Floating power generation system

Abstract

Some embodiments relate to a power generation system. An example floating power generation system includes a vessel including a vessel frame, a hull surrounding the vessel frame and defining a bow section and a stern section, and a deck supported by the vessel frame. A gas turbine may be provided on the vessel to generate electricity by combustion of natural gas. An Organic Rankine Cycle (ORC) generator may be provided on the vessel to generate power through heat recovery. A gas supply line may be provided on the vessel to supply liquefied natural gas (LNG) to the gas turbine. A power supply subsystem may be provided on the vessel to receive power from at least one of the gas turbine or the ORC generator and to power at least one remote power sink remote from the vessel.

Description

Technical Field

[0001] The present disclosure generally relates to a power generation system. More specifically, the present disclosure relates to a floating power generation system using liquefied natural gas. Background Art

[0002] There are a lot of obstacles to providing reliable electricity to geographically remote rural areas, especially at an economically viable cost. For example, the Papua New Guinea (PNG) archipelago consists of several islands, each of which has a large rural area where residents live in small, scattered communities, as well as industrial land. The topography and landforms of the islands are challenging environments for operating transmission networks. A recurring challenge faced by countries such as PNG is the variation in electricity demand in different regions and at different times. The power load consists of dispersed smaller loads. Mining, fishing and other similar industries generate a large amount of localized electricity demand, but the demand only exists during specific time periods when mine production or fishing is active. At other times, low population density will generate much smaller electricity demand. Current power generation solutions cannot effectively meet these changing needs, and therefore energy costs are high.

[0003] Disadvantages of previous concepts include that they focus on large power plants, which provide sufficient funds to overcome obstacles. In some cases, such large-scale power plants require more capital than is justified. In addition, larger manufacturers do not gain much financial benefit from small power plants, so they do not focus on smaller-scale plants. For example, a small-scale plant may involve the same amount of work as a large-scale plant because it may have all the same / similar components, but the benefits are not commensurate with the capital required.

[0004] For small power plants in remote areas, there is a need to focus on efficiency to reduce fuel deliveries and, where possible, eliminate or reduce the need for consumables that are expensive to deliver to remote locations. Therefore, it is desirable to reduce logistics costs for fuel storage and delivery (higher efficiency = less fuel = less logistics), and the same is true for consumables.

[0005] It would be desirable to address or ameliorate one or more shortcomings or deficiencies of previous power generation solutions, such as low efficiency or high energy costs, or at least provide a useful alternative.

[0006] Throughout this specification, the word "comprise" or variations such as "comprises" or "comprising" will be understood to imply the inclusion of stated elements, integers or steps or groups of elements, integers or steps but not the exclusion of any other elements, integers or steps or groups of elements, integers or steps.

[0007] Any discussion of documents, acts, materials, devices, articles, etc. included in this specification should not be taken as an admission that any or all of such content forms part of the prior art base or is common general knowledge in the field relevant to the present disclosure, merely because it existed before the priority date of each claim of the appended claims. SUMMARY OF THE INVENTION

[0008] Some embodiments relate to a floating power generation system. The floating power generation system may include: a ship, which may include: a ship frame, a hull surrounding the ship frame and defining a bow section and a stern section, and a deck supported by the ship frame; a gas turbine located on the ship for generating electricity by burning natural gas; an organic Rankine cycle (ORC) generator located on the ship for generating electricity through heat recovery; a gas supply line located on the ship for supplying liquefied natural gas (LNG) to the gas turbine; and a power supply subsystem for receiving power from at least one of the gas turbine or the ORC generator and supplying power to at least one remote power sink away from the ship.

[0009] In some embodiments, the ship may not have a propulsion member. The ship may have a recess defined in a central portion of the stern section to accommodate the bow that drives the ship. The bow section of the hull has an acute surface to facilitate the ship's forward passage on water. In some embodiments, the ship may be formed as a barge.

[0010] The floating power generation system may include at least one LNG storage tank located on the ship. The at least one LNG storage tank may include a plurality of LNG storage tanks arranged below the deck.

[0011] The ORC generator may be configured to generate electricity in addition to or instead of the gas turbine. The ORC generator may have a first power generation capacity, and the gas turbine may have a second power generation capacity higher than the first power generation capacity.

[0012] In some embodiments, the power supply subsystem may be configured to change the operation of the ORC generator in response to a change in the load when the gas turbine and the ORC generator are operating simultaneously to generate electricity and when the change in the load drawn by the at least one remote power sink is within the first power generation capacity.

[0013] The ORC generator may comprise a radial expander. The radial expander may comprise variable inlet vanes controllable to enable adjustment of the electrical output of the ORC generator.

[0014] The power output of the gas turbine may be between about 5 MW and about 20 MW. The power output of the ORC generator may be between about 2 MW and about 6 MW.

[0015] The floating power generation system may include at least one storage tank for receiving boil-off gas from one or more LNG storage tanks, and an auxiliary burner for burning the boil-off gas to generate auxiliary heat for operating the ORC generator.

[0016] The floating power generation system may include a damper that in a first position may allow the gas turbine and the ORC generator to operate together and in a second position may allow the gas turbine and ORC generator to operate independently of each other. The ORC generator may include a fresh air firing chimney.

[0017] Some embodiments relate to a power generation facility. The power generation facility may include: a floating dock coupled to a fixed tower and configured to move up and down with water level relative to the fixed tower, the floating dock positioned to allow access to the floating dock from a shoreline; at least one floating power generation system according to any of the embodiments described above moored to the floating dock; and at least one floating LNG storage vessel moored to the floating dock to supply LNG to the at least one floating power generation system.

[0018] In some embodiments, the floating dock may include: a gangway allowing personnel to enter; at least one first cabin, each of which is used to accommodate the at least one floating power generation system; and at least one second cabin, each of which is used to accommodate the at least one floating LNG storage vessel. The at least one floating power generation system may be moored closer to the coastline than the at least one floating LNG storage vessel.

[0019] The at least one floating power generation system is moored to the floating dock by using an interlocking device. The at least one floating LNG storage vessel is moored to the floating dock by using an interlocking device. The interlocking device may be a mechanical mechanism for limiting movement. In some embodiments, the interlocking device may be a hydraulic pin. BRIEF DESCRIPTION OF THE DRAWINGS

[0020] One or more embodiments will now be described by way of specific examples with reference to the accompanying drawings, in which:

[0021] Figure 1 is a schematic diagram of a floating power generation system;

[0022] Figure 2 yes Figure 1 A perspective view of a floating power generation system;

[0023] Figure 3 is a perspective view of the floating dock of the floating power generation system;

[0024] Figure 4a - b is a perspective view of a bulk LNG storage barge;

[0025] Figure 5 is a schematic diagram of the interface between the gas turbine power plant and the ORC power plant;

[0026] Figure 6 yes Figure 1 Schematic diagram of the process of equipment on the LNG storage barge;

[0027] Figure 7a -e is Figure 1 Schematic diagram of the process of equipment on the power generation barge;

[0028] Figure 8a-8c It is a process diagram of the equipment on the power generation barge;

[0029] Fig. 9 yes Fig. 9 A top-down perspective view of the power generation barge;

[0030] Fig.10 is a perspective view of a power generation barge showing the barge structure;

[0031] Fig.11 yes Figure 1 A top-down perspective view of a storage barge;

[0032] Fig.12 The barge structure is shown in FIG. Fig.11 A perspective view of the storage barge;

[0033] Fig.13a is a flow chart showing a process for determining the position of a damper;

[0034] Fig.13b is a flow chart of a process for determining whether to operate a gas turbine generator or an ORC generator;

[0035] Fig.14a -c is the 11KV main power single line diagram;

[0036] Fig.15a-c is the 415V barge power single line diagram;

[0037] Fig.16a -c is the 110VDC power generation barge power single line diagram;

[0038] Fig.17a - b is a schematic general arrangement diagram of a 110 VDC power supply; and

[0039] Fig.18a -b is a schematic diagram of the power communication architecture. DETAILED DESCRIPTION

[0040] Overview of power generation system

[0041] The disclosed power generation system has been developed to provide power to remote areas with variable power demands at the lowest possible energy cost.

[0042] The power generation system utilizes liquefied natural gas (LNG) as fuel in line with the expected available resources in countries such as PNG and the desire to transition away from existing diesel power generation.

[0043] Due to the high frequency of earthquakes and volcanic activity in countries such as PNG, any power infrastructure plan preferably incorporates a design that will mitigate the effects of earthquakes and volcanic activity experienced in these countries. Conventional land-based power plants offer little or no protection from these hazards.

[0044] An offshore power generation system 100 has been developed that significantly reduces fuel handling and LNG logistics costs compared to land-based power generation systems, while mitigating potential damage from seismic activity and minimizing any environmental impact. The floating power generation system 100 can be repositioned as needed to meet fluctuating local power demands so that LNG storage, regasification, and power generation assets do not sit idle once industrial activity in any one area ceases. The power generation system 100 is allowed to move in the water while being fixed in place and takes advantage of the natural damping effect of the ocean to reduce the likelihood of damage from earthquakes. Power plant equipment can be easily removed from any volcanic event.

[0045] The LNG used to fuel the floating power generation system 100 may initially be stored in a bulk storage facility. The bulk storage facility may be up to 800 km to 1000 km from the site of the power generation system 100.

[0046] The power generation system 100 includes an LNG storage barge 120, a power generation barge 110, and a floating dock 130 to which the LNG storage barge 120 and the power generation barge 110 are moored during operation of the power generation system 100. The power generation barge 110 is designed to minimize the draft of the barge, thereby allowing the barge to be placed in a protected port and as close to the coast as possible. This design allows the use of overhead power lines to connect to the onshore transmission and distribution system.

[0047] The LNG storage barge 120 is an unpowered barge that houses LNG storage tanks sufficient to store a minimum fuel supply, for example, a thirty-day supply of LNG, and an associated boil-off gas (BOG) collector. The LNG storage barge is transported between the bulk LNG storage facility 400 loaded with fuel and the location of the floating power generation system 100 using an articulated tugboat (ATB). The ATB uses a hydraulic interlocking method that matches the ATB with the barge to be pushed. The ATB's travel speed is generally 50% faster than that of a tugboat, can be operated on the high seas, and consumes about 25% less fuel than a tugboat. When transporting, the ATB can also be operated using LNG from the LNG storage barge to avoid the use of diesel fuel. Decoupling the propulsion member from the LNG storage barge 120 eliminates the risk of propulsion maintenance problems that may jeopardize the reliability of supplying LNG to the remote power generation system 100. It also has the additional benefit that the unpowered barge requires much fewer crew members than a powered barge.

[0048] For example, the power generation barge 110 is a single platform and an independent power plant with a power generation capacity in the range of 5-20MW. This level of power generation capacity is relatively small in scale and is suitable for providing electricity to dispersed smaller communities. The power generation barge 110 is able to operate for a minimum number of days, for example, seven days, without an external fuel supply. For this purpose, the power generation barge 110 includes two LNG tanks, one LNG tank is located on the port side of the barge, and one LNG tank is located on the starboard side of the barge. For example, the LNG tank can be a C-type cryogenic tank. The LNG tank can be configured as a pressurized tank to allow enough time to deliver LNG to the desired location within a few days without overpressure problems. This arrangement means that LNG only needs to be transferred regularly (for example, every seven days) between the LNG storage barge and the power generation barge, and the transfer can be carried out under favorable weather and sea conditions. In addition, the LNG storage barge can be completely pumped empty before returning to the bulk storage facility for refilling because the supply of LNG is accommodated on the power generation barge. Equipment for regasification, vaporizer, LNG storage, BOG tanks and high-pressure LNG liquid transfer pumps can be installed one on the port and one on the starboard side of the power generation barge to provide redundancy and ensure the reliability of the power plant in the event of failure of any one of the equipment.

[0049] The power generation barge 110 utilizes a gas turbine (GT) generator 112 to generate electricity, in part because of its lower reliability and maintenance requirements compared to reciprocating engines. The main consumables of a gas turbine generator are inlet air, lubricating oil, and fuel filters, and therefore the requirements for the main consumables of a reciprocating engine, which includes large amounts of lubricating oil, are lower. Since the power generation barge 110 can be located away from the supply of such consumables, the use of a gas turbine generator 112 reduces shipping trips and waste materials.

[0050] The power generation barge 110 also includes an organic Rankine cycle (ORC) generator 114 that generates electricity through heat recovery. The gas turbine generator 112 can be operated alone in a simple cycle, or in a combined cycle with the ORC generator 114 to produce a combined cycle efficiency that reduces the levelized cost of energy (LCOE) (the average price per unit output required for the power plant to break even during its operating life) by up to 60% when compared to the simple cycle operation of the gas turbine generator 112. Operating the gas turbine generator 112 and the ORC generator 114 together in a combined cycle improves power generation efficiency by approximately 23% compared to a natural gas fueled generator. The increase in power generation efficiency also has the additional benefit of reducing NOx emissions by approximately 25% / Kwh.

[0051] It is well known that ORC generators are used to recover low-grade thermal energy in geothermal applications. Heat recovery steam generators (HRSGs) are commonly used in power plant applications and are much less expensive. However, the present power generation system 100 utilizes an ORC generator 114 because the power generation system is offshore-based and large amounts of fresh water required to operate the HRSG are not available. In addition, the HRSG requires consumables in the form of chemicals for water treatment and is an open circuit for heat rejection to the environment. In contrast, the ORC generator is a closed circuit that does not require consumables, thereby minimizing weight and energy consumption.

[0052] The ORC generator 114 of the power generation system 100 operates using a thermal fluid as a working fluid. The power generation barge 110 includes a waste heat recovery unit (WHRU) 516 in which the thermal fluid is vaporized by the high temperature (500-600°C) exhaust gas discharged from the gas turbine and supplemented by boil-off gas (BOG) fired in an auxiliary pilot burner. The resulting high pressure steam is allowed to expand in a turbine operably associated with the generator. The expanded steam drives the generator and is then condensed using a seawater / glycol heat exchanger and then pumped back to the WHRU 516 in a closed loop.

[0053] The ORC generator 114 can operate separately from the gas turbine 112 as an independent generator. This can be achieved by adding a fresh air ignition stack and burner, and applying a diverter damper positioned between the gas turbine generator and the fresh air ignition stack / burner. The diverter damper can be positioned to operate the gas turbine generator 112 and the ORC generator 114 to operate together in a combined cycle or independently. This arrangement provides a degree of redundancy in the power generation capacity of the power generation system 100 and also allows the generators to operate during low load periods to maximize their efficiency.

[0054] The power generation system 100 includes a closed-loop thermal circuit to capture and utilize the latent energy released during LNG regasification to improve system efficiency. When the fuel is converted to a liquid state, it contains latent energy, which is approximately 10% of the BTU (British Thermal Unit) content of the fuel itself. Its capture and utilization in the thermal circuit increases the power generation capacity and reduces the parasitic load losses, thereby improving the overall efficiency of the power generation system 100.

[0055] In the regasification and vaporization of LNG, the power generation system 100 utilizes seawater at approximately 25 °C from the PNG offshore unlimited supply. Utilizing a liquid-to-liquid vaporizer allows the transfer of latent energy into the closed-loop thermal circuit, which provides a medium for converting the latent energy into useful work.

[0056] The hot fluid circuit utilizes the latent energy to cool the inlet air supplied to the gas turbine generator 112 from an average ambient temperature of 26 °C to 15 °C, which has the effect of increasing the output of the gas turbine generator 112 by approximately 10% and increasing the fuel efficiency by approximately 3%. Once a portion of the latent energy in the hot fluid is used to cool the inlet air, the inlet air is then used to provide cooling for the power generation barge equipment, which includes air conditioners, turbine lubricating oil cooling, and liquid-cooled air compressors, thereby reducing the parasitic load and further improving the overall system efficiency.

[0057] During the transportation, storage, and handling of LNG, boil-off gas (BOG) is continuously generated. The LNG must be maintained at a temperature equal to or lower than -161 °C to maintain its liquid state. The LNG gets heated when it comes into contact with the storage tank wall and evaporates to produce BOG. The conventional practice in large LNG fuel power plants is to compress the BOG, re-liquefy the BOG, and then immediately vaporize it to inject it into the gas turbine. However, the requirement for a BOG compressor and the associated high parasitic load reduce the overall efficiency of the power plant. An alternative to this arrangement is to flare the BOG to the atmosphere to control the storage tank pressure, but doing so results in approximately 10% fuel loss.

[0058] The present power generation system 100 utilizes BOG in the operation of the ORC generator 114 as fuel for the auxiliary burner. As discussed above, the BOG is fired in the exhaust stream of the gas turbine / fresh air firing stack at the auxiliary burner ahead of the WHRU 516 to capture the BOG energy in the ORC generator without the need for expensive compressors or significant addition of parasitic loads.

[0059] Detailed description of the embodiments

[0060] Figure 1 and Figure 2 A general arrangement of a power generation system 100 is shown according to some embodiments. Figure 1 The main components of the power generation system 100 are shown in schematic form, and Figure 2 is a pictorial layout of a power generation system 100. The power generation system 100 is shown installed in the sea immediately off the coast of a land-based substation 135.

[0061] The power generation system 100 includes a power generation barge 110, an LNG storage barge 120, and a floating dock 130 to which the LNG storage barge 120 and the power generation barge 110 may be moored during operation of the power generation system.

[0062] The LNG storage barge 120 comprises a floating vessel having a generally rectangular plan view. The vessel includes a frame 220 and a hull 222 surrounding the frame 220. The frame supports a plurality of LNG storage tanks 122 and a manifold system 125. The manifold system 125 is configured to facilitate the transfer of LNG from one or two storage tanks 122 to the gas turbine 112 via a supply conduit 127. The manifold system 125 may include conduits, valves, manifolds, flow control components, displays, and sensors (e.g., pressure sensors and flow sensors). The LNG storage capacity of the LNG storage barge 120 is approximately 3000m 3 , which provides thirty days of supply for Power Barge 110. Figure 1 In the exemplary embodiment shown, the LNG storage barge 120 has two LNG storage tanks 122 supported thereon, each LNG storage tank having a capacity of approximately 1500 m 3 storage capacity. Figure 2 In FIG. 1 , four LNG storage tanks 122 are shown, each of which has a capacity of about 750 m 3Storage capacity. The number of LNG storage tanks 122 on the barge 120 can vary as long as the storage capacity is sufficient to store the minimum fuel supply, e.g., sufficient to operate the gas turbine 112 for thirty days. The amount of fuel stored ensures that the LNG storage barge 120 only needs to return to the bulk storage facility 400 once every thirty days, which may be hundreds of kilometers away from the power generation system site. Providing storage capacity for a thirty-day LNG supply allows for sufficient redundancy in the shipping schedule in case weather or sea conditions prevent LNG shipments. The LNG in the storage tank 122 is supplied to the power generation barge through the LNG supply conduit 127.

[0063] The vessel frame 220 and hull 222 of the LNG storage barge 120 define a barge having a wide and shallow draft suitable for shallow water mooring. The hull 222 defines a bow section and a stern section of the barge. The deck 1110 (see Fig.11 ) is supported by the vessel frame 220 to facilitate access for operation and maintenance. The LNG storage barge 120 does not have its own built-in propulsion member. Instead, the hull 222 has a recess 224 defined in the central portion of the stern section to receive the bow of a driving vessel, such as an articulated tugboat (ATB) (not shown). The recess 224 is shaped to have an apex with an acute angle large enough to receive the bow of the driving vessel and allow the bow to drive the LNG storage barge by pushing it forward. The recess 224 includes a part of a two-part interlocking mechanism (not shown) for locking the LNG storage barge 120 to the ATB. The ATB includes the second part of the two-part interlocking mechanism. For example, a hydraulic piston can be driven from the ATB into the barge 120 to mate the two vessels into a single floating unit. In one embodiment, the hydraulic interlocking mechanism is a hydraulic pin. As Fig.11 seen, the bow section of the hull 222 has an acute angled surface 1140 which facilitates forward passage of the barge through the water. Disconnecting the propulsion member from the LNG storage barge 120 eliminates the risk of propulsion maintenance problems that could jeopardize the reliability of LNG supply to the remote power generation system 100. It also has the additional benefit that a non-powered barge requires far fewer crew members than a powered barge.

[0064] The power generation barge 110 is a generally rectangular floating vessel having a plan area of approximately 30 m 2, and includes a ship frame 230 supporting a main deck 930 and an underdeck space 1020 below the main deck. The hull 232 surrounds the frame 230 and defines the bow section and the stern section of the power barge 110. The power barge 110 is an independent LNG storage, regasification and combined cycle power plant as will be described herein. The power generation is generated using a gas turbine 112 and / or an ORC generator 114. The LNG supply conduit 127 supplies LNG to the power generation barge 120, where the LNG is vaporized for use as a fuel in the gas turbine 112. The ORC 114 operates using a hot fluid as a working fluid. Waste heat from the gas turbine 112 can be used to provide thermal energy to the hot fluid. Both the gas turbine 112 and the ORC generator 114 generate electricity to a power subsystem 116 controlled by a control center 115. The control center 115 monitors the power load demand of the land-based substation 135 and controls the operation of the power plant accordingly.

[0065] The vessel frame 230 and hull 232 of the power generation barge 110 define a barge having a wide and shallow draft suitable for shallow water mooring. The hull 232 defines a bow section and a stern section of the barge. The power generation barge 110 does not have its own built-in propulsion components. Instead, the hull 232 has a recess 234 defined in the central portion of the stern section to accommodate the bow of a driving vessel, such as an articulated tug boat (ATB) (not shown). The recess 234 is formed to have an apex with an acute angle, which is large enough to accommodate the bow of the driving vessel and allow the bow to drive the power generation barge 110 by pushing the power generation barge forward. As seen in 9, the bow section of the hull 232 has an acute surface 940, which facilitates the forward passage of the barge on the water. As with the LNG storage barge 120 , decoupling the propulsion components from the power generation barge significantly reduces the number of crew members required and avoids potential interruptions in power supply due to propulsion maintenance if a problem occurs at a location remote from the power generation system 100 .

[0066] The power generation barge 110 has a shallow draft to allow the barge to be positioned in a protected harbor and as close to the coast as possible. This allows the use of overhead power lines 132, 134 that connect from the power subsystem 116 to the land transmission and distribution system at the substation 135. In some embodiments, a first power line 132 can extend from the power subsystem 116 to a connection device 133 that is electrically connected to the second power line 134 to provide power to the substation 135. The connection device 133 can include a transformer, a fused circuit breaker and a load break elbow, a coaxially operated load break switch, and / or other systems to physically and / or electrically allow the first power line 132 to be connected and disconnected from the second power line 134. For example, the connection device 133 can be located on the floating dock 130 (e.g., at or near the safety gate 140), on the gangway 136, or at a safety device on land. A quick connect / disconnect system (not shown) on the power barge 110 may allow the gas turbine 112 and the ORC generator to be disconnected from the first power line 132 for rapid removal of the barge in an emergency.

[0067] The floating dock 130 is an elongated steel structure coupled to a fixed structural pile or tower 305 that fixes the position of the floating dock 130 relative to the seafloor while allowing it to rise and fall with sea conditions (e.g., due to tidal currents). The floating dock 130 includes an elongated landward dock section 322 and an elongated seaward dock section 326. The landward dock section 322 is connected to the seaward dock section 326 by a central platform 324 that extends at right angles to the dock sections, generally parallel to the shoreline. The seaward platform 328 extends parallel to the central platform 324 at the seaward end of the seaward dock section 326, while the landward platform 320 extends parallel to the central platform 324 at the landward end of the landward dock section 322. Between the seaward platform 328 and the central platform 324, an LNG storage barge mooring compartment 312 is defined at either side of the seaward dock section 326. Between the seaward platform 328 and the central platform 324 , a power generation barge mooring compartment 310 is defined at either side of the landward dock section 322 .

[0068] Each of the seaward dock section 326 and the landward dock section 322 includes an interlock 340 located at either side thereof for locking the power generation barge 110 and the LNG storage barge 120 into the mooring compartments 312, 310. Interlocking the barges and the floating dock 130 in this manner reduces the extent and angle of movement that may occur due to tidal and wave effects at the critical LNG fluid transfer conduit 127 between the LNG storage barge 120 and the power generation barge 110, and allows for the transfer of LNG fuel during high wind and sea conditions. The interlock 340 may be a mechanical mechanism suitable for limiting movement between the floating dock 130 and the power generation barge 110 and / or the LNG storage barge 120. For example, the interlock 340 may be a hydraulic interlock, such as a hydraulic pin.

[0069] Known floating power generation systems typically use mooring / mooring lines or sea anchor systems to secure the vessel to the platform / dock. Due to wind and / or sea conditions, these mooring / mooring lines and sea anchor systems typically result in a greater degree and angle of movement of the vessel relative to the platform / dock. Reducing this movement by using an interlock 340 can allow resources to be transferred between the LNG storage barge 120 and the power generation barge 110 when larger winds and / or sea conditions would prevent or limit resource transfers of known floating power generation systems. That is, the interlock 340 can allow the floating power generation system 100 to overcome limitations on resource transfers of known floating power generation, such as LNG and BOG transfers, for example, due to wind and / or sea conditions. This in turn allows smaller resource transfers to be performed intermittently, such as in response to demand, rather than having to perform large resource transfers in smaller winds and / or sea conditions.

[0070] The seaward end of the floating dock 130 further includes a floating wall 335 extending inline from either end of the seaward platform 328, generally parallel to the shoreline. When moored in the mooring compartment 312, the floating wall 335 extends beyond the end of the LNG storage barge 120 to provide some protection for the LNG storage barge and the power generation barge 110 from tidal surges. At the landward end of the floating dock, a gangway 136 extends from the seaward platform 320 to land to provide personnel access from shore to the floating dock 130.

[0071] As in Figure 1As schematically shown in FIG. 1 , a security gate 140 may be installed at the landward end of the floating dock 130. When the power generation barge 110 and the LNG storage barge 120 are moored in and interlocked with the floating dock 130, the security gate 140 provides controlled access to the floating dock 130, and thereby provides controlled access to the power generation barge and the LNG storage barge. The security gate 140 includes a security gate, door or other barrier, and has a controlled access device, such as a terminal that requires the presentation of a pass key or the like to allow access through the gate, door or other barrier. A person passing through the security gate 140 can access the length of the floating dock 130, which includes the landward platform 320, the center platform 324 and the seaward platform 328, to approach the moored power generation barge 110 or the LNG storage barge 120.

[0072] As in Figure 3 1 , the overhead power line 132 of the power barge 110 extends toward the shore parallel to the gangway 136. A support structure 342 extends vertically upward from the landward platform 320 to support the first power line 132 on its seaward side connected to the connection equipment 133 and / or the second power line 134. An additional support structure 342 for the first power line 132 may be provided at the power generation barge 110. For example, power from the power generation barge 110 may be connected through the 11 kV first power line 132 using a coaxially operated load break switch mounted on the pile structure 305. The overhead line pole on one of the piles of the pile structure 305 may have a fuse circuit breaker and a load break elbow mounted on the top of the pole to allow the power line 132 to be isolated and disconnected from the power generation barge 110.

[0073] The floating dock 130 rises and falls with the tide, always maintaining neutral buoyancy. The floating dock 130 accepts power generation barges 110 of different sizes, such as barges of smaller power capacity or barges of larger power generation capacity, to provide barge replacement and scalability of the power generation system 1. This is achieved through the interchangeability of the interlocking connection 340, which can be used to interlock power generation barges 110 or LNG storage barges 120 of various power capacities. In an optional embodiment, a spare power generation barge 110 is provided to allow the entire power generation barge 110 to be exchanged during maintenance work on the gas turbine 112, thereby eliminating any shutdown requirements of the power generation system 100 for this purpose.

[0074] 4A and 4B show a floating dock 130 installed adjacent a bulk storage facility 400 that is also located in the sea away from the seaward end of the floating dock 130. The bulk storage facility 400 facilitates the storage of 40,000 m3 of 3 Bulk storage facility 40 is for smaller 3,000m 3The LNG storage barge 120 provides the necessary fuel supply station, and the bulk storage facility 40 is located at a hub location where the LNG storage barge 120 can be reached by sea. The bulk storage facility 400 reduces the shipping time to the remote power generation system location. For example, the bulk storage facility 400 is located at a distance of 800-1000Km from multiple remote power generation systems 100, resulting in a return LNG delivery cycle from the bulk storage facility 400 to the power generation system 100 of approximately 9 days by sea. The bulk storage facility 400 can also supply larger volumes of LNG, which is necessary to supply multiple larger generators at remote locations where the power demand is greatest.

[0075] The bulk storage facility 400 is a floating structure having a platform 450 supported by fixed structural piles or towers 405, 465 (see FIG. 4B) that fix the position of the bulk storage facility 400 relative to the seafloor while allowing it to rise and fall with the tide. The platform 450 supports a plurality of storage tanks 452 thereon. In the example of FIG. 4A, the platform supports 17 storage tanks 452, however the number of storage tanks may vary depending on the specific storage capacity requirements at a particular location. The bulk storage facility 400 is positioned offshore of the floating dock 130 and helps provide protection for the power generation system 100 in the open sea.

[0076] The plan view of the platform 450 is rectangular and has two longer sides, including a landward facing side 424, a seaward facing side 425, and two shorter side walls 432. The platform 450 is composed of a supporting perimeter frame 464 to which the walls 424, 425, 432 are attached. The landward facing side 424 of the platform 450 extends the length of and is parallel to the seaward platform 328 and the seawall 335 of the floating dock 130. A gangway 420 extends between the platform 450 and the seaward platform 328 of the floating dock 130 to provide personnel access to the bulk storage facility 400. A pair of mooring compartments 412 are defined by sidewalls 432, access piers 430 extending from and in line with the landward facing wall 424 of the platform 450 into the sea, and seawalls 435 located at the distal end of the access piers 430 and extending parallel to the sidewalls 432, one at either side of the platform. The sidewalls 432, access platform 430, and seawalls 435 form a U-shaped barrier in the sea to define the mooring compartments 412 in which the refueling LNG storage barge 120 can be moored. When the LNG storage barge 120 is moored in the mooring compartments 412, the access piers 430 provide personnel access from the platform 450 to the LNG storage barge. A facility management control system in a control room 455 on the platform 450 controls the operation of the bulk storage facility 400, including monitoring the liquid level of the storage tanks 452 and performing LNG supply operations on the storage tanks 122 on the moored LNG storage barges 120. The facility management control system includes a dedicated control panel for each system or subsystem. For example, the gas turbine (GT) system and the ORC 114 each have a dedicated control panel to allow operator monitoring and control. In addition, the facility management control system integrates the operation of the GT, ORC, fuel transfer, heat exchange fluid system, and ballast system (which needs to be adjusted as fuel is consumed). The facility management control system further monitors the fuel level in the fuel barge and controls the fuel transfer as needed using the fluid transfer infrastructure (e.g., pumps, valves, conduits) in the system 100.

[0077] A fluid transfer conduit (not seen in the figure) is provided for the purpose of refueling the LNG storage barge 120 from the storage tank 452. A valve system (not seen in the figure) is provided to control the supply of LNG in the fluid transfer conduit.

[0078] Turning now to the operation of power generation system 100, Figure 5 FIG. 1 is a schematic diagram showing the interface between the gas turbine plant 112 and the ORC 114 and the major components of the ORC 114. FIG. 8 shows the equipment and fluid connections for the gas turbine 112 and the ORC 114 in more detail. The gas turbine plant 112 includes one or more marine versions of natural gas turbines, such as those manufactured by SolarTurbines.TM 5.3MW Solar Taurus 60 turbines (under ISO conditions) or 15.6MW Solar Titan 130 turbines (under ISO conditions) are manufactured. These marine versions of the turbines are suitable for marine environments, for example by adopting stainless steel housings and key components. The gas turbine generator 112 also has thrust bearings and a three-point mounting system to allow deflection and movement of the power generation barge 110. The power capacity of the gas turbine is selected according to the intended use of the power plant. In this example, the 5.3MW and 15.6MW gas turbines are suitable for small power plant ratings required for remote areas such as PNG. It should be understood that any suitable gas turbine suitable for the intended use can be used. The gas turbine generators require regular maintenance and overhaul. In one embodiment of the power generation system 100, an additional power generation barge 110 is provided so that during maintenance, the power generation barge 110 can be exchanged with a replacement barge without causing a significant interruption in the power supply to the substation 135.

[0079] The gas turbines 112 each include a generator for generating electricity via shaft power. Figure 5 In the schematic diagram of FIG. 1 , the gas turbine power plant 112 includes three gas turbine generators 112 that may have the same or different power capacities. However, depending on the specific design of the power barge 110, the power generation system 100 may have only a single gas turbine generator 112 or multiple gas turbine generators 112. For clarity, the following description assumes a single gas turbine generator 112.

[0080] The gas turbine 112 has an exhaust duct 512 through which the exhaust gases pass after the combustion gases pass through the engine turbine. The exhaust gases are typically at a temperature of 500-600° C. The exhaust duct 512 is arranged to be in fluid communication with the ORC chimney 514 at its lower end 515 and rises to the top of the ORC chimney 514 where the exhaust gases exit to the ambient atmosphere at an upper end 517.

[0081] As in Figure 5 As seen, the ORC stack 514 is integrated into a waste heat recovery unit (WHRU) 516. The WHRU 516 provides an interface between the gas turbine 112 and the ORC 114. The ORC power plant 114 itself is an independently operable electrical power generator, however, when the ORC power plant is operated in combination with the gas turbine power plant 112, process efficiency is improved, as will be described herein.

[0082] The evaporator 520 and optionally the preheater 518 form part of the WHRU 516 to recover heat from the exhaust gas in the ORC stack 514 to heat the hot fluid of the ORC 114. The WHRU 516 is essentially a heat exchanger that utilizes a closed loop of hot oil through the ORC stack 514 and the evaporator 520 of the ORC 114. The hot oil circuit includes the hot oil conduit 520 and the pump 814, Figure 8b The hot oil conduit 530 passes through the upper end 517 of the ORC chimney 514 and exits the chimney 514 at its lower end 515. The hot oil conduit 530 then continues to the evaporator 520. Figure 5 In the embodiment, the conduit 530 also passes through the preheater 518, however, this is optional. When leaving the evaporator 520 or the preheater 518 (if used), the conduit 530 returns to the upper end 517 of the chimney 514.

[0083] The hot fluid in conduit 530 is pumped by pump 814 into the upper end of the ORC chimney 530 and is heated by the exhaust gases flowing upward through the ORC chimney 514. The heated hot oil exits the lower end 515 of the ORC chimney 514 and passes through the evaporator 520 where its thermal energy is transferred to the ORC working fluid passing through the evaporator 520. The hot oil is thus cooled as it exits the evaporator 520. If the hot oil also passes through the preheater 518, it transfers additional thermal energy to the ORC working fluid before the working fluid enters the evaporator 520.

[0084] The cooled hot oil is then pumped back into the ORC chimney 514. The exhaust gas is cooled from 500 degrees Celsius to about 130 degrees Celsius in the ORC chimney 514, and the exhaust heat energy is transferred to the ORC working fluid and used to generate electricity at the ORC 114. The cooling of the exhaust gas in the ORC chimney 514 can reduce the parasitic load of the ORC 114. The cooling of the exhaust gas in the ORC chimney 514 can improve the overall efficiency of the floating power generation system 100.

[0085] The ORC 114 operates in a standard ORC closed loop. The cycle includes a preheater 518, an evaporator 520, an expansion turbine 522, an electric power generator 524, a condenser 526, and a recuperator 528 through which a thermal fluid passes during the cycle. The ORC working fluid is a thermal fluid that is transported through the cycle in a thermal fluid conduit 532. A pump 534 located in the conduit 532 between the condenser 526 and the recuperator 528 is used to pump a low pressure, low temperature thermal fluid out of the condenser 526 through the conduit 532 and into the recuperator 528. The thermal fluid recovers heat and pressure and then passes through the preheater 518 and the evaporator 520 where heat is transferred from the very hot hot oil in the hot oil conduit 530 of the WHRU 516 and evaporated into vapor at high temperature and pressure.

[0086] The turbine 522 may be a radial turbine, such as an Atlas Copco radial turbine, or the turbine may be an axial turbine, such as a Turboden axial turbine. In the case where the turbine 522 is a radial turbine, the turbine has variable inlet vanes that are controllable to enable the electrical output of the ORC generator 114 to be adjusted. For example, if a rapid drop or spike in voltage is detected at the control room 910 of the ORC generator 114, an automatic pneumatic control associated with the turbine 522 opens or closes the vanes to a certain degree to increase or decrease the flow of thermal fluid through it. In the case where the turbine 522 is an axial turbine, an automatic controller associated with the turbine 522 opens and closes a valve in the thermal fluid conduit 532 to increase or decrease the flow of thermal fluid through the turbine 522. The vaporized high-pressure thermal fluid leaving the evaporator flows rapidly through the turbine 522, causing the turbine shaft to rotate to produce work. The rotating shaft drives the electrical generator 524 to generate electricity for the power subsystem 116.

[0087] The hot fluid expands in turbine 522 and the hot fluid pressure and temperature are reduced. The cooled vapor passes through recuperator 528 where it is used to transfer heat to the condensed hot fluid that has left condenser 526 and passed through the recuperator in the opposite direction as described above, thereby further cooling the vapor. The cooled vapor hot fluid leaving recuperator 528 is then condensed into liquid form in condenser 526 and the cycle begins again.

[0088] The condenser 526 forms part of a separate seawater loop 536. The seawater loop supplies seawater at about 26°C into a seawater conduit 537. A seawater pump 538 in the seawater conduit 537 is arranged to pump seawater into the condenser 526 to cool the hot fluid vapour and thereby condense it. The warmed seawater leaves the condenser at a temperature of about 36°C and returns to the discharge conduit 820 where it is heated. Figure 8c See.

[0089] Figures 6 to 8c It is a LNG storage barge 120( Figure 6 ) and power barge 110 (FIGS. 7-8c). LNG is initially stored on LNG storage barge 120 and then transferred from storage barge 120 to power barge 110. FIGS. 7-8c each show a portion of the power barge process, which may be continued in another figure. Therefore, for clarity, Figure 6-8cEach figure in the diagram shows where it is connected to one of the other figures. When two related figures are viewed together, it is apparent that there may be small overlaps between some of the figures.

[0090] The LNG storage barge 120 is arranged in a port and starboard configuration, where the starboard half of the LNG storage barge 120 is a mirror image of the port half. This intentional duplication of equipment provides redundancy for the storage barge 120 and ensures that LNG is available in the event of any equipment failure on either half of the storage barge 120. Figure 6 The port half of the storage barge 120 is shown, and it will be appreciated by those skilled in the art that the starboard half is identical in terms of equipment and differs only in the placement of the pipes / conduits. Each half of the storage barge 120 houses four LNG storage tanks 122. The total volume capacity of the LNG storage tanks 122 is between 1000m3 and 1000m4. 3 About 6000m 3 In the embodiment, the four LNG storage tanks 122 have a capacity of about 3000m 3 127, however, this capacity can be provided by two or three tanks instead of four tanks. Each LNG storage tank 122 has a fluid delivery conduit 623 for supplying LNG into the tank 122. A valve system 624 in the fluid delivery conduit 623 at each tank 122 is operable to control the flow of LNG in the fluid delivery conduit 623 and into the LNG storage tank 122. An additional fluid delivery conduit 625 allows LNG to flow out of the LNG storage tank 122 and into the LNG supply conduit 127. The valve system 624 includes valves in the fluid delivery conduit 625 to control the flow of LNG out of the tank 122 and into the fluid delivery conduit 625.

[0091] The storage barge 120 further includes a boil-off gas (BOG) exhaust conduit 630 to receive and transport boil-off gas generated by the LNG in the LNG storage tank 122. The boil-off gas can be transported to the power barge 110 via the BOG exhaust conduit 630. The storage barge 120 further includes one or more compressed air tanks 612 to supply compressed air for operation of one or more ballast pumps 610 and / or one or more high pressure pumps 716. The ballast pumps 610 pump seawater into ballast tanks located within the hull 222 for ballast control when the storage of LNG is depleted. Figure 7b and 7eAs can be seen, the compressed air supply line 614 for supplying compressed air to the compressed air tank 612 is arranged to be in fluid communication with one or more air compressors 780 located on the power generation barge 110. Locating the one or more air compressors 780 on the power generation barge 110 avoids the requirement for an ignition source for the air compressors 780 located on the storage barge 120. The pump control interface at the ballast pump 610 allows for control of the ballast pump 610 by an external controller (such as the control room computing device 1815) in the control center 115 ( Fig.18a ) to control the ballast pump 610 and / or one or more high-pressure pumps 716. For this purpose, an external control line is connected to the pump control interface.

[0092] The LNG supply conduit 127 supplies LNG at -160 degrees Celsius and 1 bar to the power generation barges 110. The boil-off gas (BOG) exhaust conduit 630 delivers boil-off gas from the tanks on each barge to the power generation barges 110 at -160 degrees Celsius and 1 bar.

[0093] The LNG supply conduit 127 and the BOG exhaust conduit 630 extend to Figure 7a-7e and Fig. 9 and 10 1. The power generation barge 110 has power generation equipment arranged on the port side 711a and the starboard side 711b, distributing the weight evenly on the barge. Some equipment is duplicated on the port side and the starboard side of the power generation barge 110 to provide the necessary redundancy of the power plant equipment, thereby ensuring the continuity of power supply in the event of equipment failure.

[0094] LNG is supplied to the LNG belly tank 710 at each of the port side 711a and the starboard side 711b of the barge. The belly tank 710 is installed on the upper deck of the power barge 110, and the capacity of each belly tank is 250m 3 , which is sufficient to provide gas turbine power plant 112 with enough fuel to last for about 7 days. A single larger LNG tank has the benefit of being superior to several smaller tanks in terms of simpler fuel refueling logistics. In addition, due to the smaller tank surface area in contact with the LNG, a single well-insulated tank produces significantly less BOG than several smaller tanks. Each belly tank 710 is fluidly connected to a BOG tank 720 by a pipeline 712 to store BOG evaporated from the LNG stored in the belly tank 710. The capacity of the BOG tank 720 is 25m 3 .exist Figure 8b It can be seen that an additional pipeline 722 is provided between the BOG tank 720 and the auxiliary ignition burner 830 of the power barge 110 to provide fuel to the auxiliary ignition burner 830 .

[0095] The port side LNG belly tank 710 is fluidly connected to the vaporizer 730 via the LNG supply conduit 714. The vaporizer 730 is a plate and shell heat exchanger that receives LNG at -163°C on its 'cold' side and a hot fluid at 15.8°C on its 'hot' side. A high pressure pump 716 is located in the LNG supply conduit 714 to pump the LNG in the conduit 714 to the vaporizer 730. In some embodiments, the high pressure pump 716 is a pneumatic pump. For example, the high pressure pump 716 can be a pneumatic submersible cryogenic transfer pump. Using a pneumatic pump can reduce the risk of ignition of flammable materials (such as LNG) on the storage barge 120.

[0096] The hot fluid (ethylene glycol in this example) is introduced into the 'hot' inlet 734 of the vaporizer 730 at 15.8°C. The plate and shell vaporizer 730 promotes heat transfer between the two fluids as they pass through the vaporizer 730, so that the LNG vaporizes to natural gas as it passes through the vaporizer 730 and leaves the vaporizer at a 'cold' outlet 736 at -77°C. The hot fluid leaves the vaporizer 730 at a 'hot' outlet 738 at a temperature of 3°C.

[0097] The natural gas leaves the vaporizer 730 and enters the natural gas conduit 750 for delivery to the natural gas / hot fluid superheater 744. The superheater 744 is a further plate and shell heat exchanger which utilises the thermal energy stored in the hot fluid before it enters the vaporizer 730 to transfer further thermal energy to the natural gas in the superheater 744. The hot fluid is supplied to the superheater 744 at the 'hot' inlet 746 at a temperature of 24°C and leaves the superheater 744 at the 'hot' outlet at a temperature of 15.8°C, which is the temperature at which the hot fluid enters the vaporizer 730. The natural gas is supplied to the superheater 744 at the 'cold' inlet 751 at a temperature of -77°C, which is the temperature at which the natural gas leaves the vaporizer 730. It is warmed by heat exchange with the hot fluid and exits the superheater 744 at the superheater's 'cold' outlet 752 into a transfer conduit 754 for delivery to the gas turbine plant 112 for combustion as fuel. That is, for example, the operating temperature of the hot fluid is between about 3°C ​​and about 24°C.

[0098] The hot fluid passes through the vaporizer 730 and the superheater 744 as part of a closed loop hot fluid circuit which will be described below. The hot fluid circuit recovers the latent energy released when the LNG is converted to its vapor state in the vaporizer 730 and transfers the latent energy to the hot fluid in the hot fluid circuit. The latent energy is then utilized at several points in the hot fluid circuit to increase the efficiency or power output of the power barge. For example, Figure 7aAs shown, the hot fluid circuit includes a superheater 744, a vaporizer 730, a cooling header manifold 760, a mixing tank 762, and an ethylene glycol / seawater heat exchanger 770. As described above, the hot fluid passes through the superheater 744 and enters conduit 745, and the hot fluid is cooled to 3 °C as it passes from the conduit through the vaporizer 730. From here, the hot fluid reaches the cooling header manifold 760 through additional conduit 739. The cooling header manifold 760 also receives the hot fluid in conduit 761 that has passed through the BOG tank 720 to cool the ethylene glycol to a temperature within the target cooling temperature range before the ethylene glycol enters the cooling header manifold 760. The temperature of the cooled ethylene glycol will depend on the ambient temperature and the amount of evaporation generated, although a lower temperature is preferred. The closed-loop hot fluid circuit helps control the pressure of the boil-off gas (BOG) in the tank. The ethylene glycol will be much hotter than the boil-off gas, so this will increase the pressure in the BOG tank to help raise the pressure to the pressure required for the auxiliary burner. That is, the ethylene glycol is used to heat the BOG so that the pressure of the BOG increases before entering the auxiliary burner. Therefore, due to the heat transfer of the ethylene glycol, the temperature of the BOG also increases.

[0099] The hot fluid supply is split into multiple streams at the cooling header manifold 760 for delivery to other parts of the power barge 110. Fluid conduit 763 conveys the hot fluid from the cooling header manifold 760 to the mixing tank 762. Fluid conduit 764 conveys the hot fluid from the cooling header manifold 760 to the port side air compressor 780 (see Figure 7b ), where the hot fluid is used to cool the air compressor 780 in the fluid conduit. The hot fluid then returns to the mixing tank 762 through fluid conduit 767. Fluid conduit 765 conveys the hot fluid from the cooling header manifold 760 to the below-deck HVAC unit 782 (see Figure 7b ), where the hot fluid is used to cool the HVAC unit 782 in the fluid conduit. The hot fluid then returns to the mixing tank 762 through fluid conduit 768. Fluid conduit 766 conveys the hot fluid from the cooling header manifold 760 for use at the gas turbine 112, particularly for cooling the inlet air of the gas turbine engine 112, as will be described later. In one embodiment, a portion of the hot fluid can also be diverted for cooling the turbine lubricating oil. The hot fluid utilized at the gas turbine 112 is heated by the turbine inlet air and / or the turbine lubricating oil and returns to the mixing tank 762 through fluid conduit 783.

[0100] The capacity of the mixing tank 762 is 100 m 3, and mixes and stores hot fluids received from fluid conduits 763, 767, 768. Mixing tank 762 has an outlet to fluid conduit 769, which is fluidly connected to glycol / seawater heat exchanger 770. The glycol hot fluid in the hot loop flows from mixing tank 762 through fluid conduit 769 and is pumped by glycol pump 772 into the 'cold' inlet 774 of glycol / seawater heat exchanger 770. Glycol / seawater heat exchanger 770 is a plate and shell heat exchanger that facilitates heat transfer between the hot fluid and seawater to heat the hot fluid before it is sent to superheater 744 or to BOG tank 720 through fluid conduit 789 so that it can be cooled before it enters the cooling header manifold 760 again. The hot fluid loop is then completed and begins again.

[0101] The hot fluid enters the heat exchanger 770 at a temperature of 21°C, having been heated during the process of cooling the equipment on the power barge 110 as described above. The hot fluid is further heated in the heat exchanger 770 by the passing seawater, and leaves the heat exchanger 770 at a "cold" outlet 776 at a temperature of 24°C. The seawater is heated at 55m 3 The seawater is supplied from the sea in seawater supply conduit 777 to the 'hot' inlet 778 of the heat exchanger 770 at a flow rate of / hour and at an ambient temperature of 26°C. The seawater passes through the hot side of the heat exchanger 770 where some of its heat is transferred to the hot fluid and leaves at the 'hot' outlet 779 at a temperature of 24°C and is returned to the sea through fluid conduit 781.

[0102] Thus, the closed loop heat circuit utilizes the potential energy released during the vaporization of the LNG, captures it in the hot fluid of the superheater 744, and effectively uses it to provide cooling for the gas turbine 112 inlet air, turbine lubricating oil, and other equipment on the power barge 110, such as the air compressor 780 and HVAC unit 782. This results in an increase in the efficiency of the entire power generation system.

[0103] The seawater pump 790 pumps seawater from the sea into the power barge. Figure 7d , three seawater pumps 790 are shown, each of which can operate at a pressure of 5 bar and have a flow rate of 100 cubic meters per hour. Seawater is drawn into the seawater pumps 790 through a seawater supply conduit 792. The seawater is distributed in a distribution conduit 794 for use in a heat exchanger 780 at each side of the port and starboard sides of the power barge 110 and a ballast system 795 located below deck, as shown in FIG. Figure 7d The distribution conduit 794 supplies water to the starboard side seawater supply conduit, and a portion is diverted into the port side seawater supply conduit 777 for use in the port side heat exchanger 780 .

[0104] Conventional practice for large LNG fueled power plants is to include two or more thermal circuits, one capable of operating at cryogenic conditions and the other capable of operating at non-cryogenic conditions. Thermal circuits capable of operating at cryogenic conditions are generally not suitable for use with systems operating at non-cryogenic temperatures, as extremely low temperatures may have a negative impact on those systems. Utilization of the potential for LNG vaporization allows the use of a single closed loop thermal circuit that is not exposed to the cryogenic temperatures of the LNG.

[0105] Figure 8a-8c FIG. 1 is a schematic diagram of a gas turbine generator 112, a WHRU 516, an ORC generator 114, and pipelines for connecting any one of natural gas, boil-off gas, and compressed air. Figure 8a 1. It includes an air inlet 802, which in the example shown includes a three-stage air inlet filter. In some embodiments, the three-stage air inlet filter may include at least one low-loss filter, for example, a low-loss filter for each stage. Ambient air entering the air inlet 802 passes through the filter and enters the air inlet duct 804, which directs the air into the gas turbine engine 112. The main components of the gas turbine engine 112 are shown in FIG. Figure 8a 802, and consists of a compressor, a combustion chamber 806, a turbine, and a generator. The air inlet duct 804 includes one or more cooler coils 808 through which the inlet air passes before entering the compressor of the gas turbine engine 112. The cooler coils 808 are fluidly connected to the hot fluid supply conduit 783 to supply the cooler coils 808 with ethylene glycol hot fluid at a temperature of 3°C. Ambient air enters the air inlet 802 at a temperature of 26°C. As the ambient air flows through the cooler coils 808, the inlet air is cooled to a temperature of approximately 15°C before being compressed in the compressor.

[0106] The combustion chamber 806 is connected to a natural gas supply fluid in a supply conduit 812, which in turn is supplied with natural gas from each of the port and starboard transfer conduits 754 after vaporizing the LNG in the vaporizer 730. Compressed air enters the combustion chamber 806 where it is injected with the natural gas and ignited. The resulting combusted gases are expanded at high speed through a turbine, which rotates to drive an electrical generator. Using cold thermal fluid from the hot loop to reduce the temperature of the inlet air in the gas turbine 112 increases the efficiency of the gas turbine generator by approximately 10% and increases fuel efficiency by 3%.

[0107] In some embodiments, the supply conduit 812 may also be fluidly connected to a natural gas supply stored in a natural gas (NG) accumulator 896. For example, in the event of a sudden increase in consumption, the NG accumulator 896 may be used to store additional natural gas for supply to the combustion chamber 806. That is, for example, if a sudden load is drawn from the gas turbine generator 112, the NG accumulator 896 will supply additional natural gas to the gas turbine generator 112. The size of the NG accumulator is selected to accommodate expected differences in GT fuel gas consumption and the residence time required for the LNG process to reach pressure.

[0108] The turbine is fluidly connected to a turbine exhaust duct 814 at its outlet to discharge exhaust gases. The turbine exhaust duct is a conduit to the atmosphere and is also fluidly connected to a duct 842 through which the exhaust gases passing therethrough can be selectively diverted for use with the WHRU 116 and, therefore, also for the ORC 114. A diverter damper 840 is pivotally mounted in the turbine exhaust duct 814 to selectively divert the exhaust gases. The damper 840 is movable between a first position in which the gas turbine 112 and the ORC generator operate together and a second position in which the gas turbine 112 and the ORC generator 114 operate independently of each other. In the first position of the damper 840, the exhaust duct (or exhaust stack) 814 is closed to the gases leaving the turbine, thereby allowing the gases to flow into the duct 842. In the second position of the damper 840, the exhaust duct is opened to allow the gases leaving the gas turbine to enter the exhaust duct 814, while the duct leading to the WHRU 116 is closed to the gases. In the illustrated embodiment, the diverter damper 840 consists of an air sealing damper, but may take any suitable form that allows gases to be selectively diverted from the turbine exhaust duct 840 to the WHRU 116. Equivalent diverter devices may also be used.

[0109] Pipe 842 provides a fluid connection between the gas turbine 112 and the WHRU 116. Upstream of the WHRU 116 is a fresh air ignition chimney 844, which effectively replicates the turbine exhaust when the ORC generator 114 is to operate independently. The fresh air ignition chimney 844 includes an air inlet 845 to draw fresh air into the chimney 844. A fan 846 positioned at the air inlet draws air into the inlet 845 and through an air filter 847. A blower 854 further supplies fresh air to the fresh air ignition chimney 844 upstream of the combustion chamber 848. The supply of natural gas is diverted from the supply conduit 812 to the supply conduit 852 to provide fuel to the valve 850 of the fresh air ignition chimney 844 at a pressure of 30 bar, a flow rate of 1800 cubic meters per hour, and a temperature of 19°C. Fresh air and natural gas are combusted in combustion chamber 848 , and the co-fired gases exit fresh air ignition chimney 844 into tube 842 .

[0110] An additional diverter damper 860 is pivotally mounted in the tube 842 to selectively allow gases in the fresh air ignition chimney 844 to enter the tube 842. In a first position of the damper 860, the tube 842 is closed to the fresh air ignition chimney 844. In a second position of the damper 860, the tube 842 is open to allow the co-fired gases exiting the fresh air ignition chimney 844 to enter the tube 842. The damper 860 is comprised of an air sealing damper, but may take any suitable form that allows the tube 842 to be opened and closed to the fresh air ignition chimney 844.

[0111] Downstream of the turbine exhaust duct 512 and the fresh air firing chimney 844, the duct 842 is fluidly connected to the auxiliary burner 830. The auxiliary burner 830 includes a combustion chamber that receives ambient air from the blower 856 and fuel in the form of BOG supplied to the combustion chamber from the BOG tank 720 through the supply conduit 722.

[0112] The turbine exhaust gases leave the gas turbine at a temperature of about 500°C. The co-fired gases leave the fresh air firing stack at about the same temperature. The exhaust or co-fired gases in duct 842 enter the auxiliary burner 830 and are ignited by the BOG to further heat the gases to a temperature of about 600°C before the gases enter the WHRU 116. With this arrangement, the BOG is effectively utilized to generate auxiliary heat for operating the ORC 114 by heat transfer from the combusted BOG and the exhaust / co-fired gases to the working fluid of the ORC. The location of the auxiliary burner downstream of the gas turbine 112 and the fresh air firing stack 844 has the effect that the BOG is utilized regardless of whether the gas turbine 112 and the ORC 114 are operated independently or together.

[0113] The position of damper 840 and the position of damper 860, as well as the operation of gas turbine 112 and the operation of ORC generator 114, are controlled by a control system or controller 908, which may be operated from a control center 115 onboard power generation barge 110. Control system or controller 908 may be configured to monitor the power load drawn at at least one remote power receiving end and automatically control the operation of gas turbine 112 and ORC 114 in response to the monitored drawn load.

[0114] Whether the gas turbine 112 or the ORC 114 is operated alone, or both are operated together in a combined cycle, depends on the power load drawn by at least one remote power receiving end (e.g., a substation 135 serving an industrial facility or a residential area). Normal operation of the power barge 110 assumes that the gas turbine 112 and the ORC will operate in a combined cycle, however this is not always valid and it may be necessary to operate the gas turbine 112 or the ORC 114 alone. FIG. 13A is a flow chart of a decision process for positioning the damper 840. At step S1300, the power load drawn by the remote receiving end is determined by the control system or controller 908. The ORC 114 has a first power generation capacity and the gas turbine 112 has a second power generation capacity that is higher than the first power generation capacity. In the event that the load drawn by at least one remote power receiving end is at or above a threshold power load (e.g., the second power generation capacity of the gas turbine 112), at step S1302, the damper 840 is positioned in a first position to allow turbine exhaust to enter the duct 842 and be used for the WHRU 116. If the load drawn at at least one remote power receiving end drops below a threshold power load, it is inefficient to operate gas turbine 112 and ORC 114 in a combined cycle and at step S1304 , damper 840 is positioned in a second position to allow gas turbine 112 and ORC 114 to operate independently.

[0115] In this case, when the damper 840 is positioned in the second position, the gas turbine 112 is operated in a simple cycle without the ORC 114, or the ORC 114 is operated independently without the gas turbine 112. FIG. 13B is a flow chart of the decision process of operating the gas turbine 112 or the ORC 114. At step S1306, the power load drawn by the remote power receiving end is determined by the control system or controller 908. If the power load drawn at the remote power receiving end is higher than the first power generation capacity, that is, the power generation capacity of the ORC 114, and lower than the second power generation capacity, that is, the power generation capacity of the gas turbine 112, then at step S1308, the gas turbine 112 is operated alone in the simple cycle. If the power load drawn at the remote power receiving end is within the first power generation capacity, then at step S1310, the ORC 114 is operated alone in a simple cycle without the gas turbine 112. If the gas turbine 122 is operating alone, positioning the damper 840 in the second position prevents the turbine exhaust from entering the duct 842 instead of exiting the gas turbine through the turbine exhaust duct 512. If the gas turbine 112 is not operating, closing the damper 840 to the duct 842 ensures that the co-fired gases from the fresh air firing chimney 844 flow in the direction of the auxiliary burner 830. In this way, the power barge 110 can be operated at the most efficient level at any time to draw the electrical load. The power generation capacity of the gas turbine will depend on the specific gas turbine used, so a threshold electrical load must be set for the specific gas turbine 112 used, which is lower than the threshold electrical load of the damper 840 positioned in the second position. Therefore, if a 15.6MW solar Solar Titan 130 turbine is used, the electrical load threshold will be 15.6MW. Similarly, if the ORC 114 has a power generation capacity of 6MW, the threshold electrical load is about 6MW, which is lower than the threshold electrical load at which only the ORC 114 will operate. Being able to operate the gas turbine 112 and the ORC generator 114 independently of one another also provides a degree of redundancy should either generator require maintenance.

[0116] Fig. 9 and Fig.10The general layout of the power barge 110 is shown. Although not all equipment is visible in these figures, the LNG storage tank 710, the high-pressure LNG pump 716, the seawater pump 538 and the glycol / thermal fluid circulation pump 534 are all located below the deck. The control center 115 is located on the main deck. For safety reasons, the vaporizer 730 and the BOG tank 720 are also located on the main deck so that the vaporized LNG is not stored in the limited space below the deck. The black start generator (BSG) 920 is located on the main deck for emergency restart of the gas turbine 112. Alternatively, the black start generator 920 can be located on the floating dock 130 to reduce the weight of the power generation barge 110. The gas turbine 112, ORC 114, WHRU 116, pump 772 and heat exchangers 744, 770 are all located on the main deck to provide serviceability.

[0117] The ballast of the power generation barge 110 is controlled by adding and removing seawater to ballast tanks located below deck as fuel is transferred from the storage barge 120 or consumed by power generation.

[0118] exist Fig.10 , the deck 930 and hull 232 are removed to show in more detail the frame 230 of the power generation barge 110. The frame 230 is composed of a plurality of steel frame sections 1010 connected together in an open grid frame to minimize weight while providing the necessary strength to support the power plant equipment.

[0119] Fig.11 and Fig.12 The general layout of the LNG storage barge 120 is shown. Fig.11 As seen, the deck 1110 of the vessel is free of power plant equipment. Four LNG storage tanks 122 are positioned side by side within the vessel frame 220, extending along the length of the vessel bow and stern, and evenly spaced from port to starboard. The LNG storage tanks 122 are covered by tank hulls 1112. A gantry 1130 is mounted above the tank hulls 1112 for personnel access to the area and any equipment mounted above each tank 122. The gantry 1130 is accessed from the deck 1110 through stairs at the bow and stern of the tanks 122. An interlocking connection point 1150 at the bow end of the LNG storage barge 120 allows for interlocking connection with an interlocking device 340 at the floating dock 130 to moor the LNG storage barge 120 in the mooring compartment 310.

[0120] exist Fig.12 , the deck 1110 and cover 1112 are removed to show the frame 220 of the LNG storage barge 120 in more detail. The frame 220 is composed of a plurality of steel frame sections 1210 connected together in an open grid frame to minimize weight while providing the necessary strength to support the LNG storage tanks 122.

[0121] Fig.14a -c is an 11 KV main power single line diagram of the main power system 1400 according to some embodiments. Fig.14a -c indicates that the figure shown is continued in another figure. For example, the line marked "connects to Fig.14b "of Fig.14a The reference line is Fig.14b The corresponding "Connect Fig.14a "Continue. Similar logic applies to Fig.14a -c shows alternative reference lines.

[0122] refer to Fig.14a , the main power system 1400 may include a neutral grounding resistor panel (NGRP) 1402. For example, the NGRP 1402 may be used in the main power system 1400 to protect electrical equipment such as transformers and generators from fault events (e.g., short circuits) and transient phenomena (e.g., lightning). The NGRP 1402 may limit transient overvoltages to safe values ​​during fault events or transient phenomena to avoid outages and damage to equipment within the main power system 1400. For example, the NGRP 1402 may reduce fault current while still allowing enough fault current to flow to activate a protective device.

[0123] The main power system 1400 further includes a gas turbine system 1404 to generate electrical energy using the gas turbine 112, as previously described. The gas turbine system 1404 may further include an automatic voltage regulator (AVR) 1410 to automatically maintain the output voltage of the gas turbine system 1404. That is, for example, the AVR 1410 may be used to regulate the output voltage of the gas turbine system 1404 at a predetermined voltage value. The gas turbine system 1404 may further include a protection device 1412.

[0124] The protection device 1412 may be used to provide overcurrent protection to the main power system 1400. In some embodiments, the protection device 1412 may provide some or all of the following protection features as outlined in "IEEE Standard C37.2 Power System Device Function Numbers, Acronyms, and Contact Names" alone, in combination, or both: 87G (generator differential), 27 (undervoltage relay), 59 (overvoltage relay), 81 (frequency relay), 59N (neutral overvoltage), 32 (directional power relay), 40 (field relay / loss of field), 49G (machine or transformer thermal relay / thermal overload grounding), 46 (reverse phase or phase balance current relay or stator current unbalance), 51V (voltage suppression time overcurrent), 50 (instantaneous overcurrent relay) and / or 50G (ground instantaneous overcurrent). In some embodiments, for example, the protection device 1412 may include multiple relays.

[0125] The main power system 1400 further includes an ORC system 1406 to generate electrical energy using the ORC generator 114, as previously described. The ORC system 1406 may further include an AVR 1410 and a protection device 1412 to perform functions as previously described. The main power system 1400 further includes a BSG system 1408 to generate electrical energy using the BSG generator 920. For example, the BSG system 1408 may be used to start the gas turbine 112 of the gas turbine system 1404. For example, the BSG system 1408 may be used to start the ORC generator 114 of the ORC system 1406. The BSG system 1408 may further include an AVR 1410 and a protection device 1412 to perform functions as previously described.

[0126] refer to Fig.14b , reference letters "A" and "B" indicate Figure 14b to Figure 15b Continuation of the line. For example, Fig.14b The line marked with "A" in Fig.15b Continue at the corresponding "A" above. Similar logic applies to Fig.14b and 15b The "B" on the

[0127] The main power system 1400 further includes monitoring and protection (MP) panels 1420, 1422, and 1424 that are in electrical communication with the gas turbine system 1404, the ORC system 1406, and the BSG system 1408, respectively. Each MP panel 1420, 1422, and 1424 is used to monitor the power provided by its corresponding system and provide circuit protection in the event of a fault. The MP panels 1420, 1422, and 1424 each include a circuit breaker 1450, a step-down transformer 1452, a metering device 1454, a protection device 1456, and a plurality of current transformers 1458. In some embodiments, the circuit breaker 1450 can be a three-phase circuit breaker appropriately rated according to the system to which it is connected. For example, the circuit breaker 1450 can be rated at 1600A, 1000A, 600A, or 200A. For example, MP panel 1420 in electrical communication with gas turbine system 1404 may be rated for 1000A to accommodate the electrical output of gas generator 112. In some embodiments, circuit breaker 1450 may be a withdrawable circuit breaker. That is, circuit breaker 1450 may be a circuit breaker that can be physically removed from the system, for example, under no-load conditions.

[0128] The step-down transformer 1452 may be used to step down the voltage input to each MP panel 1420, 1422, and 1424 to power other electrical components within the panel, such as the metering device 1454 and the protection device 1456. For example, the MP panel 1420 receives an input voltage from the gas turbine system 1404, and the step-down transformer 1452 steps down the input voltage to an appropriate voltage to power the metering device 1454 and the protection device 1456. In some embodiments, the step-down transformer 1452 may include a circuit breaker in series with each secondary winding. That is, for example, a circuit breaker may be included between each secondary winding and the connected electrical component, such as the metering device 1454 and the protection device 1456.

[0129] Metering device 1454 can be used for some or all of the following: analysis of efficiency, loss, and capacity; bill verification, cost allocation, and sub-metering; power quality compliance monitoring; problem notification and diagnosis; demand for power factor management; and control of loads, generators, or other equipment. In some embodiments, for example, metering device 1454 can be an off-the-shelf device, such as Schneider ION 7650.

[0130] Protection device 1456 may be used to provide overcurrent protection to main power system 1400. In some embodiments, protection device 1456 may provide some or all of the following protection features as outlined in "IEEE Standard C37.2 Power System Device Function Numbers, Acronyms, and Contact Designations": 50 (Instantaneous Overcurrent Relay), 50N (Neutral Point Instantaneous Overcurrent), 50G (Ground Instantaneous Overcurrent), 87G (Generator Differential), 25 (Synchronization or Synchronization Check Device), 27 (Undervoltage Relay), 59 (Overvoltage Relay), and / or 81 (Frequency Relay) alone, in combination, or both. For example, protection device 1456 may be an off-the-shelf device such as Selinc SEL-351A.

[0131] In some embodiments, current transformers 1458 may be used to reduce the AC power input to each MP panel 1420, 1422, and 1424 for use by metering device 1454 and protection device 1456. For example, MP panel 1420 receives input AC power from gas turbine system 1404, and current transformer 1458 reduces the input AC power to an appropriate AC power to provide to metering device 1454 and protection device 1456.

[0132] In some embodiments, each MP panel 1420, 1422, and 1424 includes an electrical connection to a synchronizer 1459. The synchronizer 1459 can be used to 'synchronize' the frequency of the gas turbine system 1404, ORC system 1406, and BSG system 1408 to match the frequency of the operating network or the system drawing power from the generator. When at least two of the gas turbine system 1404, ORC system 1406, or BSG system 1408 are simultaneously providing power to the operating network, they must be synchronized so that they provide power in parallel. In some embodiments, the synchronizer 1459 can control the operation of the gas turbine system 1404, ORC system 1406, or BSG system 1408 so that it has the same line voltage, frequency, phase sequence, phase angle, and waveform as the operating network to which it is synchronized.

[0133] The main power system 1400 may further include a first auxiliary transformer (T-AUX1) 1432 and a second auxiliary transformer (T-AUX2) 1436. T-AUX1 1432 and T-AUX2 1436 may be used to step down the high voltage supplied by the gas turbine system 1404, the ORC system 1406, or the BSG system 1408, either alone or in combination with one another, to a lower voltage available to the barge power system 1500, which will be combined with Fig.15a -c is described. For example, T-AUX1 1432 can step down the provided 11 kV voltage to a lower voltage of 0.415 kV or 415 V. Similarly, T-AUX2 1436 can step down the provided 11 kV voltage to a lower voltage of 0.415 kV or 415 V. In some embodiments, for example, T-AUX1 1432 is a grounded Y-delta transformer. In some embodiments, for example, T-AUX2 1436 is a grounded Y-delta transformer.

[0134] The main power system 1400 further includes MP panels 1434 and 1438 for each of T-AUX1 1432 and T-AUX2 1436, respectively. The MP panels 1434 and 1438 are used to monitor the power provided to the first auxiliary transformer 1432 and the second auxiliary transformer 1436 by the gas turbine system 1404, the ORC system 1406, and / or the BSG system 1408 through their respective MP panels 1420, 1422, and 1424, and provide circuit protection in the event of a fault. The MP panels 1434 and 1438 each include a circuit breaker 1450, a step-down transformer 1452, a metering device 1454, a protection device 1456, and a plurality of current transformers 1458. The MP panels 1434 and 1438 operate in the same manner as the MP panels 1420, 1422, and 1424, as previously described.

[0135] refer to Fig.14c, the main power system 1400 further includes MP panels 1472 and 1474. The MP panels 1472 and 1474 are used to monitor the power output from the main power system 1400 to the external substation 135 and provide circuit protection in the event of a fault. The MP panels 1472 and 1474 each include a circuit breaker 1450, a step-down transformer 1452, a metering device 1454, a first protection device 1475, a second protection device 1476, a plurality of current transformers 1458, and an electrical connection to a synchronizer 1459. The MP panels 1472 and 1474 operate in the same manner as the MP panels 1420, 1422, and 1424, as previously described. In some embodiments, the first protection device 1475 and the second protection device 1476 of the MP panels 1472 and 1474 further include a fiber optic cable (FOC) communication connection 1490 with the external substation 135. That is, for example, each of the first protection device 1475 and the second protection device 1476 of the MP panels 1472 and 1474 and the metering device 1454 may provide data to and receive data from the external substation 135 .

[0136] In some embodiments, the first protection device 1475 may provide some or all of the following protection features as outlined in "IEEE Standard C37.2 Power System Device Function Numbers, Acronyms, and Contact Designations" alone, in combination, or both: 67 (AC directional overcurrent relay), 67N (neutral directional overcurrent), 21 (distance relay), 25 (synchronization or synchronization check device), 27 (undervoltage relay), 59 (overvoltage relay), 50BF (overvoltage relay circuit breaker fault), 81 (frequency relay), 87L (isolated line current differential), and / or X (auxiliary relay). In some embodiments, for example, the first protection device 1475 may be an off-the-shelf device such as MiCOM P543.

[0137] In some embodiments, the second protection device 1476 may provide some or all of the following protection features as outlined in "IEEE Standard C37.2 Power System Device Function Numbers, Acronyms, and Contact Designations" alone, in combination, or both: 67 (AC directional overcurrent relay), 67N (neutral directional overcurrent), 21 (distance relay), 25 (synchronization or synchronization check device), 27 (undervoltage relay), 59 (overvoltage relay), 50BF (overvoltage relay circuit breaker fault), 81 (frequency relay), 87L (isolated line current differential), and Y (auxiliary relay). In some embodiments, for example, the second protection device 1476 may be an off-the-shelf device such as the Selinc SEL-311L.

[0138] The main power system 1400 further includes a main control panel 1480 for metering the power output of the main power system 1400 and monitoring the main power system 1400. The main control panel 1480 includes a step-down transformer 1452, a revenue metering panel 1482, a power plant metering panel 1483, a SAC panel 1484, and a plurality of current transformers 1458. The functions of the step-down transformer 1452 and the plurality of current transformers 1458 are as previously described.

[0139] In some embodiments, the revenue meter panel 1482 includes a first metering device and a second metering device 1454 for metering the output of the main power system 1400 to the external substation 135. In some embodiments, the second metering device 1454 can be used to ensure that the first metering device 1454 is operating as required. That is, for example, the reading of the first metering device 1454 can be checked against the reading of the second metering device 1454 to ensure that the device is operating correctly. For example, the metering device 1454 of the revenue meter panel 1482 can be an off-the-shelf device, such as a Schneider ION 9600. In some embodiments, the revenue meter panel 1482 can further include at least one fiber optic cable (FOC) communication connection 1490 with the external substation 135.

[0140] In some embodiments, the power plant meter panel 1483 includes a meter device 1454 for internally monitoring the output of the primary power system 1400. The meter device 1454 of the power plant meter panel 1483 functions as previously described.

[0141] Switchyard automation control (SAC) panel 1484 may be used to monitor and control primary power system 1400. In some embodiments, SAC panel 1484 includes a control unit. For example, the control unit may be an off-the-shelf device such as an SEL-2032, or an SEL-3530, or an SEL-3555. SAC panel 1484 may communicate with some or all of: metering devices 1454 of MP panels 1420, 1422, 1424, 1426, 1428, 1472, and 1474, protection devices 1456 of MP panels 1420, 1422, 1424, 1426, and 1428, and first protection devices 1475 and second protection devices 1476 of MP panels 1472 and 1474. In some embodiments, SAC panel 1484 may further include at least one fiber optic cable (FOC) communication connection 1490 with external substation 135.

[0142] SAC panel 1484 may also be in communication with switch 1489. When actuated by SAC panel 1484, switch 1489 disconnects substation 135, which is connected via external power connection 1492, from primary power system 1400. In some embodiments, for example, switch 1489 may be a coaxially operated load break switch actuated by a motor.

[0143] Fig.15a -b is a 415V barge power single line diagram of the barge power system 1500 according to some embodiments. The barge power system 1500 receives power from the main power system 1400 through the connections marked "A" and "B", such as Fig.15b As shown. The barge power system 1500 includes a plurality of power buses 1510 to distribute the power supplied by the main power system 1400 to a plurality of components within the barge power system 1500. The barge power system 1500 further includes a plurality of motors 1530. In some embodiments, for example, the plurality of motors 1530 may include any one of a pump, a fan, an HVAC, a turbine, a hydraulic system, a lighting, and a crane system. In some embodiments, the plurality of motors 1530 receive power through the power bus 1510. The barge power system 1500 may further include a plurality of variable frequency drives (VFDs) 1520. In some embodiments, some or all of the plurality of motors 1530 may receive power from the power bus 1510 through the VFD 1520.

[0144] like Fig.15b As shown in FIG. 1 , the barge power system 1500 further includes an uninterruptible power supply (UPS) 1540. The UPS 1540 can be used to provide power to multiple components in the barge power system 1500 in the event of a failure or power outage. For example, a loss of power from the main power system 1400 may cause the UPS 1540 to start up to supply power to multiple components of the barge power system 1500, for example.

[0145] refer to Fig.15c , the barge power system 1500 may further include a power bus 1550 to distribute the power supplied by the main power system 1400 to a plurality of control panels 1560 within the barge power system 1500. In some embodiments, for example, in the event of a failure or power outage, the power bus 1550 may receive power from the UPS 1540. The plurality of control panels 1560 may be used to control various systems, electronic machines, and devices of the barge power system 1500. For example, the plurality of control panels 1560 may control lighting, general power, fire protection systems, and / or generators.

[0146] refer to Fig.16a , reference letters "W" and "X" indicate Figure 16a to Figure 16c Continuation of the line. For example, Fig.16aThe line marked with "W" in Fig.16c continues at the corresponding "W" on Fig.16b and 16c the "Y" and "Z" on

[0147] Fig.16a -c is a single-line diagram of the 110VDC power generation barge power of the barge DC power system 1600 according to some embodiments. The barge DC power system 1600 includes a first battery system 1610 and a second battery system 1620. Each of the first battery system 1610 and the second battery system 1620 includes a battery charger, a battery management system, and a battery array 1615, all of which are in electrical communication with each other. In some embodiments, the battery charger receives an input power supply from connection 1640. The battery charger can use the input power supply to charge the battery array 1615. In some embodiments, the input power supply is rated at 240V, 13A. In some embodiments, the battery charger can convert the input power supply into a 110VDC power supply. In some embodiments, the battery array 1615 can include multiple batteries.

[0148] Each of the first battery system 1610 and the second battery system 1620 provides power rated at 110VDC to the 110VDC distribution bus 1630. In some embodiments, the second battery system 1620 can act as a failover power supply. That is, for example, in the case where the first battery system 1610 cannot provide power, the second battery system 1620 can provide power to the 110VDC distribution bus 1630. The 110VDC distribution bus 1630 can supply 110VDC power supply to various systems and components of the offshore power generation system 100. In some embodiments, the distribution bus 1630 supplies power to the conversion interface circuit 1650. The conversion interface circuit 1650 converts the 110VDC power supply from the 110VDC distribution bus 1630 into a 24VDC power supply. Then the 24VDC power supply is supplied to the 24VDC distribution bus 1660. In some embodiments, the 24VDC distribution bus 1660 can supply 24VDC power supply to various systems and components of the offshore power generation system 100.

[0149] Fig.17a -b is a general layout schematic diagram of the 110VDC power supply (DCPS) 1700, such as the barge DC power system 1600. For example, in some embodiments, the DCPS 1700 can be in the form as in Fig.17a-b. This electrical cabinet can be a readily available electrical cabinet. In some embodiments, the DCPS 1700 can accommodate the barge DC power system 1600. In some embodiments, there can be a second DCPS 1700 to accommodate the elements of the barge DC power system 1600. That is, for example, the DCPS 1700 can contain a battery first battery system 1610, a battery array 1615, a 110VDC distribution bus 1630, and a 24VDC distribution bus 1660, and the second DCPS 1700 can contain a second battery system 1620, a battery array 1615, a 110VDC distribution bus 1630, and a 24VDC distribution bus 1660.

[0150] Fig.18a b is a schematic diagram of a power communication architecture 1800 according to some embodiments. At least a portion of the power communication architecture 1800 may be located in the control center 115 . Fig.18a -b provides a graphical representation of data communications between the SAC panel 1484 and the MP panels 1420, 1422, 1424, 1426, 1428, 1472, and 1474, and the power plant meter panel 1483. That is, the power communication architecture 1800 includes the SAC panel 1484, the MP panels 1420, 1422, 1424, 1426, 1428, 1472, 1474, and the power plant meter panel 1483. In some embodiments, the power communication architecture 1800 may further include an external communication connection 1810. For example, the external communication connection 1810 may provide communication between the power communication architecture 1800 and an external computing device.

[0151] In some embodiments, the power communication architecture 1800 may further include a control room computing device 1815. For example, the control room computing device 1815 may allow a user to control and monitor the systems and components of the power communication architecture 1800. In some embodiments, the power communication architecture 1800 may further include a printer 1820 or other peripheral device that communicates with the control room computing device 1815. In some embodiments, the power communication architecture 1800 may further include a barge power system control panel 1825. For example, the power system control panel 1825 may include some or all of the control panels used to control the systems of the offshore power generation system 100.

[0152] Those skilled in the art will appreciate that various changes and / or modifications may be made to the above-described embodiments without departing from the broad general scope of the present disclosure, including the following provisions. Therefore, the present embodiments should be considered in all aspects as illustrative and not restrictive.

[0153] Item 1. A power generation system comprising: a gas turbine for generating electricity by combustion of natural gas; a gas supply line for supplying vaporized liquefied natural gas (LNG) to the gas turbine; a power subsystem for receiving electricity from the gas turbine and supplying power to at least one remote power receiving end; a vaporizer configured to vaporize the LNG; and a closed-loop thermal fluid circuit configured to recover the potential energy of the vaporized LNG to cool a thermal fluid in the closed-loop thermal fluid circuit, wherein the gas turbine includes an air inlet for inhaling ambient air; and wherein the air inlet is configured so that the ambient air flowing therethrough is cooled by the cooled thermal fluid.

[0154] Clause 2. The system of clause 1, wherein the gas turbine includes a lubrication oil cooler, and wherein the thermal fluid circuit is configured to exchange thermal energy with lubrication oil in the lubrication oil cooler, thereby cooling the lubrication oil and heating the thermal fluid.

[0155] Clause 3. The system of clause 2, wherein the thermal fluid circuit comprises a heat exchanger in which the thermal fluid exchanges thermal energy with seawater passing through the heat exchanger, thereby further heating the thermal fluid before the thermal fluid is returned to the evaporator.

[0156] Clause 4. The system of any one of clauses 1 to 3, wherein a portion of the thermal fluid cooled at the evaporator is diverted from the thermal fluid circuit for use in cooling an air conditioning unit and / or a compressor unit.

[0157] Clause 5. A system according to any one of clauses 1 to 4, further comprising an organic Rankine cycle (ORC) generator for generating electricity by heat recovery, wherein the power subsystem is configured to receive power from at least one of the gas turbine or the ORC generator to supply power to the at least one remote power receiving end.

[0158] Clause 6. The system of clause 5, wherein the ORC generator is configured to generate electricity in addition to or instead of the gas turbine.

[0159] Clause 7. The system of clause 5 or clause 6, wherein the ORC generator comprises a fresh air firing stack and is configured to generate electricity from heat recovered from exhaust gases exiting the gas turbine and / or gases entering the ORC from the fresh air firing stack.

[0160] Clause 8. A system according to any one of clauses 5 to 7, further comprising an auxiliary burner arranged downstream of the fresh air ignition chimney and connected to at least one tank fluid to receive boil-off gas from one or more LNG tanks; wherein the auxiliary burner is suitable for burning the boil-off gas to generate auxiliary heat for operating the ORC generator.

[0161] Clause 9. The system of clause 8, wherein the thermal fluid of the closed-loop thermal fluid circuit and / or the ORC generator is used to heat the boil-off gas and thereby increase the pressure of the boil-off gas before the boil-off gas enters the auxiliary combustor.

[0162] Clause 10. The system of any one of clauses 5 to 9, further comprising a damper that, in a first position, allows the gas turbine and the ORC generator to operate together, and in a second position, allows the gas turbine and the ORC generator to operate independently of each other.

[0163] Clause 11. The system of any of clauses 5 to 10, wherein the ORC generator has a first power generation capacity and the gas turbine has a second power generation capacity that is higher than the first power generation capacity.

[0164] Clause 12. The system of any one of clauses 5 to 11, wherein the working fluid of the ORC generator is a thermal fluid.

[0165] Clause 13. The system of clause 12, further comprising a heat exchanger configured to receive heated gas from the auxiliary combustor and used to heat the thermal fluid of the ORC generator.

[0166] Clause 14. The system of clause 12 or clause 13, wherein the ORC generator comprises a condenser configured to condense the thermal fluid using seawater as a coolant.

[0167] Clause 15. The system of any one of clauses 5 to 14, wherein the ORC generator comprises a radial expander.

[0168] Clause 16. The system of clause 15, wherein the radial expander comprises variable inlet vanes controllable to enable adjustment of the power output of the ORC generator in response to a transient power load drawn by the at least one remote power receiving end.

[0169] Clause 17. The system of any one of clauses 5 to 14, wherein the ORC comprises an axial expander controllable to enable adjustment of the power output of the ORC generator in response to a transient power load drawn by the at least one remote power receiving end.

[0170] Clause 18. The system of any one of clauses 1 to 17, wherein the gas turbine has a power output of between about 5 MW and about 20 MW.

[0171] Clause 19. The system of any one of clauses 5 to 18, wherein the power output of the ORC generator is between about 3 MW and about 7 MW.

[0172] Clause 20. The system of any one of clauses 1 to 19, wherein the thermal fluid of the closed-loop thermal fluid circuit and / or the ORC generator is one of ethylene glycol and thermal oil.

[0173] Clause 21. The system of any one of clauses 1 to 20, wherein an operating temperature of the thermal fluid of the closed-loop thermal fluid circuit and / or the ORC generator is between about 3°C ​​and about 24°C.

[0174] Clause 22. A floating power generation system comprising a system according to any one of clauses 1 to 21 installed on a vessel, the vessel comprising a vessel frame, a hull surrounding the vessel frame and defining a bow section and a stern section, and a deck supported by the vessel frame; wherein the power subsystem is configured to supply power to at least one remote power receiving end away from the vessel.

[0175] Clause 23. The system of clause 22, wherein the vessel is devoid of propulsion means.

[0176] Clause 24. A system according to clause 22 or clause 23, wherein the vessel is formed as a barge.

[0177] Clause 25. The system of any one of Clauses 22 to 24, further comprising at least one LNG storage tank located on the vessel.

[0178] Item 26. A power generation system comprising: a gas turbine for generating electricity by combustion of natural gas; an organic Rankine cycle (ORC) generator for generating electricity by heat recovery; a gas supply line for supplying vaporized liquefied natural gas (LNG) to the gas turbine; a power subsystem for receiving power from at least one of the gas turbine or the ORC generator and supplying power to at least one remote power receiving end; and a damper that, in a first position, allows the gas turbine and the ORC generator to operate together, and in a second position, allows the gas turbine and the ORC generator to operate independently of each other.

[0179] Clause 27. The system of Clause 26, wherein the ORC generator has a first power generation capacity and the gas turbine has a second power generation capacity that is higher than the first power generation capacity.

[0180] Clause 28. The system of clause 26 or clause 27, further comprising a controller configured to control a position of the damper at the first position or the second position in response to a change in a load drawn by the at least one remote power receiving end.

[0181] Clause 29. A system according to any one of clauses 26 to 28, wherein the controller is configured to position the damper at the first position when the load drawn by the at least one remote power receiving end is at or above a first threshold power load, and to position the damper at the second position when the load drawn by the at least one remote power receiving end is below the first threshold power load.

[0182] Clause 30. The system of clause 29, wherein the first threshold electrical load corresponds to the second generation capacity.

[0183] Clause 31. A system according to any one of clauses 26 to 30, wherein the gas turbine is arranged to be selectively fluidly connected to a) an exhaust stack and b) the ORC generator, whereby in the first position of the damper, a fluid flow path from the gas turbine to the exhaust stack is closed to gases leaving the gas turbine, and a fluid flow path from the gas turbine to the ORC generator is opened, thereby allowing the gases leaving the gas turbine to flow into the ORC generator.

[0184] Clause 32. A system according to clause 31, wherein in the second position of the damper, the fluid flow path from the gas turbine to the exhaust chimney is opened to allow the gas leaving the gas turbine to enter the exhaust chimney, and the fluid flow path from the gas turbine to the ORC generator is closed to the gas leaving the gas turbine.

[0185] Clause 33. The system of any one of Clauses 26 to 32, wherein the damper comprises at least one air sealing damper.

[0186] Clause 34. A system according to any one of clauses 26 to 33, wherein the ORC generator includes a fresh air firing chimney and can be configured to generate electricity from heat recovered from exhaust gases leaving the gas turbine and / or from gases entering the ORC generator through the fresh air firing chimney.

[0187] Clause 35. The system of clause 34, wherein when the load drawn by the at least one remote power receiving end is below a second threshold power load, the ORC generator can be configured to generate power from gas entering the ORC generator through the fresh air firing chimney.

[0188] Clause 36. The system of clause 34 or clause 35, wherein the fresh air firing chimney is positioned downstream of the gas turbine.

[0189] Clause 37. A system according to any one of clauses 34 to 36, further comprising an auxiliary burner arranged downstream of the fresh air ignition chimney and connected to at least one tank fluid to receive boil-off gas from one or more LNG tanks; wherein the auxiliary burner is suitable for burning the boil-off gas to generate auxiliary heat for operating the ORC generator.

[0190] Clause 38. The system of clause 37, further comprising a heat exchanger configured to receive heated gas from the auxiliary combustor and used to heat a working fluid of the ORC generator.

[0191] Clause 39. The system of any one of clauses 26 to 38, wherein the fuel source for the gas turbine generator and the ORC generator is LNG.

[0192] Clause 40. A floating power generation system comprising a system according to any one of clauses 26 to 39 installed on a vessel, the vessel comprising a vessel frame, a hull surrounding the vessel frame and defining a bow section and a stern section, and a deck supported by the vessel frame; wherein the power subsystem is configured to supply power to at least one remote power receiving end away from the vessel.

[0193] Clause 41. A method of controlling operation of a power generation system according to any one of clauses 26 to 40, the method comprising controlling the position of the damper in the first position thereby allowing the gas turbine and the ORC generator to operate together, or in the second position thereby allowing the gas turbine and the ORC generator to operate independently of each other.

[0194] Clause 42. The method of clause 41, wherein the damper is positioned in the first position when the load drawn by the at least one remote power receiving end is at or above the first threshold power load.

[0195] Clause 43. The method of clause 41 or clause 42, wherein the damper is positioned in the second position when the load drawn by the at least one remote power receiving end is below a first threshold power load.

[0196] Clause 44. The method of any one of clauses 41 to 43, wherein the first threshold electrical load corresponds to the second generation capacity.

[0197] Clause 45. The method of any one of clauses 41 to 44, wherein the power generation system is controlled to operate the gas turbine or the ORC generator in response to a power load drawn by the at least one remote power receiving end.

[0198] Clause 46. The method of clause 45, wherein when the drawn electrical load is above a second threshold electrical load and below a first threshold electrical load, the power generation system is controlled to operate the gas turbine instead of the ORC generator.

[0199] Clause 47. The method of clause 45 or clause 46, wherein the power generation system is controlled to operate the ORC generator instead of the gas turbine when the drawn power load is within the second threshold power load.

[0200] Clause 48. The system of clause 46 or clause 47, wherein the second threshold electrical load corresponds to the first generation capacity and the first threshold electrical load corresponds to the second generation capacity.

[0201] Clause 49. A liquefied natural gas (LNG) storage system comprising: a floating vessel formed as a barge, the vessel including: a vessel frame, a hull surrounding the vessel frame and defining a bow section and a stern section, and a deck supported by the vessel frame; at least two LNG storage tanks, the at least two LNG storage tanks being carried by the vessel frame, the at least two LNG storage tanks including a first LNG storage tank positioned on the port side of the vessel and a second LNG storage tank positioned on the starboard side of the vessel; a fluid transfer conduit connected to the at least two LNG storage tanks to allow fluid to flow into and out of the at least two LNG storage tanks; and a valve system for controlling fluid flow in the fluid transfer conduit; wherein the vessel frame and the hull define a wide and shallow draft.

[0202] Clause 50. The system of clause 49, wherein the vessel is devoid of internal propulsion means.

[0203] Clause 51. The system of clause 49 or clause 50, wherein the vessel has a recess defined in a central portion of the stern section to accommodate a bow of the drive vessel.

[0204] Clause 52. The system of any one of Clauses 49 to 51, wherein the bow section of the hull has an acute angled surface to facilitate forward passage of the vessel through the water.

[0205] Clause 53. The system of any one of Clauses 49 to 52, further comprising at least one ballast pump to pump seawater into the hull for ballast control.

[0206] Clause 54. The system of Clause 53, further comprising at least one compressed air storage tank to supply compressed air for operating the at least one ballast pump.

[0207] Clause 55. The system of Clause 53 or Clause 54, further comprising a pump control interface to allow control of the at least one ballast pump by an external controller when an external control conduit is coupled to the pump control interface.

[0208] Clause 56. The system of any one of Clauses 49 to 55, further comprising at least one pneumatic pump to draw LNG from the at least two LNG storage tanks into the fluid transfer conduit.

[0209] Clause 57. The system of Clause 56, further comprising at least one compressed air tank to supply compressed air for operating the at least one pneumatic pump.

[0210] Clause 58. The system of any one of Clauses 49 to 57, wherein each of the at least two LNG storage tanks has a boil-off gas (BOG) exhaust conduit coupled thereto to allow boil-off gas to be discharged to the BOG storage tank.

[0211] Clause 59. The system of any one of clauses 49 to 58, wherein the total volume capacity of the at least two LNG storage tanks is between about 1000 m 3 About 6000m 3 between.

[0212] Clause 60. The system of clause 59, wherein the total volume capacity is between about 1500 m 3 About 4000m 3 between.

[0213] Clause 61. The system of clause 59, wherein the total volume capacity is between about 2000 m 3 About 3500m 3 between.

[0214] Clause 62. The system of any one of Clauses 59 to 61, wherein the at least two LNG storage tanks comprise a total volume capacity of about 3000 m 3 Two to four LNG storage tanks.

[0215] Clause 63. The system of any one of clauses 49 to 62, wherein the vessel has no power plant on the deck.

[0216] Clause 64. A floating LNG storage facility comprising: a floating dock secured by fixed piles located close to a shoreline; and at least one LNG storage system according to any one of clauses 49 to 63 moored to the floating dock.

[0217] Clause 65. The apparatus of Clause 64, wherein a plurality of the LNG storage systems are moored to the floating dock.

[0218] Clause 66. The apparatus of clause 64 or clause 65, further comprising a floating power generation system moored to the floating dock and configured to generate electricity from LNG, wherein the at least one LNG storage system is configured to supply LNG to the floating power generation system through the fluid transfer conduit.

[0219] Clause 67. The apparatus of any one of Clauses 64 to 66, wherein the plurality of the LNG storage systems are each moored to the floating dock using an interlocking device.

[0220] Clause 68. The apparatus of clause 67, wherein the interlock is a mechanical mechanism for limiting movement.

[0221] Clause 69. Apparatus according to clause 67 or clause 68, wherein the interlocking device is a hydraulic pin.

[0222] Clause 70. The apparatus of any one of Clauses 64 to 69, wherein the floating dock is configured to rise and fall relative to the fixed piles with sea conditions.

[0223] Clause 71. A floating LNG storage facility comprising: a floating dock secured by fixed piles positioned near a coastline; at least one mooring compartment configured to accommodate an LNG storage system according to any one of clauses 49 to 63; and a bulk LNG storage facility located at an end of the floating dock farthest from the coastline, the bulk LNG storage facility having an LNG storage capacity sufficient to refuel at least two of the LNG storage systems.

[0224] Clause 72. The floating LNG storage facility of Clause 71, wherein the bulk LNG storage facility has an LNG storage capacity sufficient to refuel at least four of the LNG storage systems.

[0225] Clause 73. The apparatus of clause 71 or clause 72, wherein the at least one mooring compartment is configured to moor the LNG storage system of any one of clauses 1 to 15 by using an interlocking mechanism.

[0226] Clause 74. The apparatus of clause 73, wherein the interlock is a mechanical mechanism for limiting movement.

[0227] Clause 75. Apparatus according to clause 73 or clause 74, wherein the interlocking device is a hydraulic pin.

[0228] Clause 76. The apparatus of any one of Clauses 71 to 75, wherein the floating dock is configured to rise and fall relative to the fixed piles with sea conditions.

[0229] Clause 77. A floating power generation system comprising: a vessel, the vessel comprising: a vessel frame, a hull surrounding the vessel frame and defining a bow section and a stern section, and a deck supported by the vessel frame; a gas turbine located on the vessel, the gas turbine being used to generate electricity by combustion of natural gas; an organic Rankine cycle (ORC) generator located on the vessel, the ORC generator being used to generate electricity by heat recovery; a gas supply line located on the vessel, the gas supply line being used to supply liquefied natural gas (LNG) to the gas turbine; and a power subsystem, the power subsystem being used to receive power from at least one of the gas turbine or the ORC generator, and to supply power to at least one remote power receiving end (sink) away from the vessel.

[0230] Clause 78. The system of clause 77, wherein the vessel is devoid of propulsion means.

[0231] Clause 79. The system of clause 77 or clause 78, wherein the vessel has a recess defined in a central portion of the stern section to accommodate a bow of the drive vessel.

[0232] Clause 80. The system of any one of Clauses 77 to 79, wherein the bow section of the hull has an acute angled surface to facilitate forward passage of the vessel through the water.

[0233] Clause 81. The system of any one of clauses 77 to 80, wherein the vessel is formed as a barge.

[0234] Clause 82. The system of any one of Clauses 77 to 81, further comprising at least one LNG storage tank located on the vessel.

[0235] Clause 83. The system of Clause 82, wherein the at least one LNG storage tank comprises a plurality of LNG storage tanks disposed below the deck.

[0236] Clause 84. The system of any of clauses 77 to 83, wherein the ORC generator is configured to generate electricity in addition to or instead of the gas turbine.

[0237] Clause 85. The system of any of clauses 77 to 84, wherein the ORC generator has a first power generation capacity and the gas turbine has a second power generation capacity that is higher than the first power generation capacity.

[0238] Clause 86. The system according to Clause 85, wherein the power subsystem is configured to change the operation of the ORC generator in response to a change in the load when the gas turbine and the ORC generator operate simultaneously to generate electricity and when the change in the load drawn by the at least one remote power receiving end is within the first power generation capacity.

[0239] Clause 87. The system according to any one of Clauses 77 to 86, wherein the ORC generator includes a radial expander.

[0240] Clause 88. The system according to Clause 87, wherein the radial expander includes variable inlet vanes that can be controlled to adjust the power output of the ORC generator.

[0241] Clause 89. The system according to any one of Clauses 77 to 88, wherein the power output of the gas turbine is between approximately 5 MW and approximately 20 MW.

[0242] Clause 90. The system according to any one of Clauses 77 to 89, wherein the power output of the ORC generator is between approximately 2 MW and approximately 6 MW.

[0243] Clause 91. The system according to any one of Clauses 77 to 90, further comprising: at least one storage tank for receiving boil-off gas from one or more LNG storage tanks; and an auxiliary burner for burning the boil-off gas to generate auxiliary heat for operating the ORC generator.

[0244] Clause 92. The system according to any one of Clauses 77 to 91, further comprising a damper that allows the gas turbine and the ORC generator to operate together in a first position and allows the gas turbine and the ORC generator to operate independently of each other in a second position.

[0245] Clause 93. The system according to any one of Clauses 77 to 92, wherein the ORC generator includes a fresh air ignition stack.

[0246] Clause 94. A power generation device comprising: a floating dock coupled to a fixed tower and configured to move up and down with the water level relative to the fixed tower, the floating dock being positioned to allow access to the floating dock from the shoreline; at least one floating power generation system according to any one of Clauses 77 to 93 moored to the floating dock; and at least one floating LNG storage vessel moored to the floating dock to supply LNG to the at least one floating power generation system.

[0247] Clause 95. An apparatus according to clause 94, wherein the floating dock comprises: a gangway allowing personnel to enter; at least one first compartment, the at least one first compartment being used to accommodate the at least one floating power generation system; and at least one second compartment, the at least one second compartment being used to accommodate the at least one floating LNG storage vessel.

[0248] Clause 96. The apparatus of Clause 95, wherein the at least one floating power generation system is moored closer to the shoreline than the at least one floating LNG storage vessel.

[0249] Clause 97. The apparatus of any one of Clauses 94 to 96, wherein the at least one floating power generation system is moored to the floating dock by use of an interlocking device.

[0250] Clause 98. The apparatus of any one of Clauses 94 to 97, wherein the at least one floating LNG storage vessel is moored to the floating pier using an interlocking arrangement.

[0251] Clause 99. Apparatus according to clause 97 or clause 98, wherein the interlock is a mechanical mechanism for limiting movement.

[0252] Clause 100. The apparatus of any one of clauses 97 to 99, wherein the interlock is a hydraulic pin.

Claims

1. A floating power generation system, comprising: ship include: a vessel frame, a hull surrounding the vessel frame and defining a bow section and a stern section, and a deck supported by the vessel frame; a gas turbine located on the vessel, the gas turbine being used to generate electricity by combustion of natural gas; an organic Rankine cycle (ORC) generator located on the vessel, the ORC generator being used to generate electricity by heat recovery; a gas supply line located on the vessel, the gas supply line being used to supply liquefied natural gas (LNG) to the gas turbine; as well as A power subsystem is provided for receiving power from at least one of the gas turbine or the ORC generator and supplying power to at least one remote power sink remote from the vessel.

2. The system of claim 1, wherein the vessel is devoid of propulsion means.

3. A system according to claim 1 or claim 2, wherein the vessel has a recess defined in a central portion of the stern section to accommodate a bow of the drive vessel.

4. The system of any one of claims 1 to 3, wherein the bow section of the hull has an acute angled surface to facilitate forward passage of the vessel on the water.

5. A system according to any one of claims 1 to 4, wherein the vessel is formed as a barge.

6. The system according to any one of claims 1 to 5, further comprising at least one LNG storage tank located on the vessel.

7. The system of claim 6, wherein the at least one LNG storage tank comprises a plurality of LNG storage tanks disposed below the deck.

8. The system of any one of claims 1 to 7, wherein the ORC generator is configured to generate electricity in addition to or instead of the gas turbine.

9. The system of any one of claims 1 to 8, wherein the ORC generator has a first power generation capacity, and the gas turbine has a second power generation capacity higher than the first power generation capacity.

10. The system of claim 9, wherein the power subsystem is configured to change operation of the ORC generator in response to a change in load when the gas turbine and the ORC generator are operating simultaneously to generate power and when a change in load drawn by the at least one remote power receiving end is within the first power generation capacity.

11. The system of any one of claims 1 to 10, wherein the ORC generator comprises a radial expander.

12. The system of claim 11, wherein the radial expander includes variable inlet vanes controllable to enable adjustment of the electrical output of the ORC generator.

13. The system of any one of claims 1 to 12, wherein the gas turbine has a power output of between about 5 MW and about 20 MW.

14. The system of any one of claims 1 to 13, wherein the ORC generator has a power output of between about 2 MW and about 6 MW.

15. The system according to any one of claims 1 to 14, further comprising: include: at least one storage tank for receiving boil-off gas from one or more LNG storage tanks; and an auxiliary burner for burning the boil-off gas to generate auxiliary heat for operating the ORC generator.

16. The system of any one of claims 1 to 15, further comprising a damper that in a first position allows the gas turbine and the ORC generator to operate together and in a second position allows the gas turbine and the ORC generator to operate independently of each other.

17. The system of any one of claims 1 to 16, wherein the ORC generator comprises a fresh air firing chimney.

18. A power generation device, comprising: a floating dock coupled to the fixed tower and configured to move up and down with the water level relative to the fixed tower, the floating dock positioned to allow access to the floating dock from a shoreline; at least one floating power generation system according to any one of claims 1 to 17 moored to the floating pier; and At least one floating LNG storage vessel is moored to the floating pier to supply LNG to the at least one floating power generation system.

19. The apparatus according to claim 18, wherein the floating dock comprises: a gangway allowing personnel to enter; at least one first tank, the at least one first tank being used to accommodate the at least one floating power generation system; and at least one second tank, the at least one second tank being used to accommodate the at least one floating LNG storage vessel.

20. The apparatus of claim 19, wherein the at least one floating power generation system is moored closer to the shoreline than the at least one floating LNG storage vessel.

21. Apparatus according to any one of claims 18 to 20, wherein the at least one floating power generation system is moored to the floating pier by use of an interlocking arrangement.

22. The apparatus according to any one of claims 18 to 21, wherein the at least one floating LNG storage vessel is moored to the floating pier by using an interlocking arrangement.

23. Apparatus according to claim 21 or claim 22, wherein the interlock is a mechanical mechanism for restricting movement.

24. Apparatus according to any one of claims 21 to 23, wherein the interlocking means is a hydraulic pin.

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