Fault type identification method in power systems

Abstract

The present disclosure relates to a method for controlling a protection system for an electric power system including a transmission line, the method including: determining, during each of at least three faults, a plurality of phase angle deviations based on a network model of the electric power system; determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle; and controlling a protection system for the electric power system based on the at least three phase angle ranges.

Description

[Technical Field]

[0001] Technical Field The present disclosure relates to methods, apparatus, computer-readable media, and systems for power systems comprising transmission lines. [Background technology]

[0002] background Current environmental challenges require the integration of large-scale converter-interfaced renewable power plants (CIRPPs) into transmission networks, and therefore different control schemes are applied through the converters connected to the CIRPPs. To meet fault ride-through requirements imposed by different grid codes, CIRPPs must be connected even during faults. The presence of such converter-interfaced renewable energy resources in the network modulates fault voltage and current signals, which are significantly different from those of conventional synchronous generators. These different fault characteristics adversely affect the performance of available phase selection or fault classification logic designed for conventional grids dominated by synchronous generators.

[0003] Accurate phase selection may refer to the ability of a protective intelligent electronic device (IED) to identify the faulted phase, which is a prerequisite for single-pole auto-reclosing. Phase selection or fault classification may be performed by identifying which of the impedances of the six loops (three phase-to-ground and three phase-to-phase loops) fall within a predetermined characteristic.

[0004] The first approach for phase selection involves relays comparing the relative angles between the net-fault phase currents available at the local end to identify fault types within the network. Such approaches remain unaffected by fault tolerance and load imbalances and quickly and accurately classify fault types. In the second approach, the adverse effects of phase angle variations in positive-sequence currents are avoided in some relays by utilizing only the angle difference between the negative-sequence current and the zero-sequence current. This technique estimates fault resistance to distinguish between single-line-to-ground and double-line-to-ground faults. In another approach, the phase angle difference of superimposed phase voltages is utilized in some relays along with the current angle feature for fault type classification in weak infeed situations.

[0005] All of the phasor-based techniques mentioned above assume uniformity within the system (angles of local and remote currents close to each other), which is true for conventional power networks connecting conventional generations. However, these methods have limitations when applied to lines connected with converter-interface renewable energy resources due to modulated voltage and current signals during faults, and the assumption of uniformity is no longer true. Yet another approach adaptively classifies faults in transmission networks connected to CIRPPs, and the non-uniformity factor is , are calculated assuming the grid is strongly connected. This technique does not work when the grid is weakly connected.

[0006] Therefore, there is a need for an accurate topology selection method, especially for networks connected with CIRPP. Summary of the Invention [Means for solving the problem]

[0007] overview The present disclosure relates to a method for a protection system for an electric power system including a transmission line, the method including: determining, during each of at least three faults, a plurality of phase angle deviations based on a network model of the electric power system; and determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle.

[0008] According to one embodiment, the transmission line is terminated by a first terminal coupled to the first generator and by a second terminal coupled to the second generator, and the method further includes obtaining a plurality of voltage measurements at the first terminal, determining a measured phase angle deviation based on the plurality of voltage measurements, and determining a fault by, in particular, comparing the measured phase angle deviation with at least one of the at least three phase angle ranges, thereby identifying in which of the at least three phase angle ranges the measured phase angle deviation is located.

[0009] According to one embodiment, the method further includes determining, during each of the at least three further faults, a plurality of further phase angle deviations based on a network model of the power system, and determining at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein the plurality of phase angle deviations are different from the plurality of further phase angle deviations, the at least three faults are different from the at least three further faults, the at least three phase angle ranges are different from the at least three further phase angle ranges, and a sum of the at least three further phase angle ranges is a complete rotation angle.

[0010] According to one embodiment, the method further includes obtaining a plurality of voltage measurements of the first terminal, determining a further measured phase angle deviation based on the plurality of voltage measurements, and determining the fault by, in particular, comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges to identify in which of the at least three further phase angle ranges the measured phase angle deviation is located.

[0011] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a zero-phase sequence current based on the plurality of current measurements at the first terminal, and determining a fault further based on the zero-phase sequence current, in particular by comparing the zero-phase sequence current to a preset value.

[0012] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0013] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0014] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0015] According to one embodiment, the transmission line carries multiple phases, and the method includes obtaining multiple voltage measurements of the first terminal measured before and during the fault, and determining an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases.

[0016] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, and determining a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determining a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0017] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0018] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0019] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0020] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0021] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0022] The present disclosure relates to a method for controlling a protection system for an electric power system including a transmission line, the method including: receiving at least three phase angle ranges determined according to any one of the above-described embodiments; and controlling a protection system for the electric power system based on the at least three phase angle ranges.

[0023] The present disclosure relates to a method for controlling a protection system for an electric power system including a transmission line, the method including: determining, during each of at least three faults, a plurality of phase angle deviations based on a network model of the electric power system; determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle; and controlling a protection system for the electric power system based on the at least three phase angle ranges.

[0024] According to one embodiment, the transmission line is terminated by a first terminal coupled to a first generator and by a second terminal coupled to a second generator, and the method further includes obtaining a plurality of voltage measurements at the first terminal, determining a measured phase angle deviation based on the plurality of voltage measurements, determining a fault, particularly by comparing the measured phase angle deviation with at least one of at least three phase angle ranges to identify in which of the at least three phase angle ranges the measured phase angle deviation is located, and controlling a protection system for the power system based on the determined fault.

[0025] According to one embodiment, the method further includes determining, during each of the at least three further faults, a plurality of further phase angle deviations based on a network model of the power system, and determining at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein the plurality of phase angle deviations are different from the plurality of further phase angle deviations, the at least three faults are different from the at least three further faults, the at least three phase angle ranges are different from the at least three further phase angle ranges, and a sum of the at least three further phase angle ranges is a complete rotation angle.

[0026] According to one embodiment, the method further includes obtaining a plurality of voltage measurements at the first terminal, determining a further measured phase angle deviation based on the plurality of voltage measurements, determining a fault, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges to identify in which of the at least three further phase angle ranges the measured phase angle deviation is located, and controlling a protection system for the power system based on the determined fault.

[0027] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal; determining a zero-phase sequence current based on the plurality of current measurements at the first terminal; determining a fault further based on the zero-phase sequence current, in particular by comparing the zero-phase sequence current to a preset value; and controlling a protection system for the power system based on the determined fault.

[0028] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0029] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0030] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0031] According to one embodiment, the transmission line carries multiple phases, and the method includes obtaining multiple voltage measurements at the first terminal measured before and during the fault, and determining an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases. , judgment Based on the determined n-phase fault, and control the protection system This includes the following.

[0032] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, and determining a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determining a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0033] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0034] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0035] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0036] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0037] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0038] The present disclosure also relates to a method for a protection system for a power system including a transmission line terminated by a first terminal, the method including: during each of at least three faults, determining a plurality of phase angle deviations based on a network model of the power system; determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete angle of rotation; obtaining a plurality of voltage measurements and current measurements of the first terminal; determining a measured phase angle deviation based on the plurality of voltage measurements and a zero-phase sequence current based on the plurality of current measurements of the first terminal; and determining the fault based on the at least three phase angle ranges, the measured phase angle deviation, and the zero-phase sequence current.

[0039] According to one embodiment, the method further includes, during each fault of the at least one further fault set, determining a plurality of further phase angle deviations based on a network model of the power system, determining at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein a sum of the at least three further phase angle ranges is a complete rotation angle, determining a further measured phase angle deviation based on a plurality of voltage measurements, and determining the fault by identifying in which of the at least three further phase angle ranges the measured phase angle deviation is located, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges.

[0040] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0041] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0042] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0043] According to one embodiment, the transmission line carries multiple phases, and the method further includes obtaining multiple voltage measurements of the first terminal measured before and during the fault, and determining an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of multiple phases.

[0044] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, and determining a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determining a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0045] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0046] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0047] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0048] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0049] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0050] The present disclosure also relates to a method for controlling a protection system for a power system including a transmission line terminated by a first terminal, the method including receiving at least three phase angle ranges, measured phase angle deviations, zero-phase sequence currents, and / or faults determined according to any one of the above-mentioned embodiments, and controlling a protection system for the power system based on the determined faults.

[0051] The present disclosure also relates to a method for a protection system for controlling a power system including a transmission line terminated by a first terminal, the method including: during each of at least three faults, determining a plurality of phase angle deviations based on a network model of the power system; determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete angle of rotation; obtaining a plurality of voltage measurements and current measurements of the first terminal; determining a measured phase angle deviation based on the plurality of voltage measurements and a zero-sequence current based on the plurality of current measurements of the first terminal; determining a fault based on the at least three phase angle ranges, the measured phase angle deviation, and the zero-sequence current; and controlling a protection system for the power system based on the determined fault.

[0052] According to one embodiment, the method further includes, during each fault of the at least one further fault set, determining a plurality of further phase angle deviations based on a network model of the power system, determining at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein a sum of the at least three further phase angle ranges is a complete rotation angle, determining a further measured phase angle deviation based on a plurality of voltage measurements, and determining the fault by, in particular, identifying in which of the at least three further phase angle ranges the measured phase angle deviation is located by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges, and controlling a protection system for the power system based on the determined fault.

[0053] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0054] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0055] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0056] According to one embodiment, the transmission line carries multiple phases, and the method includes obtaining multiple voltage measurements at the first terminal measured before and during the fault, and determining an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases. , judgment Further based on the determined n-phase fault, Controlling the protection system The present invention further includes the steps of:

[0057] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, and determining a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determining a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0058] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0059] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0060] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0061] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0062] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0063] The present disclosure also relates to an apparatus for a protection system for an electric power system including a transmission line, the apparatus comprising: a processor configured to: determine, during each of at least three faults, a plurality of phase angle deviations based on a network model of the electric power system; and determine at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle.

[0064] According to one embodiment, the transmission line is terminated by a first terminal coupled to the first generator and by a second terminal coupled to the second generator, and the processor is further configured to obtain a plurality of voltage measurements at the first terminal, determine a measured phase angle deviation based on the plurality of voltage measurements, and determine a fault, in particular by comparing the measured phase angle deviation with at least one of the at least three phase angle ranges to identify in which of the at least three phase angle ranges the measured phase angle deviation is located.

[0065] According to one embodiment, the processor is further configured to: determine, during each of the at least three further faults, a plurality of further phase angle deviations based on a network model of the power system; and determine at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein the plurality of phase angle deviations are different from the plurality of further phase angle deviations, the at least three faults are different from the at least three further faults, the at least three phase angle ranges are different from the at least three further phase angle ranges, and a sum of the at least three further phase angle ranges is a complete rotation angle.

[0066] According to one embodiment, the processor is further configured to obtain a plurality of voltage measurements of the first terminal, determine a further measured phase angle deviation based on the plurality of voltage measurements, and determine the fault, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges to identify in which of the at least three further phase angle ranges the measured phase angle deviation is located.

[0067] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a zero-phase sequence current based on the plurality of current measurements at the first terminal, determine a fault further based on the zero-phase sequence current, in particular by comparing the zero-phase sequence current to a preset value, and control a protection system for the power system based on the determined fault.

[0068] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0069] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0070] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0071] According to one embodiment, the transmission line carries multiple phases, and the processor is further configured to obtain multiple voltage measurements of the first terminal measured before and during the fault, and determine an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases.

[0072] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, determine a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determine a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0073] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0074] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0075] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0076] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0077] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0078] The present disclosure also relates to an apparatus for controlling a protection system for an electric power system including a transmission line, the apparatus comprising: a processor configured to receive at least three phase angle ranges determined according to any one of the above-described embodiments; and control a protection system for the electric power system based on the at least three phase angle ranges and at least three second phase angle ranges.

[0079] The present disclosure also relates to an apparatus for controlling a protection system for an electric power system including a transmission line, the apparatus comprising: a processor configured to: determine, during each of at least three faults, a plurality of phase angle deviations based on a network model of the electric power system; determine at least three phase angle ranges based on the plurality of phase angle deviations, a sum of the at least three phase angle ranges being a complete rotation angle; and control a protection system for the electric power system based on the at least three phase angle ranges.

[0080] According to one embodiment, the transmission line is terminated by a first terminal coupled to the first generator and by a second terminal coupled to the second generator, and the processor is further configured to obtain a plurality of voltage measurements at the first terminal, determine a measured phase angle deviation based on the plurality of voltage measurements, determine a fault, in particular by comparing the measured phase angle deviation with at least one of at least three phase angle ranges to identify in which of the at least three phase angle ranges the measured phase angle deviation is located, and control a protection system for the power system based on the determined fault.

[0081] According to one embodiment, the processor is further configured to: determine, during each of the at least three further faults, a plurality of further phase angle deviations based on a network model of the power system; and determine at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein the plurality of phase angle deviations are different from the plurality of further phase angle deviations, the at least three faults are different from the at least three further faults, the at least three phase angle ranges are different from the at least three further phase angle ranges, and a sum of the at least three further phase angle ranges is a complete rotation angle.

[0082] According to one embodiment, the processor is further configured to obtain a plurality of voltage measurements of the first terminal, determine a further measured phase angle deviation based on the plurality of voltage measurements, determine a fault, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges to identify in which of the at least three further phase angle ranges the measured phase angle deviation is located, and control a protection system for the power system based on the determined fault.

[0083] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a zero-phase sequence current based on the plurality of current measurements at the first terminal, determine a fault further based on the zero-phase sequence current, in particular by comparing the zero-phase sequence current to a preset value, and control a protection system for the power system based on the determined fault.

[0084] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0085] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0086] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0087] According to one embodiment, the transmission line carries multiple phases, and the processor obtains multiple voltage measurements of the first terminal measured before and during the fault, and determines an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases; , judgment Further based on the determined n-phase fault, Controlling the protection system The device is further configured to:

[0088] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, determine a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determine a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0089] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0090] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0091] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0092] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0093] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0094] The present disclosure also relates to an apparatus for a protection system for a power system including a transmission line, the apparatus comprising: a processor configured to: determine, during each of at least three faults, a plurality of phase angle deviations based on a network model of the power system; determine at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle; obtain a plurality of voltage measurements and current measurements of a first terminal; determine a measured phase angle deviation based on the plurality of voltage measurements and a zero-phase sequence current based on the plurality of current measurements of the first terminal; and determine a fault based on the at least three phase angle ranges, the measured phase angle deviation, and the zero-phase sequence current.

[0095] According to one embodiment, the processor is further configured to, during each fault in the at least three further fault sets, determine a plurality of further phase angle deviations based on a network model of the power system, determine at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein a sum of the at least three further phase angle ranges is a complete rotation angle, determine a further measured phase angle deviation based on a plurality of voltage measurements, and determine the fault by identifying in which of the at least three further phase angle ranges the measured phase angle deviation is located, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges.

[0096] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0097] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0098] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0099] According to one embodiment, the transmission line carries multiple phases, and the processor is further configured to obtain multiple voltage measurements of the first terminal measured before and during the fault, and determine an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases.

[0100] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, determine a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determine a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0101] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0102] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0103] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0104] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0105] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0106] The present disclosure also relates to an apparatus for controlling a protection system for a power system including a transmission line, the apparatus comprising: a processor configured to receive at least three phase angle ranges, a measured phase angle deviation, a zero-phase sequence current, and / or a fault determined according to any one of the above-mentioned embodiments; and control a protection system for the power system based on the determined fault.

[0107] The present disclosure also relates to an apparatus for controlling a protection system for a power system including a transmission line, the apparatus comprising: a processor configured to: determine, during each of at least three faults, a plurality of phase angle deviations based on a network model of the power system; determine at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle; obtain a plurality of voltage measurements and current measurements of a first terminal; determine a measured phase angle deviation based on the plurality of voltage measurements and a zero-phase sequence current based on the plurality of current measurements of the first terminal; determine a fault based on the at least three phase angle ranges, the measured phase angle deviation, and the zero-phase sequence current; and control a protection system for the power system based on the determined fault.

[0108] According to one embodiment, the processor is further configured to, during each of the at least three further faults, determine a plurality of further phase angle deviations based on a network model of the power system; determine at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein a sum of the at least three further phase angle ranges is a complete rotation angle; determine a further measured phase angle deviation based on the plurality of voltage measurements; and determine the fault by identifying in which of the at least three further phase angle ranges the measured phase angle deviation is located, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges; and control a protection system for the power system based on the determined fault.

[0109] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0110] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0111] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0112] According to one embodiment, the transmission line carries multiple phases, and the processor is further configured to obtain multiple voltage measurements of the first terminal measured before and during the fault, and determine an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of multiple phases, and controlling the protection system is further based on the determined n-phase fault.

[0113] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, determine a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determine a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0114] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0115] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0116] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0117] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0118] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0119] The present disclosure also relates to a computer-readable medium carrying instructions for performing the method of any one of the above-mentioned embodiments for controlling a protection system for an electric power system.

[0120] The present disclosure further relates to a power system comprising the transmission line and apparatus of any of the above-described embodiments.

[0121] Various exemplary embodiments of the present disclosure are directed to providing features that will become readily apparent by reference to the following description in conjunction with the accompanying drawings. In accordance with various embodiments, exemplary systems, methods, and apparatuses are disclosed herein. It is understood, however, that these embodiments are presented by way of example and not limitation, and it will be apparent to those skilled in the art upon reading this disclosure that various modifications to the disclosed embodiments may be made while remaining within the scope of the present disclosure.

[0122] Thus, the present disclosure is not limited to the example embodiments and applications described and illustrated herein. Additionally, the specific order and / or hierarchy of steps in the methods disclosed herein is merely example approaches. Based on design preferences, the specific order or hierarchy of steps in a disclosed method or process can be rearranged while remaining within the scope of the present disclosure. Thus, those skilled in the art will understand that the methods and techniques disclosed herein present various steps or operations in a sample order, and that the present disclosure is not limited to the specific order or hierarchy presented, unless otherwise stated.

[0123] Hereinafter, exemplary embodiments of the present disclosure will be described. It should be noted that some aspects of any one of the described embodiments may also be found in some other embodiments unless otherwise specified or obvious. However, for the purpose of improving comprehension, each aspect will be described in detail only when first mentioned, and repeated descriptions of the same aspects will be omitted.

[0124] These and other aspects and implementations thereof are described in more detail in the drawings, description, and claims. [Brief explanation of the drawings]

[0125] [Figure 1] 1 is a flowchart of a method according to one embodiment of the present disclosure. [Figure 2] FIG. 1 illustrates a model of a power system according to one embodiment of the present disclosure. [Figure 3] FIG. 1 illustrates a model of a power system during a fault according to one embodiment of the present disclosure. [Figure 4] FIG. 1 illustrates a model of a power system during a fault according to one embodiment of the present disclosure. [Figure 5] FIG. 1 illustrates a range of phase angles for faults in a power system according to one embodiment of the present disclosure. [Figure 6]FIG. 1 illustrates a range of phase angles for faults in a power system according to one embodiment of the present disclosure. [Figure 7] FIG. 1 illustrates a range of phase angles for various faults in a power system according to one embodiment of the present disclosure. [Figure 8] 1 is a flowchart of a method according to one embodiment of the present disclosure. [Figure 9] 1 is a flowchart of a method according to one embodiment of the present disclosure. [Figure 10] FIG. 1 illustrates a power system under test according to one embodiment of the present disclosure. [Figure 11] FIG. 1 illustrates voltage and current measurements taken during a fault in a power system according to one embodiment of the present disclosure. [Figure 12] 10 is a graph of calculated phase angle, phase angle range, and current according to one embodiment of the present disclosure. [Figure 13] FIG. 10 illustrates a calculated phase angle and a range of calculated phase angles according to one embodiment of the present disclosure. [Figure 14] FIG. 1 illustrates voltage and current measurements taken during a fault in a power system according to one embodiment of the present disclosure. [Figure 15] 10 is a graph of calculated phase angle, phase angle range, and current according to one embodiment of the present disclosure. [Figure 16] FIG. 10 illustrates a calculated phase angle and a range of calculated phase angles according to one embodiment of the present disclosure. [Figure 17] FIG. 1 illustrates voltage and current measurements taken during a fault in a power system according to one embodiment of the present disclosure. [Figure 18] 10 is a graph of calculated phase angles and ranges of phase angles according to one embodiment of the present disclosure. [Figure 19] 10 is a graph of calculated current according to one embodiment of the present disclosure. [Figure 20] FIG. 10 illustrates a calculated phase angle and a range of calculated phase angles according to one embodiment of the present disclosure. [Figure 21] FIG. 1 illustrates a power system under test according to one embodiment of the present disclosure. [Figure 22] FIG. 1 illustrates a performance summary of a method according to an embodiment of the present disclosure. [Figure 23] FIG. 1 illustrates a power system under test according to one embodiment of the present disclosure. [Figure 24] FIG. 1 illustrates a performance summary of a method according to an embodiment of the present disclosure. [Figure 25] FIG. 1 illustrates a power system under test according to one embodiment of the present disclosure. [Figure 26] FIG. 1 illustrates a performance summary of a method according to an embodiment of the present disclosure. [Figure 27] FIG. 1 illustrates a power system under test according to one embodiment of the present disclosure. [Figure 28] FIG. 1 illustrates a performance summary of a method according to an embodiment of the present disclosure. [Figure 29] FIG. 1 illustrates a performance summary of a method according to an embodiment of the present disclosure. [Figure 30] 1 illustrates an apparatus, a computer-readable medium, and a system according to an embodiment of the present disclosure. DETAILED DESCRIPTION OF THE INVENTION

[0126] Detailed Description of Disclosure 1 is a flowchart of a method according to one embodiment of the present disclosure. At S101, during each of at least three faults, a plurality of phase angle deviations are determined based on a network model of the power system. At S102, at least three phase angle ranges are determined based on the plurality of phase angle deviations, and a sum of the at least three phase angle ranges is a complete rotation angle. At S103, a protection system for the power system is controlled based on the at least three phase angle ranges.

[0127]

number

[0128]

number

[0129]

number

[0130]

number

[0131] Applying Kirchhoff's current law (KCL) at fault point k, we obtain:

[0132]

number

[0133] This can be rearranged as follows:

[0134]

number

[0135] Further rearranging equation (2) gives us:

[0136]

number

[0137] This is equivalent to:

[0138]

number

[0139]

number

[0140]

number

[0141]

number

[0142]

number

[0143]

number

[0144]

number

[0145]

number

[0146]

number

[0147]

number

[0148] Substituting equation (10) into equation (9), we obtain:

[0149]

number

[0150]

number

[0151] Referring to FIG. 4, when applying a voltage divider of the positive sequence voltage, the negative sequence voltage can be obtained as follows:

[0152]

number

[0153] Substituting equation (12) into equation (13), we obtain:

[0154]

number

[0155] Similarly, the zero-sequence voltage can be expressed as:

[0156]

number

[0157] In case of AG fault, the superimposed voltage can be written as:

[0158]

number

[0159] Substituting equation (12) into equation (16), we obtain:

[0160]

number

[0161]

number

[0162]

number

[0163]

number

[0164]

number

[0165] The phase angle range for AG fault classification, also referred to herein as a zone, may be determined based on equations (18) and (19), as shown in FIG.

[0166]

number

[0167] Similar to the AG fault, the superimposed voltage for a phase B-phase C-earth fault, a BCG fault can be written as You can:

[0168]

number

[0169] The negative sequence for a BCG fault can be written as:

[0170]

number

[0171] Then the zero sequence for the BCG fault can be written as:

[0172]

number

[0173]

number

[0174]

number

[0175] The BCG fault classification is determined based on equations (23) and (24), as shown in Figure 6. obtain.

[0176]

number

[0177]

number

[0178]

number

[0179] The following describes a method for identifying faults, and in particular fault types, based on the range of phase angles shown in FIG.

[0180]

number

[0181]

number

[0182]

number

[0183]

number

[0184]

number

[0185] According to one embodiment, the plurality of phase angle deviations are different from the plurality of further phase angle deviations. According to one embodiment, the at least three faults are different from the at least three further faults. According to one embodiment, the at least three phase angle ranges are different from the at least three further phase angle ranges.

[0186]

number

[0187] 8 and 9 illustrate further embodiments of a method for identifying faults, and in particular fault types, based on the ranges of phase angles shown in FIG.

[0188]

number

[0189] According to one embodiment, the transmission line is terminated by a first terminal coupled to the first generator and by a second terminal coupled to the second generator, and the method further includes obtaining a plurality of voltage measurements at the first terminal, determining a measured phase angle deviation based on the plurality of voltage measurements, and determining a fault by, in particular, comparing the measured phase angle deviation with at least one of the at least three phase angle ranges, thereby identifying in which of the at least three phase angle ranges the measured phase angle deviation is located.

[0190] According to one embodiment, the method further includes determining, during each of the at least three further faults, a plurality of further phase angle deviations based on a network model of the power system, and determining at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein the plurality of phase angle deviations are different from the plurality of further phase angle deviations, the at least three faults are different from the at least three further faults, the at least three phase angle ranges are different from the at least three further phase angle ranges, and a sum of the at least three further phase angle ranges is a complete rotation angle.

[0191] According to one embodiment, the method further includes obtaining a plurality of voltage measurements of the first terminal, determining a further measured phase angle deviation based on the plurality of voltage measurements, and determining the fault by, in particular, comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges to identify in which of the at least three further phase angle ranges the measured phase angle deviation is located.

[0192] According to one embodiment, the method further includes obtaining a plurality of current measurements of the first terminal, determining a zero-phase sequence current based on the plurality of current measurements of the first terminal, and determining a fault further based on the zero-phase sequence current, in particular by comparing the zero-phase sequence current to a preset value.

[0193] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0194] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0195] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0196] According to one embodiment, the transmission line carries multiple phases, and the method includes obtaining multiple voltage measurements of the first terminal measured before and during the fault, and determining an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases.

[0197] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, and determining a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determining a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0198] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0199] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0200] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0201] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0202] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0203]

number

[0204] According to one embodiment, the method further includes determining, during each of the at least three further faults, a plurality of further phase angle deviations based on a network model of the power system, and determining at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein the plurality of phase angle deviations are different from the plurality of further phase angle deviations, the at least three faults are different from the at least three further faults, the at least three phase angle ranges are different from the at least three further phase angle ranges, and a sum of the at least three further phase angle ranges is a complete rotation angle.

[0205]

number

[0206] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a zero-sequence current based on the plurality of current measurements at the first terminal, determining a fault further based on the zero-sequence current, particularly by comparing the zero-sequence current with a preset value, and controlling a protection system for the power system based on the determined fault. According to one embodiment, determining a fault based on the zero-sequence current may be performed in S804 and S805 of FIG. and / or at least one of the above criteria 1 to 9.

[0207] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0208]

number

[0209] According to one embodiment, the transmission line carries multiple phases, and the method includes obtaining multiple voltage measurements at the first terminal measured before and during the fault, and determining an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases. , judgment Further based on the determined n-phase fault, Controlling the protection system This includes the following.

[0210] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, and determining a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determining a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0211] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0212] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0213] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0214] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0215] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0216]

number

[0217] According to one embodiment, the method further includes, during each of the at least three further faults, determining a plurality of further phase angle deviations based on a network model of the power system, determining at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein a sum of the at least three further phase angle ranges is a complete rotation angle, determining a further measured phase angle deviation based on a plurality of voltage measurements, and determining the fault by identifying in which of the at least three further phase angle ranges the measured phase angle deviation is located, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges.

[0218] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0219] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviations, or the further measured phase angle deviations are or include a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a negative-sequence voltage measured during the fault and the second phase angle is a phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between the first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault. According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviations, or the further measured phase angle deviations are or include a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0220] According to one embodiment, the transmission line carries multiple phases, and the method further includes obtaining multiple voltage measurements of the first terminal measured before and during the fault, and determining an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of multiple phases.

[0221] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, and determining a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determining a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0222] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0223] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0224] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0225] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0226] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0227] According to one embodiment, the method further includes, during each of the at least three further faults, determining a plurality of further phase angle deviations based on a network model of the power system, determining at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein a sum of the at least three further phase angle ranges is a complete rotation angle, determining a further measured phase angle deviation based on a plurality of voltage measurements, and determining the fault by identifying in which of the at least three further phase angle ranges the measured phase angle deviation is located, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges, and controlling a protection system for the power system based on the determined fault. According to one embodiment, the at least three faults or the at least three further faults are or include faults involving two phases, in particular phase-to-phase-to-ground faults, more particularly ABG, BCG, and CAG faults, and / or phase-to-phase faults, more particularly AB, BC, and CA faults. According to one embodiment, the at least three faults or the at least three further faults are or include faults involving a single phase, particularly phase-to-ground faults, more particularly AG, BG, and CG faults. According to one embodiment, the at least three faults or the at least three further faults are or include faults involving any possible combination of at least three of the above-mentioned faults. According to one embodiment, the at least three faults are the same as the at least three further faults. According to one embodiment, the at least three faults are different from the at least three further faults. According to one embodiment, the at least three phase angle ranges are or include zones 1, 2, and 3 of FIG. 7a) or zones 1, 2, and 3 of FIG. 7c). According to one embodiment, the at least three second phase angle ranges are or include zones 1, 2, and 3 of FIG. 7b) or zones 1, 2, and 3 of FIG. 7c).

[0228] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0229] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0230] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0231] According to one embodiment, the transmission line carries multiple phases, and the method includes obtaining multiple voltage measurements at the first terminal measured before and during the fault, and determining an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases. And, Further based on the determined n-phase fault , control the protection system The present invention further includes the steps of:

[0232] According to one embodiment, the method further includes obtaining a plurality of current measurements at the first terminal, determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, and determining a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determining a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0233] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0234] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0235] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0236] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0237] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0238] 10 illustrates a power system under test according to one embodiment of the present disclosure. The network 1000 comprises a first power source 1021 connected to a second power source 1022 via a transmission line 1010. In this embodiment, the first power source 1021 is an asynchronous power source, in particular a type IV wind turbine generator (WTG), and the second power source 1022 is a balanced Thevenin equivalent circuit (constant voltage source behind the source impedance) on the other side of the N1052 According to one embodiment, the first power source and / or the second power source may be a synchronous power source. The transmission line 1010 is terminated by a first terminal 1051, in this embodiment, bus M, and a second terminal 1052, in this embodiment, bus N. According to one embodiment, the transmission line is terminated by further terminals, such as a third terminal, a fourth terminal, etc. The WTG 1021 is connected to a Y-Δ transformer 1091 and a ΔY transformer 1092. 092 is coupled to bus M1 051. An intelligent electronic device IED is coupled to bus M1 An intelligent electronic device IED may be installed in, on, or associated with bus N1051. According to one embodiment, the IED measures the voltage and current of bus M1051. An intelligent electronic device IED may be installed in, on, or associated with bus N1052. According to one embodiment, the IED measures the voltage and current of bus N1052. According to one embodiment, an intelligent electronic device IED may be installed in, on, or associated with bus N1052. The IEDs installed in the bus M1051 and bus N1052 are omitted. Power flows from the first power source 1021 through line 1010 between bus M1051 and bus N1052, which in this case is a nominal 220 kV It is a 100 km long line operated by voltage.

[0239] Below are three fault cases and identification methods according to one embodiment of the present disclosure.

[0240] Case 1: AG failure 10 km from bus M1051, RF=10Ω, and fault inception angle FIA=60°:

[0241]

number

[0242] Case 2: AB failure 10 km from bus M1051, RF=50Ω, FIA=60°:

[0243]

number

[0244] Case 3: BCG failure 10 km from bus M1051, RF=10Ω, FIA=60°:

[0245]

number

[0246] The following includes Type III WTG, Type IV WTG, and solar photovoltaic (PV) generators: Includes single circuit, dual circuit, and cable systems with various CIRPP installations, including: Test results for various system configurations are shown.

[0247] System configuration: Single circuit transmission line with type IV WTG (Fig. 21) The network 2100 comprises a first power source 2121 connected to a second power source 2122 via a transmission line 2110. In this embodiment, the first power source 2121 is an asynchronous power source, in particular a type IV wind turbine generator WTG, and the second power source 2122 is a power grid modeled as a Thevenin equivalent circuit (a constant voltage source behind a source impedance) across a bus N 2152. According to one embodiment, the first power source and / or the second power source may be a synchronous power source. The transmission line 2110 is terminated by a first terminal 2151, in this embodiment, bus M, and a second terminal 2152, in this embodiment, bus N. According to one embodiment, the transmission line is terminated by further terminals, such as a third terminal, a fourth terminal, etc. The WTG 2121 is connected to the power grid via a Y-Delta transformer 2141 and a Delta-Y transformer 2142. The intelligent electronic device IED is connected to the bus M2151 as The IED may be installed in, on, or associated with the bus M2151. According to one embodiment, the IED measures the voltage and current of the bus M2151. is installed in, on, or associated with bus N2152 According to one embodiment, an IED measures the voltage and current of bus N2 152. According to one embodiment, an IED installed at, in, on, or associated with bus N2 152 is omitted. Power is supplied to line 211 between bus M2 151 and bus N2 152. 0 from the first power source 2121. The test conditions, system parameters, and WTG parameters are listed below.

[0248] Total number of test cases = 660 Test conditions:

[0249]

number

[0250] 22 is a diagram illustrating a performance summary of a method according to one embodiment of the present disclosure. In particular, the performance summary includes the performance of a first approach and a second approach for comparison purposes.

[0251] System configuration: Single-circuit transmission line with wind power type III (Figure 23) The network 2300 comprises a first power source 2321 connected via a transmission line 2310 to a second power source 2322. In this embodiment, the first power source 2321 is an asynchronous power source, in particular a type III wind turbine generator WTG, and the second power source 2322 is connected to bus N23. 52. According to one embodiment, the first power source and / or the second power source may be a synchronous power source. The transmission line 2310 is terminated by a first terminal 2351, in this embodiment, bus M, and a second terminal 2352, in this embodiment, bus N. According to one embodiment, the transmission line is terminated by further terminals, such as a third terminal, a fourth terminal, etc. The WTG 2321 includes a Y-Δ transformer 2341 and a ΔY transformer 2342. The intelligent electronic device IED is connected to the bus M2351. , may be installed in, on, or associated with bus M2351. According to one embodiment, an IED measures the voltage and current of bus M2351. An intelligent electronic device IED may be installed in, on, or associated with bus N2352. According to one embodiment, an IED measures the voltage and current of bus N2352. According to one embodiment, an IED is installed in, on, or associated with bus N2352. The power is supplied to line 231 between bus M2351 and bus N2352. 0 from the first power source 2321. The test conditions, system parameters, and WTG parameters are listed below.

[0252] Total number of test cases = 528 Test conditions:

[0253]

number

[0254] 24 is a diagram illustrating a performance summary of a method according to one embodiment of the present disclosure. In particular, the performance summary includes the performance of a first approach and a second approach for comparison purposes.

[0255] System configuration: Single circuit transmission line with solar PV generator (Figure 25) The network 2500 comprises a first power source 2521 connected via a transmission line 2510 to a second power source 2522. In this embodiment, the first power source 2521 is an asynchronous power source, in particular solar PV, and the second power source 2522 is a tera- bio-electrical power source across a bus N2552. 25 is a power grid modeled as a Venant equivalent circuit (a constant voltage source behind a source impedance). According to one embodiment, the first power source and / or the second power source may be a synchronous power source. The transmission line 2510 is connected to a first terminal 2551, in this embodiment a bus M , and a second terminal 2552, which in this embodiment is terminated by bus N. According to the above, the transmission line is terminated by further terminals such as a third terminal, a fourth terminal, etc. The solar PV 2521 is connected to the bus M via a Y-Δ transformer 2541 and a ΔY transformer 2542. 2551. An intelligent electronic device IED may be installed in, on, or associated with bus M2351. According to one embodiment, an IED is , measure the voltage and current of bus M2551. The intelligent electronic device IED measures the voltage and current of bus N An IED may be installed at, in, on, or associated with bus N2552. According to one embodiment, an IED measures the voltage and current of bus N2552. According to one embodiment, an IED installed at, in, on, or associated with bus N2552 is omitted. Power flows from first power source 2521 via line 2510 between bus M2551 and bus N2552. The test conditions, system parameters, and solar PV parameters are listed below.

[0256] Total number of test cases = 528 Test conditions:

[0257]

number

[0258] 26 is a diagram illustrating a performance summary of a method according to one embodiment of the present disclosure. In particular, the performance summary includes the performance of a first approach and a second approach for comparison purposes.

[0259] System configuration: Double-circuit transmission line with wind power type IV (Figure 27) Network 2700 comprises a first power source 2721 connected to a second power source 2722 via transmission line 2710. Transmission line 2710 is a dual-circuit transmission line. In this embodiment, first power source 2721 is an asynchronous power source, specifically a Type IV wind turbine generator WTG, and second power source 2722 is a power grid modeled as a Thevenin equivalent circuit (a constant voltage source behind a source impedance) across bus N 2752. According to one embodiment, the first power source and / or the second power source may be a synchronous power source. Transmission line 2710 is connected to a first terminal 2751, in this embodiment bus M, and a second terminal 2752. 752, in this embodiment terminated by bus N. According to one embodiment, the transmission line is , a third terminal, a fourth terminal, etc. WTG2721 is coupled to bus M2751 via a Y-Δ transformer, particularly a grounded Y-Δ transformer 2741, and a ΔY transformer, particularly a grounded ΔY transformer 2742. An intelligent electronic device IED may be installed on, in, on, or associated with bus M2751. According to one embodiment, the IED measures the voltage and current of bus M2751. An intelligent electronic device IED may be installed on, in, on, or associated with bus N2752. According to one embodiment, the IED measures the voltage and current of bus N2752. According to one embodiment, the IED measures the voltage and current of bus N2752. According to one embodiment, the IED measures the voltage and current of bus N2752. The IEDs associated with this are omitted. Power is provided by buses M2751 and N275. 2. Test conditions, system parameters, and Type IV WTG parameters are listed below.

[0260] Total number of test cases = 528 Test conditions:

[0261]

number

[0262] 28 is a diagram illustrating a performance summary of a method according to one embodiment of the present disclosure. In particular, the performance summary includes the performance of a first approach and a second approach for comparison purposes.

[0263] 29 is a diagram illustrating a performance summary of a method according to one embodiment of the present disclosure. In particular, the performance summary includes the performance of a first approach and a second approach for comparison purposes.

[0264] 30 illustrates an apparatus, a computer-readable medium, and a system according to one embodiment of the present disclosure. Apparatus 3010 is an apparatus for controlling a protection system for a power system including a transmission line. Computer-readable medium 3020 is an apparatus for controlling a protection system for a power system including a transmission line, carrying instructions for performing the method of any one of the above-described embodiments. Power system 3000 includes apparatus 3010 of any one of the above-described embodiments and computer-readable medium 3020 of any one of the above-described embodiments.

[0265] According to one embodiment, the transmission line is terminated by a first terminal coupled to the first generator and by a second terminal coupled to the second generator, and the processor is further configured to obtain a plurality of voltage measurements at the first terminal, determine a measured phase angle deviation based on the plurality of voltage measurements, determine a fault, in particular by comparing the measured phase angle deviation with at least one of at least three phase angle ranges to identify in which of the at least three phase angle ranges the measured phase angle deviation is located, and control a protection system for the power system based on the determined fault.

[0266] According to one embodiment, the processor is further configured to: determine, during each of the at least three further faults, a plurality of further phase angle deviations based on a network model of the power system; and determine at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein the plurality of phase angle deviations are different from the plurality of further phase angle deviations, the at least three faults are different from the at least three further faults, the at least three phase angle ranges are different from the at least three further phase angle ranges, and a sum of the at least three further phase angle ranges is a complete rotation angle.

[0267] According to one embodiment, the processor is further configured to obtain a plurality of voltage measurements of the first terminal, determine a further measured phase angle deviation based on the plurality of voltage measurements, determine a fault, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges to identify in which of the at least three further phase angle ranges the measured phase angle deviation is located, and control a protection system for the power system based on the determined fault.

[0268] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a zero-phase sequence current based on the plurality of current measurements at the first terminal, determine a fault further based on the zero-phase sequence current, in particular by comparing the zero-phase sequence current to a preset value, and control a protection system for the power system based on the determined fault.

[0269] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0270] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0271] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0272] According to one embodiment, the transmission line carries multiple phases, and the processor obtains multiple voltage measurements at the first terminal measured before and during the fault, and determines an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of the multiple phases. And, Further based on the determined n-phase fault , control the protection system The device is further configured to:

[0273] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, determine a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determine a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0274] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0275] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0276] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0277] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0278] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0279] According to one embodiment, the processor is further configured to, during each of the at least three further faults, determine a plurality of further phase angle deviations based on a network model of the power system; determine at least three further phase angle ranges based on the further plurality of phase angle deviations, wherein a sum of the at least three further phase angle ranges is a complete rotation angle; determine a further measured phase angle deviation based on the plurality of voltage measurements; and determine the fault by identifying in which of the at least three further phase angle ranges the measured phase angle deviation is located, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges; and control a protection system for the power system based on the determined fault.

[0280] According to one embodiment, the measured phase angle deviation is the phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of the negative-sequence voltage measured during the fault and the second phase angle is the phase angle of the zero-sequence voltage measured during the fault, or the phase angle difference between the phase angle of the positive-sequence voltage measured before the fault and the phase angle of the positive-sequence voltage measured during the fault.

[0281] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is the phase angle of a negative-sequence voltage measured during the fault and the second phase angle is the phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

[0282] According to one embodiment, the plurality of phase angle deviations, the further plurality of phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or includes a phase angle difference between a first phase angle and a second phase angle, where the first phase angle is a phase angle of a first phase of a voltage or current measured at a point on the transmission line before the fault and the second phase angle is a phase angle of a second phase of a voltage or current measured at a point on the transmission line during the fault.

[0283] According to one embodiment, the transmission line carries multiple phases, and the processor is further configured to obtain multiple voltage measurements of the first terminal measured before and during the fault, and determine an n-phase fault based on a voltage difference between each phase of the multiple voltage measurements measured before the fault and the multiple voltage measurements measured during the fault, where n is a natural number greater than 1 corresponding to the number of multiple phases, and controlling the protection system is further based on the determined n-phase fault.

[0284] According to one embodiment, the processor is further configured to obtain a plurality of current measurements at the first terminal, determine a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements, determine a measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be of the first generator type, or determine a measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be of the second generator type.

[0285] According to one embodiment, the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power source or a grid having at least one synchronous power source and / or at least one non-conventional power source.

[0286] According to one embodiment, the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

[0287] According to one embodiment, the phase angle ranges of the at least three further phase angle ranges do not overlap with one another.

[0288] According to one embodiment, each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations.

[0289] According to one embodiment, each of the at least three further phase angle ranges includes a respective phase angle deviation of the plurality of further phase angle deviations.

[0290] While various embodiments of the present disclosure have been described above, it should be understood that they are presented by way of example only, and not by way of limitation. Similarly, various figures may depict example architectures or configurations provided to enable those skilled in the art to understand example features and functionality of the present disclosure. However, such persons will understand that the present disclosure is not limited to the example architectures or configurations shown, but can be implemented using a variety of alternative architectures and configurations. Moreover, as will be understood by those skilled in the art, one or more features of one embodiment can be combined with one or more features of other embodiments described herein. Thus, the breadth and scope of the present disclosure should not be limited by any of the above-described example embodiments.

[0291] It will also be understood that any reference to an element herein using a designation such as "first," "second," etc., generally does not limit the quantity or order of those elements. Rather, these designations may be used herein as a convenient means of distinguishing between two or more elements or instances of an element. Thus, a reference to a first and a second element does not imply that only two elements may be used or that the first element must in any way precede the second element.

[0292] Additionally, those skilled in the art will understand that information and signals may be represented using any of a variety of different technologies and techniques. For example, the data, instructions, commands, information, signals, bits, and symbols that may be referenced in the above description may be represented by voltages, currents, electromagnetic waves, magnetic fields or particles, optical fields or particles, or any combination thereof.

[0293] Those skilled in the art will further recognize that any of the various illustrative logical blocks, units, processors, means, circuits, methods, and functions described in connection with the aspects disclosed herein may be implemented by electronic hardware (e.g., digital implementations, analog implementations, or a combination of the two), firmware, various forms of program or design code incorporating instructions (which may be referred to herein for convenience as "software" or "software units"), or any combination of these technologies.

[0294] To clearly illustrate this interchangeability of hardware, firmware, and software, various illustrative components, blocks, units, circuits, and steps have been described above generally in terms of their functionality. Whether such functionality is implemented as hardware, firmware, or software, or a combination of these technologies, depends on the particular application and design constraints imposed on the overall system. Those skilled in the art may implement the described functionality in various ways for each particular application, and such implementation decisions do not depart from the scope of the present disclosure. According to various embodiments, a processor, device, component, circuit, structure, machine, unit, etc. may be configured to perform one or more of the functions described herein. The terms "configured to" or "configured for," as used herein with respect to a specified operation or function, refer to a processor, device, component, circuit, structure, machine, unit, etc. that is physically constructed, programmed, and / or arranged to perform the specified operation or function.

[0295] Furthermore, those skilled in the art will understand that the various example methods, logical blocks, units, devices, components, and circuits described herein can be implemented in or performed by an integrated circuit (IC), which can include a general-purpose processor, a digital signal processor (DSP), an application-specific integrated circuit (ASIC), a field programmable gate array (FPGA), or other programmable logic device, or any combination thereof. The logical blocks, units, and circuits can further include an antenna and / or transceiver for communicating with various components within a network or device. The general-purpose processor can be a microprocessor, although in the alternative, the processor can be any conventional processor, controller, or state machine. A processor can also be implemented as a combination of computing devices, e.g., a combination of a DSP and a microprocessor, multiple microprocessors, one or more microprocessors in conjunction with a DSP core, or any other suitable configuration for performing the functions described herein. If implemented in software, the functions can be stored as one or more instructions or code on a computer-readable medium. Thus, the steps of a method or algorithm disclosed herein can be implemented as software stored on a computer-readable medium.

[0296] Computer-readable media includes both computer storage media and communication media, including any medium that can enable a computer program or code to be transferred from one place to another. Storage media can be any available medium that can be accessed by a computer. By way of example, and not limitation, such computer-readable media can include RAM, ROM, EEPROM, CD-ROM or other optical disk storage, magnetic disk storage or other magnetic storage devices, or any other medium that can be used to store desired program code in the form of instructions or data structures and that can be accessed by a computer.

[0297] Additionally, memory or other storage devices, as well as communication components, may be used in embodiments of the present disclosure. It will be appreciated that, for clarity, the above description has described embodiments of the present disclosure with reference to different functional units and processors. However, it will be apparent that any suitable distribution of functionality between different functional units, processing logic elements, or domains may be used without detracting from the present disclosure. For example, functions shown to be performed by separate processing logic elements or controllers may be performed by the same processing logic element or controller. Accordingly, references to specific functional units do not indicate a strict logical or physical structure or organization, but merely to suitable means for providing the described functionality.

[0298] Various modifications to the embodiments described in this disclosure will be readily apparent to those skilled in the art, and the general principles defined herein may be applied to other embodiments without departing from the scope of the present disclosure. Thus, the present disclosure is not intended to be limited to the embodiments shown herein but is to be accorded the widest scope consistent with the novel features and principles disclosed herein, as set forth in the following claims.

Claims

1. 1. A method for controlling a protection system for an electric power system comprising a transmission line, the method comprising: determining a plurality of phase angle deviations during each of the at least three faults based on a network model of the power system; determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle; controlling the protection system for the power system based on the at least three phase angle ranges; A method comprising:

2. The transmission line is terminated by a first terminal coupled to a first generator and by a second terminal coupled to a second generator, and the method comprises: obtaining a plurality of voltage measurements at the first terminal; determining a measured phase angle deviation based on the plurality of voltage measurements; determining a fault by identifying in which of the at least three phase angle ranges the measured phase angle deviation is located, in particular by comparing the measured phase angle deviation with at least one of the at least three phase angle ranges; controlling the protection system for the power system based on the determined fault; and The method of claim 1 further comprising:

3. determining a plurality of additional phase angle deviations based on the network model of the power system during each of at least three additional faults; determining at least three additional phase angle ranges based on the additional plurality of phase angle deviations, the sum of the at least three additional phase angle ranges being a complete rotation angle; and 3. The method of claim 1 or 2, further comprising:

4. obtaining a plurality of voltage measurements at the first terminal; determining a further measured phase angle deviation based on the plurality of voltage measurements; determining the fault by identifying in which of the at least three further phase angle ranges the measured phase angle deviation is located, in particular by comparing the measured phase angle deviation with at least one of the at least three further phase angle ranges; controlling the protection system for the power system based on the determined fault; and The method of claim 3 further comprising:

5. obtaining a plurality of current measurements at the first terminal; determining a zero-sequence current based on the plurality of current measurements at the first terminal; determining the fault further based on the zero-sequence current, in particular by comparing the zero-sequence current with a preset value; controlling the protection system for the power system based on the determined fault; and The method of any one of claims 1 to 4, further comprising:

6. 6. The method according to claim 1, wherein the measured phase angle deviation is a phase angle difference between a first phase angle and a second phase angle, wherein the first phase angle is a phase angle of a negative-sequence voltage measured during a fault and the second phase angle is a phase angle of a zero-sequence voltage measured during the fault, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

7. 7. The method of claim 4, wherein the plurality of phase angle deviations, the plurality of further phase angle deviations, the measured phase angle deviation, or the further measured phase angle deviation is or comprises a phase angle difference between a first phase angle and a second phase angle, wherein the first phase angle is a phase angle of a negative-sequence voltage measured during a fault and the second phase angle is a phase angle of a zero-sequence voltage measured during the fault, a phase angle difference between a first phase angle and a second phase angle, or a phase angle difference between a phase angle of a positive-sequence voltage measured before the fault and a phase angle of a positive-sequence voltage measured during the fault.

8. The transmission line carries a plurality of phases, and the method comprises: obtaining a plurality of voltage measurements at the first terminal measured before and during the fault; determining an n-phase fault based on a voltage difference between each phase of the plurality of voltage measurements taken before the fault and the plurality of voltage measurements taken during the fault, where n is a natural number greater than 1 corresponding to the number of the plurality of phases; controlling the protection system is further based on the determined n-phase fault. The method according to any one of claims 2 to 7, comprising:

9. obtaining a plurality of current measurements at the first terminal; determining a generator type of the first generator based on the plurality of current measurements and / or the plurality of voltage measurements; determining the measured phase angle deviation based on the plurality of voltage measurements if the first generator is determined to be a first generator type; or determining the measured phase angle deviation based on the plurality of current measurements if the first generator is determined to be a second generator type; The method according to any one of claims 2 to 8, comprising:

10. The method according to any one of claims 2 to 6, wherein the first power source is one of a grid, a synchronous power source, a non-conventional power source, in particular an inverter-tied power source, and the second power source is a synchronous power or a grid having at least one synchronous power source and / or at least one non-conventional power source.

11. The method of any one of claims 1 to 7, wherein the phase angle ranges of the at least three phase angle ranges do not overlap with each other.

12. each of the at least three phase angle ranges includes a respective phase angle deviation of the plurality of phase angle deviations; The method according to any one of claims 1 to 9.

13. 1. A method for controlling a protection system for an electric power system comprising a transmission line terminated by a first terminal, the method comprising: determining a plurality of phase angle deviations during each of the at least three faults based on a network model of the power system; determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle; obtaining a plurality of voltage and current measurements at the first terminal; determining a measured phase angle deviation based on the plurality of voltage measurements and a zero-sequence current based on the plurality of current measurements at the first terminal; determining a fault based on the at least three phase angle ranges, the measured phase angle deviation, and the zero-sequence current; controlling the protection system for the power system based on the determined fault; and A method comprising:

14. 1. An apparatus for controlling a protection system for an electric power system including a transmission line, comprising: a processor; determining a plurality of phase angle deviations during each of the at least three faults based on a network model of the power system; determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle; controlling the protection system for the power system based on the at least three phase angle ranges; 11. An apparatus comprising: a processor configured to:

15. 1. An apparatus for controlling a protection system for an electric power system including a transmission line, comprising: a processor; determining a plurality of phase angle deviations during each of the at least three faults based on a network model of the power system; determining at least three phase angle ranges based on the plurality of phase angle deviations, wherein a sum of the at least three phase angle ranges is a complete rotation angle; obtaining a plurality of voltage and current measurements at the first terminal; determining a measured phase angle deviation based on the plurality of voltage measurements and a zero-sequence current based on the plurality of current measurements at the first terminal; determining a fault based on the at least three phase angle ranges, the measured phase angle deviation, and the zero-sequence current; controlling the protection system for the power system based on the determined fault; and 11. An apparatus comprising: a processor configured to:

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