GENERATION HEAT OPTIMIZATION SYSTEM

[002] BACKGROUND OF THE INVENTION

[003] There are many locations on the earth that have a need for electric power, but the cost of building a new electric power plant may be economically unfeasible, especially if there is uncooperative terrain. Combined with this is that current power plants maintain thermal independence of the stages of regasification and power generation, leading to substantial inefficiencies in power generation and loss of potential increased power production, including resulting in cold water rejected to the sea or burning of fuel for regasification process. These needs have existed for decades, with no sufficient solution presented.

[004] SUMMARY OF THE INVENTION

[005] Wherefore, it is an object of the present invention to overcome the above mentioned shortcomings and drawbacks associated with the current technology.

[006] The presently claimed invention relates to floating storage, regasification, and generation vessels (FSRGV) comprising a boat having liquid natural gas (LNG) storage tanks, a regasifier, a power plant, and an electrical power offloader. Further embodiments include a main engine by which the FSRGV is self-propelled. Further embodiments include where the power plant comprises a first power engine which powers a first electric generator. Further embodiments include where the power plant includes a second power engine which powers a second electric generator. Further embodiments include the first and the second power engines being gas turbines. Further embodiments include where the first and second power engines and the first and second electric generators are part of a combined cycle gas turbine (CCGT) which includes first and second heat recovery steam generators (HRSG) which provide steam to a steam turbine that turns a third electric generator. Further embodiments include where the first and the second power engines each generate 100 MW of power and the steam turbine generates 100 MW of power. Further embodiments include where the power plant produces between 150 MW and 650 MW of electric power. Further embodiments include where the electrical power offloader offloads electricity at between 1 1 kV and 400 kV. Further embodiments include onboard transformers to transform the voltage of the electricity produced from a first voltage to a second voltage. Further embodiments include where the regasifier is located on the bow of the boat, the power plant is located on the stern of the boat, and the LNG storage tanks axially space the power plant from the regasifier. Further embodiments include where a total capacity of all of the LNG storage tanks is one of at least 27,000 cubic meters of LNG, at least 40,000 cubic meters of LNG, at least 70,000 cubic meters of LNG, at least 140,000 cubic meters of LNG, at least 210,000 cubic meters of LNG, and at least 260,000 cubic meters of LNG. Further embodiments include LNG onboarding conduits for receiving LNG from ship to ship transfer. Further embodiments include where the LNG storage tanks are one of Moss type and membrane type LNG storage tanks. Further embodiments include one of a LNG offloading system and a natural gas (NG) offloading system. Further embodiments include a first conduit to carry LNG from the LNG tanks to the regasifier and a second conduit to carry natural (NG) from the regasifier to the power plant.

[007] The presently claimed invention further relates to methods of producing electric power for a power grid with a floating storage, regasification, and generation vessel (FSRGV), the FSRGV including a boat having liquid natural gas (LNG) storage tanks, a regasifier, a power plant, and an electrical power offloader, the method comprising transporting LNG from the LNG storage tanks to the regasifier, regasifying the LNG to become natural gas (NG), transporting the NG from the regasifier to the power plant, generating electric power from the NG, and offloading the electric power off of the FSRGV to an onshore electric power grid.

[008] The presently claimed invention further relates to methods constructing a floating storage, regasification, and generation vessel (FSRGV) comprising providing a liquid natural gas (LNG) carrier, removing one or more of a boiler and economizer, adding a regasifier, adding a power plant, and adding a power offloader. Further embodiments include generating more than 200 KW of electric power with the power plant and offloading more than 200 KW of electric power. Further embodiments include where the power plant comprises a combined cycle gas turbine (CCGT) including first and second power engines in the form of first and second gas turbines, first and second electric generators, and first and second heat recovery steam generators (HRSG), which receives exhaust from the first and second gas turbines to create steam, and which provides steam to a steam turbine that turns a third electric generator. Preferably a space ratio of power generator to fuel tank will be between 25:75 to 15:85, and more preferably 20:80.

[009] According to further embodiments power offloader is on top of the LNG storage tanks. In one embodiment the FSRGV has the three power transformers and the switchgear on top of tank 4. Though the area on Tank 4 may be hazardous, transformers/equipment is preferably used that is less prone to having fire accidents or blasts and preferably includes added fire/blast proof walls and floors for added protection and safety that will preferably be approved by class.

[010] HEAT OPTIMIZATION SYSTEM: The LNG Regasification and Power

Generation Heat Optimization System (RPGHOS) combines the LNG regasification cycle with power generation, including either or both Rankine cycle and Brayton cycles of power generation, to make the combined process more efficient and/or more productive. For example, there is waste heat in the steam turbine condenser that can be used in LNG regasification. Also, the colder the cooling water in the condenser, the lower the steam turbine back pressure, and the higher the steam turbine efficiency. Cold energy or frigories from LNG regasification process can be piped into the steam turbine condenser improving Rankine cycle efficiency and/or absorb high temperature water from the condenser into the LNG regasification process thereby also improving Rankine cycle efficiency. Frigories from LNG regasification process can also be used to cool intake air of gas turbines thereby increasing the Brayton cycle efficiency. This makes the overall regasification and power generation process more environmentally friendly, improving the efficiency of the gas turbine and reducing emissions (e.g., of NO _x , SO _x , CO, and Hg). [01 1 ] The design of the RPGHOS came about when the inventors were developting how best to utilize the cold energy from LNG in order to increase the efficiency and /or total electric power output of the FSRGV 2. The novel ship design, with the LNG regasification and power generation being in close proximity, beneficially provides potential optimization between LNG regasification process and CCGT cycles of Brayton cycle & Rankine cycle, while preferably taking safeguards with the LNG in close proximity to the power engines/ turbines. Though employing the RPGHOS on the FSRGV 2 or another floating structure is a preferred embodiment, with some distinct advantages including access to fresh supply of sea water, the RPGHOS may also be constructed on a land based regeneration and power generation facility.

[012] INTERMEDIARY FLUID: In the LNG regasification process, an intermediary fluid is preferably used to carry frigories from the LNG to the power plant. This is a separate step than just transporting the LNG to the power plant cooling location and regasifying the LNG at the location, but it provides benefits. In the FSRGV 2 embodiment of the RPGHOS, an intermediary fluid is easier to circulate from bow of the ship to the stern as opposed to circulating LNG itself which has a high frigorie density (is very cold), requiring special piping, and is flammable when exposed to air. Therefore, a primary frigorie carrying fluid is preferably used as an intermediary or working fluid to primarily accept frigories produced when the LNG regasifies to NG in the regasifier. This primary frigorie carrying fluid may then transport the power plant to deliver frigories to the locations desired and absorb heat, and then circulate back to the regasifier. Additionally or alternatively, the primary frigorie carrying fluid may transfer frigories to a secondary frigorie carrying fluid. The secondary frigorie carrying fluid could then deliver frigories to the locations desired and absorb heat.

[013] The power plant cooling locations can include, for example, the gas turbine inlet air cooler (GTIAC) and the Steam Turbine Condenser. The primary frigorie carrying fluid may be used as chiller fluid for the GTIAC. Using inlet air cooling helps increase the air density and turbine power output and decrease the power required for an air compressor. Once the inlet air is cooled, it may then be compressed and then heated prior to combustion, to increase output and also efficiency of gas turbines. Seawater from the sea may then be used as a secondary frigorie carrying fluid to accept frigories from the primary frigorie carrying fluid, warming up the primary frigorie carrying fluid to allow for acceptance of frigories from the LNG regasification process. The seawater secondary frigorie carrying fluid will be cooled down, and then may be used to cool the Steam Turbine Condenser water, thereby increasing steam turbine efficiency and output.

[014] Further, the primary frigorie carrying fluid may be used for Gas turbine

Generator cooling as well, either directly cooling the generator (or cooling the generator coolant), or indirectly by cooling secondary frigorie carrying fluid, which then cools the generator. It is beneficial to have a single primary frigorie carrying fluid on board on the ship in one circuit, but further embodiments may include multiple circuits of a variety of frigorie carrying fluids. Additionally, in some further embodiments the generator may be cooled using seawater directly, thus reserving more frigories produced from the LNG regasification process for use else ware in the power plant for maximum efficiency and output.

[015] TYPE OF INTERMEDIAEY FLUID: As a primary frigorie carrying fluid, sea water is a plentiful option for the FSRGV 2, but the high freezing point of sea or fresh water provides challenges when exposed to the very low temperatures of LNG and LNG regasification. Preferred embodiments for the primary frigorie carrying fluid include water and ethylene glycol, water and propylene glycol, ethylene glycol, propylene glycol, glycerol, methanol, methane, ethane, propane, butane, mixed refrigerant, and /or water with additives or solutes, such as antifreeze proteins, to decrease freezing point and otherwise increase frigorie carrying qualities. A more preferred embodiment uses and ethylene glycol water mixture of between 65% ethylene glycol and 35% water to 40% ethylene glycol and 60% water. The ethylene glycol / water solution safer than the lower molecular weight hydrocarbons (butane, propane, ethane, methane), and has better heat transfer properties than, for example, propane, and has a much lower freezing point than water (-45 °C for 60/40 ethylene glycol/water solution). Some benefits of some embodiments of the RPGHOS follow. Using heat from the power plant to regasify LNG or cold energy from LNG regasification to improve efficiency of power plant. From an efficiency point of view, it is much more efficient to combine the LNG regasification process and power plant cycles with intermediate heating fluids. Also, RPGHOS offers decreased air and water pollution, in-terms of ambient thermal release, CO ₂ , ΝΟχ, SOx, CO, etc. emissions to the environment, compared to conventional power plants with LNG receiving facilities. For example, with decreased NG consumption for a same rate of energy production, less hydrocarbon combustion pollutants are produced. Further embodiments could further increases the heat optimization between LNG regasification process, Brayton cycle, and Rankine Cycle, and / or could use different intermediate heating fluids for various combinations of cycles to further increase power generation efficiency and / or output, and/or further decrease environmental impact.

In one embodiment, power is generate from combustion of LNG/NG itself, and cold energy from regasficaition is used to increase efficiency, but not for power generation itself. In another embodiment, LNG/NG is used to cool a working fluid which is then in turn used to cool the inlet air that will be used in the gas turbines. In another embodiment cold energy from LNG/NG is used in cooling the condenser water that will improve the efficiency of the Rankine cycle. In another embodiment, a single Rankine cycle and a single Brayton cycle are used. In another embodiment, a single Brayton cycle per gas turbine is used. In another embodiment, regasified natural gas or natural gas is combusted and the gas turbine is cooled with the ambient air (Brayton cycle). In another embodiment, RPGHOS is directed to a CCGT. In another embodiment, there are only two cycles and an intermediary fluid working fluid is used to cool the ambient air going into gas turbines. In another embodiment, intermediary working fluid is used to accept cold energy from LNG regasification process to cool down the first Rankin cycle water in the condenser (not heat exchanger) as opposed to using LNG directly.

The present invention is further related to methods and systems of regasification and power generation heat optimization comprising a regasifier to convert liquid natural gas (LNG) to natural gas (NG) and generate frigories, a power plant that generates electricity; and a primary frigorie conduit that conveys a primary frigorie carrying fluid from the regasifier to the power plant to increase one of power plant power generation efficiency and power plant power output. According to a further embodiment the power plant generates electricity through combusting the NG. According to a further embodiment the system increases one of power plant power generation efficiency and power plant power generation output by affecting one of a Rankin cycle, a Brayton cycle and both the Rankin cycle and the Brayton cycle of the power plant. According to a further embodiment the primary frigorie conduit conveys the primary frigorie carrying fluid to and from a first gas turbine air intake cooler. According to a further embodiment the primary frigorie conduit conveys the primary frigorie carrying fluid to and from a first gas turbine air intake cooler and a second gas turbine air intake cooler. According to a further embodiment the primary frigorie carrying fluid one of directly and indirectly delivers frigories to one of a first gas turbine air intake cooler, a second gas turbine air intake cooler, a condenser, a first gas turbine driven generator, a second gas turbine driven generator, and a third steam turbine driven generator, and some combination thereof, or to all thereof. According to a further embodiment the regasifier has a primary heat exchange to exchange heat and cold energy between LNG/NG and the primary frigorie carrying fluid, and a secondary heat exchange to transfer heat and cold energy between the primary frigorie carrying fluid and a secondary frigorie carrying fluid. According to a further embodiment the secondary heat exchange is located within the regasifier. According to a further embodiment the secondary heat exchange is located external of the regasifier. According to a further embodiment the secondary frigorie carrying fluid delivers frigories to and accepts heat from a first gas turbine generator. According to a further embodiment the secondary frigorie carrying fluid passes through a tertiary heat exchange and releases heat to and accepts frigories from a tertiary frigorie carrying fluid. According to a further embodiment the tertiary frigorie carrying fluid is one of sea water and fresh water. According to a further embodiment a secondary frigorie conduit carries the secondary frigorie carrying fluid to and from the regasifier. According to a further embodiment the second frigory conduit conveys the secondary frigorie carrying fluid to and from a condenser to cool condenser fluid. According to a further embodiment steam from a steam turbine is condensed by the condenser. According to a further embodiment the condenser cools one of steam and hot water from multiple locations in the power plant, the power plant includes a combined cycle gas turbine (CCGT) which includes at least a first gas turbine and at least a first heat recovery steam generator (HRSG) which provide steam to a steam turbine that turns a third electric generator. According to a further embodiment the primary frigorie carrying fluid is one of water, salt water, water and ethylene glycol, water and propylene glycol, ethylene glycol, propylene glycol, glycerol, methanol, methane, ethane, propane, butane, mixed refrigerant, and /or water with additives or solutes, such as antifreeze proteins, to decrease freezing point and otherwise increase frigorie carrying qualities, and some combination thereto. According to a further embodiment the system includes a boat having LNG storage tanks and an electrical power offloader, wherein the regasifier and the power plant are both located on the boat. According to a further embodiment the system further includes LNG storage tanks, wherein the regasifier and the power plant are both located on land.

[019] Various objects, features, aspects, and advantages of the present invention will become more apparent from the following detailed description of preferred embodiments of the invention, along with the accompanying drawings in which like numerals represent like components. The present invention may address one or more of the problems and deficiencies of the current technology discussed above. However, it is contemplated that the invention may prove useful in addressing other problems and deficiencies in a number of technical areas. Therefore the claimed invention should not necessarily be construed as limited to addressing any of the particular problems or deficiencies discussed herein.

[020] BRIEF DESCRIPTION OF THE DRAWINGS

[021 ] The accompanying drawing, which is incorporated in and constitutes a part of the specification, illustrates an embodiment of the invention and together with the general description of the invention given above and the detailed description of the drawing given below, serves to explain the principles of the invention. It is to be appreciated that the accompanying drawing is not necessarily to scale since the emphasis is instead placed on illustrating the principles of the invention. The invention will now be described, by way of example, with reference to the accompanying drawings, in which

[022] Fig. 1 is a schematic sectional side plan view of a FSRGV according to the present invention;

[023] Fig. 2 is a schematic representation of a liquid natural gas regasification and power generation heat optimization system (RPGHOS) according to the present invention;

[024] Figs. 3-5 are a schematic representation of a first embodiment of a

RPGHOS according to the present invention.

[025] DETAILED DESCRIPTION OF THE INVENTION

[026] The present invention will be understood by reference to the following detailed description, which should be read in conjunction with the appended drawings. It is to be appreciated that the following detailed description of various embodiments is by way of example only and is not meant to limit, in any way, the scope of the present invention. In the summary above, in the following detailed description, in the claims below, and in the accompanying drawings, reference is made to particular features (including method steps) of the present invention. It is to be understood that the disclosure of the invention in this specification includes all possible combinations of such particular features, not just those explicitly described. For example, where a particular feature is disclosed in the context of a particular aspect or embodiment of the invention or a particular claim, that feature can also be used, to the extent possible, in combination with and/or in the context of other particular aspects and embodiments of the invention, and in the invention generally. The term "comprises" and grammatical equivalents thereof are used herein to mean that other components, ingredients, steps, etc. are optionally present. For example, an article "comprising" (or "which comprises") components A, B, and C can consist of (i.e., contain only) components A, B, and C, or can contain not only components A, B, and C but also one or more other components. Where reference is made herein to a method comprising two or more defined steps, the defined steps can be carried out in any order or simultaneously (except where the context excludes that possibility), and the method can include one or more other steps which are carried out before any of the defined steps, between two of the defined steps, or after all the defined steps (except where the context excludes that possibility).

[027] The term "at least" followed by a number is used herein to denote the start of a range beginning with that number (which may be a range having an upper limit or no upper limit, depending on the variable being defined). For example "at least 1 " means 1 or more than 1 . The term "at most" followed by a number is used herein to denote the end of a range ending with that number (which may be a range having 1 or 0 as its lower limit, or a range having no lower limit, depending upon the variable being defined). For example, "at most 4" means 4 or less than 4, and "at most 40%" means 40% or less than 40%. When, in this specification, a range is given as "(a first number) to (a second number)" or "(a first number)-(a second number)," this means a range whose lower limit is the first number and whose upper limit is the second number. For example, 25 to 100 mm means a range whose lower limit is 25 mm, and whose upper limit is 100 mm. The embodiments set forth the below represent the necessary information to enable those skilled in the art to practice the invention and illustrate the best mode of practicing the invention. In addition, the invention does not require that all the advantageous features and all the advantages need to be incorporated into every embodiment of the invention.

[028] Turning now to the sole Fig., a brief description concerning the various components of the present invention will now be briefly discussed. As can be seen in this embodiment, the floating storage, regasification, and generation vessel 2 (FSRGV) comprises a boat 4 having liquid natural gas (LNG) storage tanks 6, one or more regasifiers 8, a power plant 10, and an electrical power off loader 12. The power plant 10 preferably includes first and second power engines 14, 16, first, second, and third electric generators 18, 20, 22, first and second HRSGs 24, 26, and a steam turbine 28. [029] According to one embodiment of the FSRGV 2, in a single vessel 4, the

FSRGV 2 can load LNG 30, store LNG 30, regasify LNG 30 to NG, generate electric power from the NG using a Combined Cycle Gas Turbine 32 (CCGT) or Gas Engine and then offload the generated power, and move under its own power via a separate engine and propulsion system 34. The inventors have discovered that there are several challenges, but also significant efficiencies to be found in converting an existing LNG carrier to a FSRGV 2.

[030] BOAT: The boat 4 of the FSRGV 2 will be preferably an ocean worthy sea vessel 4 that is preferably sailable under its own power. A preferable embodiment of the FSRGV 2 begins with an existing LNG carrier, including an LNG containment system. A LNG carrier is a mobile LNG storage and transportation ocean going ship 4. It has the ability to receive LNG 30 from LNG liquefaction facilities, safely store it, use it when in motion, and offload it at regasification facilities.

[031 ] The FSRGV 2 preferably has a LNG receiving system 36 to receive

LNG 30 from shore or ship. LNG carriers are generally designed to receive LNG 30 from LNG liquefaction plants, not other LNG carriers. The FSRGV 2 will preferably have a LNG receiving system 18 for known as STS or Ship-To- Ship transfer system, including, for example, flexible hoses, sometimes fixed arms, fenders, emergency release systems, and the like, to allow for LNG 30 uptake from both liquefaction plants and other vessels such as LNG carriers.

[032] LNG STORAGE TANKS: The FSRGV 2 will preferably have four to six

LNG storage tanks 6 located along the center-line of the vessel 4. The regasifier(s) 8 will preferably forward of the LNG storage tanks 6, and the power plant 10 will preferably be aft of the LNG storage tanks 6. Surrounding the LNG storage tanks 6 is preferably a combination of cofferdams and voids which, in effect, gives the vessel 4 a double-hull type design.

[033] Inside each LNG storage tank 6 there are preferably two or three submerged pumps, including one or two main cargo pumps and a spray pump. The one or two main cargo pumps are used in to transfer the LNG 6 to the regasifier 8, or for LNG discharge operations. The spray pump is preferably much smaller and is preferably used for either pumping out liquid LNG 30 to be used as transportation fuel (via a vaporizer), or for cooling down the LNG storage tanks 6. The spray pump may also be used for stripping out the last of the LNG 30 in a tank. The pumps are preferably contained within a pump tower which hangs from the top of the LNG storage tank 6 and preferably runs the entire depth of the LNG storage tank 6. The pump tower preferably also contains a tank gauging system and a tank filling line, all of which are located near the bottom of the LNG storage tank 6.

[034] In membrane-type FSRGVs 2 there is preferably also an empty pipe with a spring-loaded foot valve that can be opened by weight or pressure. This is the emergency pump tower. In the event both main cargo pumps fail the top can be removed from this pipe and an emergency cargo pump lowered down to the bottom of the pipe. The top is replaced on the column and then the pump is allowed to push down on the foot valve and open it. The LNG 30 can then be pumped out. All cargo pumps preferably discharge into a common first conduit 38 or pipe leading to the regasifier 8. The first conduit 38 may also have on-loading 36 and off-loading 40 LNG manifolds or conduits used for on-loading or off-loading LNG 30. A second common conduit 42 or pipe preferably carries NG from the regasifier 8 to the power engines 14, 16 of the power plant 10.

[035] All LNG storage tank 6 vapor spaces are preferably linked via a vapor header, which preferably also has connections to the sides of the ship 4 next to the on-loading and off-loading LNG manifolds 36, 40.

[036] The total capacity of all of the LNG storage tanks 6 on the FSRGV 2 is preferably at least 27,000 cubic meters of LNG 30, more preferably at least 40,000 cubic meters of LNG 30, even more preferably at least 70,000 cubic meters of LNG 30, even more preferably between 120,000 and 266,000 cubic meters of LNG 30, even more preferably at least 140,000 cubic meters of LNG 30, even more preferably at least 210,000 cubic meters of LNG 30, and most preferably at least 260,000 cubic meters of LNG 30.

[037] The FSRGV 2 may use a variety of types of LNG storage tank 6 configurations, including those of Moss type or membrane type configuration, for example, and including spherical or non-spherical tank shapes, including cylindrical tank shapes. [038] REGASIFIER: The LNG 30 is preferably regasified via a regasifier 8.

The regasifier 8 regasifies LNG 30 from its liquid form to vaporous NG that can be burned in the power engines 14, 16, or in some embodiments, sent onshore via a NG offloading system 44. The regasifier 8 will preferably circulate a "warm fluid," such as sea water or glycol, for example, in pipes adjacent to the pipes carrying the LNG 30 from the first conduit 38. The LNG 30 will absorb heat energy from the warm fluid and become vaporous NG. The NG is then piped to the power engines 14, 16 via the second conduit 42, and the now chilled "warm fluid" may be piped to an area on the ship 4 that would benefit from cooling. Additionally or alternatively, the chilled "warm fluid" may be heated and/or may be dumped at sea.

[039] ONBOARD POWER PLANT: The onboard power plant 10 will include a means for converting the potential energy stored in the LNG 30 - including chemical and thermal potential energy - to electrical power. The preferable embodiment will include one or more combustion engines or "power engines" 14, 16 - such as gas turbines and/or reciprocating internal combustion engines for example - that will directly or indirectly turn one or more electric generators 18, 20.

[040] Other methods of converting LNG potential energy to electrical power include fuel cell systems that create Hydrogen gas from the LNG 30 or NG, and thereby create electricity and heat. The fuel cells may also be used with excess NG, including boiloff, to create electricity and heat. The fuel cells may be used in addition to the power engines 14, 16 and electric generators 18, 20. Additionally, solar panels may line the preferably generous surface area of the FSRGV 2 and may generate additional electricity to be used or offloaded, or stored for future use in onboard batteries. Wind power may also be employed.

[041 ] The size of the power plant 10 is able to be varied and can be designed for 50 or 60 Hertz markets, for example.

[042] POWER ENGINE: According to the embodiment shown in the Fig., the onboard power plant 10 for the FSRGV 2 includes a first and a second NG

(gas) "power engines" 14, 16 and first and second electric generators 18, 20.

As the Fig. is a cross section, and the second power engine 16 is hidden behind the first power engine 14, and the second electric generator 20 is hidden behind the first electric generator 18. With the various embodiments of FSRGVs 2, the power engines 14, 16 may be a combined cycle gas turbine 32 (CCGT), and/or simple cycle gas turbine (GT), and/or gas reciprocating engines, for example. The power engines 14, 16 generate electricity by burning NG in a "gas" engine, preferably a natural gas turbine that is coupled directly to a respective generator 18, 20 in a simple cycle or in combined cycle. Other engines could include reciprocating internal combustion engines. Additionally, LNG burning engines may be used, that burn LNG directly without regasification. Diesel back up engines may be used. Auxiliary starting engines may be provided to start the gas turbines 14, 16.

[043] The gas turbines 14, 16 are preferably on the order of 100 MW gas turbines, but may be between 50 MW and 250 MW gas turbines. Preferably there are two power engine gas turbines 14, 16 located on the second flat 46, as part of a CCGT 32, with a first and a second heat recovery steam generator (HRSG) 24, 26 - powered by exhaust 48 from a respective one of the two power engines 14, 16 - located on the deck 50 of the FSRGV 2. A preferably single steam turbine 28, powered by steam 52 from the HRSGs, is preferably between 50 MW and 250 MW, and more preferably around 100 MW. The configuration of the CCGT 32 may be, for example, 1x1 , or 2x1 , or 3x1 , or 4x1 depending on the gas turbine size and the power needs.

[044] ELECTRIC GENERATORS: The first and the second electric generators 18, 20 are preferably directly powered by a respective each of the first and second power engines 14, 16. The first and second electric generators 18, 20 are preferably proximate to the first and second power engines 14, 16 on the second flat 46, substantially enclosed by the FSRGV 2 hull. The exhaust 48 from first and second power engines 14, 16 will preferably go to respective first and second HRSGs 24, 26, which in turn will generate steam 52 that will drive the steam turbine 28. The steam turbine 28 will be preferably directly coupled to the third electric generator 22. The third electric generator 22 is preferably proximate to the steam turbine 28, both on the main deck 50. [045] As there is limited space on the top deck to place HRSGs 24, 26, which occupy a significant amount of space, and as there is the space in the engine room flats 46 is occupied by the first and second power engines 14, 16 and associated components, the HRSGs 24, 26 is preferably placed on the poop deck 50 along with other equipment on the poop deck 50. The HRSGs 24, 26 preferably has two horizontal gas flow HRSGs 24, 26 supplying superheated steam 52 at two pressure levels to preferably one steam turbine 28. A low pressure section of the HRSGs 24, 26 will have preferably have integral deaerators. Evaporators and economizers may also be provided for each high pressure and low pressure section of each HRSG 24, 26. As HRSGs 24, 26 are beneficial to making the power generation more efficient, but as they take up a lot of space, the inventors' arrangement is believed to be a best design for the non-stationary FSRGV 2.

[046] The electrical power generation capacity for the FSRGV 2 is preferably between 150 MW and 650 MW, more preferably between 200 MW and 400 MW, and most preferably around 300 MW. Power plant 10 control may be entirely contained on the FSRGV 2, or may be partially controlled remotely and/or onshore.

[047] ELECTRIC POWER OFFLOADER: The electric power offloader 12 moves electric power off ship 2, and preferably, on shore. The power offloading system 12 preferably transfers power from the generators 18, 20, 22 through transmission equipment and wires, to the shore grid. Electric power may be offloaded at, for example, between 1 1 kV and 400 kV, preferably between 20 kV and 132 kV, more preferably between 50 kV and 70 kV, and most preferably at 66 kV. The power offloader 12 may include one or more SF6 busses at a first voltage - for example 1 1 kV, one or more breakers at the first voltage - for example three breakers, one or more onboard transformers 54 - for example three 120 mVA transformers 54, one or more SF6 busses downstream of the transformer 54 at a second voltage - for example 66 kV, and one or more breakers at the second voltage - for example three breakers. If there is no onboard transformer 54, the electrical power would preferably be offloaded through the SF6 buss at the first voltage. If there is an onboard transformer 54, the electrical power would offloaded through the second SF6 buss at the second voltage.

[048] The transformer 54 may be onboard, on shore, and/or on another vessel or barge adjacent to the FSRGV 2 or otherwise between the FSRGV 2 and the shore. The electric power may be sent to the shore power grid at the voltage generated onboard the FSRGV 2, it may be transformed to a different voltage onboard, before sending to shore, it may be transformed at a different voltage once it reaches the shore, and/or it may be transformed to a different voltage on a separate vessel or barge between the FSRGV 2 and the shore.

[049] Power offloading or offtake may be regulated with onboard transformers 54 and switchgear, especially if the FSRGV 2 is not proximate to the shore so as to increase voltage to minimize loss of power in transmission to shore. Alternatively, raw power from the generators 18, 20, 22 may be regulated on shore with transformers 54 and switchgear onshore, especially if the FSRGV 2 is proximate to the shore. Alternatively, transformers 54 may be located in a separate vessel that transforms the electric power offloaded from the FSRGV 2 before it reaches the shore.

[050] SELF PROPULSION: The FSRGV 2 will preferably have only a single

NG powered propulsion boiler 56 for powering a ship main engine 34, especially while on open seas - for example a 24,500 kW at 78 rpm ship main engine 34, though a second propulsion boiler may be provided. A NG combustion unit may be provided (not shown) to address additional LNG boiloff gas when the FSRGV 2 is not sailing or idle. The propulsion boiler(s) 56 and NG combustion unit are preferably located on the upper deck 50 of the stern 58 of the boat 4, with the power engine gas turbines 14, 16 and first and second electric generators 18, 20 located in the second flat 46, or the area proximate to a location analogous to a propulsion engine room in LNG carriers.

[051 ] The FSRGV 2 is preferably has steam turbine and/or gas turbine propulsion systems, but may also utilize internal combustion or diesel engine driven propulsion systems, including dual fuel diesel-electric (DFDE) engines, tri-fuel diesel-electric (TFDE) engines, and M-type Electronically controlled Gas Injection (MEGI) engines, for example, or an electric motor, for example. [052] The FSRGV 2 propulsion may also be fueled using coal, diesel, biomass, electricity, and even solar power as part of solar combined cycle plants, or wind power.

[053] LNG/NG OFFLOADING: The FSRGV 2 may also include a LNG offloading system 40 for bunkering or truck loading and/or a NG offloading system 44, including associated LNG and/or NG offloading conduits 40, 44. A LNG bunker offloading system 40 may offload LNG 30 from the LNG tanks 6 to shore to be loaded onto LNG trucks, or to a small intermediate LNG storage tank, or offload LNG 30 into other vessels for bunkering LNG 30. A NG offloading system 44 may send pressurized NG, including excess NG from the regasifier 8 not consumed in the onboard power plant 10, to shore to be connected to a NG grid or for other NG consumption on land.

[054] OPERATION: According to one embodiment, the FSRGV 2 operation may be as follows. The FSRGV 2 sails under its own power, or may be towed, to a desired location and is semi permanently moored in port. The FSRGV 2 may arrive with LNG 30 in the onboard LNG storage tanks 6 or conventional LNG carriers may deliver LNG 30 to the FSRGV 2 onboard LNG storage tanks 6 using Ship-To-Ship (STS) transfer 36. The LNG 30 is pumped out through suction drum/condenser for regasification of the LNG 30 into NG in the regasifier 8. The NG routed to the power engine 14, 16 where it is combusted to turn a respective generator 18, 20 to generate electricity. The exhaust 48 from the power engine 14, 16 will preferably go to respective HRSGs 24, 26, which in turn generate steam 52 that will be used to drive a steam turbine 28. The steam turbine 28 turns a further generator 22 to generate further electricity. The generated electricity is then off-taken from the FSRGV 2, through a power offloading system 12, to another vessel or the shore. To enhance operational efficiency and have minimal effect on the environment, a series of heat recovery measures may be implemented to run the power plant 10, auxiliary equipment, and regasifier.

[055] The FSRGV 2 may function on many types and grades of LNG 30, including methane, ethane, propane, butane, and pentane.

[056] CONVERTING LNG CARRIER TO FSRGV 2: According to one embodiment, the FSRGV 2 may be constructed by converting an existing LNG carrier (LNGC) or floating storage regasification unit to a FSRGV 2. This conversion may involve adding equipment for electricity generation and offtake, LNG loading, LNG regasification, as well as discarding various existing equipment to make room for the additions.

[057] LNG carriers are generally designed to transport LNG 30 from one location to another location. The FSRGV 2 is a unique and innovative design of making a self-sustainable power plant 10, which is additionally cost effective to build and commission, in a relatively short period of time. The FSRGV 2 is an environmentally friendly mobile floating power plant 10. Additionally, it is the first large scale floating power plant 10 designed by converting an existing LNG carrier. Once commissioned, the FSRGV 2 will be able to efficiently meet high power requirement in areas where other sources of power do not exist and/or are prohibitively expensive and/or are harmful to the environment. FSRGV 2 will function in areas where electric power is nonexistent or expensive or environmentally hazardous and/or there is no land/infrastructure to build a land based power plant. The mobile floating feature of a FSRGV 2 power plant 10 also enables it to be moved from one location to another in case of natural calamity and/or reduction in demand.

[058] To convert a LNG carrier to a FSRGV 2, equipment for added for power generation and electricity offtake, among other things, are added. These preferably include one or more NG engines 14, 16 in the form of NG turbines, heat recovery steam generators 24, 26, steam turbine(s) 28, condensers, electric generators 18, 20, 22, pumps, pipes and systems for air and fluid flows, a control room and motor control center; and power off take systems 12 which may include transformers 54 and switch gear. In some embodiments, the transformer 54 and switchgear may be placed onshore or on a separate vessel and not necessarily be on the FSRGV 2. Various equipment added for regasification of LNG 30 include vaporizers, re- condenser/suction drum, sea water chest, various pumps for LNG 30, sea water, fresh water, and other intermediary fluid heat exchangers, potentially an intermediate cycle system for vaporizing LNG 30 such as an ethylene glycol cycle or propane cycle, LNG boil-off gas ("BOG") management system including but not limited to BOG compressor, and a gas combustion unit ("GCU"). Equipment added for a LNG 30 receiving system from a different LNG carrier through a STS process may include systems for LNG transfer through flexible cryogenic hoses or fixed arms, quick release safety systems. Other equipment may include a NG offloading system 44, a LNG offloading system 40 for truck loading on land or bunkering to other ships, associated pumps, fresh water generator, potentially propane or other intermediary fluid storage tank, and potentially an intermediary fluid generator. It is to be noted that additional embodiments of the FSRGV 2 may omit a LNG bunkering or truck loading system 40 and/or a NG offloading system 44. In such a configuration the LNG 30 stored onboard the FSRGV 2 will be used for power generation on the ship 4 and not for offloading to land.

[059] CONVERSION CHALLENGES: An LNG carrier is primarily used for carrying LNG 30 from one location to another. So the ship is designed to carry as much LNG 30 as possible and a majority of space on the ship is used for storing LNG 30. The LNG 30 is kept at -160 C°, and is combustible, very hazardous if it comes in contact with people or some equipment, and usually requires handling systems. The majority of the middle and front of the LNG carrier is designated Hazardous Areas and Gas Dangerous Areas, basically all area around the LNG containment system. There is limited space to work around, without reducing the LNG storage capacity and without building major side sponsons, which would increase the cost substantially. The inventors used the stern 58 of the ship to place the power plant 10 equipment , but that meant competing with space for the ship propulsion system, including the engine room and accommodations. The regasifier 8 was located in space on the front or bow 60 of the ship, spaced from the power plant 10 for safety.

[060] ADVANTAGES TO SYSTEM: The following are just some of the advantages of just some of the embodiments of the disclosed invention. Combining the regasification process and power generation process on a single vessel makes the whole system more efficient. Power generation emits heat energy and LNG regasification consumes heat energy, and depending on the configuration, each process becomes efficient because of the other and the combined process becomes more efficient. [061 ] FURTHER EMBODIMENTS: The steam cycle used for CCGT 32 can be combined with the heating medium of regas plant / regasifier 8. Also, a variation of the FSRGV 2 can be designed with the main propulsion unit 34, 56 completely removed. The vessel 2 could be propelled using external thrusters or tugs. In a further variation, the auxiliary boiler 56 and gas condenser unit can be eliminated or replaced with suitable equivalent means to manage boil-off gas during emergency conditions. In a further variation, the gas turbine inlet air cooling could be eliminated, increasing the heat rate.

[062] The FSRGV 2 may also be employed in emergency situations. In disaster areas (caused by hurricanes, earth quakes, or other natural disasters) often times power plants are knocked out. This FSRGV 2 could be transported to a disaster site and plug into the electric grid to supply power to the area.

[063] For FSRGV 2 to remain stable and sailable floating vessel, the constituent parts should preferably not be too heavy or imbalanced. The parts of the FRSGV are preferably refrained from being too many and too big, such that they cannot be fit in space available or with safe extensions of the ship.

[064] Just some benefits from just some sample embodiments of the FSRGV

2 are, for example, from a safety point of view, there will preferably not be any NG pipelines on land for the FSRGV 2. From a permitting standpoint, there will preferably only be one major structure that needs to be permitted and there will minimal installation on land or construction at a location.

[065] Reduced air and water pollution are potential benefits of at least one embodiment of the FSRGV 2, in-terms of ambient thermal release, CO2, NOx, SOx, CO, etc. emissions to the environment, compared to conventional power plants with LNG receiving facilities. The FSRGV 2 may preferably generate power at large scale, but with a low investment compared to alternative thermal power plants on shore. The option of the FSRGV 2 being self- propelled increases mobility and flexibility of the FSRGV 2. Another potential benefit is that floating and mobility, reduces the risk of loss due to many natural calamities.

[066] HEAT OPTIMIZATION SYSTEM: Turning now to Figs. 2-5, embodiments of a LNG Regasification and Power Generation Heat Optimization System (RPGHOS) 62 are shown, including a primary frigorie carrier fluid 64 and preferably a secondary frigorie carrier fluid 66. As is shown in Fig. 2 LNG 30 travels from the LNG storage tanks 6 along the first common conduit 38 and enters the regasifier 6 vie a LNG regasifier inlet 68. The LNG 30 then moves through a primary heat exchanger 70 where the LNG 30 is heated and vaporizes and releases cold energy or frigories, and a frigorie deficient or hyperthermal primary frigorie carrying fluid 72 or working fluid loses heat to the LNG 30 and accepts cold energy or frigories. The primary frigorie carrying fluid is now frigorie laden, or hypothermal 74. The primary heat exchanger 70 preferably prevents direct mixing of the LNG 30 and the primary frigorie carrying fluid 64. After passing through the primary heat exchanger 70, the LNG 30 has been heated and converted to NG 76. The NG 76 passes out of the regasifier 8 through a NG regasifier outlet 78. The NG 76 is then routed for use, such as by sending to the power plant 10 for combustion via the second common conduit 42, or for offloading or storage, such as sending to the NG offloading system 44 or to NG pipelines if, for example, the RPGHOS 62 is on land.

Exiting the primary heat exchanger 70, the hypothermal primary frigorie carrying fluid 74 may exit the regasifier 8 via a primary frigorie carrying fluid regasifier outlet 80, or stay within the regasifier 8 and flow along an intraregasifier primary frigorie carrying fluid circuit 82 to a second or secondary heat exchanger 84. The secondary heat exchanger 84 transfers frigories from the frigorie laden hypothermal primary frigorie carrying fluid 74 to frigorie deficient hyperthermal secondary frigorie carrying fluid 86, preferably without mixing the two fluids. After flowing out of the secondary heat exchanger 84, the primary frigorie carrying fluid is frigorie deficient or hyperthermal 72, and the secondary frigorie carrying fluid is frigorie laden or hypothermal 88. The intraregasifier primary frigorie carrying fluid circuit 82 then routs the hyperthermal primary frigorie carrying fluid 72 from the secondary heat exchanger 84 and back to the primary heat exchanger 70. Additional hyperthermal primary frigorie carrying fluid 72 may enter the regasifier 8 through a primary frigorie carrying fluid regasifier inlet 90 and join the intraregasifier primary frigorie carrying fluid circuit 82, preferably before or coincident with the primary frigorie carrying fluid circuit 82 enters the primary heat exchanger 70. Among other things, this allows the primary frigorie carrying fluid 64 to act as an intermediary and transport cold energy or frigories to from the LNG/NG fluid 30, 76 to the secondary frigorie carrying fluid 66, and to transport heat from the secondary frigorie carrying fluid 66 to the LNG/NG fluid 30, 76.

[068] The primary and secondary heat exchangers 70, 84 are preferably each a shell and tube heat exchanger, but may also be, for example, a plate heat exchanger, a plate and shell heat exchanger, an adiabatic wheel heat exchanger, a plate fin heat exchanger, a pillow plate heat exchanger, a helical-coil heat exchanger, a spiral heat exchanger, and a microchannel heat exchanger. The primary heat exchanger and the secondary heat exchanger 70, 84 may be the same or different designs. Though the secondary heat exchanger 84 is depicted in Fig. 2 as being located within the regasifier 8, one or more secondary heat exchangers 84 may alternatively or additionally be located at a separate location in the RPGHOS 62, as shown in Fig. 4

[069] As shown in Fig. 2, after the frigorie laden hypothermal primary frigorie carrier fluid 74 exits the regasifier 8 via the primary frigorie carrier fluid regasifier outlet 80, the primary frigorie carrier fluid 64 enters the primary frigorie carrier fluid circuit 92 via the primary frigorie conduit 94. The primary frigorie carrier fluid circuit 92 may branch off into separate power element cooling circuits 96 to then be re-routed back to the primary frigorie carrier fluid conduit 94 in the bottom of Fig. 2. The primary frigorie carrier fluid 64 is now frigorie deficient hyperthermal primary frigorie carrier fluid 72, and re-enters the regasifier 8 via the primary frigorie carrier fluid regasifier inlet 90.

[070] Continuing with Fig. 2, once the secondary frigorie carrier fluid 66 exits the secondary heat exchanger 84, the secondary frigorie carrier fluid 66 may exit the regasifier 8 via the secondary frigorie carrier fluid regasifier outlet 100 as frigorie laden hypothermal secondary frigorie carrier fluid 88. The secondary frigorie carrier fluid 66 may then deliver frigories to power element cooling circuits 96 via a secondary frigorie conduit 102. Once the frigories are delivered to the appropriate power elements 104, if the now hyperthermal secondary frigorie carrier fluid 86 is environmentally safe, for example water, and it is at an acceptable temperature range, the secondary frigorie carrier fluid 66 can then be dumped overboard 106 in a responsible manner. Alternatively, frigorie deficient hyperthermal secondary frigorie carrier fluid 86 may be routed from the power elements 104 back into the secondary frigorie carrier fluid circuit 107. (It is understood that the primary and secondary frigorie conduits 94, 102 are respective subunits of the primary and secondary frigorie carrier fluid circuits 92, 107.) The hyperthermal secondary frigorie carrier fluid 86 may be routed directly back to the secondary heat exchange 84 in the regasifier 8 via the secondary frigorie carrier fluid regasifier inlet 108. Alternatively, the hyperthermal secondary frigorie carrier fluid 86 may be routed through a tertiary heat exchanger 1 10, to receive frigories and lose heat to relatively colder sea water 1 12 that acts as a relatively frigorie laden tertiary frigorie carrier fluid 1 14. The sea water 1 12 is preferably pumped onboard, run through the tertiary heat exchanger 1 14, and then dumped overboard 106. The mesothermal secondary frigorie carrier fluid 1 16 is preferably now cooler than hyperthermal 86 but warmer than hypothermal 88. The mesothermal secondary frigorie carrier fluid 1 14 may be returned back to the appropriate power elements cooling circuit(s) 96, or back to the secondary frigorie carrier fluid circuit 107 to be delivered to the regasifier 8. If routed to the regasifier 8, the mesothermal secondary frigorie carrier fluid 1 14 would not require as many frigories from the hypothermal primary frigorie carrier fluid 74 in the secondary heat exchanger 84 to attain sufficient frigorie density as compared to the hyperthermal secondary frigorie carrier fluid 86.

[071 ] Additional secondary frigorie carrier fluid 66 may be added to the secondary frigorie carrier fluid circuit 107 from water tanks 1 18 or from the sea 120. It is noted that for the purposes of this invention, with proper modifications, if any, other water bodies may function as the sea 120, such as rivers, lakes, bayous, and aquifers and fresh or brackish water may function as sea water 1 12.

[072] The power element cooling circuits 96 may include the GTIAC cooling circuit(s) 122, the steam condenser cooling circuit 124, the gas turbine generator cooling circuit(s) 126, and the steam turbine generator cooling circuit 128. [073] Tuning now to Figs. 3-5, further embodiments of the RPGHOS 62 are shown. In Fig. 3, an embodiment of a regasifier 8 is shown, with de-aerator tank 134 and a circulation pump 132 (booster pumps 132 may be used in appropriate locations in the RPGHOS 62 as well). In alternative embodiments, a primary frigorie carrier fluid tank that stores surplus primary frigorie carrier fluid 64 and/or a primary frigorie carrier fluid generator that generates primary frigorie carrier fluid 64 may be included. The circulation pump 132 circulates the intraregasifier primary frigorie carrier fluid circuit 82 in the direction shown. One variation with the regasifier 8 embodiment of Fig. 2, is that the regasifier embodiment in Fig. 3 shows the primary frigorie carrier fluid regasifier inlet 90 rejoining the intraregasifier primary frigorie carrier fluid circuit 82 upstream of the secondary heat exchange 84, whereas in the embodiment shown in Fig. 2, the primary frigorie carrier fluid regasifier inlet 90 rejoins the intraregasifier primary frigorie carrier fluid circuit 82 downstream of the secondary heat exchange 84. Either or a combination of both designs may be used depending on the situation. The design in Fig. 3 would have the primary frigorie carrier fluid 64 entering the secondary heat exchange 84 with a lower frigorie density than the design in Fig. 2, but this may be desirable in some instances.

[074] Turning to Fig. 4 two GTIAC cooling circuits 122 and two gas turbine generator cooling circuits 126 are shown. In the GTIAC cooling circuits 122, hypothermal primary frigorie carrier fluid 74 from the primary frigorie carrier fluid circuit 92 flows into the GTIAC 136 to cool the intake air 138. Once the intake air 138 is cooled, and thereby condensed, the intake air 138 is moved into an air intake 140. In the air intake 140, the intake air 138 may be compressed further and heated before being passed into the gas turbines 18, 20. Once the now hyperthermal primary frigorie carrier fluid 72 exits the GTIAC 136, the hyperthermal primary frigorie carrier fluid 72 returns, via the primary frigorie carrier fluid circuit 92 to the regasifier 8 to pass heat to and accept frigories from LNG/NG 30, 76.

[075] Continuing with Fig. 4, two different embodiments of a gas turbine generator cooling circuit 126 are shown. With the first gas turbine generator 18, starting at the top of the Fig, hyperthermal water or another secondary frigorie carrier fluid 86 leaves the first gas turbine generator 18 frigorie deficient. The secondary frigorie carrier fluid 66 flows down to the tertiary heat exchanger 1 10 and releases heat and absorbs frigories from the relatively cold sea water 1 12 acting as a tertiary frigorie carrier fluid 1 14. The now mesothermal secondary frigorie carrier fluid 1 16 leaves the tertiary heat exchanger 1 10 and processes along the circuit 126. Before reaching the first gas turbine generator 18, the circuit flow through a secondary heat exchanger 84 that is preferably not within the regasifier 8. Hypothermal primary frigorie carrier fluid 74 from the primary frigorie carrier fluid circuit 92 flows into the secondary heat exchanger 84 and further cools down the mesothermal secondary frigorie carrier fluid 1 16 to a hypothermal state 88. The now hyperthermal primary frigorie carrier fluid 72 exits the secondary heat exchanger 84 and returns to the regasifier 8 via the primary frigorie carrier fluid circuit 92. By cooling the first gas turbine generator 18, resistance is decreased and power output and efficiency are increased. With the second gas turbine generator 20, the circuit 126 is the same, except that in this embodiment, the hyperthermal secondary frigorie carrier fluid 86 is only cooled down by the tertiary heat exchanger 1 10. This is a more simple circuit 126 and it reserves more of the cold energy produced by regasification of LNG 30 for other power element cooling circuits 96, but it sacrifices the more extensive cooling effects of the hypothermal primary frigorie carrier fluid 74 on the second gas turbine generator 20 that were experienced by the first gas turbine generator 18. A further embodiment, not shown, would have the primary frigorie carrier fluid 64 directly cooling the first and the second gas turbine generators 18, 20.

[076] Also shown in Fig. 4 is a vacuum type freshwater generator 142 that takes in sea water 1 12, produces fresh water and stores the water in a water tank 1 18 for use, among other things, in the gas turbine generator cooling circuits 126.

[077] Turning now to Fig. 5, embodiments of the steam condenser cooling circuit 124 and the steam turbine generator cooling circuit 128 are shown. For the steam turbine generator cooling circuit 128 shown, air 144 is used is used for cooling. As the steam turbine generator 22 is preferably located on the deck 50 of the boat 4, air cooling is a more viable option than if the steam turbine generator 22 was located in the hull of the boat 4. Although air 144 is shown as providing the cooling for the steam turbine generator 22, the steam turbine generator 22 may also be cooled directly or indirectly with the primary frigorie carrier fluid 64, the secondary frigorie carrier fluid 66, or even the tertiary frigorie carrier fluid 1 14. Turning to the steam condenser cooling circuit 124, a condenser 146 with the first and second HSRGs 24, 26 are shown, with the secondary frigorie carrier fluid circuit 107 and NG steam heater inlets 164, 166, 168 and outlets 152, 154, 156 and HSRG water inlets 160, 162. Starting at the bottom right of Fig. 5, hypothermal secondary frigorie carrier fluid 88 flows in the secondary frigorie carrier fluid circuit 107 toward the condenser 146 and the condenser heat exchange 148. The hypothermal secondary frigorie carrier fluid 88 surrenders frigories to and accepts heat from the fluid in the condenser 146, chilling the fluid in the steam condenser circuit 124. In the embodiment shown, the now hyperthermal secondary frigorie carrier fluid 86 exits the condenser 146 and is dumped overboard 106. The condenser heat exchange 148 may be similar or different designs as the primary and secondary heat exchanges 70, 84.

Also shown in Fig. 5 are additional hot fluid lines 150 carry relatively hot fluid (e.g., water or steam) into the condenser 146 for cooling. The hot fluid lines 150 include the first NG power engine pre-combustion steam heater outlet 152, the second NG power engine pre-combustion steam heater outlet 154, and the NG second common conduit steam heater outlet 156. The outlets or returns 152, 154, 156 return relatively hot fluid to be cooled down by the condenser 146. Once cooled down by the condenser 146, the relatively cold fluid (e.g., water) is carried from the condenser 146 by cold fluid lines 158, including the first HRSG water inlet 160, the second HRSG inlet 162, and the NG second common conduit steam heater inlet 164. The first and the second HRSG water inlets 160, 162 provide water (or other suitable fluid) to the respective first and second HRSG 24, 26 to produce steam 52 for the steam turbine 28. The HRSGs 24, 26 also preferably provide pre-heated fluid to the first and the second NG power engine pre-combustion steam heater inlets 166, 168 to pre-heat NG 76 before combustion in the first and the second power engines 14, 16.

The invention illustratively disclosed herein suitably may explicitly be practiced in the absence of any element which is not specifically disclosed herein. While various embodiments of the present invention have been described in detail, it is apparent that various modifications and alterations of those embodiments will occur to and be readily apparent those skilled in the art. However, it is to be expressly understood that such modifications and alterations are within the scope and spirit of the present invention, as set forth in the appended claims. Further, the invention(s) described herein is capable of other embodiments and of being practiced or of being carried out in various other related ways. In addition, it is to be understood that the phraseology and terminology used herein is for the purpose of 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 while only the terms "consisting of" and "consisting only of" are to be construed in the limitative sense.