump 228 (e.g., secondary feedwater pump, second feedwater pump, second feed pump, second condensate pump, etc.), the second heat exchanger 214, and the first heat exchanger 212. In an embodiment, the secondary feedwater pump 228 may be a centrifugal pump, a positive displacement pump, a single-stage pump, a multi-stage pump, steam-driven, electrically driven, or may have any other operating characteristics as required.

In an embodiment of the second loop 208, the steam compressor 226 may receive superheated steam 230 (e.g., supply steam, first steam, inlet steam, etc.) from the first heat exchanger 212 at a first pressure. The steam compressor 226 may pressurize the superheated steam 230 to generate first high pressure superheated steam 232. The first high pressure superheated steam 232 may be at a pressure that is higher than the pressure of the superheated steam 230. In an embodiment, the steam compressor 226 may produce the first high pressure superheated steam 232 at any pressure, as desired. For example, if superheated steam is required to be at a particular pressure for a specific industrial process, the steam compressor 226 may receive superheated steam 230 at a first pressure and produce first high pressure superheated steam 232 at the particular pressure, as required by the specific industrial process.

In an embodiment, the first high pressure superheated steam 232 may be at a first temperature. The first high pressure superheated steam 232 may be directed to the auxiliary heater 202 at the first temperature. The auxiliary heater 202 may receive the first high pressure superheated steam 232 at the first temperature and generate second high pressure superheated steam 234 at a second temperature, wherein the second high pressure superheated steam 234 is at a higher temperature than the first high pressure superheated steam 232. For example, if pressurized superheated steam is required to be at a particular temperature for a specific industrial process, the auxiliary heater 202 may raise the temperature of the pressurized superheated steam to the particular temperature, as required for the specific industrial process. The second high pressure superheated steam 234 may be directed to the industrial processing plant 204.

In an embodiment, the industrial processing plant 204 may receive the second high pressure superheated steam 234. The industrial processing plant 204 may include a petrochemical plant, a chemical production plant, or any other production and/or processing plant that requires steam. The industrial processing plant 204 may receive the second high pressure superheated steam 234, utilize the second high pressure superheated steam 234, and discharge secondary feedwater 236 (e.g., condensate, secondary condensate, etc.). The secondary feedwater pump 228 may receive the secondary feedwater 236 and discharge pressurized secondary feedwater 238. The pressurized secondary feedwater 238 may be directed to the second heat exchanger 214.

In an embodiment, the second heat exchanger 214 may transfer heat from the warm feedwater 220 into the pressurized secondary feedwater 238 to generate pre-heated secondary feedwater 240. The pre-heated secondary feedwater 240 may be directed to the first heat exchanger 212. The pre-heated secondary feedwater 240 may absorb, via the first heat exchanger 212, heat from the primary steam 218. By transferring heat from the primary steam 218 to the pre-heated secondary feedwater 240, the first heat exchanger 212 may generate the superheated steam 230.

FIG. 3 schematically illustrates an SMR system 300 (“system 300”) integrated with an industrial processing plant 302. In an embodiment, the system 300 may include a first loop 304 (e.g., primary loop, primary steam loop, first steam loop, etc.) and a second loop 306 (e.g., secondary loop, secondary steam loop, second steam loop, etc.). In an embodiment, the first loop 304 may include a power plant system 308, a first heat exchanger 310 (e.g., boiling heat exchanger, etc.), a second heat exchanger 312 (e.g., recovery heat exchanger, pre-heat heat exchanger, etc.), and a pump 314 (e.g., first pump, primary feedwater pump, first feedwater pump, first feed pump, first condensate pump, etc.). The primary feedwater pump 314 may be a centrifugal pump, a positive displacement pump, a single-stage pump, a multi-stage pump, steam-driven, electrically driven, or may have any other operating characteristics as required.

In an embodiment of the first loop 304, the power plant system 308 may produce first steam 316 (e.g., primary steam, main steam, etc.) that is directed to the first heat exchanger 310. The primary steam 316 may transfer sufficient heat to the first heat exchanger 310 to be condensed into warm feedwater 318 (i.e., feedwater that is warmer than ambient temperature water, but not warm enough to become steam, at the operating pressure) within the first heat exchanger 310. The warm feedwater 318 (e.g., primary condensate, primary feedwater, etc.) may be directed to the second heat exchanger 312.

In an embodiment, the warm feedwater 318 may transfer heat to the second heat exchanger 312 such that the warm feedwater 318 may be converted to cooled feedwater 320 (i.e., feedwater that is cooler than the warm feedwater 318) that is directed to the primary feedwater pump 314. In an embodiment, the primary feedwater pump 314 may receive that cooled feedwater 320 and discharge pressurized feedwater 322. In an embodiment, the primary feedwater pump 314 may be adjusted such that the pressurized feedwater 322 has a specific pressure and/or range of pressures, as required. The power plant system 308 may receive the pressurized feedwater 322 and produce the primary steam 218.

In an embodiment, the second loop 306 may include a steam compressor 324, the industrial processing plant 302, a pump 326 (e.g., secondary feedwater pump, second feedwater pump, second feed pump, second condensate pump, etc.), the second heat exchanger 312 and the first heat exchanger 310. In an embodiment, the secondary feedwater pump 326 may be a centrifugal pump, a positive displacement pump, a single-stage pump, a multi-stage pump, steam-driven, electrically driven, or may have any other operating characteristics as required.

In an embodiment of the second loop 306, the steam compressor 324 may receive superheated steam 230 from the first heat exchanger 212 at a first pressure. The steam compressor 226 may pressurize the superheated steam 328 to generate first high pressure superheated steam 330. The first high pressure superheated steam 330 may be at a pressure that is higher than the pressure of the superheated steam 328. In an embodiment, the steam compressor 324 may produce the high pressure superheated steam 330 at any pressure, as desired. For example, if superheated steam is required to be at a particular pressure for a specific industrial process, the steam compressor 324 may receive superheated steam 328 at a first pressure and produce pressurized superheated steam 330 at the particular pressure, as required by the specific industrial process.

In an embodiment, the high pressure superheated steam 330 may be directed to the industrial processing plant 302. In an embodiment, the industrial processing plant 302 may receive the high pressure superheated steam 330. The industrial processing plant 302 may include a petrochemical plant, a chemical production plant, or any other production and/or processing plant that requires steam. The industrial processing plant 302 may receive the high pressure superheated steam 330, utilize the high pressure superheated steam 330, and discharge secondary feedwater 332 (e.g., condensate, secondary condensate, etc.). The secondary feedwater pump 326 may receive the secondary feedwater 332 and discharge pressurized secondary feedwater 334. The pressurized secondary feedwater 334 may be directed to the second heat exchanger 312.

In an embodiment, the second heat exchanger 312 may transfer heat from the warm feedwater 318 into the pressurized secondary feedwater 334 to generate pre-heated secondary feedwater 336. The pre-heated secondary feedwater 336 may be directed to the first heat exchanger 310. The pre-heated secondary feedwater 336 may absorb, via the first heat exchanger 310, heat from the primary steam 316. By transferring heat from the primary steam 316 to the pre-heated secondary feedwater 336, the first heat exchanger 310 may generate the superheated steam 328.

FIG. 4 schematically illustrates a side cross-sectional view of a gas (e.g., steam) compressor 400 (“compressor 400”). In an embodiment, the compressor 400 may include an inlet 402 (e.g., low-temperature steam input, low pressure steam inlet, low-temperature gas input, low pressure gas inlet, etc.), a discharge 404 (e.g., high-temperature steam outlet, high-pressure steam outlet, high-pressure steam outlet, etc.), and a shaft 406 extending through the compressor 400. In an embodiment, the compressor 400 may include a first stage 408 (e.g., inlet stage) having a first impeller 410, a second stage 412 having a second impeller 414, a third stage 416 having a third impeller 418, a fourth stage 420 having a fourth impeller 422, a fifth stage 424 having a fifth impeller 426, and a sixth stage 428 (e.g., outlet stage) having a sixth impeller 430. Although described herein as having six stages, the compressor 400 may include any number of stages as desired with each stage having a corresponding impeller. For example, a compressor with seven stages may include seven impellers, a compressor with eight stages may include eight impellers, and so on.

In an embodiment, the shaft 406 may extend continuously through each stage (408, 412, 416, 420, 424, 428) and each corresponding impeller (410, 414, 418, 422, 426, 430). In an embodiment, each impeller (410, 414, 418, 422, 426, 430) may be coupled to the shaft 406. The shaft 406 may be configured to rotate within the compressor 400, which may, in turn, rotate each impeller (410, 414, 418, 422, 426, 430).

In an embodiment, the compressor 400 may receive steam via the inlet 402 at a first pressure and a first temperature. For example, the steam supplied to the compressor may be directed from a steam supply system (e.g., a nuclear power plant, etc.) at a first pressure and a first temperature. The compressor 400 may process the steam to a specific second pressure and second temperature, as required, for downstream processing. For example, a chemical production plant may require a continuous supply of steam at an extremely high-pressure and at an extremely high temperature for a specific process. In this example, the compressor 400 may be used to convert readily available steam (e.g., steam produced by a small modular nuclear power plant) to the pressure and temperature parameters required for the specific process.

In an embodiment, a fluid (e.g., steam) may flow through the compressor 400 such that the temperature and pressure of the fluid may incrementally increase as the fluid flows through each stage of the compressor. For example, steam may enter the first stage 408, via the inlet 402, at a first pressure and exit the first stage 408 at a second pressure that is higher than the first pressure. The steam may enter the second stage 412 at the second pressure and exit the second stage 412 at a third pressure that is higher than the second pressure. The steam may enter the third stage 416 at the third pressure and exit third stage 416 at a fourth pressure that is higher than the third pressure. The steam may enter the fourth stage 420 at the fourth pressure and exit fourth stage 420 at a fifth pressure that is higher than the fourth pressure. The steam may enter the fifth stage 424 at the fifth pressure and exit the fifth stage 424 at a sixth pressure that is higher than the fifth pressure. The steam may enter the sixth stage 428 at the sixth pressure and exit the sixth stage 428 at a seventh pressure that is higher than the sixth pressure. The compressor 400 may discharge the steam at the seventh pressure via the discharge 404.

In an embodiment, the steam may enter the first stage 408 at a first temperature and exit the first stage 408 at a second temperature that is higher than the first temperature. The steam may enter the second stage 412 at the second temperature and exit the second stage 412 at a third temperature that is higher than the second temperature. The steam may enter the third stage 416 at the third temperature and exit third stage 416 at a fourth temperature that is higher than the third temperature. The steam may enter the fourth stage 420 at the fourth temperature and exit fourth stage 420 at a fifth temperature that is higher than the fourth temperature. The steam may enter the fifth stage 424 at the fifth temperature and exit the fifth stage 424 at a sixth temperature that is higher than the fifth temperature. The steam may enter the sixth stage 428 at the sixth temperature and exit the sixth stage 428 at a seventh temperature that is higher than the sixth temperature. The compressor 400 may discharge the steam at the temperature pressure via the discharge 404.

In an embodiment, at least one impeller within the compressor 400 (e.g., impeller 410, impeller 414, impeller 418, and/or impeller 422) may be made of a first material 432 (e.g., low-temperature material, etc.) and may include a series of impeller/diffuser blades made of the first material 432. In an embodiment, the first material 432 may include an aluminum alloy, titanium alloy, stainless steel alloy, nickel alloy, or any other suitable material. In an embodiment, the first material 432 may be configured to withstand temperatures of at least 300℃. In an embodiment, the impeller/diffuser blades 434 may be aerodynamically configured. For example, the impeller/diffuser blades 434 may be arranged within the impeller (410, 414, 418, 422) to dissipate heat, increase pressure, and/or direct flow.

In an embodiment, at least one impeller within the compressor 400 (e.g., impeller 426) may be made of a second material 436 (e.g., high-temperature material, etc.) and may include a series of impeller/diffuser blades 438 made of the second material 436. In an embodiment, the second material 436 may include aluminum alloys, titanium alloys, stainless steel alloys, or any other reasonable material and/or a combination thereof. In an embodiment, the impeller/diffuser blades 438 may be aerodynamically configured. In an embodiment, the first material 432 may be configured to withstand temperatures of at least 300℃. For example, the impeller/diffuser blades 438 may be arranged within the impeller 426 to dissipate heat, increase pressure, and/or direct flow.

In an embodiment, at least one impeller within the compressor 400 (e.g., impeller 430) may be made of a third material 440 (e.g., extreme high-temperature material, highest temperature material, etc.) and may include a series of impeller/diffuser blades 442 made of the third material 440. In an embodiment, the third material 440 may include Oxide Dispersion Strengthened (ODS) alloys (e.g., GRX-810, nickel ODS alloys, iron ODS alloys, aluminum ODS alloys, etc.) or any other reasonable material and/or a combination thereof. In an embodiment, the third material 440 may be configured to withstand temperatures of at least 300℃ and may be configured to withstand temperatures of approximately 650℃ or more. In an embodiment, the impeller/diffuser blades 438 may be aerodynamically configured. For example, the impeller/diffuser blades 438 may be arranged within the impeller 426 to dissipate heat, increase pressure, and/or direct flow.

In an embodiment, one or more impellers (410, 414, 418, 422, 426, 430) may be produced via metallic additive manufacturing (e.g., laser powder bed fusion, electron beam powder bed fusion, direct energy deposition, etc.). In an embodiment, the impeller/diffuser blades (434, 438, 442) may have a complex aerodynamic arrangement that may be more cost-effectively produced via metallic additive manufacturing.

FIG. 5 schematically illustrates a side cross-sectional view of a gas compressor 500 (“compressor 500”). In an embodiment, the compressor 500 may include an inlet 502 (e.g., low-temperature steam input, low pressure steam inlet, low-temperature gas input, low pressure gas inlet, etc.), a discharge 504 (e.g., high-temperature steam outlet, high-pressure steam outlet, high-pressure steam outlet, etc.), and a shaft 506 (e.g., first shaft, primary shaft, main shaft, etc.) extending through the compressor 500.

In an embodiment, the compressor 500 may include a first stage 508 having a first impeller 510, a second stage 512 having a second impeller 514, a third stage 516 having a third impeller 518, a fourth stage 520 having a fourth impeller 522, a fifth stage 524 having a fifth impeller 526 and a gearset 528 (e.g., first gearset, first pressure controller, first speed controller, clutch assembly, etc.), and a sixth stage 530 having a sixth impeller 532 and a gearset 534 (e.g., second gearset, second pressure controller, second speed controller, clutch assembly, etc.).

Although described herein as having six stages (e.g., 508, 512, 516, 520, 524, and 530), the compressor 500 may include any number of stages as desired with each stage having a corresponding impeller. For example, a compressor with seven stages may include seven impellers, a compressor with eight stages may include eight impellers, and so on. Although depicted with only two gearsets (528 and 534), the compressor 500 may include a gear set for any number of stages as required.

In an embodiment, the gearset 528 and the gearset 534 may be configured to regulate the speed of the fifth impeller 526 and the sixth impeller 532, respectively, independent of the speed of the shaft 506 as it rotates. For example, the shaft 506 may rotate at a first speed such that the steam discharged from the compressor 500 is at a first pressure, but for a specific industrial process requires a supply of steam for a period of time at a target pressure that is lower than the first pressure. To follow the example, the gearset 528 may allow the shaft 506 to continue rotating at the first speed but reduce the rotation of the impeller 526 to a second speed that is slower than the first speed in order to reduce the output pressure of the steam exiting the fifth stage 524 to a second pressure that is less than the target pressure. The steam exiting the fifth stage 524 at the second pressure may be received by the sixth stage 530. The gearset 534 may adjust the rotational speed of the sixth impeller 532 such that the steam entering the sixth stage 530 at the second pressure may be increased to the target pressure, as required for the specific industrial process.

In an embodiment, the compressor 500 may utilize a single gearset (e.g., gearset 534) to adjust pressure as required. For example, the shaft 506 may rotate at a first speed such that the steam discharged from the compressor 500 is at a first pressure, but for a specific industrial process requires a supply of steam for a period of time at a target pressure that is lower than the first pressure. The gearset 534 may allow the shaft 506 to rotate at the first speed but reduce the rotational speed of the sixth impeller 532 such that steam discharged from the compressor 500 is at the target pressure.

In an embodiment a gearset (e.g., gearset 528 and/or gearset 534) may be adjusted in real-time based on operational needs. For example, corrective and/or preventative maintenance may require a steady supply of steam at a particular pressure while the speed of the shaft 506 must be altered, pressure must be momentarily reduced across a stage due to structural constraints, or any other situation where steam pressure must be temporarily modified.

In an embodiment, the shaft 506 may extend continuously through each stage (508, 512, 516, 520, 524, 530) and each corresponding impeller (510, 514, 518, 522, 526, 532). In an embodiment, each impeller (510, 514, 518, 522, 526, 532) may be coupled to the shaft 506. The shaft 506 may be configured to rotate within the compressor 500, which may, in turn, rotate each impeller (510, 514, 518, 522, 526, 532).

In an embodiment, the compressor 500 may include a shaft 548 (e.g., second shaft, etc.) and a shaft 550 (e.g., third shaft, etc.). In an embodiment, the shaft 548 may extend from the gearset 528 to the gearset 534 in axial alignment with the shaft 506. In an embodiment, the shaft 550 may extend from the gearset 534 to the discharge 504 of the compressor 500 in axial alignment with shaft 506 and shaft 548.

In an embodiment, the shaft 548 may rotate at a different speed than shaft 506. For example, the shaft 506 may rotate at a first speed such that the fourth stage 524 discharged steam into the fifth stage 524 at a first pressure and the gearset 528 may cause the shaft 548 to rotate at a second speed that is different (e.g., slower or faster) than the first speed. In an embodiment, the shaft 550 may rotate at a different speed than the shaft 506 and/or the shaft 548. For example, the shaft 506 may rotate at a first speed such that the fourth stage 524 discharged steam into the fifth stage 524 at a first pressure, the gearset 528 may cause the shaft 548 to rotate at a second speed that is different (e.g., slower or faster) than the first speed, and the gearset 534 may cause the shaft 550 to rotate at a third speed that is different than the first speed and/or the second speed.

In an embodiment, the gearset 528 and/or the gearset 534 may be controlled independently of each other. For example, the gearset 528 may cause the shaft 548 to rotate at the same speed as the shaft 506 for a first period of time and the gearset 528 may cause the shaft 548 to rotate at a second speed that is different than the speed at which the shaft 506 rotates. In an embodiment, the gearset 528 and/or the gearset 534 may be controlled remotely in order to adjust the speed of the corresponding impeller (526 and 532, respectively). In an embodiment, the gearset 528 and/or the gearset 534 may be configured to automatically adjust themselves to maintain a particular speed of the corresponding shaft 548 and 550) and/or discharge pressure of the corresponding stage (524 and 530).

FIGS. 6 and 7 illustrate representative nuclear reactors that may be included in embodiments of the present technology. FIG. 6 is a partially schematic, partially cross-sectional view of a nuclear reactor system 600 configured in accordance with embodiments of the present technology. The system 600 can include a power module 602 having a reactor core 604 in which a controlled nuclear reaction takes place. Accordingly, the reactor core 604 may include one or more fuel assemblies 601. The fuel assemblies 601 may include fissile and/or other suitable materials. Heat from the reaction generates steam at a steam generator 630, which directs the steam to a power conversion system 640. The power conversion system 640 generates electrical power, and/or provides other useful outputs, such as super-heated steam. A sensor system 650 is used to monitor the operation of the power module 602 and/or other system components. The data obtained from the sensor system 650 can be used in real time to control the power module 602, and/or can be used to update the design of the power module 602 and/or other system components.

The power module 602 includes a containment vessel 610 (e.g., a radiation shield vessel, or a radiation shield container) that houses/encloses a reactor vessel 620 (e.g., a reactor pressure vessel, or a reactor pressure container), which in tum houses the reactor core 604. The containment vessel 610 can be housed in a power module bay 656. The power module bay 656 can contain a cooling pool 603 filled with water and/or another suitable cooling liquid. The bulk of the power module 602 can be positioned below a surface 605 of the cooling pool 603. Accordingly, the cooling pool 603 can operate as a thermal sink, for example, in the event of a system malfunction.

A volume between the reactor vessel 620 and the containment vessel 610 can be partially or completely evacuated to reduce heat transfer from the reactor vessel 620 to the surrounding environment (e.g., to the cooling pool 603). However, in other embodiments the volume between the reactor vessel 620 and the containment vessel 610 can be at least partially filled with a gas and/or a liquid that increases heat transfer between the reactor vessel 620 and the containment vessel 610. For example, the volume between the reactor vessel 620 and the containment vessel 610 can be at least partially filled (e.g., flooded with the primary coolant 607) during an emergency operation.

Within the reactor vessel 620, a primary coolant 607 conveys heat from the reactor core 604 to the steam generator 630. For example, as illustrated by arrows located within the reactor vessel 620, the primary coolant 607 is heated at the reactor core 604 toward the bottom of the reactor vessel 620. The heated primary coolant 607 (e.g., water with or without additives) rises from the reactor core 604 through a core shroud 606 and to a riser tube 608. The hot, buoyant primary coolant 607 continues to rise through the riser tube 608, then exits the riser tube 608 and passes downwardly through the steam generator 630. The steam generator 630 may include a multitude of conduits 632 that are arranged circumferentially around the riser tube 608, for example, in a helical pattern, as is shown schematically in FIG. 6. The descending primary coolant 607 transfers heat to a secondary coolant (e.g., water) within the conduits 632, and descends to the bottom of the reactor vessel 620 where the cycle begins again. The cycle can be driven by the changes in the buoyancy of the primary coolant 607, thus reducing or eliminating the need for pumps to move the primary coolant 607.

The steam generator 630 may include a feedwater header 631 at which the incoming secondary coolant enters the steam generator conduits 632. The secondary coolant rises through the conduits 632, converts to vapor (e.g., steam), and is collected at a steam header 633. The steam exits the steam header 633 and is directed to the power conversion system 640.

The power conversion system 640 may include one or more steam valves 642 that regulate the passage of high pressure, high temperature steam from the steam generator 630 to a steam turbine 643. The steam turbine 643 converts the thermal energy of the steam to electricity via a generator 644. The low-pressure steam exiting the turbine 643 is condensed at a condenser 645, and then directed (e.g., via a pump 646) to one or more feedwater valves 641. The feedwater valves 641 control the rate at which the feedwater re-enters the steam generator 630 via the feedwater header 631. In other embodiments, the steam from the steam generator 630 can be routed for direct use in an industrial process, such as a Hydrogen (H₂) and Oxygen (O₂) production plant, a chemical production plant, and/or the like, as described in detail below. Accordingly, steam exiting the steam generator 630 can bypass the power conversion system 640.

The power module 602 includes multiple control systems and associated sensors. For example, the power module 602 can include a hollow cylindrical reflector 609 that directs neutrons back into the reactor core 604 to further the nuclear reaction taking place therein. Control rods 613 are used to modulate the nuclear reaction and are driven via fuel rod drivers 615. The pressure within the reactor vessel 620 can be controlled via a pressurizer plate 617 (which can also serve to direct the primary coolant 607 downwardly through the steam generator 630) by controlling the pressure in a pressurizing volume 619 positioned above the pressurizer plate 617.

The sensor system 650 can include one or more sensors 651 positioned at a variety of locations within the power module 602 and/or elsewhere, for example, to identify operating parameter values and/or changes in parameter values. The data collected by the sensor system 650 can then be used to control the operation of the system 600, and/or to generate design changes for the system 600. For sensors positioned within the containment vessel 610, a sensor link 652 directs data from the sensors to a flange 653 (at which the sensor link 652 exits the containment vessel 610) and directs data to a sensor junction box 654. From there, the sensor data can be routed to one or more controllers and/or other data systems via a data bus 655.

FIG. 7 is a partially schematic, partially cross-sectional view of a nuclear reactor system 700 configured in accordance with additional embodiments of the present technology. In some embodiments, the nuclear reactor system 700 (“system 700”) can include some features that are at least generally similar in structure and function, or identical in structure and function, to the corresponding features of the system 600 described in detail above with reference to FIG. 6 and can operate in a generally similar or identical manner to the system 600.

In the illustrated embodiment, the system 700 includes a reactor vessel 720 and a containment vessel 710 surrounding/enclosing the reactor vessel 720. In some embodiments, the reactor vessel 720 and the containment vessel 710 can be roughly cylinder-shaped or capsule shaped. The system 700 further includes a plurality of heat pipe layers 711 within the reactor vessel 720. In the illustrated embodiment, the heat pipe layers 711 are spaced apart from and stacked over one another. In some embodiments, the heat pipe layers 711 can be mounted/secured to a common frame 712, a portion of the reactor vessel 720 (e.g., a wall thereof), and/or other suitable structures within the reactor vessel 720. In other embodiments, the heat pipe layers 711 can be directly stacked on top of one another such that each of the heat pipe layers 711 supports and/or is supported by one or more of the other ones of the heat pipe layers 711.

In the illustrated embodiment, the system 700 further includes a shield or reflector region 714 at least partially surrounding a core region 716. The heat pipe layers 711 can be circular, rectilinear, polygonal, and/or can have other shapes, such that the core region 716 has a corresponding three-dimensional shape (e.g., cylindrical, spherical). In some embodiments, the core region 716 is separated from the reflector region 714 by a core barrier 715, such as a metal wall. The core region 716 can include one or more fuel sources, such as fissile material, for heating the heat pipe layers 711. The reflector region 714 can include one or more materials configured to contain/reflect products generated by burning the fuel in the core region 716 during operation of the system 700. For example, the reflector region 714 can include a liquid or solid material configured to reflect neutrons and/or other fission products radially inward toward the core region 716. In some embodiments, the reflector region 714 can entirely surround the core region 716. In other embodiments, the reflector region 714 may partially surround the core region 716. In some embodiments, the core region 716 can include a control material 717, such as a moderator and/or coolant. The control material 717 can at least partially surround the heat pipe layers 711 in the core region 716 and can transfer heat therebetween.

In the illustrated embodiment, the system 700 further includes at least one heat exchanger 730 (e.g., a steam generator) positioned around the heat pipe layers 711. The heat pipe layers 711 can extend from the core region 716 and at least partially into the reflector region 714 and are thermally coupled to the heat exchanger 730. In some embodiments, the heat exchanger 730 can be positioned outside of or partially within the reflector region 714. The heat pipe layers 711 provide a heat transfer path from the core region 716 to the heat exchanger 730. For example, the heat pipe layers 711 can each include an array of heat pipes that provide a heat transfer path from the core region 716 to the heat exchanger 730. When the system 700 operates, the fuel in the core region 716 can heat and vaporize a fluid within the heat pipes in the heat pipe layers 711, and the fluid can carry the heat to the heat exchanger 730. The heat pipes in the heat pipe layers 711 can then return the fluid toward the core region 716 via wicking, gravity, and/or other means to be heated and vaporized once again.

In some embodiments, the heat exchanger 730 can be similar to the steam generator 630 of FIG. 6 and, for example, can include one or more helically-coiled tubes that wrap around the heat pipe layers 711. The tubes of the heat exchanger 730 can include or carry a working fluid (e.g., a coolant such as water or another fluid) that carries the heat from the heat pipe layers 711 out of the reactor vessel 720 and the containment vessel 710 for use in generating electricity, steam, and/or the like. For example, in the illustrated embodiment the heat exchanger 730 is operably coupled to a turbine 743, a generator 744, a condenser 745, and a pump 746. As the working fluid within the heat exchanger 730 increases in temperature, the working fluid may begin to boil and vaporize. The vaporized working fluid (e.g., steam) may be used to drive the turbine 743 to convert the thermal potential energy of the working fluid into electrical energy via the generator 744. The condenser 745 can condense the working fluid after it passes through the turbine 743, and the pump 746 can direct the working fluid back to the heat exchanger 730 where it can begin another thermal cycle. In other embodiments, steam from the heat exchanger 730 can be routed for direct use in an industrial process, such as an enhanced oil recovery operation described in detail below. Accordingly, steam exiting the heat exchanger 730 can bypass the turbine 743, the generator 744, the condenser 745, the pump 746, etc.

FIG. 8 is a schematic view of a nuclear power plant system 850 including multiple nuclear reactors 800 in accordance with embodiments of the present technology. Each of the nuclear reactors 800 (individually identified as first through twelfth nuclear reactors 800a-l, respectively) can be similar to or identical to the nuclear reactor 800 and/or the nuclear reactor 800 described in detail above with reference to FIGS. 6 and 7. The power plant system 850 (“power plant system 850”) can be “modular” in that each of the nuclear reactors 800 can be operated separately to provide an output, such as electricity or steam. The power plant system 850 can include fewer than twelve of the nuclear reactors 800 (e.g., two, three, four, five, six, seven, eight, nine, ten, or eleven of the nuclear reactors 800), or more than twelve of the nuclear reactors 800. The power plant system 850 can be a permanent installation or can be mobile (e.g., mounted on a truck, tractor, mobile platform, and/or the like). In the illustrated embodiment, each of the nuclear reactors 800 can be positioned within a common housing 851, such as a reactor plant building, and controlled and/or monitored via a control room 852.

Each of the nuclear reactors 800 can be coupled to a corresponding electrical power conversion system 840 (individually identified as first through twelfth electrical power conversion systems 840a-l, respectively). The electrical power conversion systems 840 can include one or more devices that generate electrical power or some other form of usable power from steam generated by the nuclear reactors 800. In some embodiments, multiple ones of the nuclear reactors 800 can be coupled to the same one of the electrical power conversion systems 840 and/or one or more of the nuclear reactors 800 can be coupled to multiple ones of the electrical power conversion systems 840 such that there is not a one-to-one correspondence between the nuclear reactors 800 and the electrical power conversion systems 840.

The electrical power conversion systems 840 can be further coupled to an electrical power transmission system 854 via, for example, an electrical power bus 853. The electrical power transmission system 854 and/or the electrical power bus 853 can include one or more transmission lines, transformers, and/or the like for regulating the current, voltage, and/or other characteristic(s) of the electricity generated by the electrical power conversion systems 840. The electrical power transmission system 454 can route electricity via a plurality of electrical output paths 855 (individually identified as electrical output paths 855a-n) to one or more end users and/or end uses, such as different electrical loads of an integrated energy system.

Each of the nuclear reactors 800 can further be coupled to a steam transmission system 856 via, for example, a steam bus 857. The steam bus 857 can route steam generated from the nuclear reactors 800 to the steam transmission system 856 which in tum can route the steam via a plurality of steam output paths 858 (individually identified as steam output paths 858a-n) to one or more end users and/or end uses, such as different steam inputs of an integrated energy system.

In some embodiments, the nuclear reactors 800 can be individually controlled (e.g., via the control room 852) to provide steam to the steam transmission system 856 and/or steam to the corresponding one of the electrical power conversion systems 840 to provide electricity to the electrical power transmission system 854. In some embodiments, the nuclear reactors 800 are configured to provide steam either to the steam bus 857 or to the corresponding one of the electrical power conversion systems 840 and can be rapidly and efficiently switched between providing steam to either. Accordingly, in some aspects of the present technology the nuclear reactors 800 can be modularly and flexibly controlled such that the power plant system 850 can provide differing levels/amounts of electricity via the electrical power transmission system 854 and/or steam via the steam transmission system 856. For example, where the power plant system 850 is used to provide electricity and steam to one or more industrial process-such as various components of the integrated energy systems, the nuclear reactors 800 can be controlled to meet the differing electricity and steam requirements of the industrial processes.

As one example, during a first operational state of an integrated energy system employing the power plant system 850, a first subset of the nuclear reactors 800 (e.g., the first through sixth nuclear reactors 800a-f) can be configured to provide steam to the steam transmission system 856 for use in the first operational state of the integrated energy system, while a second subset of the nuclear reactors 800 (e.g., the seventh through twelfth nuclear reactors 800g-l) can be configured to provide steam to the corresponding ones of the electrical power conversion systems 840 (e.g., the seventh through twelfth electrical power conversion systems 840g-l) to generate electricity for the first operational state of the integrated energy system. Then, during a second operational state of the integrated energy system when a different (e.g., greater or lesser) amount of steam and/or electricity is required, some or all the first subset of the nuclear reactors 800 can be switched to provide steam to the corresponding ones of the electrical power conversion systems 840 (e.g., the seventh through twelfth electrical power conversion systems 840g-l) and/or some or all of the second subset of the nuclear reactors 800 can be switched to provide steam to the steam transmission system 856 to vary the amount of steam and electricity produced to match the requirements/demands of the second operational state. Other variations of steam and electricity generation are possible based on the needs of the integrated energy system. That is, the nuclear reactors 800 can be dynamically/flexibly controlled during other operational states of an integrated energy system to meet the steam and electricity requirements of the operational state.

In contrast, some conventional nuclear power plant systems can typically generate either steam or electricity for output and cannot be modularly controlled to provide varying levels of steam and electricity for output. Moreover, it is typically difficult (e.g., expensive, time consuming, etc.) to switch between steam generation and electricity generation in conventional nuclear power plant systems. Specifically, for example, it is typically extremely time consuming to switch between steam generation and electricity generation in prototypical large nuclear power plant systems.

The nuclear reactors 800 can be individually controlled via one or more operators and/or via a computer system. Accordingly, many embodiments of the technology described herein may take the form of computer- or machine- or controller-executable instructions, including routines executed by a programmable computer or controller. Those skilled in the relevant art will appreciate that the technology can be practiced on computer/controller systems other than those shown and described herein. The technology can be embodied in a special-purpose computer, controller or data processor that is specifically programmed, configured, or constructed to perform one or more of the computer-executable instructions described below. Accordingly, the terms “computer” and “controller” as generally used herein refer to any data processor and can include Internet appliances and hand-held devices (including palm-top computers, wearable computers, cellular or mobile phones, multi-processor systems, processor-based or programmable consumer electronics, network computers, mini computers and the like). Information handled by these computers can be presented at any suitable display medium, including a liquid crystal display (LCD).

The technology can also be practiced in distributed environments, where tasks or modules are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules or subroutines may be located in local and remote memory storage devices. Aspects of the technology described herein may be stored or distributed on computer-readable media, including magnetic or optically readable or removable computer disks, as well as distributed electronically over networks. Data structures and transmissions of data particular to aspects of the technology are also encompassed within the scope of the embodiments of the technology.

Conclusion

Although several embodiments have been described in language specific to structural features and/or methodological acts, it is to be understood that the claims are not necessarily limited to the specific features or acts described. Rather, the specific features and acts are disclosed as illustrative forms of implementing the claimed subject matter.

As used herein, terms such as “attached,” “fastened,” “secured,” “disposed,” “connected,” and “coupled” (including variations thereof) are intended to be used interchangeably to refer to any form of interaction between components, whether directly or indirectly, permanently or temporarily, mechanically or otherwise. It will be understood that these terms are not intended to limit the nature of the interaction to a direct or immediate connection unless specifically stated and may include indirect connections through one or more intermediary elements. Likewise, the terms “directly” and “indirectly” describe both physical contact between components and connections made through intermediate structures, mechanisms, or devices.