Systems and methods for operating a group of fluid turbines - Patents.com

Abstract

The present disclosure describes many innovations including, but not limited to, systems, methods, and non-transitory computer readable media containing instructions therefor for coordinated braking of a plurality of geographically associated fluid turbines, including accessing a memory that stores information indicative of a tolerance threshold for an operating parameter associated with the geographically associated fluid turbines, receiving information indicative of an operating parameter for a particular fluid turbine of the geographically associated fluid turbines from at least one sensor, comparing the information indicative of the operating parameter for the particular fluid turbine to a tolerance threshold, determining whether the operating parameter for the particular fluid turbine deviates from a tolerance threshold based on the comparison, and transmitting a braking signal to each of the geographically associated fluid turbines to slow down each of the geographically associated fluid turbines when the operating parameter deviates from the tolerance threshold. TIFF2025506565000003.tif103166

Description

[Technical field]

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS This application claims the benefit of priority to U.S. Provisional Patent Application No. 63 / 307,653, filed February 8, 2022, and U.S. Provisional Patent Application No. 63 / 329,900, filed April 12, 2022, each of which is incorporated by reference in its entirety.

[0002] I. Technical field The present disclosure relates generally to the field of fluid turbines and, more particularly, to systems, methods and devices for operating a group of fluid turbines. [Background technology]

[0003] II. Background Information As the challenges posed by climate change continue to increase, more attention is being paid to green energy alternatives to fossil fuels. Some attractive alternatives to fossil fuels include turbines that harness power from fluid flows, such as wind, ocean currents, steam flows, or gas flows. In some cases, due to physical constraints that limit the amount of energy that can be generated by any single turbine, turbine fleets may be constructed, which allows for the aggregation of energy generated by multiple individual turbines. For example, aggregating the energy produced by turbine fleets may scale up green energy production sufficiently to provide a reliable supply of green energy to the power grid as an alternative to fossil fuels. However, fluid turbine fleets may require coordinated maintenance, repairs, and safety inspections. Also, in some cases, coordinating the operation of the aggregated turbines may improve performance, improve efficiency, and increase green energy production. Thus, systems and methods for coordinating the operation of the aggregated turbines may be beneficial. Summary of the Invention

[0004] overview Aspects consistent with the present disclosure generally provide systems and methods related to operating a fleet of geographically associated fluid turbines. The disclosed systems and methods may be implemented using combinations of conventional hardware and software, as well as specialized hardware and software, such as machines specifically constructed and / or programmed to perform the functions associated with the disclosed method steps. Consistent with other disclosed aspects, a non-transitory computer-readable storage medium may store program instructions executable by at least one processing device to perform any of the steps and / or methods described herein.

[0005] Consistent with aspects of the disclosure, a system, method, and computer readable medium for coordinated braking of a plurality of geographically associated fluid turbines are disclosed. The aspects may include at least one processor configured to: access a memory that stores information indicative of a tolerance threshold of at least one operating parameter associated with the plurality of geographically associated fluid turbines; receive information indicative of the at least one operating parameter for a particular fluid turbine of the plurality of geographically associated fluid turbines from at least one sensor; compare the information indicative of the at least one operating parameter for the particular fluid turbine to the tolerance threshold stored in the memory; determine whether the at least one operating parameter for the particular fluid turbine deviates from the tolerance threshold based on the comparison; and transmit a braking signal to each of the geographically associated fluid turbines to slow down each of the geographically associated fluid turbines upon determining that the at least one operating parameter for the particular fluid turbine deviates from the tolerance threshold.

[0006] Consistent with aspects of the disclosure, a system, method, and computer-readable medium are disclosed for coordinating MPPT operation of a geographically associated group of fluid turbines. An aspect may include at least one processor configured to: receive data from a geographically associated group of fluid turbines; determine a change to a total power output of the group based on changes in load conditions of the individual fluid turbines in the group; select a combination of load conditions of the individual fluid turbines in the group to coordinate the total power output of the group; and transmit the selected combination of load conditions to at least some of the individual fluid turbines in the group to vary the rotational speeds of at least some of the individual fluid turbines in the group.

[0007] Consistent with aspects of the disclosure, a system, method, and computer readable medium for synchronizing a plurality of geographically associated fluid turbines is disclosed. An embodiment may include at least one processor configured to: receive a first signal indicative of a phase of a rotational cycle of a first plurality of rotating blades of a first fluid turbine of the geographically associated plurality of fluid turbines, the first plurality of rotating blades configured to generate a fluid flow downstream of the first fluid turbine; receive a second signal indicative of a phase of a rotational cycle of a second plurality of rotating blades of a second fluid turbine of the geographically associated plurality of fluid turbines, the second plurality of rotating blades configured to receive at least a portion of the fluid flow downstream of the first fluid turbine and generate a differential power output attributable to at least a portion of the fluid flow downstream of the first fluid turbine; determine from the first signal and the second signal that a greater total power output is achievable through blade phase coordination; determine a phase correction between the first plurality of rotating blades and the second plurality of rotating blades based on the first signal and the second signal to achieve the greater total power output; calculate a coordination signal based on the determined phase correction; and impose the phase correction, thereby outputting the coordination signal to achieve the greater total power output. [Brief description of the drawings]

[0008] [Figure 1] 1 illustrates various exemplary fluid turbines consistent with certain aspects of the present disclosure. [Diagram 2] 1 is an orthogonal view of a fluid energy conversion system including a fluid turbine coupled to a generator, consistent with certain aspects of the present disclosure. FIG. [Diagram 3] 1 is an orthogonal view of an example geographically associated group of fluid turbines consistent with certain aspects of the present disclosure. [Figure 4] FIG. 1 is a schematic diagram of an exemplary fluid energy conversion system configured to generate electrical power from a fluid flow and output the generated electrical power to an energy sink, consistent with certain aspects of the present disclosure. [Diagram 5] FIG. 1 illustrates an example schematic diagram of a charge controller connected to at least one sensor consistent with certain aspects of the present disclosure. [Figure 6] 1 is a cross-sectional top view of an exemplary fluid turbine configured with at least one mechanical brake, consistent with certain aspects of the present disclosure. [Figure 7] 1 is a schematic diagram of an example circuit for controlling a plurality of geographically associated fluid turbines consistent with certain aspects of the present disclosure. [Figure 8] 4 is another schematic diagram of an example circuit for controlling a plurality of geographically associated fluid turbines consistent with certain aspects of the present disclosure. FIG. [Figure 9] 4 is a further schematic diagram of an example circuit for controlling a plurality of geographically associated fluid turbines consistent with certain aspects of the present disclosure. FIG. [Figure 10] 4 is yet another schematic diagram of an example circuit for controlling a plurality of geographically associated fluid turbines consistent with certain aspects of the present disclosure. [Figure 11] 4 is a further schematic diagram of an example circuit for controlling a plurality of geographically associated fluid turbines consistent with certain aspects of the present disclosure. FIG. [Figure 12]1 is an exemplary chart illustrating the variation of power output versus rotational speed for a fluid turbine operating at various fluid velocities, consistent with certain aspects of the present disclosure. [Figure 13] FIG. 1 is a schematic diagram of an example braking circuit consistent with certain aspects of the present disclosure. [Figure 14] 1 is an example graph of a periodic power signal generated by a generator connected to a fluid turbine, consistent with certain aspects of the present disclosure. [Figure 15] FIG. 2 is a flow diagram of an example process for coordinated braking of multiple geographically associated fluid turbines consistent with aspects of the present disclosure. [Figure 16] 1 is a flow diagram of an example process for coordinating MPPT operation of a group of geographically associated fluid turbines consistent with aspects of the present disclosure. [Figure 17] 1 is a schematic diagram of fluid flows for multiple geographically associated fluid turbines consistent with certain aspects of the present disclosure. [Figure 18] 1 is an example graph of a periodic power signal over time, consistent with certain aspects of the present disclosure. [Figure 19] 1 illustrates a series of image signals of multiple blades of a rotating fluid turbine over a period of time, consistent with certain aspects of the present disclosure. [Figure 20] 1 is a chart of total power output versus number of fluid turbines in a plurality of geographically associated fluid turbines, consistent with certain aspects of the present disclosure. [Figure 21] is the average power output versus the number of fluid turbines in the geographically associated plurality of fluid turbines, consistent with certain aspects of the present disclosure. [Figure 22] 1 is a schematic diagram of an example fluid turbine group consistent with certain aspects of the present disclosure. [Diagram 23] 1 is a flow diagram of an example process for synchronizing multiple geographically associated fluid turbines consistent with certain aspects of the present disclosure. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0009] Detailed Description Disclosed herein are systems, methods, and non-transitory computer-readable media for controlling and / or coordinating the operation of a plurality of geographically associated fluid turbines (e.g., a fleet of fluid turbines). The fluid turbines referred to herein may be configured to harness energy from wind, water, steam, and / or gas streams. Although some non-limiting examples of wind turbines (specifically vertical wind turbines) are provided, these examples are intended for illustrative purposes only and are not intended to limit the present disclosure. Additionally, in some cases, the term "fluid turbine" may be understood to include a generator in an integrated fluid energy conversion system.

[0010] Various terms used in this detailed description and claims may be defined or summarized differently when discussed in connection with different disclosed aspects. It is understood that the definition, summary and explanation of a term in each instance applies to all instances, even if not repeated, unless the transitive definition, explanation or summary renders the aspect inoperable.

[0011] Throughout, this disclosure refers to "aspects of the disclosure" that refer to examples of inventive ideas, concepts, and / or expressions described herein. Throughout this disclosure, a number of related and unrelated aspects are described. The fact that some "aspects of the disclosure" are described as exhibiting a feature or characteristic does not necessarily mean that other aspects of the disclosure are devoid of that feature or characteristic.

[0012] This disclosure uses open-ended permissive language, for example, to indicate that some embodiments "may" use, involve, or include a particular feature. Use of the term "may" and other open-ended terms is intended to indicate that not all embodiments use a particular disclosed feature, but at least one embodiment does use the particular disclosed feature.

[0013] The following detailed description refers to the accompanying drawings. Wherever possible, the same reference numbers are used in the drawings and the following description to refer to the same or similar parts. Although several exemplary aspects are described herein, modifications, adaptations, and other implementations are possible. For example, substitutions, additions, or modifications may be made to the components shown in the drawings, and the exemplary methods described herein may be modified by substituting, rearranging, removing, or adding steps to the disclosed methods. Thus, the following detailed description is not limited to the specific aspects and examples, but includes the general principles described herein and illustrated in the figures, in addition to the general principles encompassed by the appended claims.

[0014] The present disclosure relates to systems, devices, methods, and non-transitory computer-readable devices for cooperatively operating multiple geographically associated fluid turbines (e.g., a group of fluid turbines) to enable the group to collectively operate as a single fluid energy conversion system. In some cases, each of the geographically associated fluid turbines may be exposed to the same environmental factors (e.g., the same or similar wind conditions, water currents, and temperature). In some cases, coordinating the operation of the geographically associated fluid turbines as a group may include responding to changes in the environmental factors. For example, if a fluid speed exceeds a safety threshold for operating the group of fluid turbines, each fluid turbine in the group may be cooperatively braked to prevent damage or destruction of mechanical parts of the entire group of fluid turbines. As another example, cooperative braking and restart of a group of fluid turbines may include coordinating and / or synchronizing power generation (e.g., AC power) from a fluid flow, for example, to synchronize the phase of AC power output, to comply with regulations for supplying electrical energy to a power grid, and / or to charge one or more batteries. As a further example, coordinating the operation of a group of fluid turbines may include, for example, coordinating the operation of each fluid turbine in the group to improve the performance of the group as a whole, as an integrated fluid energy conversion system including a plurality of individual fluid turbines. For example, the operation of one or more fluid turbines in the group may be coordinated to take advantage of aerodynamic coupling between the individual turbines and apply one or more algorithms to optimize turbine energy conversion (e.g., algorithms may be applied to individual turbines, a subset of the turbines in the group, and / or each turbine in the group).

[0015] Flow (e.g., fluid flow) may refer to the movement or continuous deformation of a fluid under an applied force. Flow may correspond to the kinetic energy of the particles or molecules of the fluid. For example, a temperature gradient within a fluid may cause warmer fluids to rise and cooler fluids to sink in a circular flow motion. Uneven heating of the Earth by the Sun (e.g., combined with the Earth's rotation) may cause wind (e.g., air currents). Similarly, wind, water density differences, gravity, and the Earth's rotation may also cause ocean currents (e.g., water currents). Examples of turbines for obtaining energy from flow may include windmills, water wheels, steam turbines, or gas turbines.

[0016] A fluid turbine may include a mechanical device configured to capture energy from a fluid flow (e.g., a flow of water, steam, gas, or wind) and convert the captured energy into a form of work (e.g., rotational motion). The fluid turbine may be combined with a generator to apply the work generated by the fluid turbine to generate electrical power (e.g., for feeding an electrical grid). The fluid turbine may include at least one moving part (e.g., a rotor) coupled to a plurality of blades. The fluid turbine may have a horizontal axis of rotation (e.g., an axis about which the fluid turbine rotates is substantially parallel to the ground or the flow) or a vertical axis of rotation (e.g., an axis about which the fluid turbine rotates is perpendicular to the ground or the flow). In some aspects, the axis of rotation may be neither horizontal nor vertical, and in other aspects, the axis of rotation may be variable. The fluid turbine may begin generating usable electrical power when the fluid flow exceeds a lower threshold (e.g., a cut-in value). The fluid turbine may include a plurality of blades connected to a shaft. The fluid flow may rotate the plurality of blades and the shaft. The blades and shaft may be connected to a rotor of a generator to convert the mechanical rotational motion of the blades and shaft into electrical energy, as described in more detail below. Some embodiments may lack a shaft, and the blades are connected to a shaftless rotating disk or support. In such examples, the rotating disk or support may be part of a rotor-stator arrangement.

[0017] In aspects including a shaft, the shaft may include a pole, rod, post, support, pylon, or any other axle or axle. In some aspects, the shaft may be used to support one or more objects in a vertical configuration. For example, the blades of a vertical fluid turbine may be connected to a shaft that allows the blades to be supported vertically by the shaft that may rotate with the blades. Connecting the shaft to a rotor with the blades may allow the kinetic energy of the flowing fluid to be transferred to rotational motion by the rotor to generate electrical energy.

[0018] A blade of a turbine (e.g., as part of a plurality of blades) may refer to an object having a cross-sectional shape with a curved surface (e.g., an airfoil shape or a cup shape typical of drag-type turbines) configured to induce motion (e.g., rotational motion) consistent with fluid motion incident on the blade. A fluid turbine may include a plurality of blades attached to the edge of a disk to generate a tangential force that rotates a connected rotor. A moving fluid may act on the blades of the fluid turbine to rotate the blades and impart rotational energy to the rotor. The blades may extend to protrude from the rotor or from a mounting plate mechanically connected to the rotor. The blades may be connected (e.g., directly or indirectly) to the rotor, thereby causing the blades to extend outward and / or upward from the rotor.

[0019] A generator (e.g., an alternator) may refer to a device including windings electromagnetically coupled to an alternating magnetic field via a rotor and a stator that allows for the conversion of non-electrical forms of energy (e.g., chemical, radiant, mechanical, thermal, or nuclear energy) into electrical energy. For example, mechanical energy as rotational motion may be transferred from a turbine to the rotor of the generator. The rotational motion of the rotor may cause an alternating magnetic field surrounding the windings, which may induce an alternating current, thereby converting the mechanical energy into electrical energy. In some aspects, the rotor may include one or more magnets and the stator may include windings. In some aspects, the rotor may include windings and the stator may include one or more magnets. In some aspects, the rotor may be configured to rotate within the stator. For example, the stator may be formed as a ring or donut surrounding the rotor. In some aspects, the rotor is configured to rotate around the stator. For example, the rotor may be formed as a ring or donut surrounding the stator. In some aspects, the rotor is connected to blades configured to rotate in response to wind flow. Wind flow may refer to a fluid flow consisting of air. In some aspects, the rotor may be configured to rotate in response to a water flow over an impeller (e.g., a paddle wheel, a water wheel) or in response to a steam or gas flow.

[0020] A rotor may refer to a rotating component of an electromagnetic system (e.g., an electric motor, a generator, or an alternator). A rotor may rotate, or orbit, or spin to induce torque about the rotor's axis. A stator may refer to a fixed (e.g., non-moving) component of a rotating electromagnetic system. A rotor electromagnetically coupled to a stator may enable interaction between an electromagnetic coil (e.g., winding) of conductive wire and an alternating magnetic field. The interaction may enable conversion of electrical energy into mechanical energy as rotational motion (e.g., as in a motor) and conversion of mechanical energy into electrical energy as rotational motion (e.g., as in a generator). For example, energy may flow from a rotating component to a stator, as in a generator, where the stator may convert a rotating magnetic field into alternating current.

[0021] A geographically associated fluid turbine may refer to a plurality of fluid turbines positioned relatively close to one another to form a group or fleet of fluid turbines. The geographically associated fluid turbines may be positioned in an arrangement such that each fluid turbine may be exposed to substantially similar environmental conditions and fluid flows (e.g., wind conditions, temperature, precipitation, water flow). In some aspects, at least some of the geographically associated fluid turbines may be fluidly coupled such that blade motion of a fluidly coupled upstream fluid turbine may cause fluid flows or turbulences that may act or affect blade motion of a fluidly coupled downstream fluid turbine in the fleet. In some aspects, each of the geographically associated fluid turbines may be fluidly coupled with at least one other geographically associated fluid turbine. In some aspects, at least one of the geographically associated fluid turbines may be independent such that a fluid flow generated by a blade motion of one of the geographically associated fluid turbines may not affect the blade motion of any of the other of the geographically associated fluid turbines and a fluid flow generated by the other geographically associated fluid turbine may not affect the one geographically associated fluid turbine, and at least some of the geographically associated fluid turbines are fluidly dependent. In some embodiments, all of the geographically associated fluid turbines may be independent such that the fluid flow generated by the blade motion of any one of the geographically associated fluid turbines cannot affect the blade motion of any other of the geographically associated fluid turbines.

[0022] In some aspects, each fluid turbine in a geographically associated group of fluid turbines may be connected to a generator to separately convert the rotating blade motion of the fluid turbine into electrical energy. In certain instances of the present disclosure, the term "fluid turbine" may refer to a fluid turbine connected to a generator as a single fluid energy conversion unit. In some aspects, the fluid turbine (e.g., each fluid energy conversion unit) may include dedicated electronic circuitry for monitoring, operating, and / or controlling the fluid turbine, as described in more detail elsewhere in this disclosure (e.g., the term "fluid turbine" may include a fluid turbine connected to a generator and dedicated electronic circuitry).

[0023] In some aspects, the geographically associated fluid turbines may be interconnected via electronic circuitry (e.g., the interconnection electronic circuitry may be different from the electronic circuitry dedicated to each fluid turbine). For example, the interconnection electronic circuitry may connect to each geographically associated fluid turbine via a respective dedicated electronic circuitry. The interconnection electronic circuitry may enable the geographically associated fluid turbines to collectively operate as a single fluid energy conversion system (e.g., as a central control). For example, the interconnection electronic circuitry may enable coordinated aggregation of power generated by each geographically associated fluid turbine in a group to output a total power to a power grid. As another example, the interconnection electronic circuitry may include a controller for coordinating operation of one or more of the geographically associated fluid turbines for braking, slowing, stopping, restarting, synchronizing two or more fluid turbines, coordinating control of relative phase between two or more fluid turbines, controlling rotational speed, rotational direction, and / or any other aspect of operating one or more fluid turbines, etc.

[0024] An electronic circuit may include any combination of electronic components (e.g., memory units, switches, transistors, diodes, gates, capacitors, inductors, resistors, transformers, converters, inverters, rectifiers, DC-DC converters, more power supplies, voltage sensors, current sensors, or other electronic components) connected via one or more connecting wires and / or contacts for performing one or more operations (e.g., logical operations) in response to receiving an electrical signal as an input (e.g., from at least one processor acting as a controller). A circuit may include one or more integrated circuits (ICs), including all or part of an application specific integrated circuit (ASIC), microchip, microcontroller, microprocessor, central processing unit (CPU), graphics processing unit (GPU), accelerated processing unit (APU), digital signal processor (DSP), field programmable gate array (FPGA), or other circuitry suitable for executing computational instructions and / or capable of performing logical operations, for example, based on computational instructions or input signals. The circuit may further include one or more memory units, such as a random access memory (RAM), cache memory, read-only memory (ROM), hard disk, optical disk, magnetic media, flash memory, other persistent, fixed, or volatile memory, or any other mechanism capable of storing data and / or computational instructions for performing logical operations. The circuit may further include one or more communication channels and / or links. The communication links may couple one or more ICs to the memory, thereby enabling the one or more ICs to receive the computational instructions and / or data stored in the memory that are necessary to perform the corresponding logical operations. The communication channels coupling one or more ICs to the memory may include wired channels, such as one or more cables, fibers, wires, buses, and any other mechanically coupled communication channels. The communication channels may include wireless channels, such as shortwave, mediumwave, and longwave wireless communication channels (e.g., Wi-Fi, Bluetooth, Zigbee, cellular, satellite), optical, and acoustic communication channels.The communication channel or link may include wires, cables, and / or fibers configured to transmit electrical power (e.g., AC and / or DC power) generated by the one or more fluid turbines. The communication channel or link may include a communication link for transmitting electronic signals readable by the at least one processor.

[0025] Direct current (DC) may refer to the flow of charge in one direction. DC power may be used to operate a processor or controller. An example of DC power may include power generated by an electrochemical cell (e.g., a battery) or power stored in a capacitor. Electronic devices such as processors, controllers, and memory devices may have DC electricity. Alternating current (AC) may refer to a bidirectional flow of charge that exhibits periodic changes in direction. AC current flow may vary between positive and negative due to the positive or negative flow of electrons, producing a sinusoidal AC wave. An alternator may create AC power by placing a conductive coil (e.g., copper winding) in a changing magnetic field. The changing magnetic polarity may cause the current in the conductive coil to change direction, producing an electrical waveform signal. AC power may travel farther than DC power without losing power, which may be advantageous for supplying power from a power generation system to a consumer of electricity. A generator may generate AC power, and a power grid may supply AC power to a consumer.

[0026] A rectifier may refer to a device or circuit (e.g., an AC-DC converter) that converts an alternating current (AC) to a direct current (DC) signal. The rectifier may convert AC power (e.g., generated by a generator) to DC power (e.g., for powering at least one processor). In some aspects, each of the geographically associated fluid turbines may be associated with a dedicated rectifier. The dedicated rectifier for each fluid turbine may be housed in a separate housing (e.g., per fluid turbine) or in a common housing for multiple fluid turbines.

[0027] An inverter (e.g., a power inverter) may refer to a device or circuit (e.g., a DC-AC converter) that converts a direct current (DC) signal to an AC signal. The inverter may convert the DC signal to generate a square wave, a sine wave, a modified sine wave, a pulsed sine wave, or a pulse-width modulated wave (PWM) depending on the inverter's circuit design. The inverter may convert the DC power to AC power for transmission to a power grid. In some aspects, multiple geographically associated fluid turbines may be associated with a single inverter for collectively outputting the generated AC power to a power grid.

[0028] For example, each AC power signal output by each geographically associated fluid turbine may be converted to a DC power signal via a respective dedicated rectifier. Circuitry (e.g., including at least one processor) may process the DC power signals to enable each of the DC power signals to be combined to form an aggregate DC power signal such that by converting the aggregate DC power signal via an inverter, an AC power signal may be generated that may be suitable for transmission to a power grid.

[0029] In some embodiments, the fluid turbine may operate under one or more loads (e.g., power sinks such as a power grid and / or a battery bank) that draw power from the fluid turbine, slowing down the rotational speed of the fluid turbine. Controlling the load of the fluid turbine may help ensure compliance with one or more regulations, specifications, and / or recommendations regarding the operation of the fluid turbine, and / or the power grid, and / or the battery bank connected thereto. For example, without a load, under high fluid velocities, the rotational speed of the fluid turbine may exceed operational thresholds, potentially leading to damage or destruction. As another example, fluctuations in fluid velocity may also cause the rotational speed of the fluid turbine to vary, leading to a variable power output that may not comply with requirements associated with the power grid.

[0030] As a further example, overcharging can lead to damage or destruction of the battery bank, and when the battery bank reaches capacity, it becomes necessary to divert power to a different load (e.g., a dump load). The dump load may provide a safety function for the fluid turbine. Excess power generated under high fluid velocities may be sent to a dump load (e.g., or a dump resistor) to prevent the fluid turbine from spinning freely. The dump load may convert the excess power into heat. In some aspects, the dump load may act as an electric brake for the fluid turbine. In some cases, combining multiple AC power outputs from geographically associated fluid turbines may cause the AC power outputs to interfere with each other, resulting in cancellations and losses.

[0031] For example, aggregating different AC power outputs from different generators can cause issues due to different operating frequencies or phase angles, which can lead to synchronization issues and potential damage. Combining different AC power signals can result in cancellation if the phase angles of the signals are not properly aligned. If the AC signals are out of phase with each other, the peaks and troughs of the signals may not align, causing some of the energy of one signal to cancel out the energy of the other signal (e.g., if the peaks of one signal align at least partially with the troughs of another signal), leading to a decrease in the overall power output of the combined signal (e.g., total power output). To avoid this, the generators may be phase synchronized (e.g., by adjusting the phase angle of one generator or by using a phase-locked loop) before combining their respective power outputs. Additionally, different generators may have different voltage levels, which may need to be regulated and / or balanced before transmitting the power. Additionally, the different AC outputs generated by the different generators may be converted to DC for combining as a total DC power output before transmitting the power. Additionally, different generators may have different response times to changes in load, making it difficult to maintain a stable total power output.

[0032] A charge controller may refer to an electronic device configured to help ensure compliance of a fluid turbine with one or more regulations, specifications, and / or recommendations. For example, the charge controller may prevent the fluid turbine from overcharging a battery bank while limiting the rotational speed of the fluid turbine (e.g., when the battery bank is full and / or under high fluid velocity conditions), and may enable aggregation of power from multiple fluid turbines without incurring losses due to interference. The charge controller may include one or more of an AC-DC converter (e.g., a rectifier), a voltage sensor switch, a voltage regulator (e.g., for adjusting the DC voltage for supplying DC power to the battery bank), and / or a dump load (e.g., for diverting excess power to prevent overcharging). In some aspects, the charge controller may include a user interface (e.g., one or more light emitting diodes, or LEDs) and / or functionality for protecting against excessive voltage, current, and / or temperature.

[0033] The charge controller may be connected to an AC output of a generator connected to the fluid turbine. An AC-DC converter of the charge controller may convert the AC output to a DC signal (e.g., for aggregation with other DC signals generated by other charge controllers associated with other fluid turbines without incurring lossy interference). At least one voltage sensor switch of the charge controller may transmit a DC signal to charge the battery bank when the DC voltage level falls below an upper limit of the battery bank and may divert the DC signal (e.g., excess DC power) to a dump load when the DC voltage level exceeds the upper limit. A voltage regulator may regulate the DC voltage transmitted to the battery bank to comply with one or more specifications, regulations, and / or recommendations associated with the battery bank.

[0034] An aggregate power signal may refer to a power signal generated by combining multiple power signals originating from different sources (e.g., generators) into a single composite power signal. Aggregating the power signals may require synchronizing the generators (e.g., synchronizing the frequency, phase angle, and / or adjusting the voltage levels to reach a matched voltage level) or synchronizing and asynchronously synchronizing the power signals. Once the power signals from each generator are synchronized and aligned, the power signals may be combined using an electrical device such as a power combiner or power distribution panel. The combined (e.g., aggregated) signal may be transmitted to a power grid or used to power a load.

[0035] In some aspects, each fluid turbine of a geographically associated plurality of turbines (e.g., a fleet of turbines) may be associated with a dedicated charge controller. In some aspects, a single charge controller may be associated with a geographically associated plurality of turbines.

[0036] A capacitor may refer to an electronic component configured to store electrostatic energy in an electric field by accumulating charges on two opposing surfaces (e.g., conductive plates) separated by an insulator (e.g., a dielectric medium). Applying a potential difference (e.g., voltage) across the plates of the capacitor can generate an electric field across the dielectric medium, causing a net positive charge to accumulate on one plate and a net negative charge to accumulate on the opposing plate, allowing for the storage of electrical energy as the potential difference between the two plates. The plates of the capacitor can be connected (e.g., via the capacitor's contacts) to other circuit components, allowing for the integration of one or more capacitors into an electronic circuit. In some embodiments, a capacitor can function as a source of electrical energy (e.g., similar to a battery). However, a capacitor can be distinguished from a battery, since the capacitor may lack the chemical reactions to receive, store, and generate electrical energy. Capacitors can be manufacturable on a microelectronic scale for integration with other microelectronic components, for example, in photolithography processes.

[0037] A battery may refer to an electrical device configured to convert chemical energy into electrical energy or vice versa. A battery may include one or more cells, each cell containing an electrode and an electrolyte. When the electrodes are connected to an external circuit, a chemical reaction may occur in the electrolyte, resulting in a flow of electrons, which generates an electric current. The amount of electrical energy that can be stored in a battery may be determined by its capacity (e.g., measured in ampere hours, Ah, or milliampere hours, mAh). A battery may be rechargeable or non-rechargeable.

[0038] A battery bank may include multiple batteries connected together in a series or parallel configuration to provide greater capacity and / or higher voltage. A battery bank may be used, for example, to store electrical energy generated by a renewable energy source, such as multiple fluid turbines, for subsequent use by a consumer. In some embodiments, a battery bank may include multiple batteries connected in series to increase voltage while maintaining a stable capacity. In some embodiments, a battery bank may include multiple batteries connected in parallel to increase capacity while maintaining a stable voltage. In some embodiments, a battery bank may include multiple batteries connected in series and in parallel to allow for increased voltage and capacity. A charge controller may be used to ensure that the batteries in a battery bank have similar states of charge and similar characteristics, for example, to prevent overcharging, over-discharging, and / or uneven aging of one or more batteries contained therein.

[0039] An electric power system (e.g., a power grid) may include an interconnection network that provides electric power (e.g., AC power) from a single or multiple generators to a single or multiple consumers. The grid may be designed to provide electricity at a substantially stable voltage level under fluctuating demand and supply by the generators. The grid may adjust the voltage to stay within specifications using one or more tap changers on nearby transformers. Attributes (e.g., frequency, phase, power level) of the electric power provided to the electric power system by one or more generators may be required to comply with regulations or standards. At least one processor may constitute any physical device or group of devices having electrical circuitry that performs logical operations on one or more inputs. For example, the at least one processor may include one or more integrated circuits (ICs) that include all or a portion of an application specific integrated circuit (ASIC), a microchip, a microcontroller, a microprocessor, a central processing unit (CPU), a graphics processing unit (GPU), a digital signal processor (DSP), a field programmable gate array (FPGA), a server, a virtual server, or other circuitry suitable for executing instructions or performing logical operations. The instructions executed by the at least one processor may be, for example, preloaded into a memory integrated with or incorporated into the controller, or stored in a separate memory. The memory may include random access memory (RAM), read-only memory (ROM), a hard disk, an optical disk, a magnetic medium, a flash memory, other persistent, fixed, or volatile memory, or any other mechanism capable of storing instructions. In some embodiments, the at least one processor may include two or more processors. Each processor may have a similar structure, or the processors may be of different structures electrically connected or disconnected from each other. For example, the processors may be separate circuits or may be integrated into a single circuit. When two or more processors are used, the processors may be configured to operate independently or cooperatively, and may be co-located or remotely located from each other.The processors may be coupled electrically, magnetically, optically, acoustically, mechanically, or by other means that allow the processors to interact.

[0040] A processor may be configured to execute software instructions, control and execute processes, and perform calculations and computations such as arithmetic and / or logical operations to store, manipulate, and remove data from memory. An example of a processor may include a microprocessor manufactured by Intel. A processor may include a single core or multiple core processors that simultaneously execute parallel processes. It is understood that other types of processor configurations may also be implemented to provide the functionality disclosed herein.

[0041] The at least one processor may include a single processor or multiple processors communicatively linked to each other and capable of cooperatively performing computational operations, such as collectively performing a single task by splitting a task into subtasks and distributing the subtasks among multiple processors using a load balancer, for example. In some aspects, the at least one processor may include multiple processors communicatively linked via a communications network (e.g., a local and / or remote communications network including wired and / or wireless communications links). The multiple linked processors may be configured to collectively perform computational operations in a distributed manner (e.g., as known in the art of distributed computing).

[0042] In some aspects, the at least one processor may include multiple processors configured to control a geographically associated plurality of fluid turbines (e.g., a group of fluid turbines). In some aspects, one or more fluid turbines in a group of fluid turbines may be associated with one or more specific processors, e.g., dedicated to a particular fluid turbine or a subset of particular fluid turbines in the group. In some aspects, the one or more processors may be configured in a central control unit to collectively control the operation of each fluid turbine in the group of fluid turbines. In some aspects, the at least one processor may include one or more processors dedicated to a particular fluid turbine in the group of fluid turbines and one or more processors in the central control unit configured to control the operation of the entire group of fluid turbines. In some aspects, the at least one processor may control the operation of the geographically associated plurality of fluid turbines to enable the geographically associated plurality of fluid turbines to collectively operate as a single fluid energy conversion system.

[0043] A non-transitory computer-readable storage medium (e.g., memory) refers to any type of physical memory capable of storing information or data readable by at least one processor. Examples include random access memory (RAM), read-only memory (ROM), volatile memory, non-volatile memory, hard drives, CD ROMs, DVDs, flash drives, disks, any other optical data storage medium, any physical medium with a pattern of holes, PROMs, EPROMs, FLASH-EPROMs or any other flash memories, NVRAMs, caches, registers, any other memory chips or cartridges, and networked versions thereof. The terms "memory" and "computer-readable storage medium" may refer to multiple structures such as multiple memories or computer-readable storage media located locally (e.g., in physical proximity to at least one processor and connected via a local communication link) or located remotely (e.g., accessible from at least one processor via a communication network). Furthermore, one or more computer-readable storage media may be utilized in implementing a computer-implemented method. Thus, the term computer-readable storage medium should be understood to include tangible items and exclude carrier waves and transient signals.

[0044] In some aspects, the memory may include a plurality of memory storage devices configured to store information for controlling a plurality of geographically associated fluid turbines (e.g., a group of fluid turbines). In some aspects, one or more fluid turbines in a group of fluid turbines may be associated with one or more specific memory devices, for example, dedicated to a particular fluid turbine or a subset of particular fluid turbines in the group. In some aspects, the one or more memory devices may be configured with a central control unit to collectively store information for controlling each fluid turbine in the group of fluid turbines. In some aspects, the memory may include one or more memory devices dedicated to a particular fluid turbine in the group of fluid turbines and one or more memory devices in the central control unit configured to store information for controlling the entire group of fluid turbines. In some aspects, the memory may store information for controlling the operation of a plurality of geographically associated fluid turbines to enable the plurality of geographically associated fluid turbines to collectively operate as a single fluid energy conversion system.

[0045] A sensor may refer to a device that may output a signal (e.g., an electronic signal) in response to detecting, sensing, or measuring a physical phenomenon (e.g., electronic or non-electronic phenomenon). A sensor may be configured to convert a measurement of a physical phenomenon into a medium (e.g., an electronic medium) for reception by at least one processor. Examples of sensors may include anemometers for measuring wind speed, water flow sensors, voltmeters and / or ammeters for measuring electrical signals, magnetometers (e.g., for measuring magnetic fields), accelerometers (e.g., for sensing vibrations such as vibrations or oscillations of blades and / or shafts), thermometers (e.g., for sensing temperature), light sensors (e.g., for sensing visible and / or IR light), microphones (e.g., for sensing sound), and / or any other type of sensor for measuring a physical phenomenon.

[0046] A signal may refer to information encoded for transmission over a physical medium. Examples of signals may include signals in the electromagnetic radiation spectrum (e.g., AM or FM radio, Wi-Fi, Bluetooth, radar, visible light, lidar, IR, Zigbee, Z-wave, and / or GPS signals), audio or ultrasonic signals, electrical signals (e.g., voltage, current, or charge signals), electronic signals (e.g., as digital data), haptic signals (e.g., touch), and / or any other type of information encoded for transmission between two entities over a physical medium.

[0047] Maximum power point tracking (MPPT) may include one or more algorithms for extracting maximum power from a fluid energy conversion system (e.g., a fluid turbine mechanically coupled to a generator) using the maximum power available in the fluid flow. Because the fluid flow varies continuously over time, the amount of power that can be generated from the fluid turbine may depend on the accuracy with which the peak power point of the fluid energy conversion system can be tracked by a controller that controls the rotational speed of the fluid turbine. The controller may enable maximum energy extraction by adjusting the shaft speed (e.g., corresponding to the rotational speed) of the fluid turbine in response to the varying fluid speed. The controller may adjust the shaft speed by sending an electrical signal to the copper windings of a generator rotor coupled to the controller. The electrical signal may introduce an impedance (e.g., by shunting or shorting the copper windings) that slows down the rotor and correspondingly slows down the fluid turbine coupled to the rotor to generate maximum power under varying fluid conditions. The charge controller may adjust the shaft speed by increasing or decreasing the load of the generator connected to it. Some MPPT algorithms may require one or more inputs, such as fluid velocity, the rotational speed of the fluid turbine (e.g., rotor speed), the maximum power curve of the fluid turbine, or the mechanical power equation of the fluid turbine (e.g., obtained experimentally or by simulation).

[0048] MPPT algorithms for fluid turbines may be based on direct and / or indirect power measurements, fluid velocity measurements, and / or hybrid and / or smart algorithms (e.g., based on artificial intelligence techniques such as neural networks and fuzzy logic controllers) to track the maximum power point of a particular fluid turbine. Some MPPT algorithms for fluid turbines may use one or more fluid velocity sensors (e.g., anemometers, ultrasonic flow sensors), such as tip speed ratio (TSR) algorithms and power signal feedback (PSF) algorithms, which are described in more detail below. Some MPPT algorithms for fluid turbines may avoid the use of fluid velocity sensors, such as perturbation and observation (P&O) algorithms, optimal relationship based (ORB) algorithms, or incremental conductance (INC) algorithms. Some MPPT techniques may combine one or more MPPT algorithms (e.g., hybrid techniques).

[0049] For example, a tip speed ratio (TSR) based MPPT algorithm may use the ratio between the fluid velocity and the rotational speed of the blade tips of the fluid turbine to adjust the rotational speed of a generator coupled to the fluid turbine to maintain the TSR of the fluid turbine at an optimal value for extracting maximum power. In addition to the fluid velocity and turbine rotational speed, the TSR algorithm may also require the optimal TSR of the fluid turbine as an input.

[0050] As another example, a power signal feedback (PSF) algorithm may be used to control a fluid turbine to extract maximum power from a fluid flow. A reference power level may be generated using a recorded maximum power curve or the mechanical force equation of the fluid turbine. The curve may be traced to vary the fluid velocity to control the fluid turbine to output maximum power.

[0051] As a further example, a hill climbing search (HCS) control algorithm may continuously track the power output of a fluid turbine to search for a peak power output. The HCS tracking algorithm may calculate a desired optimal signal to drive the fluid turbine to a maximum power point based on the location of the operating point and the relationship between the changes in power and speed.

[0052] An MPPT protocol (e.g., for a single fluid turbine) may include transmitting a signal to adjust the rotational speed of the single fluid turbine by adjusting the load, adjusting the brake (e.g., mechanical and / or electronic brake), and / or adjusting the rotational speed of the single fluid turbine using any other method. In some aspects, an MPPT protocol for a single fluid turbine may include increasing the load on a generator connected to the fluid turbine and / or sending a signal to the generator to output maximum (e.g., or near maximum) energy at a time.

[0053] An MPPT protocol (e.g., for a group of fluid turbines) may include adjusting the rotational speeds of at least some of the fluid turbines in the geographically associated group of fluid turbines to cause the group to output a maximum (e.g., or near-maximum) total power output at a time and / or under certain fluid conditions. In some aspects, implementing an MPPT protocol for a group of fluid turbines may include transmitting at least some signals associated with applying an MPPT protocol (e.g., for a single fluid turbine) to at least some individual fluid turbines in the group and at least some signals not associated with applying an MPPT protocol (e.g., for a single fluid turbine) to any individual fluid turbine in the group. In some cases, the MPPT protocol for a group of fluid turbines may override one or more signals associated with an MPPT protocol for a single fluid turbine in the group.

[0054] In some aspects, the charge controller may include at least one processor for implementing an MPPT protocol on a fluid turbine connected thereto.

[0055] Reference is made to FIG. 1, which illustrates various exemplary fluid turbines 100-112. Fluid turbine 100 is an exemplary vertical wind turbine, fluid turbine 102 is an exemplary horizontal wind turbine, fluid turbine 104 may be an exemplary water, gas, or steam turbine, fluid turbine 106 may be an exemplary Savonius (e.g., vertical) wind turbine, fluid turbine 108 may be an exemplary Darrieus rotor (e.g., vertical) wind turbine, fluid turbine 110 may be an exemplary H-type lift vertical wind turbine, and fluid turbine 112 may be an exemplary Helix (e.g., vertical) wind turbine. It should be noted that the exemplary fluid turbines 100-112 are shown for illustrative purposes and are not intended to limit the present disclosure to any particular type or implementation of a fluid turbine, as the inventive principles described herein may be applied to any turbine or group of turbines, regardless of construction or arrangement. Additionally, while some non-limiting examples may refer to any one of fluid turbines 100-112, these examples are provided for conceptual purposes only and are not intended to limit the present disclosure to any particular implementation or type of fluid turbine.

[0056] Referring to FIG. 2 , an orthogonal view of a fluid energy conversion system including a fluid turbine 100 coupled to a generator 204 is shown, consistent with certain aspects of the present disclosure. The fluid turbine 100 may include a number of blades 206, 208 configured to spin in response to a fluid flow 210. The generator 204 may include a rotor 212 and a stator 214, both of which house one or more permanent magnets and copper windings (e.g., the rotor may include magnets and the stator may include copper windings, or vice versa). The generator 204 may be configured to induce an alternating current (AC) as the rotor 212 rotates relative to the stator 214 (e.g., by generating a varying magnetic field from the rotational motion to surround the copper windings). The kinetic energy contained in the fluid flow 210 may exert a force on the fluid turbine 100, causing the blades 206, 208 to rotate. The rotational motion of the blades 206, 208 may cause the rotor 212 of the generator 204 to spin relative to the stator 214, generating an alternating current, thereby converting the kinetic energy of the fluid stream 210 into electrical energy. Although the fluid turbine 100 is shown as a vertical axis wind turbine and the fluid stream 210 is shown as an air stream, this example is not intended to be limiting and the fluid turbine 100 may be a horizontal axis wind turbine, a water turbine, a gas turbine, or a steam turbine. Similarly, the fluid stream 210 may be water, gas, or steam, respectively.

[0057] Reference is made to Figure 3, which illustrates an orthogonal view of a group 300 of example geographically associated fluid turbines 100A, 100B, 100C consistent with certain aspects of the present disclosure. The geographically associated fluid turbines 100A, 100B, 100C may be connected to at least one processor 308 via circuitry 310 and one or more communication links 312. The communication links 312 may include different types of wired communication links (e.g., wire, cable, fiber) and wireless communication links (e.g., Wi-Fi, Bluetooth, Zigbee, AM, FM, PM radio transceivers, satellite or GPS transceivers, IR transceivers, ultrasonic transceivers, and / or any other type of wireless communication link). The communication links may include, for example, high power communication links for receiving power generated by the fluid turbines 100A, 100B, 100C and / or for transmitting load bearing signals to the fluid turbines 100A, 100B, 100C, as well as low power communication links, for example, for transmitting and receiving data between multiple processors and / or sensors.

[0058] The at least one processor 308 may be configured to control each of the fluid turbines 100A, 100B, 100C separately or to coordinate the operation of each of the fluid turbines 100A, 100B, 100C, for example, by coordinating operation such as braking, slowing, stopping, locking, unlocking, and / or starting of one or more of the fluid turbines 100A, 100B, 100C, controlling the direction of rotation and / or the speed of rotation of any of the fluid turbines 100A, 100B, 100C, implementing MPPT algorithms for one or more of the fluid turbines 100A, 100B, 100C, controlling the relative rotational phase between any of the fluid turbines 100A, 100B, 100C, and / or performing any other procedure for coordinating the operation of one or more of the fluid turbines 100A, 100B, 100C. Although the group 300 is shown as having three fluid turbines, this is for illustrative purposes only, and the group 300 may include as few as two fluid turbines, or four or more fluid turbines. Additionally, while FIG. 3 illustrates the fluid turbines 100A, 100B, 100C as vertical wind turbines (e.g., corresponding to the fluid turbine 100 of FIG. 1), this is for illustrative purposes only and is not intended to limit the disclosure to a particular implementation. The group 300 may include, for example, different types of fluid turbines other than the fluid turbine 100, such as one or more horizontal wind turbines, and one or more water turbines, steam turbines, and / or gas turbines. It is important to note that while the description of FIG. 3 is provided in the context of the illustrated exemplary turbine structure, the principles described in FIG. 3 apply to all turbines, regardless of turbine structure.

[0059] Reference is made to FIG. 4, which illustrates a schematic diagram of an example fluid energy conversion system 400 configured to generate and output electrical power from a fluid stream to an energy sink 402, consistent with certain aspects of the present disclosure. The fluid energy conversion system 400 may include a plurality (e.g., a group) 401 of geographically associated fluid turbines 404 (e.g., fluid turbines 404A, 404B). Each of the fluid turbines 404A, 404B may be connected to a respective generator 406 (e.g., generators 406A, 406B) to convert the energy of the fluid stream (e.g., fluid stream 210 shown in FIG. 2) into electrical power (e.g., total power output 440) for at least one energy sink 402 (e.g., a load). The total power output 440 may include a DC power output, for example, to power a battery bank, or an AC power output, for example, to supply to a power grid. In some aspects, a portion of the total power output 440 may be supplied as a DC signal to charge one or more batteries, and a portion of the total power output 440 may be supplied as an AC signal to a power grid. The fluid turbines 404A, 404B may be any fluid turbine, including but not limited to the various exemplary turbines shown in FIG. 1. Examples of energy sinks may include a power grid, one or more batteries, and / or any other sink for power. The generators 406A, 406B may convert the mechanical rotational energy received from the fluid turbines 404A, 404B into a number of AC power outputs 408 (e.g., AC power outputs 408A, 408B). Each of the fluid turbines 404A, 404B and the generators 406A, 406B may be associated with a respective charge controller 410 (e.g., charge controllers 410A, 410B). The AC power outputs 408A, 408B may be converted to a DC power signal 412 (e.g., DC power signal 412A, 412B) via the respective charge controller 410 (e.g., charge controller 410A, 410B). The charging controller 410 may include electronic circuits such as one or more of a rectifier (e.g., an AC-DC converter), a voltage sensor switch, a dump load, a braking circuit, a capacitor, and / or a voltage booster.The DC power signals 412A, 412B may be communicated to the interconnect circuitry 414 via multiple links 416 (e.g., links 416A, 416B). The links 416A, 416B may include one or more of coaxial cables, fibers, and / or wires configured to transmit the power signals.

[0060] The charge controllers 410A, 410B may transmit one or more electronic signals via communications links 420 (e.g., links 420A, 420B) to the interconnect circuitry 414. The links 420A, 420B may include one or more wired and / or wireless communication channels configured to transmit and receive electronic signals between the at least one processor 428 and the charge controllers 410A, 410B.

[0061] Each of the fluid turbines 404A, 404B and the generators 406A, 406B may be associated with at least one sensor 418 (e.g., at least one sensor 418A, 418B), which will be described in more detail below. Each at least one sensor 418 may be coupled to the fluid turbine 404 and / or the generator 406, for example, to sense one or more operating parameters associated with the fluid turbine 404 and / or the generator 406 connected to the sensor. Each at least one sensor 418 may be coupled to the charge controller 410. For example, the at least one sensor 418A may be coupled to the fluid turbine 404A and / or the generator 406A and the charge controller 410A, and the at least one sensor 418B may be coupled to the fluid turbine 404B and / or the generator 406B and the charge controller 410B.

[0062] The interconnect circuitry 414 may include at least one sensor 438, at least one booster (e.g., voltage booster) 422, at least one capacitor 424, at least one DC-DC converter 426, at least one processor 428, at least one memory 430, at least one brake circuit 432, and / or one or more inverters 434 interconnected via a communication link 436. In some embodiments, the inverter 434 may be a single inverter configured to convert the aggregated DC power generated by the geographically associated multiple fluid turbines 404 to a grid-compatible AC signal (e.g., 110V, 120V, 220V, 240V, or any other voltage level compatible with a local power grid). One non-limiting example of an inverter that may be used is the IQ7 Plus manufactured by Enphase Energy, Inc. of Fremont, California.

[0063] 5 illustrates an example schematic diagram of a charge controller 410 connected to at least one sensor 418 consistent with certain aspects of the present disclosure. The at least one sensor 418 may include one or more rotational sensors 502, one or more fluid velocity sensors 504, one or more vibration sensors 506, one or more temperature sensors 508, one or more power output sensors 510, and / or one or more image sensors 524. The one or more rotational sensors 502 may be configured with rotating components of the fluid turbine 404 and / or the generator 406, such as one or more blades and / or shaft of the fluid turbine 404 and / or rotor of the generator 406. The fluid velocity sensor 504 may include, by way of example, one or more of anemometers, water flow sensors, gas flow meters, and / or steam flow meters for sensing the velocity of a fluid flow impacting the fluid turbine 404. The vibration sensor 506 may include, by way of example, one or more accelerometers, piezoelectric MEMS, piezoresistive MEMS, and / or capacitive MEMS for sensing vibrations of one or more components of the fluid turbine 404 and / or the generator 406. The temperature sensor 508 may include, for example, a thermometer, a thermostat, a thermocouple, a thermopile, an infrared thermometer, a bimetallic strip thermometer, or any other type of temperature measuring device. The power output sensor 510 may include, for example, a voltmeter (e.g., a voltage sensor) and / or an ammeter (e.g., a current sensor) for measuring the power generated by the generator 406. The one or more image sensors 524 may include one or more cameras (e.g., a charge-coupled device or CCD camera, and / or a CMOS camera for detecting visible light, and / or an IR camera).

[0064] Each charge controller 410 may include one or more of at least one processor 512, memory 514, input / output (I / O) 516 (e.g., for communicating with at least one processor 428 via communication link 420), electronic brake control 518, mechanical brake control 520, yaw control 526, pitch control 528, and / or rectifier 530. The at least one processor 512, memory 514, I / O 516, electronic brake control 518, mechanical brake control 520, yaw control 526, pitch control 528, and rectifier 530 may be interconnected via a bus system 522. In some aspects, a clock (e.g., of the at least one processor) may be used as a sensor, for example, to schedule maintenance or safety procedures and / or to synchronize operation of the fluid turbines 404. In some embodiments, the clock may be used in conjunction with scheduling software to issue an alarm (e.g., a signal) to cause at least one processor to brake, slow down, stop, lock, and / or unlock the fluid turbine.

[0065] The electronic brake control 518 may include an inverter and a booster, for example, to implement an electronic braking mechanism. For example, electronic braking of the fluid turbine 404 may be implemented by imposing a load (e.g., an impedance) on the generator 406. At least one processor (e.g., at least one processor 428 and processor 512) may determine an appropriate AC signal for imposing a particular load that achieves a desired level of braking. The at least one processor may transmit the DC signal to the electronic brake control 518 of the charge controller 410. The electronic brake control 518 may generate an AC signal using the DC signal, and a booster of the electronic brake control 518 may amplify the AC signal to a level corresponding to an AC signal suitable for imposing a particular load on the generator 406. The amplified AC signal may be transmitted to the rotor of the generator 406 to impose a load and thereby control the fluid turbine 404 (e.g., by slowing and / or stopping). For example, the AC signal may be used to implement an MPPT protocol, activate an electronic brake, adjust the phase of the fluid turbine 404 (e.g., by slowing down one fluid turbine relative to another), adjust the rotational speed, adjust the direction of rotation, and / or perform any other control action on the fluid turbine 404.

[0066] Mechanical brake control 520 may include one or more electronic switches that enable at least one processor (e.g., at least one processor 428 and / or processor 512) to control one or more mechanical brakes (e.g., brake pads, discs, and / or drums) configured with one or more rotating components of the fluid turbine 404 and / or generator 406.

[0067] In some aspects, electronic braking of the fluid turbine 404 may be implemented by the charge controller 410, for example, by diverting power generated by the generator 406 to a dump load.

[0068] Reference is made to FIG. 6, which illustrates a cross-sectional top view of an exemplary fluid turbine 600 configured with at least one mechanical brake, consistent with certain aspects of the present disclosure. The fluid turbine 600 may include blades 602, 604 connected to a rotatable shaft 606, at least one mechanical brake 608, a generator 610, at least one lock 612, and a charge controller 614 (e.g., corresponding to the charge controller 410). The generator 610 may be connected to the rotatable shaft 606 to convert rotational mechanical energy into electrical power by the blades 602, 604. The charge controller 614 may be connected to one or more of the generator 610, the rotatable shaft 606, the blades 602, 604, the at least one mechanical brake 608, and the at least one lock 612. The at least one mechanical brake 608 and / or the at least one lock 612 may operate on any rotatable component associated with the fluid turbine 600, such as the rotatable shaft 606, the rotor of the generator 610, and / or the blades 602, 604 (e.g., the at least one mechanical brake 608 and the lock 612 are shown operating on the shaft 606 in FIG. 6 for illustrative purposes only and not to limit the disclosure to a particular implementation). The at least one processor (e.g., the at least one processor 512 and / or the processor 428) may control the level of engagement and / or disengagement of the at least one mechanical brake 608 and the at least one lock 612 by sending a signal to the mechanical brake control 520 to control one or more switches configured to control the level of engagement and / or disengagement of the at least one mechanical brake 608 and / or the at least one lock 612.

[0069] The charge controller 614 may receive signals from one or more sensors (e.g., at least one sensor 418) configured with the fluid turbine 600 and / or generator 610 (e.g., including the rotatable shaft 606, the blades 602, 604, the at least one brake 608, and / or the at least one lock 612). The one or more signals may be received by the at least one processor to determine operating parameters associated with the fluid turbine 600. For example, the at least one processor may use the signals to communicate with the charge controller 614 to activate or deactivate electronic braking and / or to communicate with the at least one brake 608 to engage or disengage mechanical braking. Although the braking system is described above with reference to the fluid turbine 600, this is for illustrative purposes only. The braking system principles described herein are intended to apply to all fluid turbines, including but not limited to the turbine illustrated in FIG. 1.

[0070] As a non-limiting example, refer to FIG. 7, which illustrates a schematic diagram of an example circuit 700 for controlling a plurality 401 of geographically associated fluid turbines 404 consistent with certain aspects of the present disclosure. The example circuit 700 may be understood in conjunction with FIG. 4 and FIG. 5. The fluid turbines 404 (including those described in connection with FIG. 7-FIG. 11 throughout this disclosure) may be any fluid turbine, including but not limited to the various example fluid turbines illustrated in FIG. 1. The fluid turbines 404 may be geographically associated as a group 401. Each of the fluid turbines 404 may be connected to a generator 406 for converting energy of the fluid flow into an AC power output. Each of the AC power outputs 408 may be connected to a charge controller 410. Each charge controller 410 may include at least a rectifier 530, a brake circuit 712 (e.g., including a brake detection circuit), and a voltage booster 714. The rectifier 530 may convert the AC power output 408 to a DC signal and transmit the DC signal to the brake circuit 712 and the voltage booster 714. The brake circuit 712 may be configured to perform electronic braking on the fluid turbine 404 (e.g., based on information received from one or more of the at least one sensor 418). In some aspects, each charge controller 410 may be configured to implement an MPPT protocol on the generator 406 connected thereto. Each of the charge controllers 410 may be connected (e.g., in parallel) to an inverter 434 that may be connected to a power grid 718 (e.g., corresponding to the energy sink 402). The charge controllers 410 may provide an AC power signal to the inverter 434, which may convert the collection of AC power signals to a total AC power output 722. The inverter 434 may be associated with at least one processor (e.g., at least one processor 428 of FIG. 4). In some aspects, the inverter 434 (e.g., via at least one processor configured therewith) may be configured to implement an MPPT protocol on the fluid turbine 404, for example, by manipulating a load configured in the power system 718.For example, increasing the load may slow down the fluid turbine 404 and decreasing the load may increase the rotational speed of the fluid turbine 404. Thus, in some aspects, a single inverter 434 may be configured to implement an MPPT protocol on multiple fluid turbines 404 via multiple charge controllers 410. In some aspects, the inverter 434 and power grid 718 may be replaced with a battery bank 720.

[0071] As another non-limiting example, referring to FIG. 8, another schematic diagram of an exemplary circuit 800 for controlling multiple geographically associated fluid turbines 404 consistent with certain aspects of the present disclosure. The circuit 800 may be substantially similar to the circuit 700 (e.g., with reference to FIGS. 4 and 5), with the notable difference being a common (e.g., shared) charge controller 802 including multiple rectifiers 530 for each of the generators 406. Each of the generators 406 may be connected to the common charge controller 802 via multiple wires (e.g., three wires for each of the three phases of the output AC power signal). Each of the rectifiers 530 may be connected (e.g., via two wires) to a common brake circuit 804 (e.g., including at least a braking sensor). The common brake circuit 804 may be connected to a common voltage booster 806 (e.g., a single voltage booster for all the fluid turbines 404). A charge controller 802 (e.g., common to all fluid turbines 404) may be connected to an inverter 434 to output AC power to the power grid 718. Thus, a common or shared charge controller 802 may connect multiple fluid turbines 404 to a single inverter 434 via multiple rectifiers 530 (e.g., one rectifier per fluid turbine 404). In some aspects, the inverter 434 may be configured to implement an MPPT protocol on each of the fluid turbines 404 via the rectifiers 530. In some aspects, a cable may connect each generator 406 to a single charge controller 410 due to the relatively low power losses of the three-phase AC output. This may be advantageous when the fluid turbines 404 are spread over a large area (e.g., when the distance between any two of the fluid turbines 404 is at least greater than the blade diameter of each fluid turbine and / or when the turbine group includes many fluid turbines). The circuit 800 may lack MPPT control, may include individual MPPT control for each fluid turbine 404, or may include centralized MPPT control for multiple geographically associated fluid turbines 404 operating, for example, as a single fluid energy conversion system.

[0072] As another non-limiting example, refer to FIG. 9, which illustrates a further schematic diagram of an exemplary circuit 900 for controlling a plurality of geographically associated fluid turbines 404 consistent with certain aspects of the present disclosure. The circuit 900 may be substantially similar to the circuit 700 and the circuit 800 (e.g., with reference to FIGS. 4 and 5), with the notable difference being that each of the generators 406 may be connected to a different rectifier 530 (e.g., via three inputs for a three-phase AC signal). Each of the rectifiers 530 may output a DC signal (e.g., via two wires, positive and negative) to a single (e.g., common) charge controller 902 that includes a common brake circuit 804 and a common voltage booster 806 for the multiple fluid turbines 404. The rectifiers 530 may be connected in parallel to the charge controller 902.

[0073] As another non-limiting example, refer to FIG. 10, which illustrates yet another schematic diagram of an exemplary circuit 1000 for controlling a plurality of geographically associated fluid turbines 404 consistent with certain aspects of the present disclosure. The circuit 1000 may be substantially similar to the circuits 700, 800, and 900 (e.g., with reference to FIGS. 4 and 5), with the notable difference being that each generator 406 may be connected to a separate charge controller 410, each charge controller 410 including at least a rectifier 530, a brake circuit 712, an MPPT control 1002, and a voltage booster 714. Each of the charge controllers 410 may transmit a DC power signal (e.g., in parallel) to an inverter 434 for connection to a power grid 718, or alternatively to a battery bank 720.

[0074] As another non-limiting example, refer to FIG. 11, which illustrates a further schematic diagram of an exemplary circuit 1100 for controlling multiple geographically associated fluid turbines 404 consistent with certain aspects of the present disclosure. Circuit 1100 may be substantially similar to circuit 700, circuit 800, circuit 900, and circuit 1000, with the notable difference being that each charge controller 410 may include a rectifier 530, a braking circuit 712, and an MPPT control 1002. Each charge controller 410 may output a DC signal to a common voltage booster 806, which may transmit the aggregated DC power to an inverter and grid, or alternatively to a battery bank 720.

[0075] See exemplary Table 1 (below), which compares circuits 700-1100 for utilizing output from multiple geographically associated fluid turbines.

[0076] Table 1. Comparison of different configurations for utilizing the power from multiple geographically associated fluid turbines. TIFF2025506565000002.tif125150

[0077] Reference is made to FIG. 12, which illustrates an example chart 1200 showing the variation of power output versus rotational speed for a fluid turbine operating at various fluid velocities consistent with certain aspects of the present disclosure. A horizontal axis 1216 (e.g., x-axis) of the chart 1200 corresponds to the rotational speed of the fluid turbine (e.g., measured as RPM). A vertical axis 1218 (e.g., y-axis) of the chart 1200 corresponds to the power output output by the fluid turbine for each rotational speed. The chart 1200 may include multiple curves, each curve representing a different fluid velocity (e.g., v w1 ~v w6 ) Each of the curves in chart 1200 may include peaks (e.g., peaks 1204, 1206, 1208, 1210, 1212, 1214) that indicate rotational speeds at which the fluid turbine may generate a maximum (e.g., or near maximum) level of power output for a corresponding fluid velocity. For example, peak 1204 may correspond to a rotational speed at which the fluid velocity is greater than v w112. The maximum power output of the fluid turbine achievable when the fluid turbine spins at a corresponding rotational speed when the fluid velocity is v w2 may denote the maximum power output of the fluid turbine achievable when the fluid turbine spins at the corresponding rotational speed when

[0078] Line 1202 (e.g., fluid velocity v w1 ~v w6 The chart 1200 may be used to determine a target rotational speed of the fluid turbine for generating a maximum (e.g., or near maximum) power output under each fluid speed. In some aspects, the chart 1200 may be used to implement an MPPT protocol for a particular fluid turbine. In some aspects, at least one processor (e.g., at least one processor 428 and / or 512) may use the chart 1200 to control the load of the fluid turbine via a charge controller (e.g., charge controller 410, 802 and / or 902) to spin the fluid turbine at a rotational speed corresponding to the line 1202 for a particular fluid speed. In some aspects, each fluid turbine in a geographically associated plurality of fluid turbines may be associated with a different version of the chart 1200 (e.g., depending on the design and operating parameters of each fluid turbine). In some aspects, each fluid turbine in a geographically associated plurality of fluid turbines may be associated with a substantially similar version of the chart 1200.

[0079] 13, which illustrates a schematic diagram of an example braking circuit 1300 consistent with certain aspects of the present disclosure. In some aspects, at least a portion of the braking circuit 1300 may be associated with any of the charge controllers 410, 802 and / or 902. In some aspects, at least a portion of the braking circuit 1300 may be associated with the interconnect circuit 414. In some aspects, a portion of the braking circuit 1300 may be associated with any of the charge controllers 410, 802 and / or 902, and another portion of the braking circuit 1300 may be associated with the interconnect circuit 414.

[0080] The braking circuit 1300 may include at least one processor (e.g., at least one processor 512), a memory (e.g., memory 514), a mechanical brake control (e.g., mechanical brake control 520), an electronic brake control (e.g., electronic brake control 518), a rectifier (e.g., rectifier 530), a first voltage sensor 1310, a circuit protection device 1312 (e.g., including at least one of electrostatic discharge, overvoltage, and / or overcurrent protection circuitry), a switch 1314 (e.g., a single-pole double-throw switch), a first DC / DC converter 1316 (e.g., configured to operate above a voltage threshold), a second DC / DC converter 1318 (e.g., configured to operate below a voltage threshold), a second voltage sensor 1320, a capacitor 1322, and a DC output 1324. The rectifier 530 may be a three-phase rectifier configured to generate a variable DC voltage output. In some aspects, the DC power output 1324 may be directed to an inverter (e.g., inverter 434) for conversion to an AC power output signal. In some aspects, the DC output 1324 may be directed to a battery bank.

[0081] The at least one processor 512 may control braking of the fluid turbine 404 connected to the generator 406 based on one or more signals, such as the AC power output 408 (e.g., a three-phase AC power output signal) provided to the braking circuit 1300 and / or a signal received from one or more sensors (e.g., at least one sensor 418). The rectifier 530 may convert the AC power output 408 to a DC power signal. The at least one processor 512 may receive an indication of the AC power output 408 as a DC power output measurement via the first voltage sensor 1310. The fluid turbine 404 and the generator 406 may be associated with a mechanical brake 608. To control mechanical braking of the fluid turbine 404 and / or the generator 406, the at least one processor 512 may send a control signal to a mechanical brake control 520 to engage the mechanical brake 608. To control electronic braking of the fluid turbine 404, the at least one processor 512 may subject the generator 406 to a load via an electronic brake control 518. In some aspects, the power output sensor 510 may be associated with a first voltage sensor 1310 and / or a second voltage sensor 1320.

[0082] As a non-limiting example, the first DC / DC converter 1316 may be configured to operate at 500 watts, receive an input in the range of 18-60 V, output a voltage in the range of 3.3-24 V, switch on at 16.5 V, and operate with an efficiency of less than 98.5%, and the second DC / DC converter 1318 may be configured to operate at 300 watts, receive an input in the range of 9-36 V, output a voltage in the range of 8-24 V, switch on at 9 V, and operate with an efficiency of less than 97%. The switch 1314 may direct a DC signal of 22 V or greater to the first DC / DC converter 1316 and a DC signal of less than 22 V to the second DC / DC converter 1318. In some embodiments, the at least one processor 512 may cause the fluid turbine 404 to comply with an MPPT protocol by matching the electronic load imposed on the generator 406 (e.g., based on a version of the chart 1200 stored in the memory 514) to the rotational speed of the fluid turbine 404 for a given fluid speed to generate a peak (or near-peak) AC power output.

[0083] In some aspects, the at least one processor 512 may be in communication with the at least one processor 428, for example, to transmit information associated with loads imposed on the fluid turbines 404. For example, the information may be used by the at least one processor to implement one or more MPPT protocols (including, for example, an individual or low level MPPT protocol for a single fluid turbine and / or a group or higher level MPPT protocol for multiple geographically associated fluid turbines), to coordinate braking of a group of geographically associated fluid turbines, and / or to coordinate blade orientation of a group of geographically associated fluid turbines.

[0084] For example, Fig. 10 may be considered as a detailed schematic diagram of the integrated fluid energy conversion system 400 in conjunction with Fig. 4 and Fig. 13. A version of the braking circuit 1300 may be associated with each of the MPPT controls 1002 of the charge controllers 410 to enable each of the at least one processor 512 (e.g., each dedicated to one of the individual fluid turbines 404) to coordinate the operation of each (e.g., isolated) fluid turbine 404. Also, the interconnect circuit 414 may be connected to each of the MPPT controls 1002 to enable the at least one processor 428 to receive information from any of the charge controllers 410 (e.g., each dedicated to one of the individual fluid turbines 404) to coordinate the operation of the fluid turbines 404 operating in the group 401 as an integrated fluid energy conversion system 400.

[0085] 14, which illustrates an example graph 1400 of a periodic power signal generator with a generator connected to a fluid turbine consistent with certain aspects of the present disclosure. The graph 1400 may represent a power signal generated by the generator 406 as the fluid turbine 404 rotates in response to the fluid flow 210. In some aspects, the graph 1400 may be a substantially sinusoidal wave corresponding to the rotational motion of the fluid turbine 404, with different phases of rotation corresponding to the generation of different levels of energy.

[0086] In some circumstances, it may be useful to quickly slow down or shut down an entire group of (e.g., geographically associated) fluid turbines. For example, if all fluid turbines in a group are exposed to similar fluid conditions and one turbine in the group is operating outside a safety threshold, the structural integrity of the group may be preserved by slowing or shutting down all the fluid turbines. The safety threshold may also be associated, for example, with wind speeds or strong ocean currents that are likely to also affect other fluid turbines in the group. Centralized braking may also prove useful for other purposes, such as system calibration, synchronization, maintenance, testing, repair, and / or coordination to enable a group of wind-powered fluid turbines to operate as an integrated fluid energy conversion system. Aspects of a centralized braking system for an entire group of fluid turbines are disclosed.

[0087] Some aspects include a system for coordinated braking of multiple geographically associated fluid turbines. A fluid turbine may include a mechanical device configured to capture energy from a fluid flow, as described elsewhere in this disclosure. A geographically associated fluid turbine may refer to multiple fluid turbines positioned relatively close to one another to form a group or fleet of fluid turbines, as described elsewhere in this disclosure. Braking of a fluid turbine may include exerting a force that affects multiple rotating blades of the fluid turbine. This force may slow or stop the rotation of the blades, even under conditions of high fluid flow. In some aspects, braking may be accomplished mechanically, for example, by introducing friction (e.g., via brake pads, drums, or disks) to one or more rotating components of the fluid turbine. In some cases, the mechanical brake may be engaged via a switch, allowing at least one processor to control the mechanical break using one or more electronic signals (e.g., a switch may be turned on to engage the mechanical brake by transmitting a braking signal, and a switch may be turned off to disengage the mechanical brake by ceasing to transmit the braking signal). In some aspects, braking may be accomplished electrically, for example, by transmitting an electrical signal to a rotor of a generator connected to the fluid turbine. The electrical signal may introduce impedance to the rotor, slowing the rotation of the rotor, thereby also slowing down the fluid turbine connected to the rotor. Coordinated braking of multiple geographically associated fluid turbines may refer to controlled or coordinated forces (e.g., electrical and / or mechanical braking forces) exerted on one or more rotating components of each fluid turbine in a group of geographically associated fluid turbines. In some cases, coordinated braking may slow or stop each fluid turbine in the group substantially simultaneously (e.g., substantially in unison) and / or according to a pattern (e.g., a time- and / or position-based pattern). Coordinated braking may enable at least one processor to synchronize the operation of multiple geographically associated fluid turbines.In some aspects, coordinated braking may enable multiple geographically associated fluid turbines to collectively operate as a single fluid energy conversion system.

[0088] As a non-limiting example, and with reference to FIG. 4, a fluid energy conversion system 400 may provide coordinated braking to multiple geographically associated fluid turbines 404 .

[0089] As another non-limiting example, FIG. 13 illustrates that each of the fluid turbines 404 may be associated with a braking circuit 1300 to enable coordinated braking of multiple geographically associated fluid turbines 404 .

[0090] In some aspects, the geographically associated fluid turbine is a wind turbine. The wind turbine may include a horizontal axis turbine (e.g., HAWT) or a vertical axis turbine (e.g., VAWT). The HAWT wind turbine may include at least one blade, typically three equally spaced (e.g., 120° apart) blades. The amount of energy generated by the wind turbine may be proportional to the length of the at least one blade. The VAWT wind turbine may include one or more wide blades configured to receive the wind flow, or one or more elongated blades configured to be aerodynamic. Due to the horizontal shape of the HAWT wind turbine, the HAWT wind turbine with long blades for generating large amounts of energy may be located in remote locations to prevent the blades from interfering with physical structures and / or living things. A group of HAWT wind turbines (e.g., wind farms) may span a large area (e.g., hundreds of square kilometers). The vertical shape of the VAWT wind turbine may allow the VAWT fluid turbine with relatively long blades for generating large amounts of energy to be located in urban areas. Also, VAWT fluid turbines may be clustered (e.g., grouped) closer together than HAWT turbines, making it easier to interconnect geographically associated groups of wind turbines via interconnection circuits.

[0091] In some aspects, the geographically associated fluid turbine is a hydro turbine. The hydro turbine may include a reaction turbine or an impulse turbine. A reaction hydro turbine may extract energy from the flow of water passing through it such that the water pressure leaving the reaction hydro turbine is lower than the water pressure entering. An impulse hydro turbine may change the direction of the water flow. This change may induce an impulse that may cause the blades of the impulse hydro turbine to pivot.

[0092] 4 illustrates a plurality of geographically associated turbines 404 (e.g., including at least fluid turbines 404A, 404B) connected to at least one processor 428 via interconnect circuitry 310. The fluid turbines 404 may include one or more water turbines, gas turbines, and / or steam turbines (e.g., fluid turbine 104 of FIG. 1), and / or one or more wind turbines (e.g., fluid turbines 100, 102, 106-112 of FIG. 1).

[0093] Some embodiments include at least one processor (e.g., for performing operations to coordinate braking of the geographically associated fluid turbines), which may include a single processor or multiple processors communicatively linked to one another for controlling operation of the geographically associated fluid turbines to collectively operate as a single fluid energy conversion system, for example, as described elsewhere in this disclosure.

[0094] As a non-limiting example, in FIG. 4, at least one processor 428 may be coupled to multiple geographically associated fluid turbines 404A, 404B to, for example, perform operations to coordinate braking.

[0095] Some aspects include accessing a memory that stores information indicative of a tolerance threshold of at least one operating parameter associated with the geographically associated multiple fluid turbines. A memory may refer to at least one non-transitory computer-readable storage medium, as described elsewhere in this disclosure. Accessing a memory may include receiving and / or transmitting data to and from the at least one memory to perform one or more operations (e.g., read, write, modify, add, delete, and / or any other memory access operation). The operating parameters associated with the geographically associated multiple fluid turbines may include variables or settings that affect the performance and / or operation of the geographically associated multiple fluid turbines. Examples of operating parameters for a fluid turbine may include fluid flow velocity, rotor speed, blade tip speed, blade pitch, blade yaw, blade sway, blade vibration, shaft sway, shaft vibration, power output, generator temperature, and / or any other parameter that affects the operation of the fluid turbine. The operating parameters may be monitored and controlled by a control system (e.g., implemented via a circuit) for the geographically associated multiple fluid turbines to ensure proper performance and efficiency. A tolerance threshold may refer to a limit or boundary imposed on one or more parameters affecting the operation of a system (e.g., operational parameters) to cause the system to operate in accordance with (e.g., comply with) one or more standards or regulations. The standards or regulations may relate to one or more concerns, such as safety, efficiency, maintenance regulations, durability, damage control, and / or any other concern for operating a system of fluid turbines. Thus, a tolerance threshold may be associated with one or more of a safety threshold, an operational threshold, an efficiency threshold, a durability threshold, a performance threshold, a compatibility threshold (e.g., for outputting power to a power grid), an energy production threshold, a maintenance threshold, and / or any other type of threshold of a fluid turbine.Controlling the one or more fluid turbines to operate within tolerance thresholds may facilitate proper, safe, and / or efficient operation of the one or more fluid turbines, whereas operating the one or more fluid turbines outside of the tolerance thresholds may pose a risk of damage, harm, or injury. The information indicative of tolerance thresholds of operating parameters associated with the geographically associated multiple fluid turbines may include data encoding tolerance thresholds of one or more operating parameters for the fluid turbines and / or information that may be used to determine tolerance thresholds of one or more operating parameters for the fluid turbines. At least one processor may access the information indicative of tolerance thresholds of the geographically associated multiple fluid turbines for use in monitoring, controlling, and / or adjusting the one or more operating parameters for the geographically associated multiple fluid turbines.

[0096] 4, the at least one processor 428 may access a memory 430 that stores information indicative of tolerance thresholds of one or more operating parameters associated with the fluid turbines 404A, 404B. For example, the tolerance thresholds may be associated with one or more of the rotational speed of the fluid turbines 404A, 404B, the fluid speed affecting the fluid turbines 404A, 404B, the vibration of the fluid turbines 404A, 404B, the temperature of the fluid turbines 404A, 404B, and / or the power output of the fluid turbines 404A, 404B. In some cases, the tolerance thresholds may be associated with information received by the at least one processor 428 from one or more of the at least one sensor 418 configured with the charge controllers 410A, 410B.

[0097] Some aspects include receiving information indicative of at least one operating parameter for a particular fluid turbine of the geographically associated plurality of fluid turbines from at least one sensor. A sensor may refer to a device that may output a signal in response to detecting, sensing, or measuring a physical phenomenon, as described elsewhere in this disclosure. In some aspects, the at least one sensor may include one or more of a mechanical sensor, an optical sensor, a resistive sensor, a capacitive sensor, a temperature sensor, a piezoelectric sensor, a Hall sensor, a thermocouple sensor, a photoelectric sensor, a digital position sensor, a current sensor, a voltage sensor, a photoelectric encoder, a pressure sensor, a fluid level (e.g., liquid level) sensor, a temperature sensor, a flow sensor, and / or any other type of sensor that may be used to detect position, linear displacement, pressure, temperature, flow rate, vibration, rotational speed, current, voltage, power, and / or any other parameter associated with the operation of the fluid turbine. The at least one sensor indicative of an operating parameter for the particular fluid turbine may include one or more sensors connected to the particular turbine, one or more sensors connected to a device connected to the particular turbine, and / or one or more sensors located proximate to the particular turbine (e.g., an anemometer located adjacent to but mechanically decoupled from the particular fluid turbine, such as an anemometer located adjacent to the particular fluid turbine). The at least one sensor may be connected to a moving component (e.g., a blade, a rotatable shaft, and / or a rotor connected to the particular fluid turbine) and / or a stationary component associated with the particular fluid turbine (e.g., a stator, an electrical output, an electrical input, and / or a generator housing associated with the particular fluid turbine).For example, the at least one sensor may include one or more of: a sensor configured with the blades (e.g., blade tips) and / or shaft of the particular turbine, one or more sensors configured with a rotor connected to the particular turbine, one or more sensors connected to a power output of the particular fluid turbine, one or more sensors connected to an electrical input (e.g., to control an operating aspect of the particular fluid turbine), one or more sensors for measuring environmental factors affecting the operation of the particular fluid turbine, and / or one or more sensors associated with any other operating aspect of the particular fluid turbine.

[0098] Receiving information from the sensor may include periodically polling the sensor for an output signal and / or receiving a signal from the sensor as an asynchronous event, such as a synchronous event and / or a real-time interrupt event. The at least one processor may receive information from the sensor locally or remotely via a wired and / or wireless communication link and store the received information in memory (e.g., for immediate and / or subsequent access). For example, the at least one processor may receive information from a sensor configured with a remote weather monitor (e.g., a weather balloon or a weather satellite). The information indicative of at least one operating parameter for a particular fluid turbine may include data measured by one or more sensors associated with the particular fluid turbine and indicative of variables or settings affecting the performance and / or operation of the particular fluid turbine. The information may include a single measurement taken at a particular time, or multiple measurements taken over a period of time. In some aspects, the information may include an average value of multiple measurements taken over a period of time (e.g., over 10 second intervals, or over 30 second intervals) and / or a trend over a period of time. The information may be indicative of a particular operating parameter (e.g., fluid velocity) or multiple operating parameters (e.g., fluid velocity, blade tip rotational speed, and rotor rotational speed). The information may be based on a single measurement (e.g., by a single sensor) or may be based on multiple measurements (e.g., by a single sensor over a period of time, by multiple sensors each taking a single measurement, or by multiple sensors taking multiple measurements over a period of time).

[0099] In some embodiments, the at least one sensor includes a rotational sensor, and the at least one operating parameter corresponds to a rotational speed of a particular fluid turbine. The rotational speed may correspond to the number of revolutions that the blades and / or shaft of the fluid turbine complete per minute (e.g., revolutions per minute, or RPM) or the number of cycles completed per second. The rotational sensor may include one or more of a tachometer (e.g., configured to measure the rotational speed of the fluid turbine shaft), a magnetoresistive sensor, an inductive sensor, a Hall effect sensor (e.g., configured to detect the presence of a magnetic field using the Hall effect to determine the number of revolutions of the fluid turbine shaft), a vibration sensor, an optical sensor (e.g., an encoder and / or an infrared sensor configured to measure the rotational speed of the turbine shaft by counting the number of revolutions or by measuring the duration between revolutions), an ultrasonic sensor (e.g., configured to emit ultrasonic waves to measure the distance between the sensor and the blades of the fluid turbine to determine the rotational speed of the blades). The rotational speed tolerance threshold may limit the rotational speed of the fluid turbine to prevent blade erosion and / or stresses on the blades and shaft of the fluid turbine that could cause instability and failure, and to ensure proper, effective, and / or safe operation.

[0100] In some embodiments, the at least one sensor includes a fluid velocity detector, and the at least one operating parameter corresponds to a fluid velocity affecting a particular fluid turbine. Fluid velocity may refer to the movement or continuous deformation of a fluid (e.g., wind, water, steam, and / or gas) under an applied force over a given unit of time (e.g., measured as kilometers per hour or meters per second). Fluid velocity may correspond to the kinetic energy of particles or molecules of the fluid. The fluid velocity sensor may include anemometers (e.g., van anemometers, thermal anemometers, and / or cup anemometers), ultrasonic fluid velocity sensors, and / or draw wire displacement sensors, and / or any other device configured to measure fluid velocity and / or fluid direction. Fluid velocity affecting a particular fluid turbine may refer to the amount of kinetic energy transferred from the fluid flow to the blades of the fluid turbine, causing the blades to rotate. The orientation of the blades relative to the direction of the fluid flow (e.g., the angle of incidence between the blades and the fluid flow), the shape of the blades, and / or the weight of the blades (e.g., inertia) may affect the amount of kinetic energy transferred from the fluid flow to the blades, thereby affecting the rotational speed of the fluid turbine. The fluid speed (e.g., along with the fluid flow direction) may be used to predict the rotational speed of the fluid turbine and may be used as an indication of when a particular fluid turbine is operating within a rotational speed tolerance threshold. The fluid speed tolerance threshold may limit operation of the fluid turbine within fluid speeds considered safe and / or productive to ensure proper, effective, and / or safe operation of the fluid turbine.

[0101] In some aspects, the at least one sensor includes a vibration sensor, and the at least one operating parameter corresponds to vibration of the particular fluid turbine. The vibration of the fluid turbine may include interactions between mechanical components of the fluid turbine (e.g., the rotor, stator, and / or rotating bearings of the generator, one or more blades, shaft, damping mechanism, tuning mechanism) and the fluid flow, causing vibrations (e.g., regular or random) that may destabilize and damage the fluid turbine. The vibration sensor may include an eddy current sensor, an accelerometer, a displacement sensor (e.g., a laser displacement sensor, and / or a capacitive displacement sensor). The vibration tolerance threshold may limit the amount of vibration or oscillation that may be tolerated when operating the fluid turbine to ensure proper, effective, and / or safe operation.

[0102] In some embodiments, the at least one sensor includes a temperature sensor, and the at least one operating parameter corresponds to a temperature of the particular fluid turbine. The temperature may be indicative of an amount of heat generated by the fluid turbine. The temperature sensor may include a thermometer and / or a thermostat (e.g., configured to activate a switch when a threshold temperature is reached). The temperature tolerance threshold may limit the amount of heat that may be generated from the fluid turbine to prevent overheating. For example, the temperature of the generator (e.g., the copper wiring and / or bearings of the generator) may be indicative of the amount of power generated by the generator. If the generator generates a power level that exceeds a safety threshold, the generator may overheat. Monitoring the temperature of the generator may indicate whether the fluid turbine is operating within the tolerance threshold. Controlling the fluid turbine to operate within the temperature tolerance threshold may prevent overheating, damage to electronic circuitry, and / or fire, and may ensure that the fluid turbine is operating properly, effectively, and safely.

[0103] In some embodiments, the at least one sensor includes a power output sensor, and the at least one operating parameter corresponds to a power output of the particular fluid turbine. The power output may refer to an amount of AC power generated by a generator connected to the fluid turbine, and / or an amount of DC power output by a rectifier connected to the AC power output of the generator. The power output of the fluid turbine may indicate a rotational speed of the fluid turbine. For example, the frequency of the AC power output may correspond to a rotational speed of a rotor connected to the blades of the fluid turbine, thereby allowing the rotational speed of the blades to be determined. As another example, the power output (e.g., the amplitude of the AC and / or DC power output) may allow the amount of electrical energy generated by the fluid turbine to be determined, which may allow the amount of kinetic energy included in the rotation of the fluid turbine to be determined. The power output sensor may include a voltmeter and / or ammeter connected to an output of a generator connected to the fluid turbine. The power output tolerance threshold may limit the amount of electrical power that may be generated by the fluid turbine. Controlling the fluid turbine to operate within power output tolerance thresholds may prevent the fluid turbine from exceeding rotational and / or temperature tolerance thresholds to ensure that the fluid turbine is operating properly, effectively, and safely.

[0104] In some aspects, the at least one sensor includes an image sensor, and the at least one operating parameter corresponds to image data of the particular fluid turbine acquired by the image sensor. For example, the at least one processor may analyze the image data to determine an RPM speed of the particular fluid turbine.

[0105] 4, the at least one processor 428 may receive information indicative of an operating parameter for the fluid turbine 404A (e.g., of the geographically associated plurality of fluid turbines 404A, 404B) from at least one sensor associated with the charge controller 410A (e.g., at least one sensor 418 in FIG. 5). For example, the at least one processor 428 may receive one or more indications of the rotational speed of the fluid turbine 404A and / or the generator 406A from the rotational sensor 502, the fluid velocity from the fluid velocity sensor 504, the vibration of the fluid turbine 404A and / or the generator 406A from the vibration sensor 506, the temperature of the generator 406A from the temperature sensor 508, and / or the power output (e.g., AC and / or DC power) of the generator 406A from the power output sensor 510. In some aspects, the at least one processor 428 may receive image data from the image sensor 524. As another non-limiting example, in FIGS. 7-11, at least one processor (e.g., at least one processor 428) may receive information from a brake sensor (e.g., a voltage sensor) configured with the brake circuit 712.

[0106] As another non-limiting example, in FIG. 13 , the at least one processor 512 and / or the at least one processor 428 may receive voltage data (e.g., corresponding to the power output of the generator 406) from a first voltage sensor 1310 and / or a second voltage sensor 1320.

[0107] Some embodiments include comparing information indicative of at least one operating parameter for a particular fluid turbine to a tolerance threshold stored in memory. The comparing may include examining and / or evaluating similarities and differences between two or more values, such as between two or more measurements and / or between one or more measurements and a predetermined value used as a control. In some embodiments, the at least one processor may perform a direct comparison between the information received from the at least one sensor and the tolerance threshold. In some embodiments, the at least one processor may process the information received from the at least one sensor (e.g., to calculate an aggregate value, a trend or trend-based prediction, and / or a statistical attribute) and compare an output of the processing of the information to the tolerance threshold (e.g., to perform an indirect comparison between the information received from the at least one sensor and the tolerance threshold). For example, the information received from the at least one sensor may include multiple measurements (e.g., as described above), and the at least one processor may calculate an aggregate value (e.g., an overall risk level) from the information to compare to a single value tolerance threshold (e.g., an overall risk threshold). For example, the at least one processor may calculate statistical attributes (e.g., mean, median, mode, standard deviation, and / or variance), maximum or minimum values, patterns or trends (e.g., based on principal component analysis), a compressed form of the multiple data values ​​(e.g., based on t-Distributed Stochastic Neighbor Embedding, or t-SNE), and / or any other attributes of the information received from the at least one sensor. As another example, the at least one processor may receive multiple signals from different sensors, such as a fluid velocity measurement from a first sensor, a blade tip rotational speed measurement from a second sensor, and a rotor rotational speed from a third sensor. The at least one processor may calculate an average value (e.g., a weighted average value) based on the blade tip rotational speed, fluid velocity, and / or rotor rotational speed to calculate an aggregate speed for comparison to a threshold tolerance of the rotational speed.

[0108] As a non-limiting example, in FIG. 4, the at least one processor 428 may compare information indicative of at least one operating parameter for the fluid turbine 404A to a tolerance threshold stored in memory 430 .

[0109] Some aspects include determining whether at least one operating parameter for the particular fluid turbine deviates from a tolerance threshold based on the comparison. Deviating may include deviating from, not conforming to, or violating (e.g., a rule or recommended standard). Determining may refer to measuring, comparing, estimating, or calculating to arrive at a final result. Determining whether at least one operating parameter for the particular fluid turbine deviates from a tolerance threshold based on the comparison may include identifying whether at least one operating parameter measured for the particular fluid turbine deviates from or does not conform to a tolerance threshold (e.g., by exceeding, falling below, or deviating from a tolerance threshold). For example, a deviation from a tolerance threshold may indicate a violation of one or more rules and / or recommended standards. In some aspects, the determination of a deviation from a tolerance threshold may be based on a single comparison (e.g., a single operating parameter). In some aspects, the determination of a deviation from a tolerance threshold may be based on multiple comparisons (e.g., of multiple operating parameters, of the same operating parameter over time, or of multiple operating parameters over time). In some aspects, the at least one processor may assign weights to multiple indicators of different operating parameters and calculate an aggregate deviation from a tolerance threshold based on the multiple operating parameters. In some aspects, the deviation from a tolerance threshold may be determined over a period of time (e.g., at least 10 seconds, or at least 30 seconds). For example, the at least one processor may refrain from determining a deviation from a tolerance threshold if the deviation continues for a short duration (e.g., less than 1 second, less than 10 seconds, less than 30 seconds, or less than any other time frame) and / or may require the deviation to continue for a certain duration (e.g., 1 minute).

[0110] As a non-limiting example, in FIG. 4 , the at least one processor 428 may determine, based on the comparison, whether at least one operating parameter received from the at least one sensor 418 of the charge controller 410A of the fluid turbine 404A deviates from a tolerance threshold.

[0111] Some aspects include transmitting a braking signal to each of the geographically associated fluid turbines to slow down each of the geographically associated fluid turbines upon determining that at least one operating parameter for the particular fluid turbine deviates from a tolerance threshold. Slowing down the fluid turbine may include reducing the rotational speed of one or more rotating components of the fluid turbine (e.g., one or more blades, a shaft, a yaw mechanism, a rotor, and / or any other rotating components connected to the fluid turbine). Transmitting the braking signal to the fluid turbine may include transmitting an electronic notification to one or more controls configured to activate or engage one or more braking systems configured to slow down the fluid turbine. In some aspects, a braking mechanism for the fluid turbine may only be engaged while a switch is in an "on" state and requires power to continuously engage the braking mechanism (e.g., over a period of time). In some embodiments, the at least one processor may transmit a braking signal to the fluid turbine in response to receiving a signal indicating that the rotational speed of the fluid turbine has exceeded a safety threshold, that a maintenance or repair procedure has been scheduled, that a synchronization procedure has been scheduled, that the fluid speed has exceeded a safety threshold, that the power grid has reached capacity, and / or any other criteria for braking the fluid turbine.

[0112] In some aspects, a braking system for a fluid turbine may include an electronic braking mechanism. The electronic braking mechanism for a fluid turbine may include a device for emitting an electronic signal configured to introduce a load or electrical impedance to slow down the rotation of the fluid turbine and / or cause a short or shunt of a rotor connected to the fluid turbine. For example, the at least one processor may determine the braking signal based on an amount of load or impedance (e.g., controlled resistance) required to cause a corresponding amount of slowing of the rotation of the fluid turbine (e.g., based on the measured rotational speed, angular momentum, and / or moment of inertia of the fluid turbine), e.g., limiting the RPM of the fluid turbine. The at least one processor may transmit an impedance hold signal to a rotor connected to the fluid turbine. The impedance hold signal may cause a portion of the kinetic energy of the rotating fluid turbine to be converted to heat via one or more resistors included in a circuit associated with the rotor and the fluid turbine. Loss of the kinetic energy as heat may cause a slowing of the rotor and the fluid turbine connected thereto. In some aspects, the energy lost by the impedance hold signal may be utilized to power other electronic components and / or stored for later use. In some aspects, heat generated by electronic braking may be monitored by a temperature sensor and transmitted to at least one processor.

[0113] In some aspects, the braking system includes one or more mechanical braking mechanisms. Examples of some mechanical braking mechanisms for a fluid turbine may include brake pads, disc brakes, pins, and / or any other mechanical components configured to slow or stop rotation of the fluid turbine in response to receiving a braking signal (e.g., via an actuation switch). The mechanical braking mechanisms for the fluid turbine may be associated with a rotor connected to the fluid turbine, a yaw system of the fluid turbine, a shaft (e.g., a rotatable shaft) of the fluid turbine, one or more blades of the fluid turbine, and / or any other rotating components connected to the fluid turbine. For example, the at least one processor may transmit a braking signal (e.g., an "on" signal) to one or more actuation switches configured to actuate the one or more mechanical braking mechanisms for the fluid turbine. In some aspects, the braking system may be a combination of an electronic braking system and one or more mechanical braking mechanisms.

[0114] Transmitting a braking signal to each of the geographically associated fluid turbines may include transmitting a plurality of braking signals, each braking signal targeted to a different braking mechanism configured with a different geographically associated fluid turbine. For example, the at least one processor may transmit one or more braking signals via the interconnect circuitry to each braking mechanism of each of the geographically associated fluid turbines. In some aspects, each of the geographically associated fluid turbines may receive the braking signal substantially simultaneously. In some aspects, at least some of the geographically associated fluid turbines may rotate at different rotational speeds, and the at least one processor may transmit a common braking signal to each of the geographically associated fluid turbines to slow down at least some of the geographically associated fluid turbines more than others. In some aspects, the at least one processor may transmit a braking signal that slows down each of the geographically associated fluid turbines by the same amount. In some aspects, the at least one processor may transmit a braking signal to slow down the rotation of each of the geographically associated fluid turbines such that each of the geographically associated fluid turbines reach substantially the same rotational speed. In some aspects, the at least one processor may transmit a braking signal to each of the geographically associated fluid turbines in response to determining that the rotational speed of just one of the geographically associated fluid turbines exceeds a tolerance threshold.

[0115] 4, upon determining that at least one operating parameter for the fluid turbine 404A deviates from a tolerance threshold, the at least one processor 428 may transmit a brake signal to each of the geographically associated fluid turbines 404A, 404B to slow down each of the geographically associated fluid turbines 404A, 404B. For example, the at least one processor 428 may transmit a DC signal to an electronic brake control 518 (see FIG. 5) of each of the charge controllers 410A, 410B, which may convert the DC signal to an AC signal and transmit the AC signal to the rotors of the generators 406A, 406B, respectively. The AC signal may impose a load on the rotors of the generators 406A, 406B to slow down the rotation of the rotors, thereby slowing down the rotation of the fluid turbines 404A, 404B (e.g., connected thereto). As another example, the at least one processor 428 may send an electronic signal (e.g., a digital signal) to the mechanical brake control 520 to actuate a switch to engage at least one mechanical brake 608 (e.g., see FIG. 6 ) configured with each of the fluid turbines 404A, 404B and / or the generators 406A, 406B to cause deceleration of the fluid turbines 404A, 404B. As another non-limiting example, in FIG. 13 , the at least one processor 428 may communicate with each processor 512 of each braking circuit 1300 (e.g., each associated with a different one of the fluid turbines 404) to send a braking signal to the mechanical brake control 520 and / or the electronic brake control 518 to decelerate each of the fluid turbines 404.

[0116] As another non-limiting example, in Figures 7-11, at least one processor (e.g., configured with the inverter and / or MPPT control 1002) may send a braking signal to each of the charge controller 410, the common charge controller 802, and / or the common charge controller 902 to slow down each of the geographically associated fluid turbines 404.

[0117] In some aspects, the deceleration of each of the geographically associated fluid turbines includes stopping each geographically associated fluid turbine. Stopping the fluid turbine may include stopping or ceasing rotation of one or more rotating components of the fluid turbine (e.g., one or more blades, a shaft, a yaw mechanism, a rotor, and / or any other rotating components connected to the fluid turbine), such that, for example, an angular velocity of the fluid turbine is substantially zero. For example, the at least one processor may transmit a stop signal to flip a switch to activate a stop mechanism of one or more of the rotating components of the fluid turbine to ceasing rotation of the fluid turbine. The stop mechanism for the fluid turbine may include one or more of a brake pad, a drum brake, a disk brake, a spring-loaded brake, and / or a hydraulic brake, and may act to stop rotation of one or more of the rotor, the shaft, the yaw mechanism, and / or any other rotating components of the fluid turbine. In some aspects, the stop mechanism for the fluid turbine may be activated only while a switch is in an "on" state and requires power to engage the stop mechanism. In some embodiments, the at least one processor may transmit a stop signal to a shut-down mechanism of the fluid turbine in response to receiving a signal indicating that the rotational speed of the fluid turbine has slowed below a threshold, that a maintenance or repair procedure has been scheduled, that a synchronization procedure has been scheduled, that the power grid has reached capacity, that the fluid speed has exceeded a safety threshold, and / or any other criteria for shutting down the fluid turbine.

[0118] Shutting down each of the geographically associated fluid turbines may include transmitting a plurality of shut down signals, each shut down signal targeted to a different shut down mechanism configured with a different geographically associated fluid turbine. For example, the at least one processor may transmit one or more shut down signals via an interconnect circuit to each shut down mechanism of each of the geographically associated fluid turbines. In some aspects, each of the geographically associated fluid turbines may receive the shut down signals substantially simultaneously. In some aspects, at least some of the geographically associated fluid turbines may rotate at different rotational speeds, and the at least one processor may transmit a common shut down signal to each of the geographically associated fluid turbines to shut down each of the geographically associated fluid turbines. In some aspects, the at least one processor may transmit a brake signal to each of the geographically associated fluid turbines in response to receiving an indication (e.g., from the at least one sensor) to shut down only one of the geographically associated fluid turbines. For example, the indication may indicate a fluid speed exceeding a safety threshold affecting only one of the geographically associated fluid turbines, and the at least one processor may determine to shut down all of the geographically associated fluid turbines.

[0119] 4, the at least one processor 428 may transmit a signal to the charge controllers 410A, 410B configured to stop each of the fluid turbines 404A, 404B. For example, the signal may actuate the mechanical brake control 520 to engage at least one brake 608 (e.g., see FIG. 6) configured with each of the fluid turbines 404A, 404B and / or generators 406A, 406B. For example, the mechanical brake control 520 may engage the mechanical brake 608 after the fluid turbines 404A, 404B have decelerated to a threshold speed by electronic braking (e.g., via either the electronic brake control 518 and / or the charge controllers 410, 802 and / or 902). As another non-limiting example, in FIG. 13 , at least one processor 428 may communicate with each processor 512 of each braking circuit 1300 (e.g., each associated with a different one of the fluid turbines 404) to send a stop signal to the mechanical brake control 520 to stop the spinning of each of the fluid turbines 404.

[0120] Some aspects include locking each geographically associated fluid turbine at a standstill. Locking the fluid turbine at a standstill may include transmitting a locking signal configured to engage a locking mechanism to maintain the fluid turbine at a standstill (e.g., substantially not rotating) after stopping the fluid turbine. The locking mechanism for the fluid turbine may operate on a rotor, a shaft, a yaw mechanism, and / or any or rotating components of the fluid turbine and / or generator. Examples of locking mechanisms may include pins (e.g., spring-loaded pins), rods, bolts, and / or clamps. For example, the at least one processor may transmit the locking signal to flip a switch to engage a locking mechanism of one or more of the rotating components of the fluid turbine. In some aspects, the at least one processor may transmit the locking signal to the fluid turbine in response to receiving a signal (e.g., from a clock) indicating that the fluid turbine is at a standstill, that a maintenance or repair procedure is scheduled, that a synchronization procedure is scheduled, that a fluid speed has exceeded a safety threshold, that the power grid has reached capacity, and / or any other criteria for locking the fluid turbine. In some aspects, a locking mechanism for a fluid turbine may only be engaged while the switch is in an "on" state and requires power to engage the locking mechanism.

[0121] Locking each geographically associated fluid turbine at rest may include transmitting a plurality of lock signals, each lock signal targeted to a different lock mechanism configured with a different geographically associated fluid turbine. For example, the at least one processor may transmit one or more lock signals via the interconnect circuitry to each lock mechanism of each geographically associated fluid turbine. In some aspects, each of the geographically associated fluid turbines may receive the lock signals substantially simultaneously. In some aspects, the at least one processor may transmit the lock signal to each of the geographically associated fluid turbines in response to receiving an indication to lock only one of the geographically associated fluid turbines.

[0122] As a non-limiting example, in FIG. 4, the at least one processor 428 may transmit a signal to the charge controller 410A, 410B to lock the fluid turbine 404A, 404B. For example, the mechanical brake control 520 of the charge controller 410A, 410B may include one or more switches for actuating a lock 612 (see, e.g., FIG. 6) configured with the fluid turbine 404A, 404B and / or the generator 406A, 406B. For example, the lock may be an electronic control pin configured to engage an orifice in the fluid turbine 404A, 404B and / or the generator 406A, 406B to prevent rotational motion. The at least one processor 428 may transmit a lock signal to the mechanical brake control 520, thereby engaging the lock 612. As another non-limiting example, in FIG. 13 , at least one processor 428 may communicate with each processor 512 of each braking circuit 1300 (e.g., each associated with a different one of the fluid turbines 404) to transmit a lock signal to each mechanical brake control 520 to engage and lock each lock 612 of each fluid turbine 404 in a stopped state.

[0123] Some aspects include receiving an unlock signal from a local or remote location and unlocking each of the geographically associated fluid turbines in response to the unlock signal. The unlock signal may include an electronic signal indicating to unlock the fluid turbine due to, for example, a condition for the fluid turbine to lock out. For example, the unlock signal may indicate that a scheduled maintenance or repair procedure has been completed, that the fluid speed has returned to a level within a safety threshold, and / or that the power grid has the capacity to receive power. In some aspects, the unlock signal may be received after the geographically associated multiple fluid turbines have been in a locked state for a duration, for example, as part of a synchronization protocol for the geographically associated fluid turbines. The local location may refer to a proximate location that requires a short-range and / or near-field communication network (e.g., wire, fiber, bus, Wi-Fi, IR, and / or Bluetooth) to transmit and receive signals between the at least one processor and the remote location. In some aspects, the local location may include one or more locations proximate to one or more of the geographically associated multiple fluid turbines. In some aspects, the local location may include any location proximate to one or more of the geographically associated multiple fluid turbines. Receiving the unlocking signal from the local location may include receiving the unlocking signal over a short-range and / or short-range communication network. A remote location may refer to a remote location that requires a long-range communication network (e.g., long cable, fiber, wide area network, AM or FM radio, satellite communication link, and / or Internet) to transmit and receive signals between the at least one processor and the remote location. In some aspects, the remote location may include one or more locations in proximity to one or more of the geographically associated multiple fluid turbines, for example, when the geographically associated multiple fluid turbines cover a large area. In some aspects, the remote location may be associated with a weather balloon and / or a weather satellite. Receiving the unlocking signal from the remote location may include receiving the unlocking signal over a communication network.For example, the at least one processor may receive the unlocking signal from one or more sensors and / or processors (e.g., charge controllers) configured with each of the plurality of geographically associated fluid turbines. Additionally or alternatively, the at least one processor may receive the unlocking signal from one or more sensors and / or processors located remotely, such as from a weather server, a weather satellite, a maintenance server, a server associated with a power grid, and / or any other remote location.

[0124] Unlocking the fluid turbines may include disengaging locking mechanisms of the fluid turbines. For example, the at least one processor may transmit a signal to return a switch to engage one or more locking mechanisms of the rotating components of the fluid turbines. Unlocking each of the geographically associated fluid turbines in response to the unlocking signal may include transmitting a plurality of signals to each locking mechanism of each of the geographically associated fluid turbines to disengage the respective locking mechanisms, and / or ceasing transmission of one or more locking signals currently engaging the respective locking mechanisms, thereby disengaging the respective locking mechanisms.

[0125] Some embodiments include that following the locking, the at least one processor is configured to receive a fluid speed signal and unlock each geographically associated fluid turbine when the fluid speed signal corresponds to a fluid speed within a tolerance threshold. The fluid speed signal may include a weather forecast (e.g., from a weather server), anemometer readings or ocean or river current signals (e.g., configured with a charge controller associated with one or more of the geographically associated fluid turbines), and / or any other electronic indication of fluid speed. A fluid speed within a tolerance threshold may refer to a fluid speed below an upper fluid speed threshold (e.g., a safety threshold, an operational threshold, a durability threshold, an efficiency threshold, and / or a compatibility threshold) and / or above a lower fluid speed threshold (e.g., a minimum power generation threshold, an efficiency threshold, and / or a compatibility threshold). For example, operating the geographically associated multiple fluid turbines at a fluid speed below the tolerance threshold may be inefficient, ineffective, and / or unprofitable. When the fluid speed exceeds a lower fluid speed threshold, it may be beneficial to unlock the geographically associated multiple fluid turbines and resume power generation.

[0126] As a non-limiting example, in FIG. 4 , the at least one processor 428 may receive an unlock signal (e.g., a local signal) from the at least one sensor 418 to unlock the fluid turbines 404A, 404B. For example, the unlock signal may be a vibration measurement received from the vibration sensor 506 indicating that the vibrations experienced by the fluid turbines 404A, 404B are within a tolerance threshold and that conversion of fluid flow energy to electrical energy may resume. In response to the unlock signal, the at least one processor 428 may stop transmitting a lock signal to the mechanical brake control 520, disengaging the locks 612 of the fluid turbines 404A, 404B. As another non-limiting example, in FIG. 13 , the at least one processor 428 may communicate with each processor 512 of each braking circuit 1300 (e.g., each associated with a different one of the fluid turbines 404) to stop transmitting a lock signal to the mechanical brake control 520, thereby disengaging the respective locks 612 of each of the fluid turbines 404.

[0127] Some embodiments include, following the deceleration, at least one processor is configured to receive a fluid velocity signal and release braking of each geographically associated fluid turbine when the fluid velocity signal corresponds to a fluid velocity within a tolerance threshold. Release braking of the fluid turbine may refer to disengaging a braking mechanism configured with the fluid turbine. For example, a mechanical brake may be released by ceasing transmission of a signal, thereby releasing a switch that engages the mechanical brake, causing the brake pads, disks, or drums to decouple from the fluid turbine. An electronic brake may be released by ceasing transmission of a load bearing signal that introduces an impedance to a rotor connected to the fluid turbine, thereby removing the load and allowing the turbine to spin more freely. When the fluid velocity signal corresponds to a fluid velocity within a tolerance threshold, it may refer to a fluid velocity below the fluid velocity tolerance threshold.

[0128] 4, the at least one processor 428 may receive a fluid velocity signal from the fluid velocity sensor 504 indicating that the current fluid velocity is within a tolerance threshold of the fluid turbines 404A, 404B and thus conversion of fluid flow energy to electrical energy may resume. In response to the fluid velocity signal, the at least one processor 428 may stop transmitting braking signals to the electronic brake control 518 and / or the mechanical brake control 520 and cause the at least one brake 608 of the fluid turbines 404A, 404B and / or the generators 406A, 406B to disengage. As another non-limiting example, in FIG. 13, the at least one processor 428 may communicate with each processor 512 of each braking circuit 1300 (e.g., each associated with a different one of the fluid turbines 404) to stop transmitting braking signals to the respective electronic brake controls 518.

[0129] In some aspects, the braking signal is configured to synchronize each fluid turbine in the geographically associated plurality of fluid turbines. Synchronizing may include, for example, coordinating or adjusting the operation of the geographically associated plurality of fluid turbines in a coordinated manner. Slowing, stopping, and / or restarting each geographically associated fluid turbine substantially simultaneously may enable the geographically associated plurality of fluid turbines to be coordinated to operate as a single fluid energy conversion system. For example, the at least one processor may synchronize the geographically associated plurality of fluid turbines to ensure that a combined power output from the geographically associated plurality of fluid turbines meets a particular criterion (e.g., minimum or maximum thresholds to meet grid compatibility, safety, efficiency, and / or profitability criteria). As another example, the at least one processor may synchronize the geographically associated plurality of fluid turbines to enable testing and / or maintenance of the geographically associated plurality of fluid turbines to be performed.

[0130] In some aspects, the synchronization enables application of a maximum power point tracking (MPPT) protocol to the geographically associated fluid turbines upon release of braking. Release of braking may include ceasing transmission of a braking signal configured to slow and / or stop the fluid turbines. For example, after stopping or slowing down (e.g., to a substantially common rotational speed) the geographically associated fluid turbines, the at least one processor may release the braking and enable each geographically associated fluid turbine to resume energy conversion from the fluid flow to electrical energy. The MPPT protocol may be understood as described elsewhere in this disclosure. Application of the MPPT protocol to the geographically associated fluid turbines may include the at least one processor transmitting a plurality of signals to the geographically associated fluid turbines, the plurality of signals configured to apply one or more loads to one or more rotors of the geographically associated fluid turbines. The one or more loads may enable extraction of a maximum (e.g., near maximum) amount of electrical power from the geographically associated fluid turbines operating as a single fluid energy conversion system.

[0131] In some aspects, synchronizing coordinates the rotational timing of each turbine in a plurality of geographically associated fluid turbines. The rotational timing of a fluid turbine may refer to the rotational speed of each fluid turbine (e.g., corresponding to the rotational speed of a rotor connected to the fluid turbine, measured as RMP or cycles per second, for example). Coordinating the rotational timing may include coordinating the rotational timing such that each of the geographically associated fluid turbines may spin at substantially the same frequency. In some aspects, coordinating the rotational timing of each of the geographically associated fluid turbines may cause the geographically associated fluid turbines to generate power output signals having substantially the same level and / or substantially the same frequency.

[0132] In some aspects, synchronizing coordinates the rotational orientation of each of the geographically associated turbines. The rotational orientation of a fluid turbine may refer to a direction of rotation (e.g., clockwise or counterclockwise). Coordinating the rotational orientation of each of the fluid turbines may include controlling or adjusting the rotational orientation of each of the fluid turbines. For example, the at least one processor may apply a braking signal to cause all of the geographically associated fluid turbines to rotate clockwise or counterclockwise, or to alternate between clockwise and counterclockwise rotating fluid turbines.

[0133] 4, the at least one processor 428 may transmit a braking signal to the at least one brake 608 to synchronize each of the fluid turbines 404A, 404B, such as by synchronizing rotation. For example, the synchronization may enable the at least one processor 428 to simultaneously apply an MPPT protocol to each of the fluid turbines 404A, 404B such that the cooperative operation of the fluid turbines 404A, 404B extracts maximum power (e.g., or near maximum power) from the fluid flow. As another example, synchronization may enable the at least one processor 428 to coordinate the speed of rotation, starting and / or stopping of rotation, delaying of rotation, and / or any other rotation timing attributes of the fluid turbines 404A, 404B. As a further example, synchronization may enable the at least one processor 428 to coordinate the orientation of rotation of the fluid turbines 404A, 404B, for example, to cause both fluid turbines 404A, 404B to rotate clockwise or counterclockwise, or to cause the fluid turbine 404A to spin clockwise and the fluid turbine 404B to spin counterclockwise. As another non-limiting example, in FIG. 13 , the at least one processor 428 may communicate with each processor 512 of each braking circuit 1300 (e.g., each associated with a different one of the fluid turbines 404) to synchronize operation of the fluid turbines 404 via the electronic brake control 518 and / or the mechanical brake control 520.

[0134] 7-11, the at least one processor (e.g., configured with inverter 434) may transmit a braking signal to brake circuit 712 to synchronize fluid turbines 404. Synchronizing fluid turbines 404 may enable at least one processor to apply an MPPT protocol to each of the fluid turbines to extract maximum (e.g., or near maximum) power from the fluid flow. Similarly, at least one processor may coordinate the rotational speed and / or rotational orientation of fluid turbines 404.

[0135] Some aspects include a non-transitory computer-readable medium including instructions that, when executed by at least one processor, cause the at least one processor to perform operations for coordinated braking of a plurality of geographically associated fluid turbines, the operations including accessing a memory that stores information indicative of a tolerance threshold for at least one operating parameter associated with the plurality of geographically associated fluid turbines, receiving information from at least one sensor indicative of the at least one operating parameter for a particular fluid turbine of the plurality of geographically associated fluid turbines, comparing the information indicative of the at least one operating parameter for the particular fluid turbine to the tolerance threshold stored in the memory, determining whether the at least one operating parameter for the particular fluid turbine deviates from the tolerance threshold based on the comparison, and transmitting a braking signal to each of the geographically associated fluid turbines to slow down each of the geographically associated fluid turbines upon determining that the at least one operating parameter for the particular fluid turbine exceeds the tolerance threshold.

[0136] As a non-limiting example, in FIG. 4, the at least one processor 428 may perform operations for coordinated braking of the geographically associated multiple fluid turbines 404A, 404B. The at least one processor 428 may access a memory 430 that stores information indicative of a tolerance threshold value of at least one operating parameter associated with the geographically associated fluid turbines 404A, 404B. The at least one processor 428 may receive information indicative of the at least one operating parameter for the fluid turbine 404A from at least one sensor (e.g., at least one sensor 418 of FIG. 5). The at least one processor 428 may compare the information indicative of the at least one operating parameter for the fluid turbine 404A to the tolerance threshold value stored in the memory 430. The at least one processor 428 may determine whether the at least one operating parameter for the fluid turbine 404A deviates from the tolerance threshold value (e.g., for both fluid turbines 404A, 404B) based on the comparison. Upon determining that at least one operating parameter for the fluid turbine 404A exceeds a tolerance threshold, the at least one processor 428 may send a braking signal to each of the charge controllers 410A, 410A, thereby activating the electronic brakes (e.g., via the electronic brake control 518 and / or the charge controller 410) and / or at least one mechanical brake 608 (e.g., via the mechanical brake control 520) of the geographically associated fluid turbines 404A, 404B to at least slow down each of the geographically associated fluid turbines 404A, 404B.

[0137] FIG. 15 illustrates a flowchart of an example process 1500 for coordinated braking of multiple geographically associated fluid turbines consistent with aspects of the present disclosure. In some aspects, the process 1500 may be performed by at least one processor (e.g., at least one processor 428 and / or processor 512) to perform operations or functions described herein. In some aspects, some aspects of the process 1500 may be implemented as software (e.g., program code or instructions) stored in a memory (e.g., memory 430 and / or memory 514) or a non-transitory computer-readable medium. In some aspects, some aspects of the process 1500 may be implemented as hardware (e.g., dedicated circuitry). In some aspects, the process 1500 may be implemented as a combination of software and hardware.

[0138] 15, the process 1500 includes accessing 1502 a memory that stores information indicative of a tolerance threshold value of at least one operating parameter associated with the geographically associated plurality of fluid turbines. As a non-limiting example, in FIG. 4, the at least one processor 428 may access a memory 430 that stores a tolerance threshold value of a rotational speed associated with the fluid turbines 404A, 404B. The process 1500 includes receiving 1504 information indicative of at least one operating parameter for a particular fluid turbine of the geographically associated plurality of fluid turbines from at least one sensor. As a non-limiting example, in FIG. 4, the at least one processor 428 may receive a rotational speed from a rotational sensor 502 of the charge controller 410A of the fluid turbine 404A. The process 1500 includes comparing 1506 the information indicative of the at least one operating parameter for the particular fluid turbine to the tolerance threshold value stored in the memory. 4, the at least one processor 428 may compare the rotational speed tolerance threshold retrieved from the memory 430 to the rotational speed of the fluid turbine 404A received from the rotational sensor 502 associated with the charge controller 410A. The process 1500 includes step 1508 of determining whether at least one operating parameter for the particular fluid turbine deviates from the tolerance threshold based on the comparison. As a non-limiting example, the at least one processor 428 may determine that the fluid turbine 404A is spinning at a speed that exceeds the rotational speed tolerance threshold based on the comparison. The process 1500 includes step 1510 of transmitting a brake signal to each of the geographically associated fluid turbines to slow down each of the geographically associated fluid turbines upon determining that the at least one operating parameter for the particular fluid turbine exceeds the tolerance threshold. As a non-limiting example, in FIG. 4, the at least one processor 428 may send a braking signal to the charge controllers 410A, 410B of the fluid turbines 404A, 404B, respectively, to slow down each of the fluid turbines 404A, 404B.As another non-limiting example, in Figures 7-11, at least one processor (e.g., configured with inverter 434) may send a braking signal to any of charge controllers 410, 802 and / or 902 to slow down the fluid turbine 404.

[0139] Applying an MPPT protocol to a geographically associated group of fluid turbines may be beneficial to improve the efficiency of the group as a whole. However, aggregating geographically associated fluid turbines may cause at least some of the fluid turbines of the group to be hydrodynamically coupled in a non-optimal manner. Thus, some of the fluid turbines may be affected differently as fluid flows through the group because one or more downstream fluid turbines may be further affected by turbulence and / or draft generated by one or more upstream fluid turbines of the group. Furthermore, a load predicted by an MPPT protocol to produce optimal (or near-optimal) performance when applied to a single (e.g., isolated) fluid turbine may produce sub-optimal performance for a hydrodynamically coupled fluid turbine because the fluid flow used in the MPPT calculation may not account for the hydrodynamic effects of the other fluid turbines. Systems, devices, methods, and non-transitory computer readable for a coordinated MPPT protocol for a geographically associated group of fluid turbines are disclosed to enable coordinated operation of the group of fluid turbines. The coordinated MPPT protocol may predict load conditions for the geographically associated group of fluid turbines to improve the predicted power output of the entire group. In some cases, the load conditions predicted for a geographically associated group of fluid turbines may override one or more load conditions predicted by an MPPT protocol applied to an isolated fluid turbine. In some aspects, a group-level MPPT protocol may be applied when an individual fluid turbine does not have a dedicated MPPT controller.

[0140] Some embodiments include a system for coordinating MPPT operation of a group of geographically associated fluid turbines. The fluid turbines may include mechanical devices configured to capture energy from a fluid flow, as described elsewhere in this disclosure. The geographically associated group of fluid turbines may refer to a plurality of fluid turbines positioned relatively close to one another, as described elsewhere in this disclosure. Coordinating may include, for example, synchronizing, adjusting, synchronizing, and / or orchestrating to achieve a target result.

[0141] In some aspects, the fluid turbines include horizontal axis turbines. A horizontal axis turbine (e.g., HAWT) may refer to a fluid turbine in which the axis of rotation of the turbine blades may be substantially parallel to the fluid flow. In some aspects, the fluid turbines include vertical axis turbines. A vertical axis turbine (e.g., VAWT) may refer to a fluid turbine in which the axis of rotation of the turbine blades may be substantially perpendicular to the fluid flow. In some aspects, the fluid turbines may include drag type fluid turbines. Drag type fluid turbines may be directly propelled by the fluid flow and may reach a maximum rotational speed corresponding to the fluid flow velocity. In some aspects, the fluid turbines may include lift type fluid turbines. Lift type fluid turbines may have an airfoil shape (e.g., similar to a wing or sail) and may be configured to cause increased lift by assuming a larger angle (e.g., angle of attack) with respect to the fluid flow. Lift type fluid turbines may spin at a rotational speed greater than the fluid flow. In some aspects, the fluid turbine is a wind turbine. A wind turbine may refer to a fluid turbine configured to convert an air flow into kinetic energy or mechanical rotational motion. A generator driven by a wind turbine may convert the mechanical rotational motion into electrical energy. In some aspects, the fluid turbine is a hydro turbine. A hydro turbine may refer to a fluid turbine configured to convert a water flow (e.g., a river, a waterfall, a hydroelectric dam, an ocean current) into electrical energy.

[0142] 1 shows a horizontal axis fluid turbine 102 and vertical axis fluid turbines 100, 106-112. The fluid turbines 100, 102 may be wind turbines and the fluid turbine 104 may be a water turbine.

[0143] The MPPT operation may include one or more procedures associated with an MPPT protocol configured to coordinate the fluid power capture of the fluid turbine by adjusting the rotational speed of the fluid turbine. For each fluid speed, there may be an optimal or near-optimal rotational speed of the particular turbine at which the particular turbine may output a maximum or near-maximum amount of power. Thus, the fluid turbine may be designed to operate at a maximum (or near-maximum) power output when subjected to different fluid speeds by spinning at different rotational speeds. The MPPT operation may adjust the rotational speed of the fluid turbine to achieve an optimal (e.g., or near-optimal) rotational speed for a given fluid speed by adjusting the load imposed on the fluid turbine. In some aspects, the charge controller may adjust the load on the fluid turbine, for example, by diverting some power generated by the fluid turbine to a dump load. Some MPPT operations may require prior knowledge of operating parameters for the fluid turbine, and some MPPT operations may not require prior knowledge but may be based on an iterative approach using, for example, feedback. In some aspects, the MPPT operation may be performed without fluid speed data from an anemometer or with fluid speed data from an anemometer.

[0144] Coordinating the MPPT operation of the geographically associated fluid turbines may include adjusting one or more loads imposed on one or more fluid turbines included in the geographically associated fluid turbines to reach a target level of total power generated by the group. In some cases, the target level of total power output may correspond to a maximum or near-maximum level for a given fluid velocity. In some aspects, coordinating the MPPT operation of the fluid turbines may include, for example, overriding the MPPT operation of one or more individual fluid turbines in the group for a limited duration. For example, operating one or more fluid turbines in the geographically associated fluid turbines at a sub-optimal level may improve the total power output of the group as a whole. In some aspects, MPPT operation may be coordinated for the geographically associated fluid turbines in the absence of anemometer fluid velocity measurements.

[0145] Some embodiments include at least one processor (eg, configured to perform operations to coordinate MPPT operation of the fluid turbines).

[0146] The at least one processor may include a single processor or multiple processors communicatively linked to each other and capable of cooperative computational processing, as described elsewhere in this disclosure. For example, the at least one processor may include one or more processors for controlling operation of multiple geographically associated fluid turbines to collectively operate as a single fluid energy conversion system.

[0147] Some embodiments include receiving data from a geographically associated group of fluid turbines. The data from the geographically associated group of fluid turbines may include information detected by one or more sensors associated with one or more individual fluid turbines in the geographically associated group of fluid turbines and / or one or more sensors associated with the geographically associated group of fluid turbines (e.g., considered as an integrated fluid energy conversion system). The data may be associated with one or more of fluid speed, rotational speed (e.g., blade RPM, shaft RPM, and / or rotor RPM), power output (e.g., including one or more of voltage level, current level, signal amplitude, signal frequency, phase shift), load (e.g., resistance and / or impedance), vibration, temperature, braking signal, and / or any other information detected by one or more sensors associated with the geographically associated group of fluid turbines. The data may include information associated with each fluid turbine in the group and / or information aggregated for the entire geographically associated group of fluid turbines (e.g., including one or more statistics such as a mean, mode, standard deviation, maximum, minimum, and / or any other statistical measure of data associated with the geographically associated group of fluid turbines). The data may include information associated with different types of sensors (e.g., fluid velocity, rotational speed, and braking signal) or information associated with a single type of sensor (e.g., temperature). The data may be associated with an instant and / or a duration (e.g., at least 10 seconds, or at least 30 seconds). For example, the data may include a rotational speed determined for each fluid turbine in the group based on rotor RPM and blade tip RPM over a 30 second period, and / or an average rotational speed, maximum rotational speed, and minimum rotational speed determined for the group based on rotor RPM and blade tip RPM over a 30 second period.

[0148] Receiving data from the geographically associated group of fluid turbines may include receiving (e.g., by at least one processor) one or more electronic notifications from one or more sensors associated with one or more individual fluid turbines in the geographically associated group of fluid turbines and / or one or more sensors associated with the group as a whole. Receiving data may include periodically polling one or more sensors (e.g., voltage sensors, current sensors, braking sensors, temperature sensors, fluid speed sensors, rotational speed sensors, vibration sensors, and / or any other type of sensor associated with the geographically associated group of fluid turbines) for information and / or receiving electronic notifications from the one or more sensors, for example, as synchronous and / or asynchronous (e.g., interrupt) events. The at least one processor may receive data from the one or more sensors locally or remotely via wired and / or wireless communication links and may store the received information in memory (e.g., for immediate and / or subsequent access).

[0149] In some aspects, the data received from the geographically associated group of fluid turbines may include power data associated with one or more individual turbines in the group (e.g., each individual fluid turbine in the group) and / or power data associated with the total power of the entire geographically associated group of fluid turbines operating as an integrated fluid energy conversion system. The power output (e.g., power) may be measured in watts (e.g., kilowatts, or megawatts) and may refer to the rate at which electrical energy is transmitted by an electrical circuit. The power output may be calculated from known voltage and / or current levels (e.g., watts = volts x amps). The power may be generated by a generator (e.g., connected to the fluid turbine). As used herein, the phrase "electrical power generated by a fluid turbine" or "electrical power output from a fluid turbine" may refer to electrical power generated by a generator associated with the fluid turbine. The power data may include information regarding the level of power output by the fluid turbine and / or the circuitry connected thereto. The power data may include one or more of a voltage signal, a current signal, a signal amplitude, a signal frequency, a resistance level, an impedance level measurement, and / or any other measurement that allows for the power to be calculated.

[0150] The power data from the geographically associated group of fluid turbines may include information associated with the power output of one or more individual fluid turbines in the group, and / or the amount of net (e.g., total) power generated by aggregating the power generated by each fluid turbine in the group. The power data may include one or more of the voltage, current, signal amplitude, signal frequency, resistance and / or impedance of one or more individual fluid turbines in the group, and / or the total voltage, total current, total DC signal, total AC signal, total signal amplitude, total signal frequency, and / or total resistance and / or impedance associated with the group of fluid turbines (e.g., operating as an integrated fluid energy conversion system). For example, the power data may be used to determine an amount of power that a particular fluid turbine and / or the geographically associated group of fluid turbines may generate under current fluid speed conditions. Receiving the power data from the geographically associated group of fluid turbines may include receiving data from a voltmeter and / or ammeter. In some aspects, the power data associated with the geographically associated group of fluid turbines may include one or more DC power signals output by individual fluid turbines in the group and / or a total DC power output of the entire group (e.g., for charging a battery bank). In some aspects, the inverter may convert the total DC power output generated by the geographically associated group of fluid turbines to a total power AC output (e.g., for output to a power grid), and the power data associated with the geographically associated group of fluid turbines may include a total (aggregate) power AC output.

[0151] As a non-limiting example, in Figure 3, at least one processor 308 may receive data from group 300 of geographically associated fluid turbines 100A-100C. As another non-limiting example, in Figure 4, at least one processor (e.g., at least one processor 428 and / or processor 512) may receive data from fluid turbines 404A, 404B via at least one sensor 418A, 418B, respectively. For example, at least one processor may receive power data from power output sensor 510.

[0152] 13 , the generator 406 may direct an AC power output 408 to a braking circuit 1300 (e.g., associated with the charge controller 410). A rectifier 530 may convert the AC power output 408 to a DC power signal. A first voltage sensor 1310 may measure the converted DC power signal and transmit a measurement of the converted DC power signal to the at least one processor 512 to indicate the AC power output 408.

[0153] Some embodiments include determining a change to the total power output of the group based on changes in the load conditions of the individual fluid turbines in the group. The load condition of a fluid turbine may refer to one or more parameters that characterize a particular load (e.g., an electrical load) that consumes or diverts power generated by the fluid turbine and slows down the rotation of the fluid turbine. In some embodiments, the load condition of a fluid turbine may further include one or more operating parameters for the fluid turbine subjected to the particular load. The load condition of a fluid turbine may be characterized by an IV curve (e.g., current vs. voltage), resistance (e.g., for resistive loads) and / or inductance (e.g., for inductive loads), the amount of power consumed or diverted, and / or the timing and / or duration of the consumed power. In some embodiments, the load condition of a fluid turbine may be associated with a rotational speed, power output, temperature, and / or vibration level associated with the fluid turbine subjected to the load. The load condition of a fluid turbine operating under a particular fluid speed may be associated with a particular rotational speed and power output. At least one load condition of the fluid turbine may correspond to a target rotational speed configured to produce a peak (or near-peak) power output (eg, according to an MPPT protocol).

[0154] The changes in the load conditions of the individual fluid turbines may include one or more adjustments or modifications made to the loads imposed on the individual fluid turbines (e.g., changes in power levels consumed, changes in timing, changes in duration, changes in impedance levels) and / or one or more corresponding changes in one or more operating parameters for the individual fluid turbines in response to the changes made to the loads (e.g., changes in rotational speed or direction, power output, temperature, and / or vibration). In some cases, the at least one processor may subject the fluid turbines to a series of load changes (e.g., a series of changes in the load conditions of the individual fluid turbines) that cause a series of changes in the corresponding operating parameters. In some aspects, the at least one processor may modify the loads imposed on the fluid turbines to identify load conditions that correspond to a peak (or near-peak) power output of the fluid turbines operating under a particular fluid speed (e.g., in accordance with an MPPT protocol).

[0155] A change in load condition of individual fluid turbines in the group may include subjecting at least some of the fluid turbines in the group to a change in load imposed on the fluid turbine that causes a corresponding change in operation of at least some of the fluid turbines. For example, the at least one processor may generate a plurality of signals (e.g., load signals), each signal characterized by a change in an amount of power to be diverted from the fluid turbine (e.g., thereby subjecting the fluid turbine to a load). The at least one processor may transmit a signal to at least some of the fluid turbines in the group to implement the change in load condition. In some aspects, the at least one processor may subject at least some of the fluid turbines in the group to the same load condition change (e.g., the same signal). In some aspects, the at least one processor may subject at least some of the fluid turbines in the group to different load condition changes (e.g., different signals). The different load condition changes (e.g., imposed on different individual fluid turbines in the group) may be associated with the same signal characteristics (e.g., different frequency changes for different fluid turbines) or different signal characteristics (e.g., a change in frequency of some fluid turbines and a change in phase of other fluid turbines). In some aspects, the at least one processor may cause all of the fluid turbines in the group to undergo a change in load condition (e.g., the same change or different changes). In some aspects, the change in load condition of individual fluid turbines in the group may be indicated in data received from the group (e.g., power data).

[0156] In some cases, the at least one processor may generate a plurality of sets of changes to the load conditions of different individual fluid turbines in the group based on the response characteristics of the different fluid turbines. For example, the at least one processor may subject the different fluid turbines to different loads, causing the different fluid turbines to rotate at substantially the same rotational speed and / or direction, or at least some of the fluid turbines to rotate at different rotational speeds and / or directions. As another example, the at least one processor may subject the different fluid turbines to different loads, causing the different fluid turbines to generate substantially the same power output (e.g., substantially the same phase and / or frequency), or at least some of the fluid turbines to generate different power outputs (e.g., different phase and / or frequency).

[0157] (For example, the total power output of a group of geographically associated fluid turbines may include an aggregate AC power signal and / or an aggregate DC power signal generated by combining the power generated by each fluid turbine in the group. In some aspects, to avoid losses due to aggregating interfering (e.g., incompatible) AC signals output by multiple fluid turbines in a geographically associated group of fluid turbines, each AC signal generated by each fluid turbine in the group may be converted to a DC signal (e.g., via a dedicated rectifier). The multiple DC signals may be aggregated to prevent interference that could result in losses, for example.

[0158] As a non-limiting example, in FIG. 3, at least one processor 308 may determine a change to the total power output 314 of the group 300 based on changes in load conditions of the individual fluid turbines 100A-100C in the group 300.

[0159] As another non-limiting example, in FIG. 4 , at least one processor (e.g., at least one processor 428 and / or processor 512) may change one or more load conditions of the individual fluid turbines 404A, 404B, for example, by sending a signal to the charge controllers 410A, 410B to impose new load conditions on the fluid turbines 404A, 404B. The change in load condition may cause a corresponding change in the rotational speed of each of the fluid turbines 404A, 404B. The at least one processor may receive data from a rotational sensor 502 associated with each of the fluid turbines 404A, 404B and may calculate the power output by each of the fluid turbines 404A, 404B based on the measured rotational speed, for example, using one or more versions of chart 1200 (see, for example, FIG. 12 ). The at least one processor may calculate a total power output 440 generated by the group 401 of fluid turbines 404A, 404B based on the calculated output of each of the fluid turbines 404A, 404B.

[0160] 13 , at least one processor 512 (e.g., dedicated to one of the individual fluid turbines 404) may determine a power output of the individual fluid turbine 404 based on a change in load condition imposed via the electronic brake control 518 and / or based on a signal received from the first voltage sensor 1310. The at least one processor 512 may communicate the change in load condition of the individual fluid turbine 404 to at least one processor 428 associated with a group 401 of geographically associated fluid turbines 404, thereby enabling the at least one processor 428 to receive the change in load condition of each individual fluid turbine 404 in the group 401. The at least one processor 428 may determine a change in the total power output 440 of the group 401 based on the received load condition of each individual fluid turbine 404 in the group 401.

[0161] In some aspects, determining a change to the total power output of the group based on changes in load conditions of the individual fluid turbines in the group includes calculating or measuring a change to the total power output. Calculating may include performing one or more arithmetic and / or logical calculation operations. Measuring the change may include periodically sensing the total power output (e.g., by a voltage sensor and / or a current sensor). The at least one processor may receive (e.g., from a voltage sensor and / or a current sensor) a first total power output for a first time instance and a second total power output for a second time instance and may calculate a difference between the first total power output and the second total power output. In some cases, the at least one processor may measure a change to the total power output of the fluid turbine group in response to subjecting individual turbines in the group to varying load conditions.

[0162] As another non-limiting example, in FIGS. 4 and 5, based on a change in load conditions, at least one processor (e.g., at least one processor 428 and / or 512) may determine a change to the total power output output by the fluid turbines 404A, 404B by receiving power output data measured by each power output sensor 510 configured with each of the at least one sensor 418A, 418B associated with the fluid turbines 404A, 404B, respectively.

[0163] In some aspects, at least some of the turbines in the group are hydrodynamically coupled. Hydrodynamically coupled fluid turbines may refer to a situation where the output of one fluid turbine (e.g., an upstream fluid turbine) may affect the operation of another fluid turbine (e.g., a downstream fluid turbine), where the upstream fluid turbine may encounter a fluid flow before the downstream fluid turbine. For example, turbulence or fluid flow generated by one fluid turbine may affect one or more of the rotational speed, rotational direction, power output, vibration, and / or any other operational aspect of another fluid turbine. In some cases, hydrodynamic coupling of two or more fluid turbines may have a positive or negative effect on the power output of one of the coupled fluid turbines. Thus, subjecting an individual turbine to a load condition associated with a peak power output (e.g., when operating independently, without hydrodynamic coupling), may instead produce a higher / lower total power output for the entire group due to the positive / negative effect that may be attributed to the hydrodynamic coupling between two or more fluid turbines in the group. In some aspects, determining a change in the total power output of the group may include calculating, measuring, evaluating, or ascertaining a change (e.g., a positive or negative change) attributable to the fluid coupling of two or more fluid turbines in the group.

[0164] 3, one or more of the fluid turbines 100A-100C of the group 300 may be hydrodynamically coupled. For example, a draft generated by the fluid turbine 100A may flow toward the fluid turbine 100B and affect the rotational spin of the fluid turbine 100B. Similarly, a draft generated by the fluid turbine 100B may flow toward the fluid turbine 100C and affect the rotational spin of the fluid turbine 100C.

[0165] Some aspects include selecting a combination of load conditions of the individual fluid turbines in the group to coordinate the total power output of the group. Combination may refer to two or more. For example, combination may include selection of two or more elements from a set of separate member elements, e.g., selection of a subset of frequencies from a set of possible frequencies. The combination of load conditions of the individual fluid turbines may include the same or similar combination of load conditions of each turbine in the fluid turbine group, different load conditions of at least some of the fluid turbines in the group, or different load conditions of each fluid turbine in the group. For example, at least some of the fluid turbines may receive the same load signal (e.g., same level of bypass power, same timing and same duration) such that at least some of the fluid turbines may have substantially similar load conditions. Alternatively, at least some of the fluid turbines may receive different load signals (e.g., one or more of the level, timing, and / or duration of bypass power may be different) such that some of the fluid turbines may have different load conditions. In some aspects, due to different operating parameters, two or more fluid turbines may experience similar conditions and be in different load conditions. Selecting a combination of load conditions for the individual fluid turbines may include selecting a particular combination of load conditions from a plurality of candidate combinations. The selection may be based on efficiency, compliance with one or more standards or regulations (e.g., associated with the fluid turbine and / or power sink), maximizing power output, minimizing wear, safety, and / or any other concern for coordinating operation of a group of geographically associated fluid turbines.

[0166] Coordinating the total power output of the group (e.g., of fluid turbines) may include synchronizing, tuning, and / or adjusting the total power output of the entire group of fluid turbines, for example, to achieve a peak (or near-peak) total power output, an optimal (or near-optimum) total power output, an increase in the total power output (e.g., relative to a total power output associated with a load condition other than the selected combination), to achieve compliance with one or more specifications, regulations, and / or recommendations (e.g., associated with a battery bank, a power system, a test protocol, a maintenance protocol, and / or an MPPT protocol), and / or to achieve any other concerns associated with the group of fluid turbines. In some aspects, selecting a combination of load conditions of the individual turbines may include overriding one or more load conditions associated with implementing an MPPT protocol on a single fluid turbine. For example, a load condition configured to generate a peak power output of a non-hydrodynamically coupled fluid turbine (e.g., based on an MPPT protocol applied to a single fluid turbine, isolated from other fluid turbines in the group) may result in a sub-peak total power output of the group as a whole due to hydrodynamic coupling between some of the fluid turbines. Thus, in some aspects, at least one processor may select load conditions for individual fluid turbines in the group that take into account the hydrodynamic coupling of at least some of the fluid turbines and may override one or more load conditions associated with an MPPT protocol applied to one or more isolated fluid turbines.

[0167] As a non-limiting example, in FIG. 3, the at least one processor 308 may select a combination of load conditions for the individual fluid turbines 100A-100C. The selected combination of load conditions may coordinate the total power output by the group 300. As another non-limiting example, in FIGS. 4, 5, and 13, the at least one processor 512 (e.g., dedicated to one of the individual fluid turbines 404) may transmit load condition data for the individual fluid turbine 404 to the at least one processor 428. The load condition data may coordinate the power output of the individual fluid turbine 404 (e.g., operating without regard to the other fluid turbines 404 in the group 401). In some aspects, the at least one processor 428 may select a combination of load conditions for the individual fluid turbines 404 based on the load condition data received from each at least one processor 512 associated with each fluid turbine 404 in the group 401. The selected combination of load conditions may coordinate the total power output 440 generated by the group 401.

[0168] In some aspects, selecting a combination of load conditions of the individual fluid turbines in the group accounts for variations in fluid conditions that affect the group. The variations in fluid conditions may include changes in fluid velocity, fluid flow direction, turbulence, and / or moving (e.g., airborne) objects in the fluid flow. The variations in fluid conditions that affect the group may include fluid velocity below an operational threshold of the fluid turbines in the group, fluid velocity above a safety threshold of the fluid turbines in the group, a change in fluid velocity that causes one or more fluid turbines to stop or start producing a peak (or near-peak) power output, a change in fluid flow that causes a stop, stop, increase, or decrease in hydrodynamic coupling between two or more fluid turbines, and / or any other effect of a change in fluid flow on the fluid turbine group. In some aspects, the variations in fluid conditions are associated with variations in power output by different ones of the fluid turbines in the group. The variations in power output may include an increase or decrease in power output, starting or stopping producing a peak (or near-peak) power output, starting or stopping producing a threshold power output of the power system, starting or stopping producing a threshold power output associated with a safety regulation, and / or any other type of variation in power output. Variations in the power output by different ones of the fluid turbines may refer to different power levels output by at least some of the fluid turbines in the group in response to varying fluid conditions. For example, as fluid flow changes, the most upstream fluid turbine in the group may increase its power output by 5%, while the most downstream fluid turbine in the group may decrease its output by 2%. For example, each individual fluid turbine in the group may be associated with a different graph (e.g., a version of chart 1200 of FIG. 12) that maps the power output for different rotational speeds under different fluid conditions. The graph may include a mapping (e.g., curve) for each fluid condition that shows a different power output response versus rotational speed. For example, under a first fluid speed, the fluid turbine may generate a peak (or near-peak) power output while spinning at the first rotational speed. However, under a second fluid speed, the fluid turbine may generate a sub-peak power output while operating at the first rotational speed. As fluid conditions vary, the at least one processor may monitor the power output of the fluid turbines.Based on the power output, the at least one processor may modify load conditions of at least some of the fluid turbines to cause corresponding changes in rotational speed to accommodate variations in fluid conditions. For example, the at least one processor may modify load conditions to track peak (or near-peak) power output of individual fluid turbines.

[0169] As a non-limiting example, in FIG. 4, the at least one processor 428 may select a combination of load conditions for the individual fluid turbines 404A-404B to account for variations in fluid conditions (e.g., of the fluid stream 210) affecting the group 401. For example, the at least one processor 428 may detect an increase in fluid flow rate. An increase in fluid flow rate may cause the fluid turbines 404A-404B to operate outside of their peak (or near-peak) power output (e.g., in FIG. 12, when the fluid flow rate is v w1 ~v w6 As the fluid speeds vary, the rotational speeds required to generate the peak power output 1204-1214 will vary as well. The at least one processor 428 may select a combination of loads on the individual fluid turbines 404A-404B to vary their respective rotational speeds to cause each of the fluid turbines 404A-404B to generate a peak (or near-peak) power output. In some embodiments, the variations in fluid conditions are associated with variations in the power output by different ones of the fluid turbines 404A-404B. For example, a 5% decrease in fluid speed may cause the power output of the fluid turbine 404A to decrease by 4%, but the power output of the fluid turbine 404B to decrease by only 2%. The at least one processor may adjust the load conditions to cause each of the fluid turbines 404A-404B to generate a peak (or near-peak) power output for the new fluid speed conditions.

[0170] In some aspects, the selected combination of load conditions is configured to cause some fluid turbines in the group to operate differently than other fluid turbines in the group. A fluid turbine that operates differently from another fluid turbine may refer to differences in rotational speed, braking force, other resistance, power output, blade orientation, and / or any of the other examples provided herein. The turbines in the group may be loaded differently (e.g., alterable characteristics are altered) such that not all turbines in the group operate the same way. For example, similar changes to the load conditions of different turbines may cause different rotational speeds, different rotational directions, generation of different output powers (e.g., different frequencies, phases, amplitudes), operation under different impedances and / or resistances, different temperatures, and / or different vibration modes of the different fluid turbines.

[0171] 4, the at least one processor 428 may select a combination of load conditions to cause fluid turbine 404A to operate differently than fluid turbine 404B. For example, the combination of load conditions may cause fluid turbine 404B to spin at a different rotational speed and / or direction than fluid turbine 404A (e.g., due to fluid turbine 404B being downstream from fluid turbine 404A).

[0172] In some aspects, the operational differences vary based on changing fluid conditions. A change in fluid conditions may refer to one or more of a change in direction of fluid flow, a change in velocity, and / or a change in turbulence. The physical characteristics of the fluid turbine may further affect the response of the fluid turbine to changes in fluid conditions. For example, under a first fluid condition, a selected combination of load conditions may produce a first set of differences between the first and second fluid turbine groups, and under a second fluid condition, the same selected combination of load conditions may produce a second set of differences between the first and second fluid turbine groups. For example, under a first fluid condition, a selected combination of load conditions may cause the first group to spin faster than the second group, and under a second fluid condition, the same selected combination of load conditions may cause the first group to spin slower than the second group.

[0173] 4, the difference in operation of fluid turbines 404A-404B may vary based on changing conditions in the fluid flow (e.g., fluid flow 210). For example, upon sensing a change in direction of the fluid flow (e.g., via fluid velocity sensor 504 of FIG. 5), at least one processor 428 may determine that fluid turbine 404A is now downstream of fluid turbine 404B. The changing conditions in the fluid flow may cause at least one processor 428 to spin fluid turbine 404B at a different rotational speed than fluid turbine 404A.

[0174] In some aspects, the selected combination of load conditions varies over time for different combinations of fluid turbines in the group, where variation over time may refer to a change or partial change over a period of time. Different combinations of fluid turbines may refer to different subsets of fluid turbines included in the group. Over time, the conditions under which the fluid turbine group operates may change. For example, fluid conditions may change, power demand may change (e.g., peak demand on a power grid may change to a lull in demand), or a battery bank may need to be filled / emptied. The changed conditions may affect some fluid turbines differently than others. Under a first operating condition, the at least one processor may select a first combination of load conditions for the first turbine group. Over time, as conditions change to a second condition, the at least one processor may select a second combination of load conditions for the second fluid turbine group. For example, during the morning hours, an easterly wind may affect the wind turbine group, and the at least one processor may select load conditions for the easterly facing turbines in the group. In the afternoon, the wind may shift to a westerly wind, and the at least one processor may select a different load condition for the westward facing turbines in the group.

[0175] 3, the at least one processor 308 may vary the selected combination of load conditions over time for different combinations of fluid turbines 100B-100C in group 300. For example, during a first time period, the at least one processor 308 may select a first load condition for fluid turbine 100A and a second load condition for each of fluid turbines 100B-100C. During a second time period (e.g., after sensing a change in condition of fluid stream 210), the at least one processor 308 may select a third load condition for each of fluid turbines 100A, 100B and a fourth load condition for fluid turbine 100C.

[0176] In some aspects, the different operations in the group include at least one of rotational speed (RPM), voltage output, current output, rotational direction, blade orientation with respect to the fluid flow, or relative blade orientation between at least two fluid turbines in the group. The rotational speed may refer to the rotational speed, acceleration, or pace of the blade tips, shaft, mounting plate connecting the plurality of blades to the rotor, rotor, and / or any other rotatable components associated with the fluid turbine. The voltage output may refer to a potential difference associated with the power output of the fluid turbine. The current output may refer to a net flow rate of electricity associated with the power output of the fluid turbine. The rotational direction may refer to a clockwise or counterclockwise rotation of the plurality of blades of the fluid turbine. The blade orientation with respect to the fluid flow may refer to an angle of incidence (e.g., blade pitch and / or blade yaw) between the fluid flow and the blades. The relative blade orientation between at least two turbines in the group may refer to at least two fluid turbines having different pitch and / or yaw with respect to a common (e.g., vertical) axis. For example, the at least one processor may select a combination of load conditions that causes some fluid turbines to output power at a different voltage and spin at a different pitch and / or yaw angle than other fluid turbines.

[0177] 3, the different operations in the group 300 may include at least one of the RPM of any of the fluid turbines 100A-100C, the blade orientation of any of the fluid turbines 100A-100C relative to the fluid flow 210, and / or the relative blade orientation between the fluid turbines 100A, 100B in the group 300. As another non-limiting example, in FIGS. 4-5, the at least one processor 428 (e.g., corresponding to the at least one processor 308) may communicate with at least one processor 512 of the individual fluid turbine 404A and / or the individual fluid turbine 404B to adjust the blade yaw via a blade yaw control 526 and / or adjust the blade pitch via a blade pitch control 528. Additionally or alternatively, the different operations in the fluid turbines 404A, 404B may include a voltage output and / or a current output (e.g., as detected by the power output sensor 510 of at least one sensor 418A, 418B, respectively).

[0178] In some aspects, selecting a combination of load conditions of the individual fluid turbines in the group accounts for the spatial distribution of the individual fluid turbines in the group. The spatial distribution may refer to one or more of the relative distance, relative orientation, and / or relative height between the individual fluid turbines, and / or the location of the fluid turbines relative to one or more physical objects (e.g., buildings, trees, objects, mountains, valleys, bridges) that may affect the operation of one or more fluid turbines in the group. The spatial distribution may affect the hydrodynamic coupling between two or more fluid turbines (e.g., having one fluid turbine downstream of another fluid turbine). In some cases, the at least one processor may store the spatial distribution of the individual fluid turbines in a memory and may use the spatial distribution to determine the hydrodynamic coupling between different fluid turbines (e.g., based on current fluid conditions). The at least one processor may select a combination of load conditions of the individual fluid turbines to account for any hydrodynamic coupling based on the spatial distribution. In some cases, the at least one processor may determine the spatial distribution of the individual fluid turbines in the group based on image data received from one or more image sensors associated with the fluid turbines.

[0179] 3, the combination of load conditions selected by the at least one processor 308 for the individual fluid turbines 100A-100C in the group 300 may describe the spatial distribution of each of the fluid turbines 100A-100C in the group 300. For example, the at least one processor may select a different load condition for fluid turbine 100A and fluid turbine 100C (e.g., positioned at the ends of the group 300) than the load condition selected for fluid turbine 100B (e.g., sandwiched between fluid turbines 100A and 100C). For example, the at least one processor 308 may cause fluid turbine 100A and fluid turbine 100C to spin at a different rotational speed than fluid turbine 100B.

[0180] Some embodiments include transmitting a combination of selected load conditions to at least some of the individual fluid turbines in the group to vary the rotational speeds of at least some of the individual fluid turbines in the group. Transmitting may include, for example, transmitting a signal over a wired or wireless channel. Transmitting the combination of selected load conditions to at least some of the individual fluid turbines in the group may include generating a signal configured to impose the combination of selected load conditions on at least some of the individual fluid turbines (e.g., the generated signal may describe a physical characteristic of each individual fluid turbine), and transmitting the signal to the individual fluid turbines (e.g., or to a generator connected thereto), thereby imposing the load conditions on the individual fluid turbines. Varying may include changing or modifying. Varying the rotational speeds of some of the individual fluid turbines may include slowing down one or more rotational speeds (e.g., by increasing a load), accelerating one or more rotational speeds (e.g., by decreasing a load), and / or changing the rotational direction of some of the individual fluid turbines. In some cases, varying the rotational speeds of at least some of the fluid turbines may cause each of the fluid turbines to generate a target power output. The target power output may be associated with a peak (or near-peak) power output and / or compliance with one or more specifications and / or recommendations (e.g., associated with maintenance, safety, testing, compatibility, and / or any other concerns associated with the fluid turbines). Similarly, the total target power output may be associated with a peak (or near-peak) total power output and / or compliance with one or more specifications and / or recommendations (e.g., associated with maintenance, safety, testing, compatibility, and / or any other concerns associated with the group of fluid turbines). In some cases, varying the rotational speed of some of the fluid turbines may cause at least one fluid turbine to generate a non-target power output (e.g., different from the target power output). In some cases, the target total power output of the group of fluid turbines may include at least one non-target power output from at least one of the fluid turbines.For example, at least one non-target output may, when combined with outputs from other fluid turbines in the group, produce a target total power output for the group, eg, through hydrodynamic coupling.

[0181] As a non-limiting example, in FIG. 3, at least one processor 308 may transmit a selected combination of load conditions to at least one fluid turbine 100A, 100B of group 300 to vary the rotational speed of at least one fluid turbine 100A, 100B. As another non-limiting example, in FIG. 4, at least one processor (e.g., at least one processor 428 and / or processor 512) may transmit a selected combination of load conditions to the fluid turbines 404A, 404B via charge controllers 410A, 410B, respectively. The charge controllers 410A, 410B may impose the selected combination of load conditions on the fluid turbines 404A, 404B by diverting a portion of the power output by the generators 406A, 406B to a dump load.

[0182] As another non-limiting example, in FIG. 10 in conjunction with FIG. 4 and FIG. 13, a version of the braking circuit 1300 may be associated with each charge controller 410 that allows for individual coordination of (e.g., isolated) fluid turbines 404. For example, the MPPT control 1002 of each braking circuit 1300 may be associated with at least one processor 512 and at least one memory 514 of the charge controller 410 dedicated to the individual fluid turbine 404. Each at least one processor 512 may communicate with at least one processor 428 via the interconnect circuit 414, allowing the at least one processor 428 to coordinate a group 401 of fluid turbines 404 operating together as an integrated fluid energy conversion system 400. The at least one processor 428 may transmit a combination of selected load conditions to at least a portion of the charge controller 410, allowing at least a portion of the processor 512 (e.g., and a portion of the MPPT control 1002) to vary the rotational speed of at least a portion of the fluid turbines 404 in the group 401.

[0183] In some aspects, the combination of load conditions of the individual fluid turbines in the group is selected based on applying an MPPT protocol to each individual fluid turbine to determine an associated individual load condition for each individual fluid turbine and subjecting at least one of the individual load conditions of the individual fluid turbine to at least one global constraint of the group. The MPPT protocol may include transmitting a signal to adjust the rotational speed of the fluid turbine as described elsewhere in this disclosure. Applying the MPPT protocol to each individual fluid turbine in the group may include at least one processor communicating with one or more MPPT units to generate a signal configured to impose a load condition on each individual fluid turbine conforming to the MPPT protocol, and transmitting the signal to the MPPT unit. In some aspects, each fluid turbine may be associated with a dedicated MPPT unit. In some aspects, multiple fluid turbines may be associated with the same (e.g., common) MPPT unit. Determining an associated individual load condition for each individual fluid turbine (e.g., based on applying an MPPT protocol to each individual fluid turbine) may include determining a signal for each individual fluid turbine configured to impose a load condition associated with generating a peak (or near-peak) power output. Because one or more individual fluid turbines may have different physical characteristics (e.g., size, shape, type, orientation and / or position relative to other objects, and / or wear), different load conditions (e.g., generated by different signals) may be required to generate the peak (or near-peak) power output of each individual fluid turbine. At least one processor may associate an individual load condition with each individual fluid turbine in the group (e.g., to account for the different physical characteristics).

[0184] A constraint may refer to a limit, a boundary (e.g., an upper and / or lower limit). A constraint may be imposed on a system to achieve a target result associated with, for example, efficiency, safety, reliability, and / or durability. A global constraint on a group of fluid turbines may refer to a constraint imposed on each fluid turbine in the group and / or on the entire group of geographically associated fluid turbines operating as an integrated fluid energy conversion system (e.g., imposing a constraint globally on the group may allow, in some aspects, the constraint on an individual fluid turbine to be violated locally). A global constraint on a group of fluid turbines may be associated with one or more of load, power output, rotational speed, vibration, temperature, impedance, resistance, compliance with one or more regulations or recommendations, compliance and / or compatibility with a power grid, compatibility with a battery bank (e.g., voltage compatibility), timing, duration, maximum, minimum, average, mode, and / or standard deviation associated with any of the above, and / or any other concern associated with the group of fluid turbines. Forcing at least one individual load state of the individual fluid turbine to at least one global constraint of the group may include modifying the individual load state of the individual fluid turbine (e.g., conforming to an MPPT protocol applied to the individual fluid turbine) to cause the fluid turbine group to adhere to the global constraint. In some aspects, forcing at least one individual load state of the individual fluid turbine to the global constraint of the group may cause the individual fluid turbine to cease producing a peak (or near-peak) power output according to the MPPT protocol for the individual fluid turbine. For example, according to the MPPT protocol, the load state of the individual fluid turbine may be associated with a first rotational speed. Forcing the load state to the global constraint may cause the individual fluid turbine to rotate at a second rotational speed (e.g., faster or slower than the first rotational speed). For example, the global constraint may account for hydrodynamic coupling between at least some of the individual fluid turbines.

[0185] As a non-limiting example, in FIGS. 10 and 11, at least one processor (e.g., at least one processor 428 and / or 512) may select a combination of load conditions for the individual fluid turbines 404 by applying an MPPT protocol to each individual fluid turbine 404 (e.g., isolated) to determine an associated individual load condition for each of the fluid turbines 404. For example, the at least one processor may transmit a signal to an MPPT control 1002 included in each of the charge controllers 410 to cause each of the fluid turbines 404 to undergo a load condition that conforms to an MPPT protocol (e.g., configured for a single fluid turbine). As another example, the at least one processor may transmit a signal to an MPPT unit configured with an inverter 434 to control the load on the fluid turbines 404. In some aspects, the at least one processor may apply an MPPT protocol to each of the fluid turbines 404 by using one or more versions of a chart 1200 (see, e.g., FIG. 12) stored in a memory (e.g., memory 430 of FIG. 4). The at least one processor may subject at least one of the fluid turbines 404 to at least one global constraint for a group including all of the fluid turbines 404. For example, the constraint may limit the total (e.g., aggregate) power output generated by all of the fluid turbines 404 to comply with specifications of the electrical energy sink 402 (e.g., by limiting the total DC power output 724 for supply to the battery bank 720 and / or by capping the total AC power output 722 for supply to the power grid 718). For example, the DC power output 724 may be limited to 14V, or 40V, or any other voltage level compatible with the battery.

[0186] 13, each of the at least one processor 512 (e.g., dedicated to an individual fluid turbine 404) may apply an MPPT protocol to the individual fluid turbines 404 of the group 401 via the electronic brake control 518 to determine associated load conditions of the individual fluid turbines 404. Each of the at least one processor 512 may transmit information indicative of the associated load conditions to at least one processor 428 (e.g., associated with the group 401 of fluid turbines 404). The at least one processor 428 may subject at least one of the associated load conditions of the individual fluid turbines 404 of the group to a global constraint (e.g., maximum or minimum power output or maximum or minimum rotational speed). The at least one processor 428 may select a combination of load conditions of the individual fluid turbines 404 in the group based on the associated individual load conditions of each individual fluid turbine 404 (e.g., received from each processor 512) and application of the at least one global constraint.

[0187] In some embodiments, applying the MPPT protocol to each individual turbine includes initially testing the generator electrical output of the individual turbine under a series of different loads while each individual turbine is operating in a first fluid state. The fluid state may include a speed, direction, and / or turbulence of the fluid flow. While each individual turbine is operating in a first fluid state, it may refer to a period during which each individual fluid turbine in the group operates under a substantially uniform fluid flow (e.g., a substantially uniform fluid speed and / or direction) such that changes in an operating parameter associated with each individual fluid turbine cannot be attributed to changes in the fluid flow state. The generator electrical output may refer to electrical power generated by a generator connected to the fluid turbine by converting the mechanical rotational energy of the fluid turbine into electrical energy. Initially testing the generator electrical output may refer to measuring, receiving, assessing, inspecting, or probing electrical power before performing or implementing other procedures or actions. The series of different loads may refer to a series or sequence of different loads, e.g., a sequence of different signals, each signal configured to impose a different load on the generator. Testing the generator electrical outputs based on a series of different loads may include, for example, assessing or evaluating each electrical output in response to one or more different loads to determine a correspondence between the different loads and the electrical outputs.

[0188] 10 and 11, while each individual turbine 404 is operating at a first fluid condition (e.g., a first wind speed), at least one processor (e.g., processor 428 and / or 512) may apply an MPPT protocol to each individual fluid turbine 404 by testing each of the AC power outputs 408 (e.g., generator electrical outputs) of each of the generators 406 based on a series (e.g., at least five or at least ten) different loads. For example, the at least one processor may impose a load via each of the MPPT controls 1002.

[0189] As another non-limiting example, in FIG. 13 , while each of the group of fluid turbines 404 is operating at a first fluid state (e.g., 6 m / s), each of the at least one processor 512 (e.g., dedicated to one of the individual fluid turbines 404) may first test the AC power output 408 (e.g., generator electrical output) of each fluid turbine 404 based on a series of ten different loads imposed on each of the fluid turbines via each of the electronic brake controls 518, thereby applying an MPPT protocol to each of the fluid turbines 404.

[0190] In some embodiments, testing the generator of each individual turbine under a series of different loads includes simulating different loads of the generator and predicting the response of the generator. Simulating may refer to, for example, using at least one processor to implement an abstraction of a physical phenomenon using a model (e.g., a mathematical model). Simulating different loads of the generator may include assessing the response of the generator to different loads using a mathematical and / or computerized model of the generator (e.g., a generator output curve based on a previous physical test of the same or similar generator, etc.). Predicting may refer to, for example, anticipating, extrapolating, interpolating, and / or otherwise gauging potential outcomes based on a model or simulation. Predicting the response of the generator (e.g., connected to a fluid turbine) to different loads may include inputting different load values ​​into a model of the generator and calculating an output response value (e.g., a simulated power output) for each input load value. In some embodiments, the at least one processor may construct a power output curve for each generator using the simulated power output values.

[0191] 10 and 11, at least one processor (e.g., at least one processor 428 and / or 512) may test each of the generators 406 of each individual fluid turbine 404 by simulating different loads for each of the generators 406 and predicting the response based on a series of different loads. For example, the at least one processor may use a version of the chart 1200 for each of the fluid turbines 404 (e.g., stored in memory 430) and simulate the response of each generator 406 to a series of different loads based on the version of the chart.

[0192] As another non-limiting example, in Figures 4 and 13, the at least one processor 428 may test each of the generators 406 of each individual fluid turbine 404 by simulating different loads and predicting the response of each generator 406 based on a model stored in memory 430.

[0193] In some aspects, testing the generators of each individual turbine based on a first series of different loads includes applying different loads to each generator and measuring a response of each generator. Applying different loads to each generator may include generating a signal (e.g., a physical signal) configured to impose a different load on the generator and transmitting the generated signal to each generator. Measuring the response of each generator may include receiving a signal (e.g., a physical signal) from at least one sensor (e.g., a voltage sensor and / or a current sensor) configured with each generator (e.g., after transmitting the signal configured to impose the load) and determining a physical power output of each generator from the received signal. In some aspects, the at least one processor may store the power output of each generator in a memory. In some aspects, the at least one processor may construct a power curve for each generator using the power output.

[0194] 10 and 11 , at least one processor (e.g., at least one processor 428 and / or 512) may test each of the generators 406 of each individual fluid turbine 404 by applying different loads to each of the generators 406 via each of the MPPT controls 1002 and / or the MPPT controls configured with the inverters 434 based on a first series of different loads. The at least one processor may measure the response of each of the generators 406, for example, by measuring each of the AC power outputs 408.

[0195] As another non-limiting example, in FIG. 13 , each of the at least one processor 512 may apply different loads to each generator 406 via the electronic brake control 518 and measure the response of each generator 406 to the different loads, thereby testing each generator 406 of each individual fluid turbine 404.

[0196] In some aspects, the at least one processor is configured to receive, determine, select, and transmit continuously. Continuously may refer to an ongoing or extended period of time. The receiving, determining, selecting, and transmitting may occur at regular intervals (e.g., continuously, every fraction of a minute, every minute, every 10 minutes, every 30 minutes, or based on any other time interval). In some cases, the determining, selecting, and transmitting may occur in response to receiving notifications from one or more sensors (e.g., in response to polling one or more sensors and / or in response to receiving synchronous and / or asynchronous messages from one or more sensors). In some aspects, the at least one processor is configured to adjust for fluid conditions that vary over time. For example, the determining, selecting, and transmitting may occur in response to receiving notifications from one or more of anemometers, weather servers, weather satellites, and / or weather balloons.

[0197] 4, at least one processor (e.g., at least one processor 428 and / or processor 512) may continuously receive, determine, select, and transmit. For example, during a first time period, the fluid velocity may reach 6 m / s and at least one processor 428 may transmit a first combination of load conditions to the fluid turbine 404 (e.g., via the charge controller 410). During a second time period, the fluid velocity may change to 7 m / s and at least one processor may adjust one or more load conditions and select a second combination of load conditions for transmission to the fluid turbine 404 via the charge controller 410.

[0198] In some aspects, the upper level MPPT protocol is applied at the DC stage via a charge controller. The charge controller may refer to an electronic device configured to help ensure compliance with one or more regulations, specifications, and / or recommendations of the fluid turbine, as described elsewhere in this disclosure. The DC stage may refer to a portion of an electronic circuit configured to pass direct current. The DC stage of the circuit may be disposed downstream of a rectifier configured to convert an AC signal (e.g., the AC power output of a generator) to a DC signal. The DC stage of the circuit may be associated with at least one processor. The upper level MPPT protocol may refer to an MPPT protocol applied to a group of fluid turbines to determine a maximum (or near maximum) power point tracking of the group operating as an integrated fluid energy conversion system. The upper level MPPT protocol may encompass multiple MPPT protocols (e.g., lower level MPPT protocols) applied to each individual fluid turbine in the group. The upper level MPPT protocol may override one or more outputs of one or more lower level MPPT protocols, for example, to account for the hydrodynamic coupling of at least some of the individual fluid turbines. For example, each generator may be associated with a charge controller that includes an MPPT control unit. Each MPPT control unit may apply a (e.g., lower level) MPPT protocol to the associated generator. The at least one processor may receive signals from each MPPT control unit and determine upper level load conditions that correspond to the fleet-wide upper level MPPT protocol. The at least one processor may transmit signals to each associated charge controller configured to impose the upper level load conditions. Each of the associated charge controllers may use the signals to impose the upper level load conditions on the associated generator.

[0199] 8 , each of the rectifiers 530 may convert each of the AC power outputs 408 to a DC power output, which may be transmitted to a common charge controller 802 at the DC stage. At least one processor 428 (e.g., associated with a group 401 of fluid turbines 404) may apply a high-level MPPT protocol via the common charge controller 802 at the DC stage. The high-level MPPT protocol may affect the operation of each of the fluid turbines 404 in the group 401 to coordinate the total power output (e.g., total AC power output 722 and / or total DC power output 724) by all of the fluid turbines 404.

[0200] In some aspects, the upper level MPPT protocol is applied at the AC stage via an inverter. The inverter may refer to a device or circuit (e.g., a DC-AC converter) that converts a direct current (DC) signal to an AC signal, as described elsewhere in this disclosure. The AC stage may refer to a portion of an electronic circuit configured to have an alternating current flow through it. The AC stage of the circuit may be disposed downstream of the inverter configured to convert the DC signal to an AC signal. The circuit for the fluid turbine may include a first AC stage and a second AC stage. The first AC stage may correspond to an AC power output from the fluid turbine. The AC power output may be converted to a DC power signal (e.g., a DC stage) using a rectifier. The DC power signals may be combined in the DC stage to form a total power signal. The total DC power signal may be converted to a total AC power output corresponding to a second AC stage (e.g., downstream of the DC stage) using an inverter. The inverter may include an MPPT unit for loading the fluid turbine connected thereto. A group of geographically associated fluid turbines may be connected to a common (e.g., shared) inverter for converting a total DC power signal generated by the group to a total AC power signal (e.g., for output to a power grid). In some aspects, the shared inverter may include an MPPT unit for loading the entire group of fluid turbines according to a higher level MPPT protocol at an AC stage (e.g., second AC stage). In some aspects, a higher level MPPT protocol applied at the AC stage via an inverter associated with the group of fluid turbines may be implemented in conjunction with multiple (e.g., lower level) MPPT protocols applied to each individual fluid turbine, e.g., at the DC stage via a charge controller and / or at the AC stage (e.g., first AC stage) via electronic brake control.

[0201] 8 , each of the rectifiers 530 may convert each of the AC power outputs 408 to a DC power output signal. The DC signals may be combined into an aggregate DC signal and transmitted to the inverter 434. The inverter 434 may convert the aggregate DC signal to a total AC power output 722 (e.g., AC stage). The at least one processor 428 may apply an upper level MPPT protocol at the AC stage via the inverter 434. The upper level MPPT protocol may affect the operation of each of the fluid turbines 404 to coordinate the AC power output 722 of the aggregate (e.g., total) power of the group 401.

[0202] Some aspects include a non-transitory computer-readable medium including instructions that, when executed by at least one processor, cause the at least one processor to perform operations for coordinating MPPT operation of a group of geographically associated fluid turbines, the operations including receiving data from the group of geographically associated fluid turbines, determining changes to a total power output of the group based on changes in load conditions of the individual fluid turbines in the group, selecting a combination of load conditions of the individual fluid turbines in the group for coordinating the total power output of the group, and transmitting the selected combination of load conditions to at least some of the individual fluid turbines in the group for varying rotational speeds of at least some of the individual fluid turbines in the group.

[0203] 4-5, at least one processor (e.g., at least one processor 428 and / or 512) may perform operations to coordinate MPPT operation of the group 401 of geographically associated fluid turbines 404A-404B. The at least one processor may receive data (e.g., via each of at least one sensor 418A-418B) from the group 401 of geographically associated fluid turbines 404A-404B. The at least one processor may determine changes to the total power output 440 of the group 401 based on changes in load conditions of the individual fluid turbines 404A-404B in the group 401. The at least one processor may select a combination of load conditions of the individual fluid turbines 404A-404B in the group 401 to coordinate the total power output 440 of the group 401. The at least one processor may transmit a selected combination of load conditions to at least each individual fluid turbine 404A in the group 401 to vary a rotational speed of the at least each individual fluid turbine 404A in the group 401 .

[0204] FIG. 16 illustrates a flowchart of an example process 1600 for coordinating MPPT operation of a geographically associated group of fluid turbines consistent with aspects of the present disclosure. In some aspects, the process 1600 may be performed by at least one processor (e.g., at least one processor 428 and / or processor 512) to perform operations or functions described herein. In some aspects, some aspects of the process 1600 may be implemented as software (e.g., program code or instructions) stored in memory (e.g., memory 430 and / or memory 514) or a non-transitory computer-readable medium. In some aspects, some aspects of the process 1600 may be implemented as hardware (e.g., dedicated circuitry). In some aspects, the process 1600 may be implemented as a combination of software and hardware.

[0205] 16, the process 1600 includes receiving 1602 data from a group of geographically associated fluid turbines. As a non-limiting example, in FIG. 43, the at least one processor 428 may receive data from a group 401 of geographically associated fluid turbines 404A-404B. The process 1600 includes determining 1604 a change to a total power output of the group based on changes in load conditions of the individual fluid turbines in the group. As a non-limiting example, in FIG. 4, the at least one processor 428 may determine a change to a total power output 440 of the group 401 based on changes in load conditions of the individual fluid turbines 404A-404B in the group 401. The process 1600 includes selecting 1606 a combination of load conditions of the individual fluid turbines in the group to coordinate a total power output of the group. As a non-limiting example, in FIG. 4 , the at least one processor 428 may select a combination of load conditions for the fluid turbines 404A-404B in the group 401 to coordinate the total power output 440 of the group 401. The process 1600 includes an operation 1608 of transmitting the selected combination of load conditions to at least some of the individual fluid turbines in the group to vary a rotational speed of at least some of the individual fluid turbines in the group. As a non-limiting example, in FIG. 4 , the at least one processor 428 may transmit the selected combination of load conditions to at least one of the individual fluid turbines 404A-404B in the group 401 to vary a rotational speed of at least one of the individual fluid turbines 404A-404B in the group 401.

[0206] Fluid turbines arranged in a group may be synchronized to take advantage of the variations in output and fluid flow from other wind turbines, thereby improving the total power output. To achieve this, systems, methods, and computer program products are disclosed for coordinating the cycles of each turbine in the group by controlling one or more operating parameters. For example, controlling the load to adjust the rotational speed of one or more fluid turbines may allow the relative phase of the rotational cycles of two or more fluid turbines to be adjusted, thereby allowing the hydrodynamic coupling between them to be taken advantage of. Controllably varying the operating parameters for each turbine may allow at least some turbines to take advantage of the fluid flow and draft generated by one or more neighboring turbines in the group. For example, coordinating the blade orientation of an upstream fluid turbine may allow the upstream fluid turbine to take advantage of at least a portion of the draft generated by the downstream fluid turbine, and coordinating the blade orientation of two adjacent fluid turbines may allow each adjacent fluid turbine to mutually take advantage of at least a portion of the draft generated by the fluid turbine adjacent to each other.

[0207] Some embodiments include a system for synchronizing a plurality of geographically associated fluid turbines. The fluid turbines may include mechanical devices configured to capture energy from a fluid flow, as described elsewhere in this disclosure. The geographically associated plurality of fluid turbines may refer to a group of fluid turbines positioned relatively close to one another, as described elsewhere in this disclosure. Synchronizing the geographically associated plurality of fluid turbines may include coordinating, adjusting, and / or tuning one or more operating parameters for one or more of the geographically associated plurality of fluid turbines to achieve a targeted goal (e.g., increased total power output). Such operating parameters may be associated, for example, with a hydrodynamic coupling between two or more of the fluid turbines of the geographically associated plurality of fluid turbines. Such operating parameters may include, for example, the rotational speed and / or phase of a rotational cycle of one or more of the fluid turbines. For example, synchronization may increase and / or decrease the hydrodynamic coupling, adjust the timing (e.g., start and stop times) and / or duration of the hydrodynamic coupling, and / or affect any other characteristic of the hydrodynamic coupling between at least two of the fluid turbines of the geographically associated plurality of fluid turbines.

[0208] As a non-limiting example, the fluid energy conversion system 400 of Figures 4-5, in conjunction with the braking circuit 1300 of Figure 13, collectively illustrate a system for synchronizing multiple geographically associated fluid turbines 404.

[0209] Some embodiments include at least one processor, which may include a single processor or multiple processors communicatively linked to one another for controlling operation of multiple geographically associated fluid turbines to collectively operate as a single fluid energy conversion system, for example as described elsewhere in this disclosure.

[0210] Some aspects include receiving a signal indicative of a phase of a rotational cycle of a plurality of rotating blades of a fluid turbine of a geographically associated plurality of fluid turbines. The signal may refer to information encoded for transmission over a physical medium, as described elsewhere in this disclosure. Receiving a signal (e.g., from a sensor) may include periodically polling for an output signal, as described elsewhere in this disclosure, and / or receiving the signal as an asynchronous event, such as a synchronous event and / or a real-time interrupt event. A rotational cycle of a plurality of rotating blades of a fluid turbine may refer to one of a series of repeating rotations (e.g., a full 360° rotation) by the plurality of blades of the fluid turbine spinning in response to a fluid flow. A phase of a rotational cycle may refer to a particular stage or position within a rotation of the series of repeating rotations. A phase of a rotational cycle may be measured as an angle, e.g., in degrees, radians, minutes, and / or seconds. For example, when measured in degrees, a full rotation may correspond to 360°, a quarter of a counterclockwise rotation may correspond to a 90° phase, and a quarter of a clockwise rotation may correspond to a -90° phase. A blade may refer to an object having a cross-sectional shape with a curved surface configured to induce a rotational motion coincident with a fluid flow incident on the blade, as described elsewhere in this disclosure. A plurality of rotating blades of a fluid turbine may include a plurality of blades that can rotate or spin. A phase of a rotation cycle of a plurality of rotating blades of a fluid turbine may refer to a position of the plurality of blades within a rotation cycle. A phase in a rotation cycle of a plurality of blades may indicate an absolute position and / or a relative position of each of the blades with respect to one or more other objects, such as a sensor configured with a connected fluid turbine, and / or one or more blades of another fluid turbine. The phase of the rotation cycle, together with the rotation speed, may enable tracking of a distance and / or an orientation between any one blade (e.g., or a particular region on any one blade) and one or more other objects over time. At least one processor may receive signals from at least one sensor associated with the fluid turbine.

[0211] In some aspects, the at least one processor may receive a first signal indicative of a phase of a rotational cycle of a first plurality of rotating blades of a first fluid turbine of the geographically associated plurality of fluid turbines and may receive a second signal indicative of a phase of a rotational cycle of a second plurality of rotating blades of a second fluid turbine of the geographically associated plurality of fluid turbines. For example, a first processor associated with the first fluid turbine may receive a first signal from one or more sensors associated with at least one blade of the first fluid turbine and a second sensor associated with the second fluid turbine may receive a second signal from one or more sensors associated with at least one blade of the second fluid turbine. The first processor and the second processor may each transmit the first and second signals to at least one processor configured to synchronize operation of the first and second fluid turbines to operate as an integrated fluid energy conversion system.

[0212] As a non-limiting example, in FIGS. 4-5, for each fluid turbine 404A, 404B, at least one processor (e.g., each processor 512 dedicated to each of the fluid turbines 404A, 404B and / or processor 428 associated with group 401) may receive a signal from at least one sensor 418A, 418B, respectively. The signal may be indicative of a phase rotation cycle of a plurality of blades (see, e.g., blades 206, 208 in FIG. 2) of each fluid turbine 404A, 404B. For example, the at least one sensor 418 may include a rotation sensor 502 for measuring the rotational speed of each fluid turbine 404A, 404B. The rotation sensor 502 may include, for example, an internal measurement unit (e.g., an IMU) that allows for tracking the orientation of each of the plurality of blades of the fluid turbines 404A, 404B over time. The at least one processor may use the tracked orientation of each of the first and second pluralities of blades to determine a phase of a rotational cycle, for example, relative to a stationary object and / or relative to each other.

[0213] In some aspects, the first plurality of rotating blades are configured to generate a fluid flow downstream of the first fluid turbine. Downstream may refer to a relative position in the direction of the fluid flow where the fluid may reach a downstream position from an upstream position. An object located downstream may encounter the fluid flow after an object located upstream. A downstream fluid flow may refer to a fluid flowing from an upstream position to a downstream position. A fluid flow downstream of a fluid turbine may refer to a downstream fluid flow caused or generated by the rotating blades of a fluid turbine located beyond the rotating blades of an upstream turbine or upstream of another object (e.g., upstream of another fluid turbine located downstream). For example, the rotating blades of an upstream fluid turbine may generate turbulence and / or draft that may alter the fluid passing beyond the upstream fluid turbine.

[0214] As a non-limiting example, refer to FIG. 17 illustrating fluid flow of a plurality 1700 geographically associated fluid turbines 1702, 1704, 1706 consistent with certain aspects of the disclosure. Each of the fluid turbines 1702, 1704, 1706 includes a plurality of blades 1708A, 1708B, a plurality of blades 1710A, 1710B, and a plurality of blades 1712A, 1712B, respectively. In some aspects, the fluid turbines 1702, 1704, 1706 may correspond to the fluid turbine 404 (see, e.g., FIG. 4). Thus, each of the fluid turbines 1702, 1704, 1706 may be associated with a generator (e.g., generator 406), at least one sensor (e.g., at least one sensor 418), at least one processor (e.g., at least one processor 308, 428, and / or 512), and a charge controller (e.g., charge controller 410). In some aspects, the fluid turbines 1702, 1704, 1706 may correspond to the fluid turbines 100A, 100B, 100C (see, e.g., FIG. 2). A plurality of blades 1710A, 1710B of the fluid turbine 1704 may generate fluid flows 1714, 1716 downstream of the fluid turbine.

[0215] In some embodiments, the second plurality of rotating blades is configured to receive at least a portion of the fluid flow downstream of the first fluid turbine. The plurality of blades configured to receive the fluid flow may refer to the blades of the fluid turbine that are shaped, rotationally phased, and / or oriented to capture or interact with the fluid flow to create a pressure differential on opposing sides of each blade and move the plurality of blades in a spinning motion. Receiving at least a portion of the flow downstream of the fluid turbine may refer to capturing or interacting with at least a portion of the turbulence and / or draft generated by the upstream-located fluid turbine. For example, the ambient fluid flow (e.g., wind or ocean currents) may spin the blades of the upstream fluid turbine. The spinning motion of the upstream-located blades may generate turbulence and / or draft (e.g., the fluid flow downstream of the fluid turbine). The blades of the fluid turbine disposed downstream of the upstream fluid turbine may capture or interact with the ambient fluid flow that affects the upstream fluid turbine, and may further capture or interact with at least a portion of the downstream flow of the fluid turbine generated by the blades disposed upstream. In other words, due to the hydrodynamic coupling between the upstream and downstream fluid turbines, the downstream fluid turbine may be influenced by the downstream flow of the fluid turbine generated by the upstream fluid turbine in addition to being influenced by the ambient flow fluid. The downstream flow of the fluid turbine (e.g., hydrodynamic coupling) may affect the characteristics of the rotation of the blades of the downstream fluid turbine. Such characteristics may include, for example, the rotational speed (e.g., an increase or decrease in the rotational speed), the phase of the rotational cycle (e.g., relative phase and / or absolute phase), the direction of rotation (e.g., clockwise or counterclockwise rotation), the stationary (e.g., regular) or unsteady (e.g., irregular) rotation (e.g., caused by vibration of multiple blades of a downstream fluid turbine), and / or any other characteristic of the rotation of multiple blades of a fluid turbine.

[0216] 17, the blades 1708A, 1708B of the fluid turbine 1702 (e.g., the second blades of the second fluid turbine) may be positioned downstream of the blades 1710A, 1710B of the fluid turbine 1704 (e.g., the first blades of the first fluid turbine) with respect to an ambient fluid flow 1718 (e.g., atmospheric wind or ocean current). The blades 1708A, 1708B of the fluid turbine 1702 may receive the ambient fluid flow 1718 and may further receive at least a portion of the fluid turbine downstream fluid flow 1714 (e.g., the fluid flow of the first fluid turbine) generated by the first blades 1710A, 1710B of the first fluid turbine 1704. Similarly, the blades 1712A, 1712B of the fluid turbine 1706 may be positioned downstream of the first plurality of blades 1710A, 1710B of the first fluid turbine 1704 and may receive the ambient fluid flow 1718 and at least a portion of the fluid turbine downstream fluid flow 1716 generated by the first plurality of blades 1710A, 1710B of the first fluid turbine 1704.

[0217] In some aspects, the second plurality of rotating blades are configured to generate a differential power output that can be attributed to at least a portion of the fluid flow downstream of the first fluid turbine. The differential power output can refer to the difference (e.g., delta) between two different power outputs. The differential power output can be an absolute difference and may not indicate which of the two power outputs is larger and which is smaller. Attributable can refer to, for example, originating from, caused by, or otherwise associated with another source or operation. The differential power output that can be attributed to at least a portion of the fluid flow downstream of the fluid turbine can refer to a differential power output (e.g., positive or negative) of the downstream fluid turbine that can originate from, caused by, or otherwise associated with turbulence and / or draft generated by the upstream fluid turbine. For example, a hydrodynamically isolated fluid turbine can generate a first power output under an ambient fluid flow. By positioning a fluid turbine downstream of an upstream fluid turbine (e.g., under the same ambient fluid flow) to create a hydrodynamic coupling therebetween, the downstream fluid turbine may be influenced by at least a portion of the downstream fluid flow generated by the upstream fluid turbine. Thus, the downstream fluid turbine may generate a second power output that is different from the first power output. The difference between the second power output and the first power output may be attributable in part to the turbulence of the draft generated by the upstream fluid turbine.

[0218] 17 , the plurality of rotating blades 1708A, 1708B of the fluid turbine 1702 (e.g., a second plurality of rotating blades of a second fluid turbine) may generate a differential power output that may be attributable to at least a portion of a fluid turbine downstream fluid flow 1714 generated by the first plurality of blades 1710A, 1710B of the first fluid turbine 1704. Similarly, the plurality of rotating blades 1712A, 1712B of the fluid turbine 1706 may generate a differential power output that may be attributable to at least a portion of a fluid turbine downstream fluid flow 1716 generated by the first plurality of blades 1710A, 1710B of the first fluid turbine 1704.

[0219] 18 , which illustrates an example graph 1800 of periodic power outputs 1802, 1804 over time, consistent with certain aspects of the present disclosure. The power output 1804 may be greater than the power output 1802. The power output 1802 may correspond to an AC power output of a generator associated with a second plurality of rotating blades of a second fluid turbine that may be attributable (e.g., solely) to the ambient fluid flow 1718. For example, the second plurality of rotating blades of the second fluid turbine may correspond to the plurality of blades 1708A, 1708B of the fluid turbine 1702 or the plurality of blades 1712A, 1712B of the fluid turbine 1706. The greater power output 1804 may correspond to an AC power output of a generator associated with the second plurality of rotating blades that may be attributable to the ambient fluid flow 1718 and further attributable to at least a portion of the first fluid turbine downstream fluid flow (e.g., fluid turbine downstream flow 1714 or 1716) generated by the first plurality of blades 1710A, 1710B of the first fluid turbine 1704. The differential power output 1806 may be attributable to at least a portion of the first fluid turbine downstream fluid flow (e.g., fluid turbine downstream flow 1714 or 1716) received by the first plurality of rotating blades (e.g., blades 1708A, 1708B, or blades 1712A, 1712B, respectively). For example, the differential power output 1806 may correspond to the peak-to-peak or trough difference between the (e.g., AC) power output 1802 and a larger power output 1804, the average difference between the power outputs 1802, 1804, or any other measure of difference between the power outputs 1802, 1804. In some embodiments, the power output 1804 may correspond to the total AC power output 722 (see, e.g., FIGS. 7-11).

[0220] In some aspects, the first fluid turbine is disposed upstream of the second turbine. Upstream may refer to a relative position in a fluid stream where the fluid may flow from an upstream location to a downstream location. An object disposed upstream may encounter the fluid stream before an object disposed downstream. The first fluid turbine may receive the fluid stream before the second fluid turbine. The first fluid turbine may generate a fluid stream downstream of the first fluid turbine from the received fluid stream such that the second fluid turbine may receive both the fluid stream and at least a portion of the fluid stream downstream of the first fluid turbine.

[0221] As a non-limiting example, the first fluid turbine 1704 may be positioned upstream of the fluid turbine 1702 and the fluid turbine 1706 with respect to the fluid flow 1718 .

[0222] In some aspects, the geographically associated fluid turbines are wind turbines and the fluid is an airflow. A wind turbine may include a fluid turbine configured to convert wind (e.g., airflow) into electrical energy via a generator connected thereto. An airflow may refer to the flow of air (e.g., the movement of air) from one location to another. An airflow may be associated with a direction that indicates a trajectory of motion.

[0223] In some aspects, the geographically associated plurality of fluid turbines are hydro turbines and the fluid is flowing water. The hydro turbine may include a fluid turbine configured to convert the flow of water into electrical energy via a generator connected thereto. The flowing water may include ocean currents, river currents, waterfalls, and / or any other movement of water from one location to another. The flowing water may be associated with a direction indicative of a locus of motion.

[0224] In some embodiments, the rotational axis of the first and second fluid turbines is substantially vertical. In some embodiments, the rotational axis of the first and second fluid turbines is substantially horizontal. The rotational axis of the fluid turbine may be defined by a shaft, rod, or line about which the rotating elements of the fluid turbine rotate. Vertical may refer to being substantially perpendicular to the ground and / or fluid flow. A vertical fluid turbine (e.g., VAWT) may refer to a fluid turbine in which the rotational axis of the turbine blades may be substantially perpendicular to the ground and / or fluid flow. Horizontal may refer to being parallel to the fluid flow and / or ground. A horizontal fluid turbine (e.g., HAWT) may refer to a fluid turbine in which the rotational axis of the turbine blades may be substantially parallel to the ground and / or fluid flow.

[0225] In some embodiments, each blade of the first and second plurality of blades is a lift blade. A lift blade may refer to a blade configured to generate lift by, for example, having a curved surface to generate a lower fluid pressure from a fluid flow and an opposing flatter surface to generate a higher fluid pressure from the fluid flow. The pressure differential may generate a lift force perpendicular to the direction of the fluid flow.

[0226] As a non-limiting example, the plurality 1700 of fluid turbines 1702, 1704, 1706 may be wind turbines (e.g., see fluid turbines 100, 102, and 106-112 of FIG. 1 ) and the fluid flow 1718 may be an air current (e.g., wind). Alternatively, the plurality 1700 of fluid turbines 1702, 1704, 1706 may be water turbines (e.g., see fluid turbine 104) and the fluid flow 1718 may be flowing water (e.g., ocean or river currents). In some embodiments, at least a portion of the plurality 1700 of fluid turbines 1702, 1704, 1706 may be vertical fluid turbines (e.g., see vertical axis fluid turbines 100, 106-112). Alternatively, at least some of the fluid turbines 1702, 1704, 1706 of the plurality 1700 may be horizontal fluid turbines (see, e.g., horizontal fluid turbine 102). In some aspects, each blade of the first plurality of blades 1710A, 1710B and each blade of the plurality of blades 1708A, 1708B (e.g., second plurality of blades) may be a lift blade. Similarly, each blade of the plurality of blades 1712A, 1712B may be a lift blade.

[0227] In some embodiments, the first and second fluid turbines are similarly shaped. Similar shapes may refer to having components of substantially the same size, design, and / or relative arrangement. For example, the first and second fluid turbines may both be vertical axis type fluid turbines or both horizontal axis type turbines. As another example, the first and second fluid turbines may have the same number of rotating blades, each of which has a substantially similar airfoil shape.

[0228] As a non-limiting example, in FIG. 3, each of the fluid turbines 100A, 100B, 100C may be similarly shaped.

[0229] In some embodiments, the first signal and the second signal are image signals received from at least one image sensor. The image signal may include an electronic signal associated with data formatted according to a protocol associated with image or video data (e.g., JPEG, PNG, MP5). An image sensor may refer to a device that captures light and converts it into an electronic signal. Non-limiting examples of image sensors include cameras, CCDs, CMOS, CIDs, InGaAs, rolling shutters, and global shutters. The image sensor may operate in the visible spectrum and / or the IR spectrum. The image sensor may convert an image formed on the image sensor plane into an image signal for transmission to at least one processor. The at least one image sensor may be fixed (e.g., attached to a generator associated with a plurality of rotating blades) and / or may rotate (e.g., attached to one or more blades or a rotatable shaft connected to the blades). The at least one image sensor may, for example, capture a sequence of images over a period of time of the multiple rotating blades relative to one or more additional objects (e.g., a stationary object, such as a generator connected to the rotating blades, and / or a rotating object, such as another multiple rotating blades). The at least one processor may analyze the image signals received from the at least one image sensor to determine a phase of the rotational cycle of the multiple blades (e.g., using one or more image processing techniques, such as edge detection, object recognition, convolution, Fourier transform, and / or any other image processing technique), where the phase may be relative to the one or more objects captured in the image signals. Additionally or alternatively, the at least one image sensor may be associated with a magnetometer (e.g., a compass), enabling the at least one processor to determine the phase of the rotational cycle of the multiple blades based on the image signals together with signals from the magnetometer.

[0230] As a non-limiting example, in Figures 4-5, at least one processor (e.g., at least one processor 308, 428 and / or 512) may receive image signals from at least one image sensor 524 associated with each of the fluid turbines 404A, 404B.

[0231] As another non-limiting example, see FIG. 19 , which illustrates a sequence 1900 of image signals 1902-1916 (e.g., images) of a plurality of blades of a fluid turbine rotating over a period of time, consistent with certain aspects of the present disclosure. The image signals 1902-1916 may be acquired with at least one image sensor 524. The fluid turbine depicted in the image signals 1902-1916 may correspond to any of the fluid turbines 100A-100C, the fluid turbine 404, and / or the fluid turbines 1702, 1704, 1706. The rotation of the plurality of blades depicted over time in the image signals 1902-1916 may be clockwise and may generate a periodic power output 1802 and / or 1804. From left to right and top to bottom, at least one processor (e.g., at least one processor 308, 512 and / or 428) may determine from image signals 1902-1916 a rotational phase of a plurality of blades depicted therein, beginning at 0° (e.g., image signal 1902) and increasing to 10° (e.g., image signal 1904), 30° (e.g., image signal 1906), 45° (e.g., image signal 1908), 60° (e.g., image signal 1910), 90° (e.g., image signal 1912), 135° (e.g., image signal 1914), and 155° (e.g., image signal 1916). Upon reaching a full rotation (e.g., a phase of 360°), the at least one processor may reset the phase to 0° and repeat the process. The at least one processor may receive a version of sequence 1900 for each fluid turbine of the plurality of fluid turbines. For example, at least one processor may receive a version of sequence 1900 for each of the fluid turbines 1702, 1704, 1706, enabling the at least one processor to analyze each version of sequence 1900 to determine the phase of the rotational cycle of each of the fluid turbines 1702, 1704, 1706 and determine the relative phase shift therebetween.

[0232] Some embodiments include determining from the first signal and the second signal that a greater total power output is achievable through blade phase coordination. Blade phase coordination may include one or more of adjusting, aligning, and / or positioning the (e.g., relative) phases of the rotational cycles of the blades of the at least two fluid turbines to cause the at least two fluid turbines to operate in a coordinated manner (e.g., as an integrated fluid energy conversion system). Blade phase coordination may be achieved, for example, by slowing down and / or accelerating the rotational speed of at least one of the at least two fluid turbines for at least a limited period of time. Blade phase coordination between the first and second plurality of blades (e.g., rotating at a substantially similar rotational speed) may enable a target distance and / or orientation between at least one blade (e.g., or a particular region on at least one blade) of the first plurality of blades and at least one blade (e.g., or a particular region on at least one blade) of the second plurality of blades to be maintained over time. A total power output (e.g., total power signal) may refer to a power signal output (e.g., generated) by combining multiple power signals originating from different power sources (e.g., generators) into a single composite power signal. For example, a total power output may be generated by converting multiple AC power outputs from multiple fluid turbines into multiple DC power signals, combining the multiple DC power signals into a total DC power output, and optionally converting the total DC power output into a total AC power output using an inverter. A greater total power output may include an increased total power output, a target power output value (e.g., a minimum power output value), a target range of power output, a statistical measure of the target power output over time (e.g., the average, mode, and / or standard deviation of the total power output over a period of time), and / or any other measure of a total power output that is greater than the total power output achieved, for example, before implementing phase correction. Achievable (e.g., to be achieved) may include reachable, feasible, and / or capable of being implemented to achieve a desired result.Determining from the signal that a greater total power output is achievable through blade phase coordination may include using the received signal to perform one or more measurements, comparisons, simulations, estimates, and / or calculations indicating that a greater total power output and / or a potentially greater total power output is achievable. For example, the at least one processor may apply blade phase coordination to the geographically associated multiple fluid turbines and measure a total power output by the geographically associated multiple fluid turbines that have received the blade phase coordination. The at least one processor may compare the measured total power output under the blade phase coordination to a total power output by the geographically associated multiple fluid turbines prior to applying the blade phase coordination. Based on the comparison, the at least one processor may determine whether a greater total power is achievable through the blade phase coordination. In some aspects, the at least one processor may apply a series of different blade phase coordination to the geographically associated multiple fluid turbines and perform a series of measurements of the different total power output under each different blade phase coordination, followed by a series of comparisons (e.g., iteratively) to determine a particular blade phase coordination associated with a maximum (e.g., or near maximum) total power output. In some aspects, the at least one processor may simulate application of one or more blade phase coordination on the geographically associated multiple fluid turbines and calculate one or more potential total power outputs attributable to the simulated blade phase coordination to determine whether a greater total power output is achievable by applying one or more of the simulated blade phase coordination to the geographically associated multiple fluid turbines. In some aspects, the at least one processor may calculate one or more potential total power outputs attributable to the one or more simulated blade phase coordination using one or more charts (e.g., see FIG. 12 ) that compare power output to rotational speeds associated with one or more of the geographically associated multiple fluid turbines.

[0233] 17 and 18, at least one processor (e.g., at least one processor 308, 512 and / or 428) may determine from the first signal and the second signal that a greater total power output is achievable through blade phase coordination. For example, referring to FIG. 19, at least one processor may identify a fluid flow 1714, 1716 downstream of one or more fluid turbines that is greater than a fluid flow 1920 downstream of one or more smaller fluid turbines generated by the first fluid turbine 1704. The at least one processor may determine that the phase of the downstream fluid turbine 1702 causes the blades 1708A, 1708B to capture (e.g., or not capture) a small portion of the fluid turbine's downstream fluid flow 1714 and instead capture a larger portion of the smaller fluid turbine's downstream fluid flow 1920. Similarly, the phasing of the downstream fluid turbine 1706 may cause the blades 1712A, 1712B to capture (e.g., or not capture) a small portion of the fluid flow 1716 downstream of the fluid turbine and instead capture a larger portion of the fluid flow 1920 downstream of the smaller fluid turbine. The at least one processor may determine that the blade phase coordination may enable the blades 1708A, 1708B to be positioned and / or oriented relative to the blades 1710A, 1710B such that the blades 1708A, 1708B capture a larger portion of the fluid flow 1714 downstream of the larger fluid turbine. Similarly, the at least one processor may calculate the blade phase coordination of the blades 1712A, 1712B. At least one processor may determine that by enabling multiple blades 1708A, 1708B and multiple blades 1712A, 1712B to each capture a larger portion of the fluid flow 1714, 1716 downstream of the fluid turbine (e.g., via blade phase coordination), the geographically associated multiple fluid turbines 1700 may achieve a greater total power output.

[0234] Refer to FIG. 20, which illustrates a chart 2000 of total power output 2002 versus the number of fluid turbines 2004 included in a geographically associated plurality of fluid turbines consistent with certain aspects of the present disclosure. The chart 2000 illustrates that as the number of fluid turbines 2004 increases linearly (e.g., more than three fluid turbines), the total power output 2002 may increase non-linearly. The non-linear increase may be attributed to the hydrodynamic coupling between four or more individual fluid turbines in the group, which may be synchronized or coordinated by blade phase coordination. For example, a single fluid turbine (e.g., operating independently) may generate a power output of 36.5 watts, whereas a group of five geographically associated fluid turbines may generate a total power output of 417 watts, leading to a total power increase of 128%. The total power increase may be attributed to the hydrodynamic coupling and blade phase coordination between the individual fluid turbines in the group.

[0235] Refer to FIG. 21, which illustrates a chart 2100 of average power output 2002 versus the number 2004 of fluid turbines included in a geographically associated plurality of fluid turbines consistent with certain aspects of the present disclosure. The chart 2100 illustrates that as the number 2104 of fluid turbines increases linearly (e.g., more than three fluid turbines), the average power output 2102 may increase non-linearly. The non-linear increase may be attributed to hydrodynamic coupling between four or more individual fluid turbines in a group, which may be synchronized or coordinated by blade phase coordination. For example, a single fluid turbine (e.g., operating independently) may generate an average power output of 36.5 watts, whereas a group of five geographically associated fluid turbines may generate a total output of 83.4 watts, leading to a total power increase of 128%. The total power increase may be attributed to hydrodynamic coupling and blade phase coordination between the individual fluid turbines in the group.

[0236] Some embodiments include determining a phase correction between the first and second plurality of rotating blades based on the first and second signals to achieve a greater total power output. The phase correction between the first and second plurality of rotating blades may refer to an adjustment or modification of the relative phase between the first and second plurality of rotating blades to produce a corrected relative phase therebetween. For example, prior to the phase correction, the relative phase between the first and second plurality of rotating blades may be 45°. A phase correction of 15° (e.g., counterclockwise) may change the relative phase between the first and second plurality of rotating blades to 60°, whereas a phase correction of -15° (e.g., clockwise) may change the relative phase between the first and second plurality of rotating blades to 30°. Implementing the phase correction may include adjusting the rotational speed of at least one of the fluid turbines (e.g., over a limited period of time). For example, if the first and second fluid turbines are rotating at substantially the same rotational speed, the at least one processor may slow down and / or accelerate the rotational speed of at least one of the fluid turbines until a targeted phase between the first and second plurality of rotating blades is achieved. Ceasing the slowing down and / or accelerating of at least one of the fluid turbines may allow the first and second plurality of rotating blades to resume rotation at substantially the same rotational speed, thereby maintaining the corrected phase therebetween. In some aspects, implementing the phase correction may include adjusting the rotational speed of at least one of the fluid turbines over an extended period of time. For example, if the first and second fluid turbines are rotating at substantially different rotational speeds, after implementing the phase correction, the at least one processor may continuously accelerate and / or decelerate at least one of the fluid turbines to rotate the first and second plurality of blades at substantially the same rotational speed to maintain the phase correction over time. Achieving a greater total power output may refer to realizing or achieving an increase (e.g., a targeted increase) in the total power output.In some aspects, achieving a greater total power output may include utilizing or reducing (e.g., suppressing) the effect of hydrodynamic coupling between the first and second plurality of rotating blades via phase correction. For example, if a differential power output attributable to a portion of the fluid flow downstream of the first fluid turbine is positive, a phase correction configured to utilize hydrodynamic coupling between the first and second plurality of rotating blades may facilitate achieving a greater total power output. Alternatively, if a differential power output attributable to a portion of the fluid flow downstream of the first fluid turbine is negative, a phase correction configured to suppress at least a portion of the hydrodynamic coupling between the first and second plurality of rotating blades may facilitate achieving a greater total power output.

[0237] 17 , at least one processor (e.g., at least one processor 308, 428 and / or 512) may determine a phase correction 1720 between the first plurality of rotating blades 1710A, 1710B and the second plurality of rotating blades 1708A, 1708B based on the first signal and the second signal to achieve a greater total power output including, for example, a greater power output 1804 instead of the power output 1802. For example, temporarily slowing down and / or increasing the rotational speed of the first plurality of rotating blades 1710A, 1710B and / or the second plurality of rotating blades 1708A, 1708B to introduce the phase correction 1720 may enable the second plurality of rotating blades 1708A, 1708B to capture a greater portion of the fluid flow 1714 downstream of the fluid turbine and a smaller portion of the fluid flow 1920 downstream of the smaller fluid turbine. By capturing a larger portion of the fluid flow 1714 downstream of the fluid turbine, the second fluid turbine 1702 may be rotated at an increased speed and / or comply with an MPPT protocol, thereby achieving a larger total power output (e.g., total power output 440 of FIG. 4 and total AC power output 722 and / or total DC power output 724 of FIGS. 7-11). For example, the phase correction 1720 may correspond to a relative phase shift of 10° (e.g., in a counterclockwise direction). Similarly, the at least one processor may calculate a blade phase coordination 1722 of the fluid turbine 1706 (e.g., corresponding to a relative clockwise phase shift of −20°).

[0238] Some embodiments include calculating a coordination signal based on the determined phase correction. Calculating the coordination signal may include performing one or more mathematical and / or logical operations to determine a signal configured to facilitate, generate, or otherwise effect coordinated operation of two or more fluid turbines. Calculating the coordination signal based on the phase correction may include calculating a coordination signal configured to implement the phase correction, for example, by applying a load to one or more generators associated with the first fluid turbine and / or the second fluid turbine. The load may adjust (e.g., temporarily) a rotational speed of the first fluid turbine and / or the second fluid turbine to impose the phase correction therebetween.

[0239] 17, at least one processor (e.g., at least one processor 308, 428 and / or 512) may calculate a coordination signal based on the determined phase corrections 1720, 1722. For example, the coordination signal may correspond to temporarily increasing and / or decreasing the load on the fluid turbines 1702, 1706.

[0240] Some embodiments include outputting a coordination signal to impose a phase correction and thereby achieve a greater total power output. Outputting a coordination signal to impose a phase correction may include transmitting one or more electronic signals configured to cause a phase correction between the first plurality of rotating blades and the second plurality of rotating blades. The at least one processor may transmit the coordination signal to a braking system (e.g., a mechanical and / or electronic braking system) using one or more wired and / or wireless communication links. For example, the at least one processor may transmit a coordination signal indicative of a load (e.g., a positive or negative load) to one or more charge controllers associated with the first plurality of blades and / or the second plurality of blades. The at least one charge controller may adjust the load associated with the first plurality of blades and / or the second plurality of blades according to the coordination signal, for example using an electronic braking system.

[0241] 13 and 17, at least one processor (e.g., at least one processor 428 and / or 512) may output a coordination signal via the braking circuit 1300. For example, each of the fluid turbines 1702, 1704, 1706 may be associated with a version of the braking circuit 1300. The version of the braking circuit 1300 associated with the fluid turbine 1702 may impose a phase correction 1720, and the version of the braking circuit 1300 associated with the fluid turbine 1706 may impose a phase correction 1722.

[0242] In some aspects, the at least one processor is further configured to receive a third signal indicative of a phase of a rotational cycle of a third plurality of rotating blades of a third fluid turbine of the geographically associated plurality of fluid turbines, the third plurality of rotating blades being configured to generate a fluid flow downstream of the third fluid turbine; and a fourth signal indicative of a phase of a rotational cycle of a fourth plurality of rotating blades of a fourth fluid turbine of the geographically associated plurality of fluid turbines, the fourth plurality of rotating blades being configured to receive at least a portion of the fluid flow downstream of the third fluid turbine and generate a differential power output attributable to at least a portion of the fluid flow downstream of the third fluid turbine, wherein calculating the coordination signal is further based on the third signal and the fourth signal, wherein the coordination signal is further configured to impose an additional phase correction between the third plurality of rotating blades and the fourth plurality of rotating blades to achieve a greater total power output, and wherein outputting the coordination signal is further configured to impose the additional phase correction, thereby achieving a greater total power output. For example, receiving, calculating, and outputting for the third and fourth fluid turbines may include performing substantially similar functions as described elsewhere in this disclosure with respect to the first and second fluid turbines.

[0243] 22, which illustrates a schematic diagram of an exemplary fleet 2200 of fluid turbines consistent with certain aspects of the present disclosure. The fleet 2200 includes at least four geographically associated fluid turbines 2202, 2204, 2206, 2208 (e.g., each corresponding to any of the fluid turbines 404 and / or 1702, 1704, 1706). As such, each of the fluid turbines 2202, 2204, 2206, 2208 may be associated with a generator (e.g., the generator 406), at least one sensor (e.g., the at least one sensor 418), at least one processor (e.g., at least one processor 308, 428 and / or 512), and a charge controller (e.g., the charge controller 410). The fluid turbines 2202, 2204 may correspond to a first fluid turbine and a second fluid turbine, respectively, and the fluid turbines 2206, 2208 may correspond to a third fluid turbine and a fourth fluid turbine, respectively. The at least one processor may receive a third signal (e.g., see image signal 1900 of FIG. 19 ) indicative of a phase of a rotational cycle of the third plurality of rotating blades 2210. The third plurality of rotating blades 2210 may generate a fluid flow 2212 downstream of the third fluid turbine. The at least one processor may receive a fourth signal (e.g., see image signal 1900 of FIG. 19 ) indicative of a phase of a rotational cycle of the fourth plurality of rotating blades 2214 of the fourth fluid turbine 2208 of the geographically associated plurality of fluid turbines 2200. The fourth plurality of rotating blades 2214 may receive at least a portion of the fluid flow 2212 downstream of the third fluid turbine and may generate a differential power output (e.g., see differential power output 1806 in FIG. 18 ) that can be attributed to at least a portion of the fluid flow 2212 downstream of the third fluid turbine.

[0244] The at least one processor may further calculate a coordination signal based on the third signal and the fourth signal. The coordination signal may impose an additional phase correction 2216 between the third plurality of rotating blades 2210 and the fourth plurality of rotating blades 2214 to achieve a greater total power output. Outputting the coordination signal may impose the additional phase correction 2216, thereby achieving a greater total power output.

[0245] In some aspects, the coordination signal is configured to generate a load to slow down the rotation of at least one of the first and second plurality of blades for a limited period of time, thereby imposing a first phase correction between the first and second plurality of blades. A load (e.g., an electrical load) may refer to an impedance or a resistance. Such a load may be imposed on the generator (e.g., and a fluid turbine connected to the generator) to slow down the rotation of the generator and / or the fluid turbine connected to the generator. Generating the load may include drawing at least a portion of the electrical energy generated by the generator to an energy sink. Drawing more electrical energy (e.g., increasing the load) may increase the impedance and slow down the rotational speed of the fluid turbine. Drawing less electrical energy (e.g., decreasing the load) may decrease the impedance and increase the rotational speed of the fluid turbine. The coordinated signal configured to generate a load to slow down the rotation of the blades (e.g., of a fluid turbine) may include an electronic signal (e.g., transmitted by at least one processor) instructing the electronic braking system and / or the charge controller to divert (e.g., or increase the amount diverted) electrical energy generated by the rotation of the blades to an energy sink. Diverting the electrical energy may introduce an impedance that may slow down the rotation of the blades. The limited time period may refer to a delimited or limited duration. Generating a load to slow down the blades for a limited time period may include introducing a load by diverting electrical energy generated by a generator connected to the blades, and removing the load when the limited time period ends, for example, by ceasing to divert the electrical energy. Generating a load to slow down the blades for a limited time period may temporarily slow down the rotation of the blades to introduce a phase shift relative to another blade.By removing the load when the limited time period expires, the plurality of blades may resume their previous rotational speed (e.g., before generating the load) to maintain the phase shift between the first and second plurality of blades.

[0246] In some aspects, the coordination signal is configured to modify an application of a load to at least one generator connected to at least one of the first and second fluid turbines. Modifying the application of the load to the generator may include changing, adjusting, tuning, and / or otherwise modifying the load imposed on the generator, for example, by modifying the level of power diverted from the generator, modifying the impedance imposed on the generator, and / or adjusting the load imposed on the generator using any other technique. Modifying the application of the load to the generator may cause a corresponding modification to the rotational speed of the rotor of the generator. Increasing the load applied to the generator may cause the rotational speed to increase, and decreasing the load may cause the rotational speed to increase. Increasing or decreasing the rotational speed of the generator may cause a corresponding increase or decrease in the rotational speed of the fluid turbine connected to the generator.

[0247] 17, at least one processor (e.g., at least one processor 308, 428 and / or 512) may calculate a coordination signal to generate a load to slow down the rotation of at least one of the first plurality of blades 1710A, 1710B and the second plurality of blades 1708A, 1708B for a limited period of time. For example, the at least one processor may transmit a coordination signal to a charge controller (e.g., see charge controller 410 of FIG. 4) associated with each of the first plurality of blades 1710A, 1710B and the second plurality of blades 1708A, 1708B. The coordination signal may impose a first phase correction 1720 between the first plurality of blades 1710A, 1710B and the second plurality of blades 1708A, 1708B. In some aspects, the coordination signal may modify the application of a load to a generator (e.g., generator 406) connected to at least one of the first fluid turbine 1704 and the second fluid turbine 1706. For example, the coordination signal may increase or decrease the load, modify a start or end time for applying the load, extend or shorten the duration for applying the load, and / or introduce any other modification to the load.

[0248] In some aspects, the coordination signal is configured to reduce a load, thereby accelerating the rotation of at least one of the first and second plurality of blades for a limited period of time, thereby imposing a first phase correction between the first and second plurality of blades. Reducing the load (e.g., on the generator and / or the fluid turbine connected to the generator) may include reducing an imposed impedance, for example, by reducing an amount of energy diverted to an energy sink. Reducing the load may increase the rotational speed of the generator and / or the fluid turbine connected to the generator. Accelerating the rotation of the plurality of blades may include increasing the rotational speed of the plurality of blades, for example, by reducing a load imposed on the generator connected to the plurality of blades. Reducing the load to accelerate the rotation of the plurality of blades for a limited period of time may include removing the load by ceasing to divert energy generated by the connected generator for a limited period of time, and reintroducing the load by diverting energy from the generator after the limited period of time has expired. By reducing the load to accelerate the rotation of the blades for a limited period of time, the rotation of the blades may be temporarily increased to introduce a phase shift relative to other blades, and the previous rotational speed of the blades (e.g., before generating the load) may be resumed to maintain the phase shift.

[0249] 17, the coordination signal may reduce the load, thereby accelerating the rotation of at least one of the first and second plurality of blades 1710A, 1710B and 1708A, 1708B for a limited period of time. The reduction in the load may impose a first phase correction 1720 between the first and second plurality of blades 1710A, 1710B and 1708A, 1708B.

[0250] Some aspects include that calculating the coordination signal includes applying a maximum power point tracking (MPPT) protocol to the geographically associated multiple fluid turbines. The maximum power point tracking (MPPT) protocol may include transmitting a signal to adjust the rotational speed of the fluid turbine, as described elsewhere in this disclosure. In some aspects, each fluid turbine may be associated with a chart or look-up table (e.g., stored in memory) that maps the variation of power output versus rotational speed under various fluid speeds. The at least one processor may use the chart or look-up table to select an optimal (e.g., or near-optimal) rotational speed of each associated fluid turbine that corresponds to a peak (e.g., or near-peak) power output under a given fluid speed. In some aspects, the at least one processor may apply one or more algorithms, such as machine learning algorithms. The at least one processor may transmit a signal to adjust the rotational speed of each geographically associated fluid turbine to achieve a selected rotational speed of each fluid turbine, e.g., in compliance with the MPPT protocol.

[0251] As a non-limiting example, in FIG. 17 , at least one processor (e.g., at least one processor 308, 428 and / or 512) may apply an MPPT protocol (e.g., based on a version of chart 1200 associated with each of the fluid turbines 1702, 1704, 1706) to calculate a coordination signal for each of the fluid turbines 1702, 1704, 1706 of the group 1700.

[0252] Some embodiments include obtaining at least one of a time-based or frequency-based power wave for a plurality of geographically associated fluid turbines, and applying the MPPT protocol includes applying at least one of the time-based or frequency-based power wave to the MPPT protocol. The time-based power wave may refer to a correspondence (e.g., a graph, chart, table, algorithm, numerical model, or analytical model) indicating an amount of power output at any given instant over time. The frequency-based power wave may refer to a correspondence (e.g., a graph, chart, table, algorithm, numerical model, or analytical model) indicating an amount of power output at any particular frequency over a frequency range. The time-based power wave may be converted to a frequency-based power wave using a mathematical transformation, such as, for example, a Fourier transform, or vice versa. Applying at least one of the time-based or frequency-based power wave to the MPPT protocol may include adjusting a rotational speed of the fluid turbine based on the time-based or frequency-based power wave to transmit a signal to the generator to operate according to the adjusted rotational speed and thereby generate a maximum (or near maximum) power output.

[0253] As a non-limiting example, FIG. 14 illustrates a graph 1400 representing a time-based power wave of a plurality of geographically associated fluid turbines. For example, the time-based power wave may correspond to the total AC power output of the fluid turbines 1702, 1704, 1706 of FIG. 17 (e.g., total AC power output 722 of FIGS. 7-11). At least one processor (e.g., at least one processor 308, 428 and / or 512) may apply the graph 1400 representing the time-based power wave to an MPPT protocol. For example, the frequency of the graph 1400 may indicate an average rotational speed of the plurality of geographically associated fluid turbines, and the amplitude of the graph 1400 may indicate a peak (or near-peak) power output.

[0254] In some embodiments, each blade of the first and second plurality of blades includes a flow receiving surface and a flow deflecting surface opposite the flow receiving surface. The opposing surface may refer to the opposing surface of the object. For example, a substantially flat object may have an upward facing surface and a downward facing surface opposite the upward facing surface. The flow receiving surface may refer to a first blade surface (e.g., or an edge) configured to capture or interact with the fluid flow to create a differential fluid velocity between the first blade surface and a second blade surface opposite the first blade surface. The differential fluid velocity may create a pressure difference that promotes rotation of the blade. The flow deflecting surface may refer to a second blade surface (e.g., or an edge) opposite the flow receiving surface and may be configured to push the fluid flow away from the blade as the blade rotates. In some embodiments, the flow receiving surface of the blade may be substantially flat and the flow deflecting surface of the blade may be curved, creating a higher fluid pressure on the substantially flat flow receiving surface and a lower fluid pressure on the curved flow deflecting surface. The difference in fluid pressure can induce a force (eg, lift) that drives blade motion.

[0255] As a non-limiting example, in FIG. 17, each blade of the first plurality of blades 1710A, 1710B and the second plurality of blades 1708A, 1708B may include a flow receiving surface 1724 (e.g., see the concave surface of the second plurality of blades 1708A, 1708B) and a flow deflecting surface 1726 (e.g., see the convex surface of the first plurality of blades 1710A, 1710B).

[0256] In some aspects, each flow receiving surface is configured to receive a first rotation-induced fluid flow. A rotation-induced fluid flow may refer to a fluid flow that, when incident on one or more blades of a fluid turbine, may cause the one or more blades to spin. A flow receiving surface configured to receive a rotation-induced fluid flow may refer to at least a portion of a blade surface configured to capture or interact with the fluid flow to generate a differential fluid velocity between the flow receiving surface of the blade and an opposing flow deflection surface. The differential fluid velocity may cause a pressure difference that promotes the rotational motion of the blade. For example, a blade having a flow receiving surface may have a curved or airfoil shape.

[0257] As a non-limiting example, in FIG. 17 , the flow receiving surface 1724 of the second plurality of blades 1708A, 1708B may receive a fluid flow 1714 downstream of the first fluid turbine 1704, for example, in addition to a fluid flow 1718 that induces rotation of the second plurality of blades 1708A, 1708B.

[0258] In some aspects, the flow deflection surface of the first plurality of blades is configured to at least partially generate the fluid flow downstream of the first fluid turbine in a first angular region of the plurality of blades during rotation. The angular region of the rotating plurality of blades may refer to an arc (e.g., a portion of a rotation) spanned by the plurality of blades as the rotating blades encompass a full rotation (e.g., 360°) during rotation. The angular region may be measured in degrees, radians, minutes, and / or seconds and may correspond to a portion of a full rotation. The angular region of the rotating plurality of blades may remain substantially fixed as the blades rotate such that each blade of the plurality of blades may move in and out of the angular region in each full rotation. For example, the angular region may span a 30° arc between 75° and 105° of a full (e.g., counterclockwise 360°) rotation on a Cartesian plane. A flow deflection surface of the plurality of blades configured to at least partially generate a fluid flow downstream of the first fluid turbine in a first angular region may refer to a hydrodynamic characteristic of the flow deflection surface of the plurality of blades that pushes (e.g., deflects) the fluid flow away from the flow deflection surface when the blade is disposed in the angular region. The flow deflection surface of the plurality of blades may deflect more of the fluid flow in some angular regions than in other angular regions, depending on, for example, the shape of the flow deflection surface and / or the direction of the fluid flow.

[0259] As a non-limiting example, in FIG. 17 , the flow deflection surface 1726 of the first plurality of blades 1710A, 1710B may at least partially generate a fluid flow 1714 downstream of the first fluid turbine in a first angular region 1728 of the plurality of blades during rotation.

[0260] In some embodiments, the first angular region is characterized by a flow velocity that is greater than the flow velocity in the second angular region. The flow velocity may refer to an instantaneous flow velocity or flow rate, or a flow velocity or flow rate over a time interval. A (e.g., first) flow velocity that is greater than a (e.g., second) flow velocity may refer to a first motion velocity of the continuous flow that is greater or higher than a second motion velocity of the continuous flow. In a fixed period of time, a fluid moving at a first flow velocity may cover a greater distance than a fluid moving at a second flow velocity. A first angular region (e.g., of a plurality of blades) that is characterized by a flow velocity that is greater than the flow velocity in a second angular region (e.g., of a plurality of blades) may refer to a first motion velocity of the continuous flow associated with the first angular region (e.g., a first rate of rotation) being greater or higher than a second motion velocity of the continuous flow associated with a different angular region, e.g., outside the first angular region. In some embodiments, the first angular region may be characterized by a higher average flow velocity over time, a higher maximum or minimum flow velocity, and / or a narrower standard deviation of flow velocity than the second angular region. For example, the first angular region may correspond to a 30° arc around 12 o'clock, and the second angular region may correspond to a 30° arc around 3 o'clock. The flow velocity of the fluid stream deflected from a blade positioned in a 30° arc around 12 o'clock may be greater than the flow velocity of the fluid stream deflected from a blade positioned in a 30° arc around 3 o'clock.

[0261] As a non-limiting example, in Figure 19, a first angular region 1922 of the plurality of blades shown in image signal 1902 may be characterized by a greater flow velocity than a second angular region 1924 shown in image signal 1906. For example, the first angular region 1922 may be characterized by a greater flow velocity than any angular region outside of angular region 1922. As another non-limiting example, in Figure 17, a first angular region 1728 of the first plurality of blades 1710A, 1710B may be characterized by a greater flow velocity (e.g., of the fluid flow downstream of the first fluid turbine) than an angular region of the first plurality of blades 1710A, 1710B outside of angular region 1728.

[0262] In some aspects, the first phase correction is configured to cause the downstream fluid flow of the first fluid turbine in the first angular region to be at least partially received by the flow receiving surface of the second plurality of blades, thereby achieving a greater total power output. The phase correction configured to cause the downstream fluid flow of the fluid turbine in the first angular region to be at least partially received by the flow receiving surface of the second plurality of blades may include applying the phase correction to adjust a distance and / or an orientation of the flow receiving surface of the blades of the second plurality of blades relative to the flow deflection surface of the blades of the first plurality of blades when the blades of the first plurality of blades are disposed in the first angular region. The phase correction may enable the flow receiving surface of the blades of the second plurality of blades to receive at least a portion of the downstream fluid flow of the first fluid turbine deflected from the flow deflection surface of the blades of the first plurality of blades. Because the blades of the first plurality of blades that deflect the fluid flow downstream of the first fluid turbine are positioned in the first angular region, the flow velocity of the fluid flow downstream of the first fluid turbine may be greater than if the blades were positioned outside the first angular region. Thus, the flow receiving surfaces of the blades of the second plurality of blades may receive the fluid flow downstream of the first fluid turbine having a greater velocity (e.g., by being deflected from the first angular region). The greater velocity may enable the second fluid turbine to generate a differential power output, for example, in addition to the power output generated from the fluid flow in the absence of the fluid flow downstream of the first fluid turbine. By aggregating the differential power output into the power generated by the geographically associated multiple fluid turbines, a greater total power output may be achieved.

[0263] As a non-limiting example, in FIG. 19, the image signal 1902 includes a first angular region 1922. When the flow deflection surface of the blade is disposed in the first angular region 1922, the fluid flow 1714 downstream of the fluid turbine deflected from the flow deflection surface may be greater than the fluid flow downstream of the fluid turbine deflected from the other angular regions. In FIG. 17, the first phase correction may align the flow receiving surface 1724 of the blade 1708B of the second fluid turbine 1702 with the flow deflection surface 1726 of the blade 1710A of the first fluid turbine 1704 when the flow deflection surface 1726 is disposed in the first angular region 1728. Thus, the flow receiving surface 1724 of the blade 1708B may receive the fluid flow 1714 downstream of the fluid turbine having a greater fluid velocity, increasing the rotational speed of the second fluid turbine 1702. Increasing the rotational speed of the second fluid turbine 1702 may allow a greater total power output (see, for example, total power output 440 in FIG. 4) to be achieved.

[0264] In some aspects, the at least one processor is configured to determine from the first signal and the second signal that the first plurality of blades has a similar phase cycle as the second plurality of blades. A phase cycle may refer to a single element (e.g., a motif) of a sequence of repeating elements that form a pattern that characterizes a time-based waveform of a signal (e.g., a power signal). Characteristics of a phase cycle (e.g., of a signal) may include one or more of the time at which the cycle begins, the time at which the cycle ends, the duration of the cycle, the time in the cycle at which the signal reaches a maximum value, the time in the cycle at which the signal reaches a minimum value, the time in the cycle at which the signal reaches zero, and / or any other attribute of the waveform that describes the signal over time. A phase cycle of the multiple blades may include a correspondence between the position and / or orientation of the multiple rotating blades at a given time and the time-based waveform of the power signal generated by the multiple rotating blades. The phase cycle of the multiple blades may indicate the position and / or orientation of the multiple blades corresponding to peak (or near peak) power output, minimum (or near minimum) power output, zero power output, the duration of a complete rotation, the time when a rotation begins, the time when a rotation ends, and / or any other attribute that characterizes the rotation of the multiple rotating blades associated with the power output waveform. In some aspects, the phase cycle of the multiple blades may include the direction of rotation (e.g., clockwise or counterclockwise).

[0265] In some aspects, outputting the coordination signal to impose the first phase correction is configured to cause the first and second plurality of blades to assume different phase cycles. Different phase cycles may refer to two or more phase cycles (e.g., of two or more plurality of rotating blades) that are distinguished by at least one characteristic of the phase cycles. Taking may refer to accepting or undertaking. Caused the first and second plurality of blades to assume different phase cycles may include adjusting (e.g., temporarily or continuously) the rotation of the first and / or second plurality of blades (e.g., by adjusting a load imposed on a connected generator) such that the phase cycle of the first plurality of blades can be distinguished from the second plurality of blades by at least one phase cycle characteristic. For example, the at least one processor may transmit the coordination signal to make the phase cycle of the first plurality of blades longer / shorter than the phase cycle of the second plurality of blades and / or to cause the maximum / minimum power output of the first plurality of blades to occur before / after the maximum / minimum power output of the second plurality of blades. In some aspects, the at least one processor may determine that the first plurality of blades and the second plurality of blades have different phase cycles, and the coordination signal may cause the first plurality of blades and the second plurality of blades to assume substantially similar phase cycles.

[0266] 4, at least one processor (e.g., processors 308, 428, and / or 512) may determine from a first signal received from at least one sensor 418A and a second signal received from at least one sensor 418B that a first plurality of blades of the first fluid turbine 404A have a similar phase cycle as a second plurality of blades of the second fluid turbine 404B (e.g., they rotate in unison and begin and end each rotation in the same sense). The at least one processor may output a coordination signal (e.g., to a version of the braking circuit 1300 associated with each of the first fluid turbine 404A and the second fluid turbine 404B) to cause the first plurality of blades of the first fluid turbine 404A to have different phase cycles. For example, the phase cycle of the first fluid turbine 404A may cause a peak power output to occur one second before the peak power output of the second fluid turbine 404A.

[0267] Some embodiments include determining from the first signal and the second signal that an orientation of the first plurality of blades is similar to an orientation of the second plurality of blades. The orientation of the plurality of blades may refer to a position (e.g., relative position) of at least one blade of the plurality of blades (e.g., at a given moment). For example, the orientation of the plurality of blades may be such that at the beginning of each phase cycle, a first blade of the first plurality of blades faces north and a second blade faces south, and halfway through the phase cycle, the first blade faces south and the second blade faces north. Similar orientations may refer to two (or more) equivalents of matching orientations. An orientation of the first plurality of blades similar to an orientation of the second plurality of blades may include the first and second plurality of blades starting to rotate from substantially equivalent orientations (e.g., each including blades oriented in substantially the same direction) and continuing to rotate at substantially the same rotational speed (e.g., in unison), thereby maintaining substantially equivalent orientations over time.

[0268] In some aspects, outputting the coordination signal is configured to cause the orientation of the first plurality of blades to differ from the orientation of the second plurality of blades. The differing orientations may refer to dissimilar or non-equivalent orientations. For example, at the beginning of a phase cycle, one blade of the first plurality of blades may face north and a second blade of the first plurality of blades may face south, while one blade of the second plurality of blades may face west and a second blade of the second plurality of blades may face east. In such a case, the orientation of the first plurality of blades may differ from the orientation of the second plurality of blades by a quarter of a cycle (e.g., corresponding to a relative phase shift of 90° in each rotation cycle). Making the orientation of the first plurality of blades different from the orientation of the second plurality of blades may include adjusting (e.g., temporarily or continuously) the rotation of the first and / or second plurality of blades (e.g., by adjusting a load imposed on a connected generator) such that the orientation of the first plurality of blades may be distinguished from the orientation of the second plurality of blades. For example, the at least one processor may adjust the rotational speed of the first and / or second plurality of blades to introduce a relative phase shift therebetween. In some aspects, the at least one processor may determine from the first and second signals that the orientations of the first and second plurality of blades are different, and the coordination signal may cause the orientations of the first and second plurality of blades to be substantially similar.

[0269] 4 , at least one processor (e.g., at least one processor 308, 428 and / or 512) may determine from a first signal received from the at least one sensor 418A and a second signal received from the at least one sensor 418B that an orientation of the first plurality of blades of the first fluid turbine 404A is similar to an orientation of the second plurality of blades of the second fluid turbine 404B. The at least one processor may output a coordination signal to cause the orientation of the first plurality of blades of the first fluid turbine 404A to be different from the orientation of the second plurality of blades of the second fluid turbine 404B.

[0270] In some aspects, the first signal indicates a first AC signal generated by a first fluid turbine, and the second signal indicates a second AC signal generated by a second fluid turbine. The AC signal may refer to an alternating current signal. The AC signal generated by the fluid turbine may include an AC signal generated by a generator connected to the fluid turbine. When the fluid flow rotates the blades of the fluid turbine, the rotation of the blades may cause a corresponding rotation of a rotor of the generator. The rotation of the rotor may cause a varying magnetic field to induce an alternating current (e.g., an AC signal) in copper windings of the generator (e.g., the rotor may include magnets surrounding copper windings disposed in a stator of the generator, or vice versa). Thus, characteristics (e.g., phase, frequency) of the AC signal generated by the generator connected to the fluid turbine may correspond to characteristics (e.g., phase, frequency) of the rotation of the blades of the fluid turbine. The at least one processor may use the AC signal generated by the generator as an indication of the rotation of the blades connected to the generator (e.g., accounting for one or more gears for adjusting the rotational speed of the blades and / or the rotor).

[0271] In some embodiments, the first AC signal is characterized by a frequency and a relative phase corresponding to the frequency and phase of a rotation cycle of the first plurality of rotating blades at a particular time, and the second AC signal is characterized by a frequency and a relative phase corresponding to the frequency and phase of a rotation cycle of the second plurality of rotating blades at a particular time. The frequency may refer to the number of cycles per unit time (e.g., per second or per minute). The frequency of the AC signal may be measured in Hz (e.g., cycles per second), and the frequency of the rotation cycle of the plurality of blades may be measured as revolutions per minute (e.g., RPM). As described above, the rotation of the plurality of blades of a fluid turbine may correspond to an AC signal generated by a generator connected to the plurality of blades due to an associated varying magnetic field that induces an AC signal. Thus, a waveform representing an A...

Claims

1. 1. A system for coordinated braking of a plurality of geographically associated fluid turbines, comprising: accessing a memory that stores information indicative of a tolerance threshold for at least one operating parameter associated with the plurality of geographically associated fluid turbines; receiving information from at least one sensor indicative of the at least one operating parameter for a particular fluid turbine of the geographically associated plurality of fluid turbines; comparing the information indicative of the at least one operating parameter for the particular fluid turbine to the tolerance threshold stored in memory; determining whether the at least one operating parameter for the particular fluid turbine deviates from the tolerance threshold based on the comparison; transmitting a braking signal to each of the geographically associated fluid turbines to slow down each of the geographically associated fluid turbines upon determining that the at least one operating parameter for the particular fluid turbine deviates from the tolerance threshold; 10. A system comprising: at least one processor configured to:

2. The system of claim 1 , wherein the at least one sensor includes a rotational sensor, and the at least one operating parameter corresponds to a rotational speed of the particular fluid turbine.

3. The system of claim 1 , wherein the at least one sensor includes a fluid velocity detector, and the at least one operating parameter corresponds to a fluid velocity affecting the particular fluid turbine.

4. The system of claim 1 , wherein the at least one sensor includes a vibration sensor, and the at least one operating parameter corresponds to a vibration of the particular fluid turbine.

5. The system of claim 1 , wherein the at least one sensor includes a temperature sensor, and the at least one operating parameter corresponds to a temperature of the particular fluid turbine.

6. The system of claim 1 , wherein the at least one sensor includes a power output sensor, and the at least one operating parameter corresponds to a power output of the particular fluid turbine.

7. The system of claim 1 , wherein the slowing down of each of the geographically associated fluid turbines comprises shutting down each geographically associated fluid turbine.

8. The system of claim 7 , wherein the at least one processor is further configured to lock each geographically associated fluid turbine in a stopped state.

9. The system of claim 8 , wherein the at least one processor is further configured to receive an unlock signal from a local or remote location and unlock each of the geographically associated fluid turbines in response to the unlock signal.

10. 9. The system of claim 8, wherein following the locking, the at least one processor is configured to receive a fluid velocity signal and cause each geographically associated fluid turbine to unlock when the fluid velocity signal corresponds to a fluid velocity within the tolerance threshold.

11. 2. The system of claim 1, wherein following the deceleration, the at least one processor is configured to receive a fluid velocity signal and cause the braking of each geographically associated fluid turbine to be released when the fluid velocity signal corresponds to a fluid velocity within the tolerance threshold.

12. The system of claim 1 , wherein the braking signal is configured to synchronize each fluid turbine in the geographically associated plurality of fluid turbines.

13. The system of claim 12 , wherein the synchronization enables application of a maximum power point tracking (MPPT) protocol to the geographically associated fluid turbines upon release of braking.

14. The system of claim 12 , wherein the synchronizing coordinates rotational timing of each turbine in the plurality of geographically associated fluid turbines.

15. The system of claim 12 , wherein the synchronizing coordinates a rotational orientation of each turbine in the geographically associated plurality of turbines.

16. The system of claim 1 , wherein the geographically associated fluid turbine is a wind turbine.

17. The system of claim 1 , wherein the geographically associated fluid turbine is a water turbine.

18. 1. A non-transitory computer-readable medium comprising instructions that, when executed by at least one processor, cause the at least one processor to perform operations for coordinated braking of a plurality of geographically associated fluid turbines, the instructions comprising: The operation is accessing a memory storing information indicative of a tolerance threshold for at least one operating parameter associated with the plurality of geographically associated fluid turbines; receiving information from at least one sensor indicative of one of the at least one operating parameter for a particular fluid turbine of the geographically associated plurality of fluid turbines; comparing the information indicative of the at least one operating parameter for the particular fluid turbine to the tolerance threshold stored in a memory; determining whether the at least one operating parameter for the particular fluid turbine deviates from the tolerance threshold based on the comparison; and transmitting a braking signal to each of the geographically associated fluid turbines to slow down each of the geographically associated fluid turbines upon determining that the at least one operating parameter for the particular fluid turbine exceeds the tolerance threshold.

1. A non-transitory computer-readable medium comprising:

19. A method for coordinated braking of a plurality of geographically associated fluid turbines, the operation comprising: accessing a memory storing information indicative of a tolerance threshold value of at least one operating parameter associated with the plurality of geographically associated fluid turbines; receiving information from at least one sensor indicative of at least one operating parameter for a particular fluid turbine of the geographically associated plurality of fluid turbines; comparing the information indicative of the at least one operating parameter for the particular fluid turbine to the tolerance threshold stored in a memory; determining, based on the comparison, whether the at least one operating parameter for the particular fluid turbine deviates from the tolerance threshold; and transmitting a braking signal to each of the geographically associated fluid turbines to slow down each of the geographically associated fluid turbines upon determining that the at least one operating parameter for the particular fluid turbine exceeds the tolerance threshold. A method comprising:

20. 1. A system for coordinating MPPT operation of a group of geographically associated fluid turbines, comprising: receiving data from the geographically associated fleet of fluid turbines; determining a change to the total power output of the group based on changes in load conditions of individual fluid turbines within the group; selecting a combination of load conditions of the individual fluid turbines in the group to coordinate the total power output of the group; transmitting the selected combination of load conditions to at least some of the individual fluid turbines in the group to vary the rotational speeds of at least some of the individual fluid turbines in the group.

10. A system comprising: at least one processor configured to:

21. The system of claim 20 , wherein at least some of the turbines in the group are hydrodynamically coupled.

22. The combination of load conditions of the individual fluid turbines in the group is applying an MPPT protocol to each individual fluid turbine to determine an associated individual load state for each individual fluid turbine, and subjecting at least one of the individual load states of the individual fluid turbine to at least one global constraint of the set; 21. The system of claim 20, wherein the method is selected based on:

23. 23. The system of claim 22, wherein applying the MPPT protocol to each individual turbine comprises first testing a generator electrical output of each individual turbine under a series of different loads while the individual turbine is operating at a first fluid state.

24. 24. The system of claim 23, wherein testing the generator of each individual turbine under the series of different loads comprises simulating the different loads on the generator and predicting a response of the generator.

25. 24. The system of claim 23, wherein testing the generator of each individual turbine under the first series of different loads comprises applying the different loads to each generator and measuring a response of each generator.

26. The system of claim 20 , wherein selecting the combination of load conditions for the individual fluid turbines in the group accounts for variations in fluid conditions affecting the group.

27. The system of claim 26 , wherein the variations in fluid conditions are associated with variations in electrical power output by different ones of the fluid turbines in the group.

28. The system of claim 20 , wherein selecting the combination of load conditions of the individual fluid turbines in the group accounts for a spatial distribution of the individual fluid turbines in the group.

29. 21. The system of claim 20, wherein the at least one processor is configured to receive, determine, select, and transmit sequentially.

30. 30. The system of claim 29, wherein the at least one processor is configured to adjust for fluid conditions that vary over time.

31. The system of claim 20 , wherein the fluid turbine is a wind turbine.

32. The system of claim 20 , wherein the fluid turbine is a water turbine.

33. 21. The system of claim 20, wherein determining comprises calculating or measuring a change to the total power output.

34. The system of claim 20 , wherein the selected combination of load conditions is configured to cause some fluid turbines in the group to operate differently than other fluid turbines in the group.

35. 35. The system of claim 34, wherein the difference in operation varies based on changing fluid conditions.

36. 36. The system of claim 35, wherein the selected combination of load conditions varies over time for different combinations of fluid turbines in the group.

37. 35. The system of claim 34, wherein the different operations within the group include at least one of rotational speed (RPM), voltage output, current output, direction of rotation, blade orientation relative to fluid flow, or relative blade orientation between at least two fluid turbines in the group.

38. The system of claim 20 , wherein the group of fluid turbines comprises horizontal axis turbines.

39. The system of claim 20 , wherein the group of fluid turbines comprises vertical axis turbines.

40. 21. The system of claim 20, wherein the higher level MPPT protocol is applied at the DC stage via the charge controller.

41. 21. The system of claim 20, wherein the upper level MPPT protocol is applied at the AC stage via the inverter.

42. 1. A non-transitory computer-readable medium comprising instructions that, when executed by at least one processor, cause the at least one processor to perform operations for coordinating MPPT operation of a group of geographically associated fluid turbines, the instructions comprising: The operation is receiving data from the geographically associated fleet of fluid turbines; determining a change to the total power output of the group based on changes in load conditions of individual fluid turbines within the group; selecting a combination of load conditions of the individual fluid turbines in the group to coordinate a total power output of the group; and transmitting the selected combination of load conditions to at least some of the individual fluid turbines in the group to vary the rotational speeds of at least some of the individual fluid turbines in the group.

1. A non-transitory computer-readable medium comprising:

43. 1. A method for coordinating MPPT operation of a group of geographically associated fluid turbines, comprising: receiving data from the geographically associated fleet of fluid turbines; determining a change to the total power output of the group based on changes in load conditions of individual fluid turbines within the group; selecting a combination of load conditions of the individual fluid turbines in the group to coordinate the total power output of the group; and transmitting the selected combination of load conditions to at least some of the individual fluid turbines in the group to vary the rotational speed of at least some of the individual fluid turbines in the group. A method comprising:

44. 1. A system for synchronizing a plurality of geographically associated fluid turbines, comprising: receiving a first signal indicative of a phase of a rotational cycle of a first plurality of rotating blades of a first fluid turbine of the geographically associated plurality of fluid turbines, the first plurality of rotating blades being configured to generate a fluid flow downstream of the first fluid turbine; receiving a second signal indicative of a phase of a rotational cycle of a second plurality of rotating blades of a second fluid turbine of the geographically associated plurality of fluid turbines, the second plurality of rotating blades being configured to receive at least a portion of the fluid flow downstream of the first fluid turbine and to generate a differential power output attributable to the at least a portion of the fluid flow downstream of the first fluid turbine; determining from the first signal and the second signal that a greater total power output is achievable through blade phase coordination; determining a phase correction between the first plurality of rotating blades and the second plurality of rotating blades based on the first signal and the second signal to achieve the greater total power output; calculating a coordination signal based on the determined phase correction; Imposing the phase correction and thereby outputting the coordinated signal to achieve the greater total power output.

10. A system comprising: at least one processor configured to:

45. the at least one processor: receiving a third signal indicative of a phase of a rotational cycle of a third plurality of rotating blades of a third fluid turbine of the geographically associated plurality of fluid turbines, the third plurality of rotating blades being configured to generate a fluid flow downstream of the third fluid turbine; and receiving a fourth signal indicative of a phase of a rotational cycle of a fourth plurality of rotating blades of a fourth fluid turbine of the geographically associated plurality of fluid turbines, the fourth plurality of rotating blades being configured to receive at least a portion of the fluid flow downstream of the third fluid turbine and to generate a differential power output attributable to the at least a portion of the fluid flow downstream of the third fluid turbine. further configured as follows: calculating a coordination signal further based on the third signal and the fourth signal, the coordination signal further configured to impose an additional phase correction between the third plurality of rotating blades and the fourth plurality of rotating blades to achieve the greater total power output; outputting the coordination signal is further configured to impose the additional phase correction, thereby achieving the greater total power output.

45. The system of claim 44.

46. each blade of the first plurality of blades and the second plurality of blades includes a flow receiving surface and a flow deflecting surface opposite the flow receiving surface, each flow receiving surface configured to receive a first rotation-induced fluid flow, the flow deflecting surface of the first plurality of blades configured to at least partially generate a fluid flow downstream of the first fluid turbine in a first angular region of the plurality of blades during rotation, the first angular region being characterized by a fluid velocity greater than a fluid velocity in a second angular region; 45. The system of claim 44, wherein the first phase correction is configured to cause fluid flow downstream of the first fluid turbine in the first angular region to be at least partially received by the flow receiving surfaces of the second plurality of blades, thereby achieving the greater total power output.

47. 45. The system of claim 44, wherein the coordination signal is configured to generate a load to slow down the rotation of at least one of the first and second plurality of blades for a limited period of time, thereby imposing the first phase correction between the first and second plurality of blades.

48. 48. The system of claim 47, wherein the coordination signal is configured to modify application of the load to at least one generator connected to at least one of the first fluid turbine and the second fluid turbine.

49. 45. The system of claim 44, wherein the coordination signal is configured to reduce a load thereby accelerating rotation of at least one of the first plurality of blades and the second plurality of blades for a limited period of time thereby imposing the first phase correction between the first plurality of blades and the second plurality of blades.

50. 45. The system of claim 44, wherein the first fluid turbine is located upstream of the second turbine.

51. The system of claim 44 , wherein calculating the coordination signal comprises applying a maximum power point tracking (MPPT) protocol to the geographically associated plurality of fluid turbines.

52. the at least one processor is further configured to obtain at least one of time-based or frequency-based power waves for the geographically associated plurality of fluid turbines; applying the MPPT protocol includes applying at least one of the time-based or frequency-based power waves to the MPPT protocol.

52. The system of claim 51.

53. 45. The system of claim 44, wherein the plurality of geographically associated fluid turbines are wind turbines and the fluid is an air current.

54. 45. The system of claim 44, wherein the plurality of geographically associated fluid turbines are water turbines and the fluid is a water current.

55. 45. The system of claim 44, wherein the axes of rotation of the first fluid turbine and the second fluid turbine are substantially perpendicular.

56. the at least one processor is configured to determine from the first signal and the second signal that the first plurality of blades has a similar phase cycle as the second plurality of blades; outputting the coordination signal to impose the first phase correction is configured to cause the first plurality of blades and the second plurality of blades to assume different phase cycles.

45. The system of claim 44.

57. the at least one processor is configured to determine from the first signal and the second signal that an orientation of the first plurality of blades is similar to an orientation of the second plurality of blades; outputting the coordination signal is configured to cause the orientation of the first plurality of blades to differ from the orientation of the second plurality of blades.

45. The system of claim 44.

58. 45. The system of claim 44, wherein each blade of the first plurality of blades and the second plurality of blades is a lift blade.

59. 45. The system of claim 44, wherein the first fluid turbine and the second fluid turbine are similarly configured.

60. 45. The system of claim 44, wherein the axes of rotation of the first fluid turbine and the second fluid turbine are substantially horizontal.

61. 61. The system of claim 60, wherein the first signal represents a first AC signal generated by the first fluid turbine, the second signal represents a second AC signal generated by the second fluid turbine, the first AC signal characterized by a frequency and relative phase corresponding to a frequency and phase of the rotational cycle of the first plurality of rotating blades at a particular point in time, and the second AC signal characterized by a frequency and relative phase corresponding to a frequency and phase of the rotational cycle of the second plurality of rotating blades at the particular point in time.

62. 45. The system of claim 44, wherein each fluid turbine in the group of fluid turbines includes a rotating shaft having a respective first plurality of blades and a second plurality of blades connected thereto, the first signal being associated with a rotational speed or position detector associated with the shaft of the first fluid turbine, and the second signal being associated with a rotational speed or position detector associated with the shaft of the second fluid turbine.

63. 45. The system of claim 44, wherein the geographically associated plurality of fluid turbines includes a plurality of additional turbines, and the coordination signal is configured to impose an additional phase correction on each of the additional turbines.

64. 45. The system of claim 44, wherein the first signal and the second signal are image signals received from at least one image sensor.

65. 45. The system of claim 44, wherein calculating the coordination signal is further based on at least one of a blade orientation, a blade rotational speed, or a power output of at least one of the first fluid turbine and the second fluid turbine.

66. 45. The system of claim 44, wherein the at least one processor is associated with a charge controller connected to the plurality of geographically associated fluid turbines.

67. The system of claim 44 , wherein the at least one processor is associated with an inverter connected to the plurality of geographically associated fluid turbines.

68. The system of claim 44 , wherein the at least one processor is associated with a control system external to the plurality of geographically associated fluid turbines.

69. 1. A non-transitory computer-readable medium comprising instructions that, when executed by at least one processor, cause the at least one processor to perform operations for synchronizing a plurality of geographically associated fluid turbines, the instructions comprising: The operation is receiving a first signal indicative of a phase of a rotational cycle of a first plurality of rotating blades of a first fluid turbine of the geographically associated plurality of fluid turbines, the first plurality of rotating blades being configured to generate a fluid flow downstream of the first fluid turbine; receiving a second signal indicative of a phase of a rotational cycle of a second plurality of rotating blades of a second fluid turbine of the geographically associated plurality of fluid turbines, the second plurality of rotating blades being configured to receive at least a portion of the fluid flow downstream of the first fluid turbine and to generate a differential power output attributable to the at least a portion of the fluid flow downstream of the first fluid turbine; determining from the first signal and the second signal that a greater total power output is achievable through blade phase coordination; determining a phase correction between the first plurality of rotating blades and the second plurality of rotating blades based on the first signal and the second signal to achieve the greater total power output; calculating a coordination signal based on the determined phase correction; and Imposing the phase correction and thereby outputting the coordinated signal to achieve the greater total power output.

1. A non-transitory computer-readable medium comprising:

70. 1. A method for synchronizing a plurality of geographically associated fluid turbines, comprising: receiving a first signal indicative of a phase of a rotational cycle of a first plurality of rotating blades of a first fluid turbine of the geographically associated plurality of fluid turbines, the first plurality of rotating blades being configured to generate a fluid flow downstream of the first fluid turbine; receiving a second signal indicative of a phase of a rotational cycle of a second plurality of rotating blades of a second fluid turbine of the geographically associated plurality of fluid turbines, the second plurality of rotating blades being configured to receive at least a portion of the fluid flow downstream of the first fluid turbine and to generate a differential power output attributable to the at least a portion of the fluid flow downstream of the first fluid turbine; determining from the first signal and the second signal that a greater total power output is achievable through blade phase coordination; determining a phase correction between the first plurality of rotating blades and the second plurality of rotating blades based on the first signal and the second signal to achieve the greater total power output; calculating a coordination signal based on the determined phase correction; and outputting the coordinated signal to impose the phase correction and thereby achieve the greater total power output. A method comprising:

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