Patent Application
20050288877
1. The Field of the Invention
The present invention relates to systems and methods for measuring a power parameter on a high voltage power line. More particularly, the present invention relates to systems and methods for improving the accuracy of measurement of power parameters on a high voltage power line including compensating for inaccuracies in the output of instrument transformers designed for connection to power lines of 10 kV or higher.
2. Background and Relevant Art
Instrument transformers for installation on high voltage power lines, which may include those transformers used for protective relaying and metering, are large and expensive. This is especially true at higher power line voltages. For instance, instrument transformers for installation on 230 kV lines may cost more than $100,000 U.S. each. Replacement of instrument transformers is thus very costly in terms of capital costs. It is also very costly to replace instrument transformers due to the necessity to power down the power line while doing so. The large size of the instrument transformers also means that installation/removal and transportation costs are high.
It is quite common in legacy installations (such as at a substation) that the only instrument transformers that are installed are those used for protective relaying. These instrument transformers are typically designed to operate during large fault currents or voltages and are therefor not optimized for accuracy at normal currents and voltages. For example a relaying current transformer may have a large magnetic core and high core losses.
When instrument transformers optimized for metering applications are provided in an installation, they may be subject to degradation in accuracy over time. This may be due to magnetization from surge voltages or currents, insulation breakdown, degradation due to environmental stresses, etc.
It is therefor common in legacy installations to have inaccuracies in the measurement of voltage, current and therefore power flow due to the degradation and/or inherent inaccuracy of the installed instrumentation.
The present invention is defined by the following claims, and nothing in this section should be taken as a limitation on those claims. By way of introduction, the preferred embodiments described below relate to systems and methods for measuring power parameters of a power line and more particularly to systems and methods for improving the accuracy of or correcting the measurements of power parameters monitored by legacy instrumentation.
One embodiment includes a method for reclassifying legacy instrumentation. The method couples a first line device to a power line and a second line device to the legacy instrumentation. First data representing at least one power parameter is generated with the first line device and second data representing the at least one power parameter is generated using the second line device. Transfer characteristics of the legacy instrumentation are then identified based on at least the first data and the second data.
Another embodiment includes a method for reclassifying a current transformer in a legacy instrumentation. The method includes connecting a first line device on a bus line associated with a particular transmission line, wherein the bus line includes one or more current transformers. The method connects a second line device on a secondary of a particular current transformer. In the method, the second line device is similar to the first line device. The method then determines transfer characteristics of the particular current transformer by comparing first data measured by the first line device for current in the bus line with second data measured by the second line device. Next, the method reclassifies the particular current transformer based on the transfer characteristics.
Another embodiment includes a system for reclassifying the legacy instrumentation. The system includes a first line device operative to couple to the power line and monitor at least one parameter of the power line. The first line device generates first data indicative of the at least one parameter of the power line. The system also includes a second line device operative to interface with the legacy instrumentation and monitor the at least one parameter of the power line at the legacy instrumentation. The second line device generates second data indicative of the at least one parameter of the power line at the legacy instrumentation. In the system, a microprocessor based device is coupled with the first line device and with the second line device. The microprocessor based device identifies one or more transfer characteristics of the legacy instrumentation based on the first data and the second data.
Another embodiment includes a system for reclassifying a current transformer. The system has a first line device operative to couple with a particular bus line in the power station. The first line device generates first characteristics relating to current in the particular bus line. In the system, a second line device is operative to couple with a secondary of a particular current transformer connected with the particular bus line and the second line device generates second characteristics relating to current in the particular current transformer. The system also includes a microprocessor device coupled with the first line device and the second line device such that current flow through the particular current transformer is characterized using the first characteristics and the second characteristics.
Another embodiment of the invention includes a method for correcting power parameters measured by legacy instrumentation. The method attaches a sensor to a transmission line. The method then monitors one or more power parameters of The transmission line with the sensor and detects a transient condition in the transmission line with the sensor. The method then determines if characteristics of the legacy instrumentation have changed in response to the transient condition and reclassifies the legacy instrumentation if the characteristics have changed.
Further aspects and advantages of the invention are discussed below in conjunction with the preferred embodiments.
In order to describe the manner in which the above-recited and other advantages and features of the invention can be obtained, a more particular description of the invention briefly described above will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings. Understanding that these drawings depict only typical embodiments of the invention and are not therefore to be considered to be limiting of its scope, the invention will be described and explained with additional specificity and detail through the use of the accompanying drawings in which:
Herein, the phrase “coupled with” is defined to mean directly connected to or indirectly connected through one or more intermediate components. Such intermediate components may include both hardware and software based components. Further, to clarify the use in the pending claims and to hereby provide notice to the public, the phrases “at least one of <A>, <B>, . . . and <N>” or “at least one of <A>, <B>, . . . <N>, or combinations thereof” are defined by the Applicant in the broadest sense, superceding any other implied definitions herebefore or hereinafter unless expressly asserted by the Applicant to the contrary, to mean one or more elements selected from the group comprising A, B, . . . and N, that is to say, any combination of one or more of the elements A, B, . . . or N including any one element alone or in combination with one or more of the other elements which may also include, in combination, additional elements not listed.
Examples of the present invention provide systems and methods for improving the accuracy of monitoring of voltage, current and power flowing in power lines. These power lines typically include three-phase transmission and distribution lines of 10 kV and up. One embodiment of an apparatus includes a line mounted device that can be temporarily or permanently attached to a power line. The line mounted device may be mounted to a transmission conductor, bus bar, jumper, or any other conductor carrying the voltage and/or current of the power line as appropriate. The line mounted device measures at least one of voltage, current and power flowing in the power line. The apparatus further includes a microprocessor device capable of comparing the output of the line mounted device with the output of the legacy instrumentation, which is already installed and monitoring the power line. The microprocessor based device is further operative to produce an output that is usable to compensate the output of the existing legacy instrumentation such that after the line mounted device is removed from the power line, accurate measurement of voltage, current and/or power is still possible with the legacy instrumentation. The microprocessor based device may be a computer, computing device, and/or IED such as an existing digital power meter, protective relay, etc., that is capable of receiving communication from the sensor.
One implementation of the sensor may be the HVTLAD described in U.S. patent application Ser. No. 10/774,088 entitled “BODY CAPACITANCE ELECTRIC FIELD POWERED DEVICE FOR HIGH VOLTAGE LINES” which is incorporated by reference herein. Alternatively, the sensor may be powered by current flow in the power line, a battery, solar power, wind power or other energy source. Any of these energy sources may be complemented by a large value capacitor (typically referred to as a supercapacitor). The supercapacitor may store energy while the device is operating in a low power mode and deliver energy in order that the device may periodically perform operations that require more energy.
A processor 110 couples to the sensor 150 and is operative to receive this digital representation of the voltage, current, and/or power. The processor 110 may also receive a digital representation of other data including temperature, humidity, wind speed, line sag, and the like. The processor 110 may perform calibration, rms calculations, compensations, phase calculations, etc., on the digital representation to produce modified digital representations. The modified digital representations are communicated via communication circuitry 130 to a microprocessor based device 160. The communications pathway between the communication circuitry 130 and the microprocessor device 160 may be a wireless link such as Bluetooth®, wireless telephone, or other radio frequency wireless links.
In the process of generating the modified digital representations, the processor 110 may include position and or time information provided by time/position circuitry 120. The time/position circuitry 120 may be, for example, a global positioning satellite (GPS) receiver that determines accurate time and position using global positioning satellites. The time/position circuitry may also be comprised within communications circuitry 130 such as wireless telephone circuitry. Alternatively, time/position circuitry 120 may be replaced by accurate time circuitry such as an atomic clock module coupled to the processor 110 if position is not important in the particular application.
The line mounted device 105 comprises a power source 140 to provide operating power to the circuitry within the line mounted device 105. As described above, the power source 140 may derive power from a body capacitance coupled to the power line 170, a battery or other appropriate power source.
Legacy instrumentation 180 also couples to the power line 170. The legacy instrumentation 180 may comprise current transformer(s), voltage transformer(s), power meter(s), protective relay(s), etc. The legacy instrumentation 180 produces output or readings (including measurements of voltage, current, and/or power in the power line 170) that may be in error due to age, deterioration, operating range, etc., of the legacy instrumentation 180 as described above. At least the metering portion of the legacy instrumentation 180 may be comprised within the microprocessor based device 160.
The line mounted device 105 transmits the at least one power parameter using communications circuitry 130 to the microprocessor based device 160 (block 220). The microprocessor based device 160 may have a memory that enables it to store multiple values of the at least one power parameter. The microprocessor based device 160 also receives and stores power parameters from the legacy instrumentation. Over a time period (for example one hour, one day, one week, one month, one year, etc.) the microprocessor based device 160 compares the power parameters received from the line mounted device 105 with the power parameters received from the legacy instrumentation 180 (block 230). The time period may be selected such that the power line will transition through most or all of its normal range of operation. The utility operating the power line 170 may also cycle the power line 170 through a range of operating current, voltage levels, etc. This may be done by changing the routing of power within the grid, ramping up or down generators located on the grid, opening/closing breakers within a substation, etc. The microprocessor based device 160 then produces compensation data that will facilitate correction of the power parameter measurement of the legacy instrumentation 180 (block 240). The compensation data is based, in one example, on the power parameters received from the line mounted device 105, the power parameters received from the legacy instrumentation 180, and/or a comparison of these power parameters.
The correction of the power parameters received from or generated by the legacy instrumentation may occur in several ways. The microprocessor based device 160 may receive the power parameter measurements of the legacy instrumentation 180 and produce corrected measurements using the compensation data. This may be accomplished using algorithms similar to those described in U.S. Pat. No. 6,671,635 entitled “Systems for Improved Monitoring Accuracy of Intelligent Electronic Devices” which is incorporated by reference herein. In another embodiment, the legacy instrumentation 180 may already contain correction algorithms in which case the legacy instrumentation 180 may be configured to use the new compensation data generated by the microprocessor based device 160. This may be facilitated by an instrument transformer correction function such as described on pages Instr Xformer Correction (ITC) Module −1 to 5 in the document entitled “ION Reference” published in March 2004 by Power Measurement located in Saanichton, B.C., Canada which is incorporated by reference herein. The microprocessor based device 160 may alternatively or in addition correct voltages and currents sample by sample, by phase, by frequency response, by power factor, using polynomial or other types of interpolation, using multiple calibration constants depending on load, based on temperature or humidity measurements, and the like or any combination thereof. For instance it may be found that a CT has a non-linear amplitude transformation ratio which is primarily based on the input signal amplitude, but also dependent on temperature. The line mounted device 105 may thus accurately measure amplitude and temperature which are reported to the microprocessor based device 160 and a multidimensional correction of the characteristics of the legacy CT may be determined based on these parameters. The data transmitted from the line mounted device 105 to the microprocessor based device 160 may include data indicative of voltage, current or power in the time domain or frequency domain.
The correction of the power parameters may then be applied on an ongoing basis (block 250). A power customer may thereafter be billed for their power usage based on the corrected power parameters. The line mounted device 105 may be removed (block 260) from the power line 170. Alternatively, the line mounted device 105 may be left on the power line 170. If the line mounted device 105 is left on the power line 170, it may be considered part of legacy instrumentation 180 to which the procedure of the present invention may be applied to in the future. This helps to compensate for any degradation of accuracy that may occur over time in the line mounted device 105 that has been permanently installed.
After the line mounted device 105 has been removed from the line, it may be taken to a laboratory and connected to a test set to verify that the line mounted device is still accurate (block 270). If it is still accurate, the correction factors to be used are thus validated. If not, the process may be restarted after the line mounted device 105 is re-calibrated. If the line mounted device 105 comprises a current sensor, the laboratory tests may include injecting a known current with a known phase with respect to a reference and comparing these known values to the output of the line mounted device 105.
Alternatively, the line mounted device 105 may monitor power parameters only under certain conditions. For example if a transient (such as a current surge, lightning strike, etc.) is detected (block 210a), the line mounted device 105 may notify the microprocessor based device 160 of this occurrence (block 210b). Under this condition, it may be determined that the characteristics of the legacy instrumentation 180 may have changed due to the transient and therefore, previous comparisons of the legacy instrumentation 180 output and the line mounted device 105 output may be discarded (block 210c). Alternatively, a more steady state condition such as high levels of harmonics may be detected by the line mounted device 105 which may indicate that some comparison algorithms may (at least temporarily) be unusable.
The characteristics of the legacy instrumentation 180 may change over time due to other influences (for example temperature, humidity, long term drift, etc.). If, for example, the legacy instrumentation 180 and line mounted device 105 are detecting current in the power line 170, the microprocessor may flag occurrences when the line mounted device 105 indicates the same current is flowing in the power line 170 as a previous measurement, but the legacy instrumentation 180 does not have the same output (within a desired accuracy specification) as previously. This may be an indication that reclassification of the legacy instrumentation to the desired accuracy may not be possible or additional influences may need to be taken into account.
The line mounted device 105 may also only monitor power parameters when the power line 170 is in a state not previously measured (for instance current is at a magnitude that has not been detected by the line mounted device 105 before). If a new condition is detected (210d), the power parameters are monitored (block 210e). The line mounted device 105 or microprocessor based device 160 may determine that all necessary conditions of the power line 170 have been seen (block 210f) (for instance, the power line has transitioned through various current levels such as 1-5A, 5-50A, 50-200A, etc.). In this case, an indication may be given to a user that the process is complete (block 210g). The monitoring process concludes with the line mounted device 105 going into a power saving sleep mode (210h). The line mounted device 105 may exit the sleep mode after a given passage of time or may detect a new condition during sleep mode and only wake up if a new condition is detected.
In another example, the legacy instrumentation 180 itself also acts as the microprocessor based device 160 and communicates to the line mounted device 105 through a wireless connection. In this example, the legacy instrumentation 180 performs and implements the compensation characteristic calculations. Alternately, data, that may include but is not limited to, power parameters, and/or compensation data or characteristics, is loaded into a first device 160, such as a portable energy meter, laptop or other portable computing device, and then transferred into the legacy instrumentation 180, ultimately allowing the legacy instrumentation 180 to perform the compensation characteristic calculations with its own microprocessor based on the power parameter data measurements of the line mounted device 105 and the power parameter data measurements of the legacy instrumentation 180.
In another example the line mounted device 105 incorporates wireless circuitry, such as cellular telephony circuitry, that enables it to communicate with the legacy instrumentation 180 to continue to compensate for the legacy instrumentation 180 measurement drift or error. In operation the line mounted device 105 is coupled to the power line 170 through methods known for attaching devices to power lines, such as a “hot stick”. The line mounted device 105 then utilizes the wireless circuitry to communicate the sensor power parameter data to a microprocessor device 160, which also contains the legacy instrumentation 180 power parameter data. It can be appreciated that the microprocessor device 160 can be either an element of the legacy instrumentation 180 or a separate device. Next compensation characteristics for the legacy instrumentation 180 to utilize are created. Once the initial power parameters have been recalibrated for the legacy instrumentation 180, the line mounted device 105 periodically (such as weekly or monthly) sends new time stamped power parameter data to the microprocessor device 160, which checks for drift errors in the legacy instrumentation 180 power parameter data. When the drift exceeds a predetermined threshold, such as 0.2%, 2%, etc. error, then new compensation characteristics are calculated by the microprocessor device 160.
The sensor 150, may contain a limitation for the time or number of uses that it can be used before it ceases operation. Given the large cost savings the reclassification apparatus 100 can facilitate, it may be advantageous for the manufacturer of the reclassification apparatus 100 to limit or control the use of the reclassification apparatus 100, and thus be in the position to charge on a per use basis, instead of for the one time sale of the reclassification apparatus 100. In a first example for limiting the use of a sensor or of the line mounted device 105 may contain a security module 122 coupled to the microprocessor which controls the power parameter collection from the sensor 150 and power line 170. It can be appreciated that the security module can be a hardware security module requiring a hardware key, such as a dongle type key, or a software key requiring a user communicate an activation code to the line mounted device 105, through its communication circuitry 130. In a second example the security module 122 limits the use of the line mounted device 105 based on time. For example the line mounted device 105 may only measure the power parameters on the power line 170 for a period of 30 days before it needs to be reset either at the factory, or through another automated reset method dictated by the security module 122 as described above. Alternatively, the reclassification apparatus 100 or line mounted device 105 may operate only for a fixed number of reclassification cycles (such as an integer multiple of 3 for 3 phase systems). In a third example the security module 122 encrypts the power parameter data before transmitting it using the communications circuitry 130, thereby requiring the recipient to have the decryption key. It can be appreciated that this encryption may be rotated on a per-use basis of the device and the new decryption key may be reacquired from the manufacturer for every subsequent use. The security module 122 may be implemented through appropriate code executing on the processor 10.
The line mounted device 105 or reclassification apparatus 100 may communicate through appropriate networks such as the Internet, satellite, and or cellular telephone networks to a central server. The central server may also receive readings from the legacy instrumentation 180. The central server may thus generate compensation data or characteristics to be returned to the legacy instrumentation 180. Alternatively, the central server may continue to receive readings from the legacy instrumentation 180 and generate compensated readings. These readings may be returned by appropriate networks to the owner of the legacy instrumentation 180. In this scenario, the central server may be located at a facility owned by the provider of the reclassification apparatus 100 or another service provider. It will be appreciated that the central server may implement the security mechanisms previously described by for instance, only providing the compensation data for a fixed period of time from a given reclassification apparatus 100 or line mounted device 105 to the customer or legacy instrumentation 180.
It will be clear that various modification to the foregoing detailed description of the invention are possible without departing from the spirit and scope of the invention. For instance, the functionality of the microprocessor device 160 may be integrated into the sensor 105 or the legacy instrumentation 180. In addition, the sensor may retrieve data from the legacy instrumentation 180 over a wireless or other appropriate link and produce compensation data that is immediately or later incorporated into the legacy instrumentation 180 calculations. The legacy instrumentation 180 or microprocessor device 160 may comprise time circuitry to receive a time reference from a GPS satellite, cellular phone network, etc. This time reference may be synchronized with the time reference received by time/position circuitry 120. This time reference may be used to associate time with measurements, calculations, etc. generated by the legacy instrumentation 180 or microprocessor device 160.
Referring now to
In this implementation, the microprocessor based device 160 is split into two sections. A computer 470 interfaces through wireless communications to the line mounted device 105 and via wired or wireless communications to a ground sensor 105a. The ground sensor 105a, as described below, is substantially similar or the same as a line mounted device 105. The ground sensor 105a interfaces to the legacy CT 480. The ground sensor may have almost identical circuitry as the line mounted device 105. The only difference may be that the ground sensor 105a has a sensor input operative to receive the signal range of the legacy current transformer 480, whereas the line mounted device 105 monitors current flow in the power line 170 directly. In one embodiment, the ground sensor 105a may differ from the line mounted device 105 primarily in nominal current input specification. This may be implemented by having the same circuitry in the line mounted device except that the line mounted device has an additional current transformer operative to transform the relatively higher current levels in the power line 170 to a lower current level compatible with the rest of the sensor circuitry. In addition, the ground sensor 105a may have conventional powering means whereas the line mounted sensor has powering means as previously described. Although the ground sensor 105a can be powered as previously described. Therefore, the sensing characteristics of the line mounted device 105 and the ground sensor 105a are very similar which allows transfer characteristics of the legacy current transformer 480 such as non-linearity, phase shift, frequency response, etc. to be isolated.
Since the line mounted device 105 and the ground sensor 105a, may have the same time/position circuitry 120 (such as a GPS receiver), both may sample a parameter (such as current) of the power line 170 at the same time. Alternatively, only one of line mounted device 105 and ground sensor 105a may have time/position circuitry 120 and time information may be transferred from one to the other over the wireless communications link.
Differential techniques for position determination may be used for determining sag in the power line 170. For example, GPS systems typically have an absolute position error in the order of approximately 10 meters, but the relative error between two GPS receivers located relatively close to each other may be much less than this. Therefore, using the relative change in height position between the stationary ground sensor 105a and the potentially moving line mounted device 105, an accurate determination of line sag may be determined. The ground sensor 105a and the line mounted device 105 can be separated by various distances that may range, by way of example, from meters to kilometers.
Referring to
An installer has a choice of where to install line mounted devices 105. The line mounted device may be installed in position A 560, position B 570, position C 550, or another location in the substation or on a transmission line. The ground sensor 105a may be installed in position a 580, position b 590, position a1581, position b1591, position a+b 595 or another location in the substation. As will be seen in the following discussion, the position of mounting of the line mounted device 105 and ground sensor 105a may have a significant impact on the operation of the system.
Breakers 510 and 540 generally contain a number of CTs 520, 521, 530, 531 which are often referred to as bushing CTs. These CTs may be supplied as a part of the breaker by the breaker manufacturer and are often optimized for protective relaying functions. For instance if a protective relay is installed in position a+b 595, it can protect against faults on the transmission line due to the summing effect of connecting the secondaries of CTs 520 and 530 together. Breakers often contain multiple CTs and often there are spares which the substation may not initially be using (such as CTs 521 and 531).
If the line mounted device 105 is installed only in position C 550, it can accurately measure characteristics of the transmission line 500. This position may make it difficult to reclassify CTs 520, 521, 530, 531 since the current flow in the transmission line divides between the two breakers. Similarly a ground sensor mounted in position a+b 595 will see the sum of the currents in the two breakers, but will not be able to determine the operating point of the individual CTs 520, 530. Therefore, it will be difficult to reclassify the CTs 520, 530 due to the fact that the magnitude and phase characteristics of CTs is generally variable based on flux level in the CT core. Often in a legacy substation, protective relaying and metering is installed in the position a+b 595 only.
In order to reclassify a CT, it is generally desirable to install the line mounted device 105 in position A 560 and the ground sensor 105a in location a 580 or position al 581. At the same time or a different time, a line mounted device 105 may be installed in position B with a ground sensor 105a installed in position b 590 or, position b1591. This allows direct monitoring of current flow through the CT to be reclassified (e.g., CT 520).
A new metering device may have to be installed in positions a 580, a1581, b 590 or b1591 after the reclassification process is complete. If new metering devices are installed in at least one of positions a 580 and a1581 and positions b 590 and b1591 it may be possible to combine the output of these two metering devices in software to derive the current or power flow through transmission line 500. Alternatively, a metering device may comprise the ground sensor 105a and therefore, the ground sensor 105a may remain installed after the reclassification process.
The aforementioned system can be used to enable a utility to maximize usage of its assets. For instance, a power line, breaker, transformer, etc. can be run very close to its maximum specification if the current flow through that asset is accurately monitored in addition to other parameters such as wind speed, temperature, humidity, etc.
The aforementioned system can be used by a utility to satisfy Sarbanes-Oxley requirements since very accurate measurements of power flow throughout the utility's system can be realized.
If the line mounted device 105 contains a CT that is coupleable to the power line 170, the line mounted device may be able to induce current into the power line 170. This current injection may be used to stimulate a second line mounted device 105. For instance, if the power line 170 is otherwise unenergized, one line mounted device may induce a current into the power line which excites both a second line mounted device 105 and the legacy instrumentation 180. This current may be used in the reclassification process. The amount of current that can be injected and the amount of time it can be injected for may depend on the amount of power available to the line mounted device 105. The line mounted device may store energy over a period of time in supercapacitors and then convert this energy to current in a second time period. The current injection may be performed at different frequencies in order to characterize the frequency response of the legacy instrumentation 180.
Instead of or in addition to exciting a second line mounted device 105 for reclassification purposes, current injection may be used for communication over the power line 170.
It may not be possible to have the power line 170 transition through all conditions for which reclassification of the legacy instrumentation is desired. For instance, all voltage, current, power, temperature, harmonic content, etc. conditions may not be realizable in a reasonable time or it may be difficult or expensive to transition the power line 170 through all possible conditions in order to produce compensation characteristics over the entire desired range. Therefore, the microprocessor based device 160 (or another device) may contain characterization data for typical legacy instrumentation 180. For instance, if it is not possible to transition the power line 170 through all current levels, but it is known that the current transformers within the legacy instrumentation are of a certain manufacturer/type, the characterization data from the current levels that are realizable may be compared to the typical data for that model/type. If the data correlates for the realizable current levels, it is reasonable to assume that it will correlate for the un-realizable current levels also. Even if the manufacturer/type of legacy instrumentation 180 is not known (which may for instance occur when a CT is built into a breaker) it may be possible to identify the manufacturer/type based on its characterization data for a limited range of current levels.
It is therefore intended that the foregoing detailed description be regarded as illustrative rather than limiting, and that it be understood that it is the following claims, including all equivalents, that are intended to define the spirit and scope of this invention.
This application is a continuation in part under 37 C.F.R § 1.53(b) of U.S. patent application Ser. No. 10/877,742, filed Jun. 25, 2004 (pending), the entire disclosure of which is hereby incorporated by reference.
| Number | Date | Country | |
|---|---|---|---|
| Parent | 10877742 | Jun 2004 | US |
| Child | 11043403 | Jan 2005 | US |
