Systems and methods for precipitate collection in evaporation processes

Abstract

A system is provided for the thermal separation of a process liquid using an immiscible liquid, in accordance with some embodiments. In some embodiments, the system comprises a precipitate extraction evaporator configured to receive the process liquid and immiscible liquid within an enclosed vessel. In some embodiments, the process liquid is injected into the immiscible liquid and undergoes phase change to form steam. In some embodiments, the steam is condensed by a condenser positioned above the immiscible liquid. In some embodiments, the condensed steam is collected and discharged as fresh water. In some embodiments, precipitate formed in the immiscible liquid is directed to a precipitate collection area. In some embodiments, a conveyor is configured to remove the precipitate from the enclosed vessel. In some embodiments, the system is integrated with one or more desalination and / or heat recovery subsystems.

Description

SYSTEMS AND METHODS FOR PRECIPITATE COLLECTION IN EVAPORATION PROCESSESCROSS-REFERENCE TO RELATED APPLICATION

[0001] This application claims the benefit of and priority to U.S. Provisional Application No. 63 / 675,098, filed July 24, 2024, which is hereby incorporated herein by reference in its entirety for all purposes.BACKGROUND

[0002] The increasing demand for fresh water, coupled with the scarcity of natural freshwater resources, has led to the development of various water purification and desalination technologies. Among these, the process of evaporation and condensation is a widely used method for converting seawater or brackish water into fresh water. However, conventional evaporators used in the desalination process often face several challenges. They typically require substantial energy inputs, which can lead to high operational costs and environmental concerns.

[0003] Furthermore, these systems often produce concentrated brine as a byproduct, which poses disposal and environmental issues. Additionally, the efficiency of these systems can be compromised by the accumulation of scale or salt precipitates, which can hinder heat transfer and require frequent maintenance. Therefore, there is a need for a more efficient and sustainable solution to these challenges.SUMMARY

[0004] The present disclosure relates to a system configured for the thermal separation of a process liquid using an immiscible liquid, in accordance with some embodiments. In some embodiments, the system is configured to evaporate the process liquid, condense the resulting vapor, and extract precipitate formed during the evaporation process. In some embodiments, the system is configured to operate under a range of pressures and temperatures and may be integrated with other desalination or thermal recovery systems to improve energy efficiency and reduce waste.

[0005] The system may be described using various combinations of features presented herein. As a non-limiting example, in some embodiments, the system can be described as comprising a precipitate extraction evaporator comprising. In some embodiments, precipitate extractionevaporator comprises one or more of an enclosed vessel, a process liquid inlet, a condenser, a precipitate collection area, and a conveyor. In some embodiments, the enclosed vessel is configured to contain an immiscible liquid within the precipitate collection area. In some embodiments, the process liquid inlet is configured to inject process liquid into the immiscible liquid. In some embodiments, the condenser is configured to condense steam generated from the process liquid. In some embodiments, the precipitate collection area is configured to direct precipitate from the process liquid formed in the immiscible liquid to the conveyor. In some embodiments, the conveyor is configured to remove the precipitate from the precipitate collection area to outside of the enclosed vessel.

[0006] In some embodiments, the process liquid inlet comprises a plurality of directional inlets. In some embodiments, the plurality of directional inlets are configured to inject the process liquid downward into the immiscible liquid. In some embodiments, the precipitate collection area comprises one or more immiscible liquid inlets. In some embodiments, the one or more immiscible liquid inlets are configured to be below a top surface of the immiscible liquid during normal operation.

[0007] In some embodiments, the conveyor comprises an inclined portion. In some embodiments, the inclined portion is configured to raise the precipitate above a top surface of the immiscible liquid. In some embodiments, inclined portion is configured to enable the immiscible liquid to drain back into the enclosed vessel.

[0008] In some embodiments, the enclosed vessel comprises upper immiscible liquid baffles configured to deflect rising immiscible liquid. In some embodiments, the enclosed vessel comprises lower immiscible liquid baffles oriented in a different direction that the upper immiscible liquid baffles. In some embodiments, the enclosed vessel comprises one or more perforated plates configured to allow steam to rise through one or more perforations within the one or more perforated plates. In some embodiments, the upper immiscible liquid baffles, the lower immiscible liquid baffles, and the one or more perforated plates are all configured to be below a top surface of the immiscible liquid during normal operation.

[0009] In some embodiments, the system comprises a desalination plant. In some embodiments, the desalination plant is configured to receive seawater and separate the seawater into fresh water and brine. In some embodiments, the desalination plant includes a brine conduit configured totransfer the brine to the precipitate extraction evaporator as the process liquid. In some embodiments, the precipitate includes salt.

[0010] In some embodiments, the system comprises a heat pump. In some embodiments, the heat pump is configured to receive heated process fluid from the precipitate extraction evaporator. In some embodiments, the heat pump is configured to receive heated process fluid from the precipitate extraction evaporator. In some embodiments, the heat pump is configured to receive heated cooling fluid from the condenser.

[0011] Other features and functionality, in accordance with some embodiments, will become apparent in the detailed non-limiting examples described below.DRAWING DESCRIPTION

[0012] FIG. 1 depicts a precipitate extraction evaporator for process water evaporation, according to some embodiments.

[0013] FIG. 2 presents a rotated isometric view of the precipitate extraction evaporator from FIG. 1, according to some embodiments.

[0014] FIG. 3 shows a first section view of the precipitate extraction evaporator of FIG. 1, according to some embodiments.

[0015] FIG. 4 illustrates a second section view of the precipitate extraction evaporator of FIG. 1, according to some embodiments.

[0016] FIG. 5 shows a precipitate extraction evaporator configuration to minimize the build-up of scale according to some embodiments.

[0017] FIG. 6 shows the precipitate extraction evaporator integrated into reverse osmosis plant, according to some embodiments.

[0018] FIG. 7 exhibits the precipitate extraction evaporator configured to operate in conjunction with a desalination process and a thermal power station that utilizes fossil fuel, according to some embodiments.

[0019] FIG. 8 shows the precipitate extraction evaporator configured to operate in conjunction with a thermal power station that utilizes renewable energy, according to some embodiments.

[0020] FIG. 9 depicts the precipitate extraction evaporator configured to operate in conjunction with a desalination plant and a thermal power station that utilizes renewable energy, according to some embodiments.

[0021] FIG. 10 illustrates the precipitate extraction evaporator coupled to a multi-stage flash (MSF) desalination plant according to some embodiments.

[0022] FIG. 11 depicts the precipitate extraction evaporator coupled to a multi-effect distillation (MED) plant according to some embodiments.DETAILED DESCRIPTION

[0023] The present disclosure will now be described more fully hereinafter with reference to the accompanying drawings, which form a part hereof, and which show, by way of non-limiting illustration, certain example configurations in accordance with some embodiments. Subject matter may, however, be embodied in a variety of different forms, as well as combinations of features depicted in non-limiting configurations. Therefore, covered or claimed subject matter is intended to be construed as not being limited to any example configuration of structures or function set forth herein. Example configurations, which borrow from portions of the system, are provided merely to show how one of ordinary skill would make and use the system using some embodiments of the present disclosure. Likewise, a broad scope for claimed or covered subject matter is intended. Among other things, for example, subject matter may be embodied as methods, devices, components, computer implemented instructions, control systems, and / or structure. Accordingly, some embodiments may, for example, take the form of hardware, software, firmware or any combination thereof (other than software per se). The following detailed description is, therefore, not intended to be taken in a limiting sense.

[0001] As used throughout the specification and claims, terms may carry nuanced meanings that are informed by context and are not limited to explicitly stated definitions. The phrase “in some embodiments” is not intended to refer exclusively to the same embodiment or to distinct embodiments, unless clearly indicated. Furthermore, the absence of the phrase “in some embodiments” in a sentence should not be interpreted to mean that the described subject matter cannot be combined with or omitted from other elements or embodiments described herein when defining the metes and bounds of the system. Thus, the system may be described using any combination of the features described herein.

[0002] In general, terminology may be understood at least in part from usage in context. For example, conjunctions such as “and,” “or,” and the phrase “and / or” are, by default, inclusive. When a list such as A, B, or C is joined by “or,” the phrase encompasses any of A, B, or C individually as well as any combination of two or three of them, unless the surrounding text expressly limits the meaning to a single, mutually exclusive option. Likewise, “and / or” refers to one or more of the listed items in any combination.

[0003] The phrase “one or more” indicates that the referenced element may be present as a single instance or as multiple instances and should be understood to cover either possibility unless a different intent is clearly expressed.

[0004] Similarly, the articles “a,” “an,” and “the” can denote either singular or plural usage depending on context, unless the claim language expressly limits them to one or to multiple instances.

[0005] As used herein, “can” and “may,” and derivations thereof, denote functional capability, where a clause such as “the system can execute instructions X” is equivalent in scope to “the system is configured to execute instructions X” when defining the metes and bounds of the claimed subject matter. The phrase “configured to” indicates that the identified structure has been configured, arranged, or otherwise adapted to perform the recited function. The terms “can” and “may” also highlight the modular nature of the architecture, signifying that individual components may be present, omitted, or combined in different implementations without departing from the scope of the claims, in a manner analogous to phrases such as “in some embodiments,” “according to some embodiments,” “in accordance with some embodiments,” or comparable expressions.

[0024] In some embodiments, the system includes a precipitate extraction evaporator configured for process liquid evaporation, precipitate separation, precipitate collection, controlled precipitate transfer, and / or controlled precipitate removal, in accordance with some embodiments. In some embodiments, the precipitate extraction evaporator may also be referred to as a boiler or desalinator and may generally be referred to as part of the “system” described herein. In some embodiments, the system is configured for the heating and evaporation of process liquids, which may include brine, seawater, brackish water, and / or any other liquid capable of being evaporated and condensed. As used herein, the term “process liquid” refers collectively to any such liquid suitable for thermal separation.

[0025] In some embodiments, the system comprises an enclosed vessel containing a bath of immiscible liquid. In some embodiments, the term “immiscible liquid” refers to a liquid that does not mix or form a homogeneous solution with the process liquid under operating conditions. In some embodiments, the immiscible liquid is configured to remain physically and chemically distinct from the process liquid throughout the heating and evaporation cycle. In some embodiments, the immiscible liquid is further characterized by a boiling point that is higher than that of the process liquid, thereby enabling thermal transfer without undergoing phase change.

[0026] While the detailed description herein refers to the immiscible liquid as oil and the process liquid as water, the system is not limited to these specific materials. The described configurations, components, and operational principles may be applied to a variety of immiscible liquid and process liquid pairings, provided the immiscibility and boiling point differential are maintained.

[0027] Referring now to FIG. 1, in some embodiments, the system comprises an enclosed vessel 100 configured to contain hot brine 115 (process liquid) and hot oil 116 (immiscible liquid) within an interior volume. As used herein, the term “hot” refers to a condition in which the temperature of a liquid at an inlet of the vessel is greater than the temperature of the same liquid at a respective outlet of the vessel 100. Likewise, as used herein, the term “cold” refers to a condition in which the temperature of a liquid at an inlet of the vessel is less than the temperature of the same liquid at a respective outlet of the vessel 100. In some embodiments, these temperature differentials are the result of thermal energy transfer from the immiscible liquid to the process liquid, thereby facilitating evaporation of the process liquid within the vessel.

[0028] In some embodiments, heat is applied to the oil 116 either directly or indirectly, for instance, via a heat exchange with a closed-circuit flow circulation stream (see FIG. 6). In some embodiments, an oil heater 117 is included in the oil bath to facilitate fine temperature adjustments, where the hot oil can be heated or cooled to above or below an incoming temperature of the oil. In some embodiments, a circulation loop where the oil is heated maintains a desired hot oil process temperature, which may range from 80 to 150 degrees Celsius, or may potentially exceed 150 degrees Celsius depending on the boiling point of the process liquid based on the pressure in the vessel. In some embodiments, the system includes an enclosed vessel 100 operates at a pressure that is one of greater than, less than, or equal to an ambient pressure.

[0029] In some embodiments, the upper limit of the immiscible liquid temperature range is determined based on the thermal stability of the selected fluid. In some embodiments, theimmiscible liquid includes vegetable oils (e.g., olive oil, sunflower oil, soybean oil, palm oil, coconut oil), animal fats (e.g., lard, tallow), silicone oils, synthetic thermal fluids, and food-grade heat transfer fluids (e.g., DOWTHERM®, DOW SYLTHERM™, Eastman Therminol XP, Globaltherm FG, Relatherm FG-1, etc.). In some embodiments, the immiscible liquid is selected to remain in the liquid phase throughout operation, thereby enabling continuous heat transfer without undergoing vaporization.

[0030] In some embodiments, the system includes a cold seawater inlet 101 configured to introduce cold seawater 117 into a condenser 102. In some embodiments, condenser 102 is configured to condense steam rising from the hot oil bath 110 and transfer heat to the incoming cold seawater 117. While cold seawater is used as a non-limiting example, any suitable cooling fluid or liquid may be used, in accordance with some embodiments. In some embodiments, the warmed seawater is discharged through warm seawater outlet 103.

[0031] In some embodiments, the condensed steam is collected in a condensation container 104 and discharged as fresh water through freshwater outlet 105. In some embodiments, the system includes a non-condensable gas vent 106 configured to release gases that do not condense during the evaporation process, which is described further below.

[0032] FIG. 2 shows a rotated isometric view of the precipitate extraction evaporator of FIG. 1 according to some embodiments. In some embodiments, hot oil is introduced into the vessel through hot oil inlet 107. In some embodiments, hot brine 115 is injected directly into the hot oil bath 110 via hot brine inlet 109. As used herein, the term “hot brine 115” refers to process liquid that has been preheated to a temperature above its ambient or source temperature and is sufficiently elevated to promote rapid phase change upon contact with the immiscible liquid. In some embodiments, brine 115 is heated to a temperature near or slightly below its boiling point at the operating pressure of the vessel, thereby reducing the thermal energy required to initiate evaporation once it enters hot oil bath 110.

[0033] In some embodiments, brine 115 is preheated to improve energy efficiency and enhance evaporation kinetics. In some embodiments, the preheat temperature of brine 115 is selected based on the boiling point of brine 115 at the operating pressure of the vessel 100. At a vessel pressure of approximately 0.3 psia, the boiling point of brine 115 is approximately 25.0°C, and the brine 115 may be preheated to a temperature in the range of approximately 20°C to 24°C, in accordance with some embodiments. At a pressure of approximately 3 psia, the boiling point of brine 115 isapproximately 69.0°C, and the brine 1 15 may be preheated to a temperature in the range of approximately 60°C to 67°C, in accordance with some embodiments. At a pressure of 10 psia, the boiling point of brine 115 is approximately 93.3°C, and the brine 115 may be preheated to a temperature in the range of approximately 85°C to 92°C, in accordance with some embodiments. At atmospheric pressure (14.7 psia), the boiling point of brine 115 is approximately 100.0°C, and the brine 115 may be preheated to a range of approximately 90°C to 98°C, in accordance with some embodiments. At a pressure of 20 psia, the boiling point of brine 115 is approximately 107.5°C, and the brine 115 may be preheated to a range of approximately 95°C to 105°C, in accordance with some embodiments.

[0034] Operating under elevated pressure may be advantageous in certain industrial applications where increased boiling temperatures enhance component separation, such as in the purification of multi-component chemical mixtures or recovery of volatile solvents. Additionally, systems deployed in cold environments or specialized field applications, such as oilfield brine treatment or lithium extraction, may utilize pressurized evaporators to maintain fluid phase stability or manage highly saturated or scale-prone solutions.

[0035] In some embodiments, the hot oil bath 110 is configured to transfer thermal energy to brine 115, causing brine 115 to undergo a phase change from liquid to vapor. In some embodiments, the thermal energy transfer occurs through direct contact between brine 115 and hot oil 116, wherein brine 115 is injected into hot oil bath 110 via directional brine inlets 307 (see FIG. 3). In some embodiments, the direct injection of brine 115 into hot oil 1 16 eliminates the need for intermediary surfaces such as heat exchanger walls or tubes, thereby reducing the likelihood of scale formation or fouling on internal vessel surfaces. In some embodiments, the immiscible nature of hot oil 116 relative to brine 115 ensures that precipitate formed during evaporation does not adhere to the vessel walls, but instead remains suspended until settling downward through the oil to the precipitate collection area 111.

[0036] In some embodiments, the density and viscosity of hot oil 116 are selected to promote the gravitational settling of precipitate particles, such as salt or scale, toward the bottom of the vessel. In some embodiments, the buoyant and lubricating properties of hot oil 116 reduce the adhesion of precipitate to internal surfaces, including the vessel wall and structural baffles, thereby maintaining system cleanliness and operational efficiency. In some embodiments, the absence of solid contact surfaces in the heat transfer zone further reduces nucleation sites for crystallization,allowing precipitate to form in free suspension and fall naturally into precipitate collection area 111.

[0037] In some embodiments, the precipitate accumulates in precipitate collection area 111 and is subsequently conveyed by conveyor 113 to a downstream process. In some embodiments, the continuous circulation of hot oil 116 through hot oil inlets 306 and discharge through warm oil outlet 112 maintains a stable thermal gradient within the vessel. In some embodiments, this thermal gradient is configured to ensure that brine 115 injected into the vessel 100 is rapidly vaporized, while precipitate is efficiently separated and removed without fouling or clogging the system.

[0038] In some embodiments, precipitate formed during the evaporation process settles to the bottom of hot oil bath 110 and is collected in precipitate collection area 111. In some embodiments, precipitate collection area 111 includes one or more sloped interior surfaces configured to direct precipitate toward conveyor 113. In some embodiments, the sloped surfaces are arranged to promote gravitational flow of precipitate from the periphery of the vessel toward a central or lower region where conveyor 113 is positioned. In some embodiments, the slope includes an angle configured to prevent accumulation or bridging of precipitate, thereby ensuring continuous flow toward the conveyor inlet.

[0039] In some embodiments, the condenser 102 is separated from the hot oil bath 110 by one or more baffles. In some embodiments, the baffles include oil baffles 201 configured to reduce splashing of hot oil 116 during boiling of the brine 115. In some embodiments, the one or more baffles include condenser baffles 202 positioned adjacent to condensation container 104, which are configured to prevent oil droplets from entering the condensation container 104 and contaminating the condensed fresh water. Baffles are discussed further in relation to FIG. 3, in accordance with some embodiments.

[0040] In this non-limiting example, process water is injected into the hot oil bath 110 via hot brine inlet 109, causing it to boil and evaporate, with the resulting steam rising out of the bath. In some embodiments, the rising steam is condensed at the top portion of the enclosed vessel 100 by condenser 102. In some embodiments, the collected condensate water, now fresh water, is then discharged from the vessel via freshwater outlet 105. In some embodiments, minerals and dissolved solids in the process water remain in the hot oil bath 110 and, over time, crystallize to form a precipitate such as scale and / or salt. In some embodiments, the precipitate eventually accumulates and settles at the bottom of the hot oil bath 110 in the boiler vessel.

[0041] In some embodiments, situated at the base of the enclosed vessel 100 is a portion of conveyor 113 configured to remove precipitates, such as scale or salt, which are byproducts of the evaporation process, out of the enclosed vessel 100. In some embodiments, the conveyor 113 (e.g., screw conveyor) includes a substantially horizontal portion 204, which is configured to transport the scale and / or salt that accumulates and settles at the bottom of the hot oil bath. Adjacent to this horizontal portion 204, in some embodiments, an inclined portion 203 of the conveyor 113 is configured to remove of the precipitates from the vessel by raising the precipitates so that they may be dropped and collected in a pile in the precipitate collection area 111.

[0042] In some embodiments, at least a portion of the inclined portion 203 of the conveyor 113 is configured to be filled with hot oil from the bath under normal operating conditions. In some embodiments, the incline portion 203 enables separation of the oil from the precipitate by enabling the oil to drain back through the precipitate to the interior portion of the enclosed vessel 100 after the precipitate is conveyed above a top surface 205 of the oil, draining the precipitate of oil, resulting in less oil loss.

[0043] FIG. 3 shows a first section view of the precipitate extraction evaporator of FIG. 1, according to some embodiments of the present disclosure. In some embodiments, the system is configured to receive brine 115 from an upstream process at a temperature above the boiling point of brine 115 at the operating pressure of the vessel 100. In some embodiments, the vessel 100 operates under vacuum or sub-atmospheric conditions, such that the boiling point of brine 115 is significantly reduced.

[0044] In some embodiments, brine 115 is introduced into the vessel 100 at a temperature greater than the local boiling point, resulting in immediate flash evaporation upon contact with the hot oil bath 110. In some embodiments, this flash evaporation effect enhances thermal efficiency by utilizing the sensible heat of the incoming brine 115 to drive phase change without requiring additional heat input from the immiscible liquid 116. In some embodiments, this configuration is particularly advantageous when brine 115 is discharged from a preceding thermal process, such as a reverse osmosis reject stream, a multi-effect distillation stage, or a thermal power station cooling loop, where the brine 115 exits at elevated temperatures.

[0045] In some embodiments, the system includes directional brine inlets 307 configured to manage the velocity and angle of the incoming brine 115 to control turbulence and prevent entrainment of oil or precipitate. In some embodiments, one or more baffles are strategicallypositioned within the hot oil bath 110 and / or above the oil bath's top surface. In some embodiments, these baffles serve to minimize the splattering of hot oil resulting from the boiling action of the injected process water from contaminating the fresh water.

[0046] In some embodiments, the baffles 201 include upper oil baffles 301, and lower oil baffles 302, as well as perforated plate 305, which are each configured to mitigate splashing and maintain separation between the oil phase and the rising steam. In some embodiments, the system is configured to accommodate rapid vapor expansion and maintain pressure stability during flash evaporation events. In some embodiments, the flash evaporation of brine 115 reduces the thermal load on the immiscible liquid 116 and improves overall system throughput and energy efficiency.

[0047] In some embodiments, lower oil baffles 302 are arranged as elongated plates set at an angle to a horizontal surface (relative to ground) in a first direction, with spaces in-between forming slots that allow steam to rise while directing oil and / or particulate matter back downward into the hot oil bath 110. In some embodiments, upper oil baffles 301 are similarly configured but oriented to form slots in a second direction, such as perpendicular to the first direction, providing additional deflection of rising oil and / or particulate.

[0048] In some embodiments, a perforated plate 305 is positioned above hot oil inlets 306 and below lower oil baffle 302. In some embodiments, perforated plate 305 is configured to allow steam to rise while controlling the movement of oil due to expansion forces associated with boiling. In some embodiments, perforated plate 305 serves as a first layer of separation between the boiling region and the upper condensation region.

[0049] In some embodiments, upper oil baffles 301, lower oil baffles 302, and perforated plate 305 are all configured and arranged to be submerged in the hot oil during normal operation, enabling steam to pass through apertures formed by each while preventing large bubble from collapsing at the surface of the hot oil 115.

[0050] In some embodiments, hot oil 115 is introduced into the enclosed vessel 110 through a plurality of inlet branches 308, which are configured to distribute the incoming oil 115 to a plurality of hot oil inlets 306 positioned around the lower portion of precipitate collection area 111, above the horizontal portion of spiral conveyor 113. In some embodiments, the distributed arrangement of hot oil inlets 306 enables uniform thermal distribution across the lower region of the vessel. In some embodiments, the hot oil inlets 306 are placed far enough above the conveyor 113 such that they will not be covered by precipitate under normal operation.

[0051] In some embodiments, directional brine inlets 307 are configured to inject brine directly into the hot oil bath 110. In some embodiments, one or more directional brine inlets 307 (process liquid inlets) are oriented to direct brine downward, upward, vertically, horizontally and / or at an angle, such as between 15 degrees and 90 degrees from horizontal, in either direction, in accordance with some embodiments. A downward directional injection reduces turbulence at the top surface 205, in accordance with some embodiments. In some embodiments, directional brine inlets 307 are configured to enable a desired flow circulation and / or dispersion pattern within the hot oil bath 110 providing optimal heat transfer and evaporation of the brine 115.

[0052] In some embodiments, condensation container 104 includes one or more condenser baffles 303 extending outward from a connection point at the bottom of condensation container 104. In some embodiments, one or more condenser baffles 303 are spaced above an upper surface of the oil bath 110, such that they are not submerged under normal operation. In some embodiments, vessel baffles 304 are coupled to respective vessel walls 309 and / or extend parallel to condenser baffles 303. In some embodiments, vessel baffles 304 and condenser baffles 303 are vertically offset along a projecting edge such that they overlap along a vertical axis, thereby preventing a direct path for oil and / or precipitate to reach condenser 102 or freshwater outlet 105.

[0053] FIG. 4 shows a second section view of the precipitate extraction evaporator of FIG. 1, in accordance with some embodiments. In some embodiments, steam generated within hot oil bath 110 rises into condensation container 104, where it is directed toward condenser 102. In some embodiments, condenser 102 comprises a plurality of condenser tubes 402, which are configured to receive cold seawater from cold seawater inlet 101 and discharge warmed seawater through warm seawater outlet 103. In some embodiments, the condenser tubes 402 are arranged to maximize surface area exposure to rising steam, thereby enhancing condensation efficiency.

[0054] In some embodiments, as steam contacts the cooled surfaces of condenser tubes 402, thermal energy is transferred from the steam to the circulating cold seawater, resulting in phase change from vapor to liquid. In some embodiments, the condensed process water accumulates within condensation container 104 and is discharged as fresh water via freshwater outlet 105. In some embodiments, the geometry and / or location of condensation container 104 is configured to enable gravitational collection of condensates from condenser tubes 402.

[0055] In some embodiments, non-condensable gases such as air, carbon dioxide, or other vaporphase impurities, are vented through non-condensable gas vent 106. In some embodiments, non-condensable gas vent 106 is positioned at or near the apex of condensation container 104 to facilitate passive or active removal of residual gases. In some embodiments, vent 106 is coupled to a pressure-regulated exhaust system or a passive check valve configured to maintain internal vessel pressure within a desired operating range.

[0056] In some embodiments, the presence of non-condensable gases within the condensation container 104 may reduce condensation efficiency by forming insulating boundary layers on condenser tubes 402. Accordingly, in some embodiments, vent 106 is configured to operate continuously or intermittently to purge accumulated gases and restore optimal thermal transfer conditions. In some embodiments, the venting process may be automated via pressure sensors or gas composition monitors integrated into the vessel control system. In some embodiments, the condenser 102, condensation container 104, and non-condensable gas vent 106 are collectively configured to ensure that only purified, condensed process water exits the system via freshwater outlet 105, while residual gases are safely discharged, and thermal efficiency is maintained throughout the condensation cycle.

[0057] FIG. 5 shows a precipitate extraction evaporator container 500 configured to facilitate thermal separation of process liquids and minimize scale formation, similar to FIGs. 1-4, in accordance with some embodiments. In some embodiments, evaporator container 500 comprises an outer shell 501 and an inner shell 502, which together define a cavity 503. In some embodiments, cavity 503 is configured to receive hot oil 504 via a hot oil inlet 505, where the hot oil 504 is directed upward through cavity 503 toward a shell lid 506. In some embodiments, the hot oil 504 spills over an upper lip 507 of inner shell 502 and forms a hot oil bath 508 within the interior volume defined by inner shell 502.

[0058] In some embodiments, the hot oil bath 508 is configured to maintain a top surface 509 at a level below upper lip 507. In some embodiments, top surface 509 is positioned at approximately 50% or less of the vertical height of inner shell 502, although a selection of the level of the top surface 509 is ultimately chosen to ensure that precipitate formed during evaporation remains contained within the inner volume (e.g., the precipitate cannot enter cavity 503).

[0059] In some embodiments, the hot oil 504 comprises an immiscible liquid selected to remain in the liquid phase throughout operation. In some embodiments, the immiscible liquid includes vegetable oils (e.g., olive oil, sunflower oil, soybean oil, palm oil, coconut oil), animal fats (e.g., lard, tallow), silicone oils, synthetic thermal fluids, and food-grade heat transfer fluids (e.g.,DOWTHERM®, DOW SYLTHERM™, Eastman Therminol XP, Globaltherm FG, Relatherm FG-1), similar to FIGs. 1-4. Any features of FIGs. 1-4 may be combined with the configuration shown in FIG. 5 (e.g., baffles, condenser), when defining the meets and bounds of a particular configuration of the system.

[0060] In some embodiments, brine 510 (i.e., process liquid) is introduced into evaporator container 500 via a brine inlet 511. In some embodiments, brine 510 is injected into hot oil bath 508 through a plurality of injection ports 512, which may be directionally arranged similar to FIGs. 1-4. In some embodiments, injection ports 512 are formed in branches extending substantially radially from brine inlet 511. In some embodiments, injection ports 512 are configured to deliver brine 510 in a dispersed or directional pattern to enhance mixing and promote uniform heat transfer. In some embodiments, upon contact with hot oil 504, brine 510 undergoes rapid phase change, forming steam and leaving behind dissolved solids that precipitate within the bath. Temperatures and pressures described in relation to FIGs. 1-4, in accordance with some embodiments, are also applicable to FIG. 5 but will not be repeated in the interest of being concise.

[0061] In some embodiments, precipitate formed during the evaporation process settles to the bottom of inner shell 502. In some embodiments, the density and viscosity of hot oil 504 are selected to promote gravitational settling of precipitate particles, such as salt or scale, toward the lower region of the vessel. Similar to FIGs. 1-4, the immiscible nature of hot oil 504 relative to brine 510 prevents adhesion of precipitate to vessel walls and structural surfaces, in accordance with some embodiments. In some embodiments, the buoyant and lubricating properties of hot oil 504 reduce the likelihood of precipitate accumulation on internal surfaces, thereby maintaining system cleanliness and operational efficiency.

[0062] In some embodiments, evaporator container 500 includes one or more agitators configured to suspend precipitate within the lower region of hot oil bath 508. In some embodiments, the agitators include a mechanical agitator 513 and / or an ultrasonic agitator 514. In some embodiments, mechanical agitator 513 comprises rotating paddles or impellers configured to generate localized turbulence and maintain precipitate suspension. In some embodiments, ultrasonic agitator 514 is configured to impart acoustic energy to hot oil bath 508 at frequencies between 20-40 kHz, thereby disrupting particle agglomeration and enhancing fluid mixing. In some embodiments, the agitation system is positioned adjacent to a precipitate and cool oil outlet 515, which is configured to deliver the suspended mixture to a downstream processing unit, suchas the system shown in FIGs. 1 -4, where the precipitate / oil mixture can be introduced through hot oil inlet 107.

[0063] In some embodiments, the system includes a post-treatment process configured to neutralize and / or add minerals to the precipitate and oil mixture. In some embodiments, the precipitate extraction evaporator is configured to transport a precipitate and oil mixture to a precipitate extractor, a non-limiting example of which is the screw mechanism shown in FIGs. 1- 4. Other non-limiting examples of precipitate extractors for FIGs. 1-5 include one or more, including any combination of filters (e.g., mesh, cartridges, belt filter), centrifuges (e.g., tubular bowl, disc-stack), sedimentation filtering (e.g., removal of gravity settled particulate through the bottom; see FIG. 10), floatation filtering (e.g., dissolved air flotation, induced air floatation), electrocoagulation (e.g., batch, continuous), and membrane filtration (e.g., microfiltration, ultrafiltration).

[0064] In some embodiments, steam generated within hot oil bath 508 rises through the interior volume of inner shell 502 and exits evaporator container 500 via a steam outlet 516. In some embodiments, steam outlet 516 extends from shell lid 506 and is configured to direct vapor-phase process liquid to a downstream condenser or vapor handling subsystem. In some embodiments, steam outlet 516 is positioned at or near the apex of shell lid 506 to facilitate efficient removal of steam while minimizing entrainment of oil droplets or precipitate. In some embodiments, the geometry of steam outlet 516 is selected to maintain pressure stability within evaporator container 500 and to accommodate variable steam flow rates during transient or steady-state operation. In some embodiments, steam outlet 516 is fluidly coupled to a condenser (e.g., similar to condenser 102 arrangement) configured to condense the vapor into fresh water for collection and discharge.

[0065] In some embodiments, the evaporator container 500 is configured to operate with various configurations of heat sources and heat exchange mechanisms, as well as different methods for the removal and management of scale or salt. In some embodiments, the evaporator container 500 and / or enclosure vessel 100 may be integrated with other processes or energy sources to enhance efficiency and sustainability, as further described below.

[0066] FIG. 6 illustrates an integrated desalination system configured to enhance water purification efficiency through thermal coupling between a desalination plant 601 and a precipitate extraction evaporator, in accordance with some embodiments. A non-optimized plant 610 is depicted on the right side of FIG. 6, in accordance with some embodiments. In some embodiments,desalination plant 601 is configured to process seawater and separate it into fresh water and concentrated brine. In some embodiments, the system is configured to recover and reuse thermal energy from various process streams, thereby reducing energy consumption and improving overall system throughput.

[0067] In some embodiments, seawater is introduced into the system via cold seawater inlet 101. In some embodiments, cold seawater inlet 101 is fluidly coupled to a precipitate extraction evaporator, which in this non-limiting example includes enclosure vessel 100, where the seawater absorbs heat from rising steam and exits the system via warm seawater outlet 103. In some embodiments, this heat exchange process enables the condenser to operate efficiently while simultaneously preheating the seawater for use in the desalination plant 601.

[0068] In some embodiments, desalination plant 601 is configured to receive seawater that has been preheated by the condenser subsystem of enclosure vessel 100. In some embodiments, cold seawater enters the system via cold seawater inlet 101 and is thermally conditioned as it passes through condenser 102, where it absorbs heat from rising steam. The preheated seawater is then directed to desalination plant 601, where, in some embodiments, it undergoes membrane-based separation, such as reverse osmosis, as a non-limiting example, to produce two output streams: a fresh water stream and a concentrated brine stream.

[0069] In some embodiments, the fresh water stream is routed through plant fresh water inlet 602 and collected in freshwater container 603. The collected fresh water may be used for municipal, agricultural, or industrial applications, depending on system configuration. In some embodiments, the concentrated brine stream is discharged from desalination plant 601 via plant brine outlet 604. In some embodiments, a portion of this brine is further heated within the plant and discharged as hot brine out 606. In some embodiments, hot brine out 606 is fluidly coupled to hot brine inlet 109 of enclosure vessel 100, enabling the reuse of thermal energy and dissolved solids in a secondary evaporation cycle.

[0070] In some embodiments, one or more heat pumps 607 are configured to extract thermal energy from low-grade heat sources, including ambient air, freshwater discharge streams, and condenser cooling water. In some embodiments, heat pumps 607 operate as closed-loop thermodynamic systems that utilize refrigerant cycles to transfer heat from a lower-temperature source to a higher-temperature target. In some embodiments, heat pumps 607 are fluidly and thermally coupled to the boiler system and are configured to raise the temperature of hot oil 116entering the enclosed vessel 100 via hot oil inlet 107, and / or brine 510 entering via hot brine inlet 109. In some embodiments, the heat pumps 607 are configured to deliver thermal energy to both immiscible and process liquids, thereby enabling rapid phase change and efficient thermal cycling within the boiler.

[0071] In some embodiments, heat pumps 607 are configured to operate in a staged or cascaded arrangement, wherein multiple units are deployed in series to optimize the temperature lift across each stage. In some embodiments, this configuration allows each heat pump 607 to operate within its optimal thermodynamic range, thereby maximizing the coefficient of performance (COP) and overall energy efficiency. In some embodiments, the heat pumps 607 are equipped with variablespeed compressors and adaptive control systems configured to respond to real-time temperature and flow conditions within the integrated system. In some embodiments, heated oil exits the boiler system via warm oil outlet 112, completing the thermal loop and enabling continuous operation.

[0072] In some embodiments, the heat pumps 607 are further configured to preheat brine 510 prior to injection into hot oil bath 508, thereby reducing the thermal load on the immiscible liquid and improving evaporation kinetics. In some embodiments, the heat pumps 607 may also be used to maintain temperature stability within the condenser subsystem by regulating the temperature of cold seawater entering via cold seawater inlet 101. In some embodiments, the integration of heat pumps 607 into the desalination and boiler system enables recovery of waste heat, reduction of external energy input, and enhancement of overall system sustainability.

[0073] In some embodiments, heat pumps 607 are configured to operate as thermal bridges between distinct subsystems of the integrated desalination and boiler systems. In some embodiments, heat pumps 607 are fluidly coupled to multiple thermal sources and sinks, enabling bidirectional or multi-stream heat exchange. For example, in some embodiments, heat pumps 607 extract thermal energy from the warm seawater exiting the condenser via warm seawater outlet 103 and transfer that energy to the incoming brine 510 prior to injection into hot oil bath 508. In some embodiments, this configuration enables the system to recover latent heat from the condensation process and redirect it to the evaporation process, thereby improving thermal efficiency.

[0074] In some embodiments, heat pumps 607 are further configured to extract heat from the warm oil stream exiting the boiler via warm oil outlet 112 and use that energy to preheat cold seawater entering via cold seawater inlet 101. In some embodiments, this cross-stream heat exchangereduces the thermal load on the condenser and improves the effectiveness of the seawater preheating stage. In some embodiments, heat pumps 607 may also be used to transfer heat from the freshwater discharge stream exiting via cool fresh water outlet 609 to the incoming brine 510 or oil 116, thereby closing the thermal loop and minimizing waste heat loss.

[0075] In some embodiments, each heat pump 607 includes a set of dedicated heat exchangers, valves, and control systems configured to dynamically allocate thermal energy based on real-time temperature, flow rate, and pressure conditions. In some embodiments, the system includes sensors and controllers configured to monitor the thermal state of each stream and adjust the operation of heat pumps 607 accordingly. In some embodiments, this enables the system to prioritize heat delivery to the most thermally demanding process, such as brine preheating during peak evaporation cycles or oil reheating during startup conditions.

[0076] In some embodiments, warm fresh water enters the heat pump 605 from desalination plant 601 via warm freshwater inlet 608 and exits through cool freshwater outlet 609 where it is delivered to freshwater container 603. As discussed above, in some embodiments, the temperature differential across warm freshwater inlet 608 and cool freshwater outlet 609 may be used to recover residual heat, which may be redirected to heat pumps 607 or other subsystems. In some embodiments, this configuration enables the system to maintain a closed-loop thermal cycle, reducing waste and improving sustainability.

[0077] FIG. 7 illustrates a precipitate extraction evaporator integrated with a desalination process and a thermal power plant 701 that utilizes fossil fuels, in accordance with some embodiments. This configuration is structurally similar to the integrated system shown in FIG. 6, in accordance with some embodiments, except that thermal energy is supplied by power plant 701 instead of, or in addition to, heat pumps 607. In some embodiments, the system is configured to recover and repurpose thermal energy and process streams from thermal power plant 701 to improve the efficiency of water purification and brine concentration.

[0078] In some embodiments, thermal power plant 701 includes a plant cool seawater inlet 702 and a plant warm seawater outlet 702, which are configured to circulate seawater for cooling purposes. In some embodiments, seawater enters thermal power plant 701 via plant cool seawater inlet 702, absorbs waste heat during the cooling cycle, and exits as warmed seawater via plant warm seawater outlet 703. In some embodiments, the plant steam 704 generated by power plant 701 is directed to the desalination plant 601, where it is used to in the desalination process. In someembodiments, the plant steam 704 is condensed in the desalination plant 601 and produced fresh water that is delivered to freshwater container 603.

[0079] In some embodiments, the plant steam 704 provides thermal energy for other process flows. In some embodiments, plant steam 704 is used to heat the immiscible liquid (e.g., oil) entering the boiler via hot oil inlet 107 and / or to preheat brine entering via hot brine inlet 109. In some embodiments, the use of plant steam 704 as a thermal input reduces the need for external energy sources and improves the thermal efficiency of the system. In some embodiments, heated oil exits the boiler via warm oil outlet 112 and is heated by the thermal power plant 701 and returned to the enclosed vessel 100 via hot oil inlet 107.

[0080] In some embodiments, cold seawater for desalination is introduced into the system via cold seawater inlet 101, where it enters the enclosed vessel 100 containing the condenser 102. In some embodiments, condenser 102 is positioned above a hot oil bath and is configured to condense steam rising from the evaporation process. As the steam condenses on the surface of condenser 102, thermal energy is transferred to the cold seawater circulating through the condenser. In some embodiments, this heat exchange process preheats the cold seawater to an elevated temperature suitable for downstream desalination.

[0081] In some embodiments, the preheated seawater exits the enclosed vessel 100 via warm seawater outlet 103 and is directed to desalination plant 601, where it is used as feedwater for membrane separation or thermal distillation. This configuration, in accordance with some embodiments, enables the system to recover latent heat from the vapor phase and repurpose it to improve the efficiency of the desalination process. In some embodiments, the fresh water is routed to and stored in a freshwater container 603. In some embodiments, the concentrated brine is directed to the boiler system via hot brine inlet 109 for further evaporation and salt recovery.

[0082] FIG. 8 depicts precipitate extraction evaporator configured to operate in conjunction with a desalination plant and a renewable power plant 801 that utilizes renewable energy (e.g., geothermal, concentrated solar power, nuclear power). The function and arrangement of the components described in FIG. 8 is the same as described in relation to FIG. 7, in accordance with some embodiments, and are not repeated in the interest of being concise.

[0083] FIG. 9 illustrates a precipitate extraction evaporator integrated with a desalination process and a geothermal power station 901, in accordance with some embodiments. In someembodiments, geothermal power station 901 provides a renewable thermal energy source for water purification and brine concentration.

[0084] In some embodiments, cold seawater is introduced into the system via cold seawater inlet101, where it enters an enclosed vessel 100 containing a condenser 102. In some embodiments, condenser 102 is positioned above a hot oil bath and is configured to condense steam rising from the evaporation process. In some embodiments, as the steam condenses on the surface of condenser102, thermal energy is transferred to the cold seawater circulating through the condenser. In some embodiments, the seawater exits the condenser as warmed seawater via warm seawater outlet 103.

[0085] In some embodiments, the warmed seawater exiting warm seawater outlet 103 is discharged from the system and subsequently reintroduced into the system via warm seawater inlet 901. In this configuration, the seawater, now thermally conditioned, functions as heated brine and is directed to hot brine inlet 109 of the boiler system for further evaporation and salt recovery. This flow path represents a distinction from the configuration shown in FIG. 1, where the cold seawater stream is not recirculated in this manner, in accordance with some embodiments. The configuration shown in FIG. 8, where seawater is used to cool the condenser 102, then routed to warm seawater outlet 103 and reintroduced as heated brine via warm seawater inlet 901, may be applied to any of the examples described herein, in accordance with some embodiments.

[0086] In some embodiments, geothermal power station 901 includes a plant warm seawater inlet 902 and a plant cool / seawater outlet 903, which are configured to circulate seawater for internal cooling purposes. In some embodiments, geothermal power station 901 supplies thermal energy to heat the immiscible liquid (e.g., oil) entering the boiler via hot oil inlet 107. After transferring heat to the process liquid, in some embodiments, the oil exits the boiler via warm oil outlet 112 and may be recirculated through geothermal plant 901 for reheating. In some embodiments, fresh water generated by the condensation of steam is discharged from the boiler system via freshwater outlet 105 and collected in freshwater container 603.

[0087] FIG. 10 illustrates two configurations of a multi-stage flash (MSF) desalination system, in accordance with some embodiments. The top diagram shows a non-precipitate extraction MSF system 1020, while the bottom diagram shows an enhanced MSF system 1030, in accordance with some embodiments.

[0088] In some embodiments, in the top arrangement 1020, steam 1001 from boiler is introduced into a conduit within brine heater 1002, where brine heater 1002 is configured to transfer thermalenergy to a brine stream via indirect heat exchange. In some embodiments, the steam 1002 condenses within the conduit and exits the brine heater 1002 as condensed water, which may be routed back to the boiler via condensed to boiler line 1003. In some embodiments, the heated brine is then delivered to a series of flash stages, including first stage 1010, second stage 1011, and nth stage 1012, where the pressure is progressively reduced, causing the brine to undergo rapid phase change. In each stage, a portion of the brine flashes into steam, in accordance with some embodiments.

[0089] The final stage(s) of the MSF may be cooled by seawater 1007, in accordance with some embodiments. In some embodiments, the cooled seawater outlet 1004 discharges the cooled seawater from the system. In some embodiments, a portion of the cooled seawater may be sent to brine pump 1009. In some embodiments, brine recirculation pump 1009 is configured to return brine, which may include cooled seawater, from the final stage to brine heater 1002 for reprocessing. In some embodiments, the steam generated in each stage is condensed on heat exchanger tubes carrying the returning brine collected at the final MSF stage(s). In some embodiments, the brine and / or brine / seawater mixture is routed through the condenser tubes in each MSF stage, where it absorbs heat from the condensing steam and is thereby preheated. In some embodiments, the preheated brine is then further heated by the brine heater 1002, by the steam 1001, before being delivered to the first stage 1010.

[0090] In some embodiments, ejector 1005 is configured to remove non-condensable gases from the system and may be coupled to the steam outlet of brine heater 1002. In some embodiments, condensate and / or gases that are unsuitable for reuse is discharged via contaminated waste outlet 1006. In some embodiments, fresh water 1008 is collected from the condensed steam and routed to downstream use or storage.

[0091] The bottom arrangement 1030 builds upon the top configuration 1020 by replacing the conventional brine heater 1002 with a brine and oil heater 1013 and integrating the precipitate extraction evaporator’s enclosed vessel 100 at the far left of the system, in accordance with some embodiments.

[0092] In some embodiments, steam from boiler 1001 is introduced into a conduit within brine and oil heater 1013, where it is configured to transfer thermal energy to an oil stream via indirect heat exchange. In some embodiments, the steam condenses within the conduit and exits the brine and oil heater 1013 as condensed water, which may be returned to a boiler. In some embodiments,the heated oil is circulated from brine and oil heater 1013 through hot oil line 1014 to enclosed vessel 100, where it is used to facilitate evaporation of brine and separation of precipitate. In some embodiments, the oil is returned to brine and oil heater 1013 via cool oil return line 1015 for reheating. In some embodiments, the brine and oil heater 1013 is further configured to transfer thermal energy from the heated oil to a brine stream via a separate conduit, thereby preparing the brine for flash evaporation.

[0093] In some embodiments, the heated brine is delivered to a series of flash stages, including first stage 1010, second stage 1011, and nth stage 1012, where the pressure is progressively reduced, causing the brine to undergo rapid phase change. In each stage, a portion of the brine flashes into steam. In some embodiments, the steam is condensed on heat exchanger tubes carrying cooler seawater 1007 or brine from the final stage(s). In some embodiments, the cooling water discharge from the final MSF stages is routed through condenser 102 within enclosed vessel 100, where it is used to condense steam generated during the precipitate extraction process. In some embodiments, this configuration enables the system to recover latent heat from both the MSF and boiler subsystems.

[0094] In some embodiments, brine recirculation pump 1009 is configured to return brine from the final stage to brine and oil heater 1013 for reprocessing. In some embodiments, the system is further configured to direct a portion of the brine from the final stage to enclosed vessel 100 for additional evaporation and precipitate extraction. In some embodiments, salt discharge 114 is configured to remove crystallized solids from the system, supporting zero liquid discharge operation. In some embodiments, ejector 1005 is configured to remove non-condensable gases from the system and may be coupled to the steam supplying brine and oil heater 1013. In some embodiments, gases and / or condensate that is unsuitable for reuse is discharged via contaminated condensate to waste 1006. In some embodiments, fresh water 1008 is collected from the condensed steam and routed to downstream use or storage.

[0095] FIG. 11 illustrates two configurations of a multi-effect distillation (MED) system, in accordance with some embodiments. The top diagram shows a non-optimized MED system 1020, while the bottom diagram shows an enhanced MED system 1030 that incorporates evaporator container 500, as described in relation to FIG. 5, in accordance with some embodiments. In some embodiments, both systems are configured to produce fresh water from seawater using staged thermal separation under vacuum conditions.

[0096] In the top arrangement 1 120, steam from boiler 1101 is introduced into a conduit within first effect 1103, where it is configured to transfer thermal energy to seawater introduced into the effect. In some embodiments, the steam condenses within the steam conduit and exits via condensed line 1102. In some embodiments, the seawater is injected onto the steam coils, where the seawater is partially evaporated into process steam and partially concentrated into brine.

[0097] In some embodiments, the process steam generated in first effect 1103 rises and is partially condensed in first condenser 1107 positioned adjacent the effect. In some embodiments, the condensed steam is collected and delivered as fresh water via freshwater outlet 1112. In some embodiments, uncondensed steam is routed to second effect 1104, where it is used to heat additional seawater introduced into the effect. In some embodiments, the process steam generated in second effect 1104 is partially condensed in second condenser 1108. In some embodiments, the process steam generated in third effect 1105 is partially condensed in third condenser 1109. In some embodiments, the process steam generated in nth effect 1106 is condensed in nth condenser 1110. In some embodiments, the condensed steam from each condenser is routed through a common conduit and delivered as fresh water via freshwater outlet 1112.

[0098] In some embodiments, seawater 1113 is introduced into each effect and / or is used as a cooling medium in condensers 1107, 1108, 1109, and 1110, which preheats the seawater passing through the conduits. In some embodiments, brine 1114 is collected from each effect and discharged. In some embodiments, the system operates under vacuum conditions, which are maintained across all effects to facilitate low-temperature evaporation and improve energy efficiency.

[0099] The bottom arrangement 1030 builds upon the top configuration 1020 by integrating evaporator container 500, as described in relation to FIG. 5, and replacing direct steam heating with an oil-based thermal loop, in accordance with some embodiments. In some embodiments, steam from boiler 1101 is introduced into a conduit within oil heater 1115, where it is configured to transfer thermal energy to an oil stream via indirect heat exchange. In some embodiments, the steam condenses within the conduit and exits via condensed to boiler line 1102. In some embodiments, the heated oil is circulated through hot oil line 1116 to evaporator container 500, where it is used to heat brine and facilitate evaporation and precipitate separation. In some embodiments, the oil is returned to oil heater 1115 via cool oil return line 1117 for reheating.

[0100] The bottom arrangement 1130 builds upon the top configuration 1120 by integrating evaporator container 500, as described in relation to FIG. 5, and replacing direct steam heating with an oil-based thermal loop, in accordance with some embodiments. In some embodiments, steam from boiler 1101 is introduced into a conduit within oil heater 1115, where it is configured to transfer thermal energy to an oil stream via indirect heat exchange. In some embodiments, the steam condenses within the conduit and exits via condensed to boiler line 1102. In some embodiments, the heated oil is circulated through hot oil line 1116 to evaporator container 500, where it is used to heat brine and facilitate evaporation and precipitate separation. In some embodiments, the oil is returned to oil heater 1115 via cool oil return line 1117 for reheating.

[0101] In some embodiments, brine 1114 collected from the final effect of the MED system is directed to evaporator container 500, where it is flashed to vapor and solids are separated. In some embodiments, salt discharge 1118 is configured to remove crystallized solids from evaporator container 500 and may include any conveying method described herein.

[0102] In some embodiments, the vapor generated in evaporator container 500 is routed to first effect 1103, where it is used to heat seawater introduced into the effect. In some embodiments, the seawater condenses the vapor into fresh water, which is collected and delivered via freshwater outlet 1112. In some embodiments, the seawater is partially evaporated into process steam, which rises and is partially condensed in first condenser 1107 positioned above first effect 1103. In some embodiments, uncondensed steam is routed to second effect 1104, where it is used to heat additional seawater.

[0103] In some embodiments, the process repeats through third effect 1105 and nth effect 1106, with each subsequent effect operating at a lower pressure and temperature to enable cascading vapor reuse. In some embodiments, the process steam generated in second effect 1104 is partially condensed in second condenser 1108, the process steam from third effect 1105 is partially condensed in third condenser 1109, and the process steam from nth effect 1106 is condensed in nth condenser 1110. In some embodiments, the condensed steam from each condenser is routed through a common conduit and delivered as fresh water via freshwater outlet 1112. In some embodiments, seawater 1113 is introduced into each effect and / or used as a cooling medium in condensers 1107, 1108, 1109, and 1110. In some embodiments, brine 1114 is collected from each effect and returned to evaporator container 500.

[0104] It is understood that the system is not limited in its application to the details of construction and the arrangement of components set forth in the previous description or illustrated in the drawings. The system and methods disclosed herein fall within the scope of numerous embodiments. The previous discussion is presented to enable a person skilled in the art to make and use the system according to some embodiments. Any portion of the structures and / or principles included in some embodiments can be applied to any and / or all embodiments: it is understood that features from some embodiments presented herein are combinable with other features according to some other embodiments. Thus, some embodiments of the system are not intended to be limited to what is illustrated but are to be accorded the widest scope consistent with all principles and features disclosed herein.

[0105] Some embodiments of the system are presented with specific values and / or setpoints. These values and setpoints are not intended to be limiting and are merely examples of a higher configuration versus a lower configuration and are intended as an aid for those of ordinary skill to make and use the system.

[0106] Any text in the drawings is part of the system’s disclosure and is understood to be readily incorporable into any description of the metes and bounds of the system. Any functional language in the drawings is a reference to the system being configured to perform the recited function, and structures shown or described in the drawings are to be considered as the system comprising the structures recited therein. It is understood that defining the metes and bounds of the system using a description of images in the drawing does not need a corresponding text description in the written specification to fall with the scope of the disclosure.

[0107] Furthermore, acting as Applicant’s own lexicographer, Applicant imparts the explicit meaning and / or disavow of claim scope to the following terms:

[0108] “Substantially” and “approximately” when used in conjunction with a value encompass a difference of 5% or less of the same unit and / or scale of that being measured (e.g., degrees, volume, mass, distance).

[0109] In addition, the term “configured to” means that the limitations recited in the specification and / or the claims must be arranged in such a way to perform the recited function: “configured to” excludes structures in the art that are “capable of’ being modified to perform the recited function but the disclosures associated with the art have no explicit teachings to do so. For example, a recitation of a “container configured to receive a fluid from structure X at an upper portion anddeliver fluid from a lower portion to structure Y” is limited to systems where structure X, structure Y, and the container are all disclosed as arranged to perform the recited function. The recitation “configured to” excludes elements that may be “capable of’ performing the recited function simply by virtue of their construction but associated disclosures (or lack thereof) provide no teachings to make such a modification to meet the functional limitations between all structures recited.

[0110] It is understood that the phraseology and terminology used herein is for description and should not be regarded as limiting. The use of “including,” “comprising,” or “having” and variations thereof herein is meant to encompass the items listed thereafter and equivalents thereof as well as additional items. Unless specified or limited otherwise, the terms “mounted,” “connected,” “supported,” and “coupled” and variations thereof are used broadly and encompass both direct and indirect mountings, connections, supports, and couplings. Further, “connected” and “coupled” are not restricted to physical or mechanical connections or couplings.[0U1] The previous detailed description is to be read with reference to the figures, in which like elements in different figures have like reference numerals. The figures, which are not necessarily to scale, depict some embodiments and are not intended to limit the scope of embodiments of the system.

[0112] It will be appreciated by those skilled in the art that while the system has been described above in connection with particular embodiments and examples, the system is not necessarily so limited, and that numerous other embodiments, examples, uses, modifications and departures from the embodiments, examples and uses are intended to be encompassed by the claims attached hereto. The entire disclosure of each patent and publication cited herein is incorporated by reference, as if each such patent or publication were individually incorporated by reference herein. Various features and advantages of the system are set forth in the following claims.

Claims

We claim:

1. A system comprising: a precipitate extraction evaporator comprising: an enclosed vessel, a process liquid inlet, a condenser, a precipitate collection area, and a conveyor; wherein the enclosed vessel is configured to contain an immiscible liquid within the precipitate collection area; wherein the process liquid inlet is configured to inject process liquid into the immiscible liquid; wherein the condenser is configured to condense steam generated from the process liquid; wherein the precipitate collection area is configured to direct precipitate from the process liquid formed in the immiscible liquid to the conveyor; and wherein the conveyor is configured to remove the precipitate from the precipitate collection area to outside of the enclosed vessel.

2. The system of claim 1, wherein the process liquid inlet comprises a plurality of directional inlets; and wherein the plurality of directional inlets are configured to inject the process liquid downward into the immiscible liquid.

3. The system of claim 1, wherein the precipitate collection area comprises one or more immiscible liquid inlets; wherein the one or more immiscible liquid inlets are configured to be below a top surface of the immiscible liquid during normal operation.

4. The system of claim 1, wherein the conveyor comprises an inclined portion.

5. The system of claim 4, wherein the inclined portion is configured to raise the precipitate above a top surface of the immiscible liquid.

6. The system of claim 5, wherein the inclined portion is configured to enable the immiscible liquid to drain back into the enclosed vessel.

7. The system of claim 1, wherein the enclosed vessel comprises upper immiscible liquid baffles configured to deflect rising immiscible liquid.

8. The system of claim 7, wherein the enclosed vessel comprises lower immiscible liquid baffles oriented in a different direction that the upper immiscible liquid baffles.

9. The system of claim 8, wherein the enclosed vessel comprises one or more perforated plates configured to allow steam to rise through one or more perforations within the one or more perforated plates.

10. The system of claim 9, wherein the upper immiscible liquid baffles, the lower immiscible liquid baffles, and the one or more perforated plates are all configured to be below a top surface of the immiscible liquid during normal operation.

11. The system of claim 1, further comprising: a desalination plant; wherein the desalination plant is configured to receive seawater and separate the seawater into fresh water and brine; and wherein the desalination plant includes a brine conduit configured to transfer the brine to the precipitate extraction evaporator as the process liquid.

12. The system of claim 11, wherein the precipitate includes salt.

13. The system of claim 12, further comprising a heat pump; wherein the heat pump is configured to receive heated process fluid from the precipitate extraction evaporator.

14. The system of claim 12, further comprising a heat pump; wherein the heat pump is configured to receive heated process fluid from the precipitate extraction evaporator.

15. The system of claim 12, further comprising a heat pump; wherein the heat pump is configured to receive heated cooling fluid from the condenser.

16. A method comprising: providing an immiscible liquid within a container; supplying a process liquid to the container; and executing a thermal process to raise a process temperature of the process liquid above a process liquid boiling point using the immiscible liquid; wherein the thermal process includes direct liquid-to-liquid contact between the process liquid and the immiscible liquid wherein the thermal process is configured to cause a phase change of the process liquid.

17. The method of claim 16, further comprising: collecting a precipitate formed from the process liquid during the phase change within a lower region of the container.

18. The method of claim 17, further comprising: removing the precipitate from the container using a conveyor. wherein the conveyor is positioned in the lower region of the container; and wherein the conveyor is in direct contact with the immiscible liquid.

19. The method of claim 16, wherein the immiscible liquid includes oil; and wherein the process liquid includes salt water.

20. The method of claim 19, further comprising: providing a condenser coupled to the container; condensing steam formed from the phase change of the salt water using the condenser; collecting salt formed from the salt water during the phase change; and removing the salt from the container using a conveyor; wherein the conveyor is in direct contact with the immiscible liquid.

Images