EP1337862A2 - Communication asymetrique dans un systeme de compteur a prepaiement - Google Patents

Communication asymetrique dans un systeme de compteur a prepaiement

Info

Publication number
EP1337862A2
EP1337862A2 EP01992926A EP01992926A EP1337862A2 EP 1337862 A2 EP1337862 A2 EP 1337862A2 EP 01992926 A EP01992926 A EP 01992926A EP 01992926 A EP01992926 A EP 01992926A EP 1337862 A2 EP1337862 A2 EP 1337862A2
Authority
EP
European Patent Office
Prior art keywords
customer
resource
meter
prepayment
amount
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP01992926A
Other languages
German (de)
English (en)
Inventor
Alan Jones
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
BCN Data Systems
Original Assignee
BCN Data Systems
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by BCN Data Systems filed Critical BCN Data Systems
Publication of EP1337862A2 publication Critical patent/EP1337862A2/fr
Withdrawn legal-status Critical Current

Links

Classifications

    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q20/00—Payment architectures, schemes or protocols
    • G06Q20/22—Payment schemes or models
    • G06Q20/28—Pre-payment schemes, e.g. "pay before"
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
    • G01D4/00—Tariff metering apparatus
    • G01D4/002—Remote reading of utility meters
    • G01D4/004—Remote reading of utility meters to a fixed location
    • G—PHYSICS
    • G07—CHECKING-DEVICES
    • G07F—COIN-FREED OR LIKE APPARATUS
    • G07F15/00—Coin-freed apparatus with meter-controlled dispensing of liquid, gas or electricity
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B3/00—Line transmission systems
    • H04B3/54—Systems for transmission via power distribution lines
    • H04B3/546—Combination of signalling, telemetering, protection
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01D—MEASURING NOT SPECIALLY ADAPTED FOR A SPECIFIC VARIABLE; ARRANGEMENTS FOR MEASURING TWO OR MORE VARIABLES NOT COVERED IN A SINGLE OTHER SUBCLASS; TARIFF METERING APPARATUS; MEASURING OR TESTING NOT OTHERWISE PROVIDED FOR
    • G01D2204/00—Indexing scheme relating to details of tariff-metering apparatus
    • G01D2204/10—Analysing; Displaying
    • G01D2204/12—Determination or prediction of behaviour, e.g. likely power consumption or unusual usage patterns
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B2203/00—Indexing scheme relating to line transmission systems
    • H04B2203/54—Aspects of powerline communications not already covered by H04B3/54 and its subgroups
    • H04B2203/5404—Methods of transmitting or receiving signals via power distribution lines
    • H04B2203/542—Methods of transmitting or receiving signals via power distribution lines using zero crossing information
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B2203/00—Indexing scheme relating to line transmission systems
    • H04B2203/54—Aspects of powerline communications not already covered by H04B3/54 and its subgroups
    • H04B2203/5429—Applications for powerline communications
    • H04B2203/5433—Remote metering
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B2203/00—Indexing scheme relating to line transmission systems
    • H04B2203/54—Aspects of powerline communications not already covered by H04B3/54 and its subgroups
    • H04B2203/5429—Applications for powerline communications
    • H04B2203/5441—Wireless systems or telephone
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04B—TRANSMISSION
    • H04B2203/00—Indexing scheme relating to line transmission systems
    • H04B2203/54—Aspects of powerline communications not already covered by H04B3/54 and its subgroups
    • H04B2203/5429—Applications for powerline communications
    • H04B2203/5445—Local network
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02B—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO BUILDINGS, e.g. HOUSING, HOUSE APPLIANCES OR RELATED END-USER APPLICATIONS
    • Y02B90/00—Enabling technologies or technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02B90/20—Smart grids as enabling technology in buildings sector
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S20/00—Management or operation of end-user stationary applications or the last stages of power distribution; Controlling, monitoring or operating thereof
    • Y04S20/30—Smart metering, e.g. specially adapted for remote reading

Definitions

  • the present invention relates to utility metering.
  • Utilities usually implement prepayment metering by adding prepayment meters to their utility systems.
  • Prepayment metering in its simplest form refers to paying for utilities, such as but not limited to electricity, gas, and water, before the resource is consumed. In such systems, a consumer purchases credit and then uses the resource until the credit expires.
  • utilities such as but not limited to electricity, gas, and water
  • prepayment metering was introduced in the form of coin gas meters in the UK. Major development took place in the 1980s when electronic or numeric transfer of the credit was introduced and used to transfer other information.
  • a conventional electronic prepayment metering system operates on three levels. At the first level are the prepayment meters (“PPMs” or “PPM”) that are installed at the homes of consumers. At the next level are the vending stations that are usually situated at the utility company's offices or at an appointed agent's place of business. The communication between the vending stations and the PPMs is usually in the form of a token, which is used to top up the credit in a prepayment meter. Tokens also transfer or download information to the PPMs and, in some cases, upload information (depending on the token choice) back to the vending stations. At the top level is a control system, which is necessary to ensure a common database for reporting and to provide total management, administration, financial, and engineering control.
  • the control system communicates with the various vending stations by the plain old telephone network ("PSTN") or, alternatively, by other data links.
  • PSTN plain old telephone network
  • Information related to utility service such as but not limited to information on consumers and tariff changes, is communicated to the vending stations and detailed customer sales are communicated back up to the control system.
  • PSTN plain old telephone network
  • Prepayment metering is now an established technology with a significant role to play in helping both the consumer and utility.
  • the prime benefits to the utility include:
  • prepayment metering is costly. As discussed, in conventional utility systems, prepayment requires the installation of a conventional PPM, which is usually complex and expensive; and continuation of supply requires regular credit transfer by a payment 'token' that is passed between the PPM and a payment center. Often, these tokens are electronic and are extended to transfer other information, such as meter readings and control information for the remote meter.
  • the cost of serving prepayment customers is exacerbated by the nature of their geographic dispersal. Complexity is increased considerably with the need to have a two-way communication method to download credit and other data. Therefore, the cost of installing a two-way communication system solely for prepayment meters becomes disproportionate to the savings.
  • a utility system includes a distribution network for distributing a resource to a customer.
  • the system includes a meter for metering the resource and for connecting and disconnecting a supply of the resource distributed to the customer.
  • the meter includes a control system for maintaining an account of the customer and for controlling distribution of the resource based on the account information.
  • the meter includes a first communication system for sending, over a first medium, information from the prepayment meter to the control system.
  • the meter includes a second communication system for sending, over a second medium, information from the control system to the prepayment meter, wherein the information includes signals for disconnecting or connecting the supply of the resource distributed to the consumer.
  • a prepayment meter in another aspect, includes a measuring unit for metering consumption of a resource by a customer.
  • the meter includes a keypad for receiving a prepayment token that represents an amount of resource available to the customer for consumption.
  • the meter includes a processor electrically connected for receiving input from the measuring unit and from the keypad.
  • the processor is configured to determine, from the token, an amount of resource available to the customer, calculate an amount of resource consumed by the customer based on input from the measuring unit, and decrement the amount of resource available to the customer by the amount of resource consumed by the customer.
  • the meter includes a radio transmitter electrically connected for transmitting from the processor information specifying the amount of resource consumed by the customer.
  • a system in accordance with the invention enables the use of asymmetrical communication channels to communicate with prepayment meters.
  • the communication channels can be selected to best suit the type of data being transmitted.
  • the ability to maximize the rate of transmission of data increases the efficiency of the system and provides other operational, strategic, and external benefits.
  • the system provides two-way communication over multiple mediums thus allowing meters to operate as a part of a remote meter reading system and, furthermore, to have full functionality without requiring direct two-way communication via that communication network.
  • a significant cost of a utility system is attributable to the cost of its prepayment meters.
  • a system in accordance with the invention reduces cost by using one method to send information to its prepayment meters and another method to receive information to its prepayment meters.
  • the system thus can use simplified prepayment meters that uses a simple transmitter.
  • the simple transmitter can communicate on a regular basis to a local collector.
  • the system can use a fixed radio network that enables prepayment meters to be read remotely at a cost level not attainable by other communication solutions.
  • Low cost telemetry is a key enabler for providing additional services and capabilities to utilities that would normally require more complex prepayment meters.
  • Regular raw data from the prepayment meters can be processed and used by other systems for enhanced customer service, billing, load control, other network management systems, and prepayment.
  • the system can combine the communications technology of network meter reading ("NMR") with low cost prepayment meters.
  • NMR network meter reading
  • the system includes prepayment meters as a part of a remote meter reading system. NMR has solves all of the problems of both communicating with prepayment meters and administering a support system. Combining NMR technology with conventional prepayment meters further enhances the benefits to both utility companies and consumers.
  • FIG. 1 is a block diagram of a system in accordance with the invention.
  • FIG. 2 shows one implementation of the system.
  • FIG. 3 shows a fixed radio network.
  • FIG. 4 shows a power distribution network of a second implementation of the system.
  • FIG. 5 shows an asymmetrical two-way communication scheme of the second implementation of the system.
  • FIG. 6a-c illustrates power-line communication.
  • FIG. 7 shows a keypad meter.
  • FIG. 8 shows a third implementation of the system.
  • FIG. 9 shows a conventional prepayment system.
  • a utility system 100 in accordance with the invention includes distribution lines such as distribution line 102, utility meters such as meter 104, and a utility control center such as utility control center 106.
  • the system 100 further includes a first communication system 108 and a second communication system 110.
  • the system includes vending terminals 112.
  • the distribution line 102 carries the resource being distributed.
  • the resource can be but is not limited to electricity, gas, or water.
  • the utility meter 104 usually includes a sensing circuit (not shown) and a processor (not shown) to calculate information related to utility consumption. The information calculated includes but is not limited to the amount and rate of resource consumption.
  • the utility meter 104 also includes a transmitter (not shown) for transmitting information to the control center. The transmitter is part of the first communication system 108.
  • the utility meter 104 further includes a receiver (not shown) for receiving information from the control center 106.
  • the receiver is part of the second communication system 110.
  • the receiver can be a simple user interface device for a user to enter data into the processor of the utility meter 104. Such devices include but are not limited to a simple alpha-numeric keypad, an optical port, or an LCD display having a graphical user interface.
  • the utility control center 106 includes memory (not shown) for storing information related to utility service.
  • the utility control center 106 also includes applications (not shown) such as a database, a corresponding database management system for maintaining and calculating information related to utility service, as well as a prepayment programs that can interact with the database system or, alternatively, directly with the database.
  • the utility control center 106 further includes a processing device such as a computer or a server (neither shown) for processing information related to utility service.
  • Information related to utility service includes but is not limited to customer profile information and customer account information.
  • the first and second communication system 108 and 110 can be any two communication systems that use different mediums.
  • the first communication system can be a wireless communication system that sends signals over the atmosphere and the second communication system can be one that sends signals over the distribution line 102.
  • a customer prepays either at the utility control center 106 or remotely by calling the utility control center 106 and providing an operator there with a credit card number.
  • the customer can remotely interface with a server or computer of the utility control center 106 through a network such as the Internet.
  • the user can prepay and access account information without having to rely on a human operator.
  • the server or computer of the utility control center 106 processes the prepayment and stores the prepayment information in memory.
  • the meter 104 tracks the amount of resource consumed and sends this information to the utility control center 106 using the first communication system 108.
  • the utility control center 106 uses the information sent from the meter 104 to maintain the customer's account balance.
  • the utility control center 106 When the customer has nearly consumed the amount of resources that was prepaid for, i.e., when the customer's account balance is close to zero, the utility control center 106 optionally sends a signal to the meter 104 through the second communication system 110 that causes the meter to indicate that the customer's account balance is near zero. Such indication can be a simple flashing LED or any warning that can notify the customer. Prompted by the meter 104, the customer makes another prepayment. Alternatively, the utility control center 106 can automatically telephone the customer and report that a prepayment is required. When the customer's account balance is zero and the customer has not made another prepayment, the utility control center 106 sends a signal to the meter stopping the distribution of resources to the customer. Alternatively, the utility control center 106 can send a signal to a switch or valve (not shown) that stops the distribution of resources to the customer.
  • the meter 104 can track the account balance.
  • the meter does not rely on the utility control center 106 to control a cut-off switch or valve.
  • the optional vending terminals 112 connect with a server or computer of the utility control center 106 through the PSTN.
  • the vending terminals 112 can connect through any link or network, including but not limited to El lines and the Internet.
  • the vending terminals 112 are in essence extensions of the utility control center 106 and allow customers to prepay remotely.
  • FIG. 2 shows an electricity distribution system 200, which is one implementation of utility system 100.
  • the system 200 includes an asymmetrical two-way communication system between its endpoints such as the prepayment meters and its utility control center.
  • two-way communications In conventional two-way communication system, a common medium is used to both transmit and receive.
  • two-way communications can mean more expensive endpoints (such as meters) and, worse still, drive a need to significantly increase the network density and complexity to compensate for the random distribution of prepayment customers.
  • the low density of prepayment customers may make it economically unfeasible to deploy a full two-way network for this purpose.
  • the electricity distribution system uses radio as the communication medium from the meter to a utility control center and power line communication back to the meter from the utility control center.
  • the electricity distribution system can use power line communication as the medium from the meter to a utility control center and radio back to the meter from the utility control center.
  • the system 200 includes a pre-payment application 202, a distribution network 204, a remote prepayment meter 206 having a radio transmitter and a receiver (neither shown), a MicroCell Controller ("MCC") radio receiver 208, a low power transmitter 210, and a control switch 212 (or valve when the utility resource is a fluid such as water or gas).
  • the application 202 (which can be located at a utility control center) receives regular consumption updates from the remote prepayment meter 206.
  • the physical prepayment meter 206 and the calculation logic of the application 202 create a virtual prepayment meter that has can calculate any function related to utility distribution, including but not limited to the customer's remaining credit with respect to energy consumed.
  • the prepayment meter 206 Only consumption data is required from the prepayment meter 206.
  • the prepayment meter 206 sends this data through its radio transmitter (not shown).
  • the MCC radio receiver 208 receives the data and, in turn, sends the data to the application 202 through the wide area network ("WAN") 214. This communication method is further described below in reference to FIG. 3. Other data such as tariff and time of use calculations is determined by the application 202.
  • the application 202 sends a signal to shut or open the control switch 212 (or valve for resources that are fluids) that either connects or disconnects the electricity supply to the consumer.
  • the control switch 212 (or valve) is internal to the prepayment meter 206. Alternatively, the control switch or valve can be positioned at any location where it can selectively control distribution the customer.
  • the signal path of the signal includes the WAN 214, the low power transmitter 210, the distribution network 204, and the receiver in the prepayment meter 206. This communication method is similar to that described in reference to FIGs. 5 and 6. As discussed, the system 200 uses radio as the communication medium.
  • the system includes a fixed-network automatic meter reading system (“NMR”) that uses radio communication to remotely monitor prepayment meters distributed over a wide geographic area.
  • NMR fixed-network automatic meter reading system
  • the system 200 collects energy usage and other information and delivers it to utility companies and customers on a real-time basis. Utility companies can then use the information to reduce operating costs, improve customer service, increase revenues, and differentiate themselves from other service providers in competitive environments.
  • the NMR can also be used, where radio frequency rules allow, for other commercial wireless data applications such as home security and remote status monitoring of vending machines and office equipment.
  • the NMR includes a hierarchy of three tightly integrated networks: A microcellular local area network (LAN), a wide area network (WAN), and a system controller network.
  • the NMR is made up of hundreds or thousands of LAN micro-cells, each operating independently to provide reliable data collection.
  • Utility meters and other endpoint devices equipped with radio communications modules transmit data on a regular basis to a MCC located at the center of each micro-cell.
  • the communication modules can be a simple radio transmitter which reduces the cost of the meters.
  • the MCC stores and processes the data received, and sends it up via the WAN to the System Controller on a scheduled or event-driven basis.
  • the WAN provides data communications between the System Controller and MCCs, distribution automation devices, and other WAN clients.
  • the System Controller Network manages overall network communications and processes and stores the data received from devices on the network.
  • the System Controller needs to have the ability to manage a network potentially containing millions of devices transmitting information every few minutes.
  • FIGs. 4-6 show an electricity distribution system 400, which is another implementation of system 100.
  • the system 400 includes an electrical power distribution network 401, as shown in FIG. 4.
  • the power distribution network 401 includes a very high voltage (VHV) network 402, a high voltage (HN) network 404, a medium voltage (MV) network 406, and a low voltage (LV) network 408.
  • VHV very high voltage
  • HN high voltage
  • MV medium voltage
  • LV low voltage
  • the power station 410 supplies electrical power to the network 400 at a significantly higher voltage than that required by the end user.
  • the voltage from the power station 410 is reduced at a number of stages; the final stage is at a secondary substation 422, which is configured to reduce the voltage from typically about 11 kV to 415 volts.
  • This voltage can be distributed from a feeder node of the substation 422 to a plurality of low voltage customers 424 in the LV network 408.
  • Power lines interconnect the components of the power distribution network 400.
  • the system 400 further includes a system controller 502 communicating with one or more remote stations 504 through wired or wireless communication channels 506.
  • the system controller 502 can be a computer used by an electrical utility company for preparing customer billing statements and monitoring the operation of the system 400, for example.
  • the system controller 502 includes a database of control signals that can be transmitted to the remote stations 504 as desired.
  • the functions of the system controller 202 depend upon the intended application for the system 400. For example, an electrical utility company could use the system controller 502 to send control signals to determine the power consumed each hour over the last twenty-four hours, the total amount of power consumed between 6 p.m. and 8 p.m. over the last month, and the time of peak power consumption in the previous day for each house in a residential neighborhood.
  • the system controller 502 can send a control signal after a resumption of power following a power outage in the system 400 to query the number and location of the houses in a residential neighborhood without power.
  • Each remote station 504 is connected to the feeder node 508 of the substation 422.
  • the remote station 504 includes a signal injector 510 (e.g., an injection transformer) that is constructed to send a power line signal from the feeder node 508 to the meters 512 at the meter nodes 514 over the power lines 516 of the power distribution network 401.
  • the signal injector 510 is implemented as a power line carrier (PLC) transmitter, which uses the existing power lines 516 as a communication channel.
  • PLC power line carrier
  • the signal injector 510 may be attached permanently to the power distribution network 401; alternatively, the signal injector 510 may be attached on an ad hoc basis.
  • the signal injector 510 is configured to send the power line signal containing the control signal over the power lines by modulating supply voltage waveform 602 (e.g., of the form E pk Sin( ⁇ t)) near the zero crossover point 604.
  • supply voltage waveform 602 e.g., of the form E pk Sin( ⁇ t)
  • the signal injector 510 distorts the supply voltage waveform 604 in the region of zero crossover. In this way, a relatively high power line signal amplitude may be used without significant disturbance to the RMS (root mean square) value of the supply voltage.
  • the disturbance of the supply voltage waveform 604 is created using a thyristor 606 connected between each phase and neutral of the transformer of the substation 422.
  • the thyristor 606 is switched at a point 610 on the supply voltage waveform 602 that is displaced by a switching angle ⁇ (e.g., about 25°) before a zero crossing.
  • the resulting current produces a depression 612 of the supply voltage waveform 602 at the point of common crossing (PCC), the value of which depends upon the relative impedances R s , L s , R t and L t .
  • the thyristor current is limited by DC (direct current) transients to about 10% of the peak prospective fault current, and turns off upon returning to zero as a result of the unidirectional characteristic of the thyristor 606.
  • the line to neutral voltage at the transmitter terminals collapses to near zero for the duration of the current flow.
  • the power line signals are received between line and neutral at any low voltage point supplied from the same substation transformer.
  • the power line signals are detected by integrating the supply voltage waveform 614 during a small fixed period before each positive-going zero crossing.
  • the amplitude of each integral is compared with that of the previous supply cycle in order to determine whether the difference exceeds a pre-set value (the receiver setting), in which case a power line signal is assumed to have been detected.
  • the meters 514 construct the power line signal message (i.e. the control signal) from a number of individual cycles, altered in a coded pattern, which is produced by a code generator 616 (FIG. 6c).
  • each meter has a receiver 516, which is configured to receive and decode the power line signal sent by the signal injector 510.
  • the meter 512 performs a status inquiry or measuring operation as required, and transmits a response signal containing the meter status (e.g., "in service” or “out of service") or the meter measurement (e.g., current power consumption, cumulative power consumption over a time period, or otherwise) from a transmitter 518 to the remote station 504 through a wireless communication channel 520.
  • the response signal can be in the form of any sort of wireless signal (e.g., radio frequency, microwave, and infrared signals).
  • the remote station 504 receives response signals from one or more meters 512. Although only four meters 512 are shown, the remote station 504 may receive response signals from fifty to one thousand meters, more preferably two hundred to five hundred meters. Each remote station 504 and its associated meters 512 form a "cell". Each meter 512 has to have enough processing power to decode the power line signal received, perform the required status inquiry or measuring operations and transmit the response signal to the remote station 504. Although only one remote station 504 is shown, there may be hundreds or thousands of remote stations 504, depending upon the number of meters 512 in the system 400. The remote stations 504 communicate with the system controller 502 through wired or wireless communication channels 506.
  • some or all of the remote stations 504 are positioned at elevated locations (e.g., placed on a telephone pole) to facilitate the two-way communication with the system controller 502, as well as, facilitate the reception of wireless response signals from the meters 512.
  • System 400 operates similarly to system 200.
  • a customer prepays for electricity.
  • the system controller 502 maintains the customer's account balance.
  • the meters 512 transmit by radio meter measurements to the system controller 502.
  • the system controller 502 calculates the customer's power consumption and decrements the customer's account.
  • the system controller 502 causes the signal injector 510 to send a power line signal to the meter 512, causing the meter to cut-off power to the customer.
  • FIGs. 7 and 8 show power distribution system 700, which is another implementation of the system 100.
  • radio is used to communicate to an application as described above and a simple physical token is used as a means to communicate payment back to the meter.
  • the low-cost prepayment meters include keypad technology. These simple meters when combined with network radio technology provide asymmetrical two-way communication without requiring an expensive two-way network.
  • FIG. 7 shows a keypad meter, which works as follows: Instead of using a token, the customer is given a multi digit code number, which the customer enters using a keypad on the meter. Conventionally, this code credits the meter with the appropriate number of units of the commodity, which in the case of electricity would be a kWh figure. A realistic limit to the code is twenty digits, this limits the input to a single parameter. The input of a single parameter confines the meter to a single tariff rate, unless an internal clock is included. An internal clock increases cost and requires a site visit to change tariff rates.
  • FIG. 8 illustrates the operation of system 700. No physical token is required at the point of purchase. A printed receipt with the code number can contain all the details of the consumers account, i.e., debt and credit status. Alternatively, the number and data could be issued via IVR and payment made by transferring money from a credit card.
  • the code number would make electricity/gas supply available for a pre-set period of time. This is a fundamental difference to how conventional prepayment meters operate. At the end of that time period, represented by the code number, the meter would disconnect the supply of resource.
  • the credit is decremented remotely from the payment made.
  • the decrement will vary according to the rate of consumption communicated via the radio transmitter, amount of debt recovery and current time varying tariff rate. In actual fact, this does not need to be real time and can be reconciled when a new transaction takes place. Using this approach tariffs and debt collection can be implemented.
  • the consumer can buy more time; the cost or time the customer is given will depend on whether the customer has remaining credit or debit. This is a function of past consumption, rate of debt collection, and tariff scheme. As described, a closed loop is implemented where the available time or cost is modified to ensure the net credit/debt balance is approximately zeroed.
  • IVR can be used to reduce infrastructure cost • consumers will have convenience of purchasing via the vending units or via telephone.
  • Some or all aspects of the invention can be implemented in digital electronic circuitry, or in computer hardware, firmware, software, or in combinations of them.
  • the described electricity related functions can be implemented in a computer program product tangibly embodied in a machine-readable storage device for execution by a programmable processor; and method steps of the invention can be performed by a programmable processor executing a program of instructions to perform functions of the invention by operating on input data and generating output.
  • the invention can be implemented advantageously in one or more computer programs that are executable on a programmable system including at least one programmable processor coupled to receive data and instructions from, and to transmit data and instructions to, a data storage system, at least one input device, and at least one output device.
  • Each computer program can be implemented in a high-level procedural or object-oriented programming language, or in assembly or machine language if desired; and in any case, the language can be a compiled or interpreted language.
  • Suitable processors include, by way of example, both general and special purpose microprocessors.
  • a processor will receive instructions and data from a read-only memory and/or a random access memory.
  • a computer will include one or more mass storage devices for storing data files; such devices include magnetic disks, such as internal hard disks and removable disks; magneto-optical disks; and optical disks.
  • Storage devices suitable for tangibly embodying computer program instructions and data include all forms of non- volatile memory, including by way of example semiconductor memory devices, such as EPROM, EEPROM, and flash memory devices; magnetic disks such as internal hard disks and removable disks; magneto-optical disks; and CD-ROM disks. Any of the foregoing can be supplemented by, or incorporated in, ASICs (application-specific integrated circuits).
  • ASICs application-specific integrated circuits.
  • the invention has been described in terms of particular embodiments. Other embodiments are within the scope of the following claims.
  • the commodity described is not limited to electrical power, water, and gas, but can be any utility commodity.

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  • Engineering & Computer Science (AREA)
  • General Physics & Mathematics (AREA)
  • Physics & Mathematics (AREA)
  • Business, Economics & Management (AREA)
  • Accounting & Taxation (AREA)
  • General Business, Economics & Management (AREA)
  • Strategic Management (AREA)
  • Theoretical Computer Science (AREA)
  • Power Engineering (AREA)
  • Computer Networks & Wireless Communication (AREA)
  • Signal Processing (AREA)
  • Financial Or Insurance-Related Operations Such As Payment And Settlement (AREA)
  • Meter Arrangements (AREA)
  • Control Of Vending Devices And Auxiliary Devices For Vending Devices (AREA)
  • Management, Administration, Business Operations System, And Electronic Commerce (AREA)

Abstract

La présente invention concerne des procédés et des appareil mettant en oeuvre des techniques de communication asymétrique dans un système de compteur à prépaiement. De manière générale, dans un mode de réalisation, les techniques fournissent un système utilitaire comprenant un réseau de distribution pour la distribution d'une ressource à un client. Le système comporte un compteur destiné au comptage de la ressource et à la connexion et la déconnexion d'une fourniture de la ressource distribuée au client. Le compteur comprend un système de contrôle pour l'entretien d'un compte du client et pour contrôler la distribution de la ressource en fonction de l'information de compte. Le compteur comporte un premier système de communication pour l'envoi, sur un premier support, une information à partir du compteur de prépaiement vers le système de contrôle. Le compteur comporte un deuxième système de communication pour l'envoi, sur un deuxième support, une information à partir du système de contrôle vers le compteur de prépaiement, dans lequel l'information comprend des signaux de déconnexion ou de connexion de la fourniture de la ressource distribuée au consommateur.
EP01992926A 2000-11-06 2001-11-06 Communication asymetrique dans un systeme de compteur a prepaiement Withdrawn EP1337862A2 (fr)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US24640800P 2000-11-06 2000-11-06
US246408P 2000-11-06
PCT/US2001/046577 WO2002037227A2 (fr) 2000-11-06 2001-11-06 Communication asymetrique dans un systeme de compteur a prepaiement

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EP1337862A2 true EP1337862A2 (fr) 2003-08-27

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EP01992926A Withdrawn EP1337862A2 (fr) 2000-11-06 2001-11-06 Communication asymetrique dans un systeme de compteur a prepaiement

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EP (1) EP1337862A2 (fr)
AR (1) AR031294A1 (fr)
AU (1) AU2002227238A1 (fr)
UY (1) UY27013A1 (fr)
WO (1) WO2002037227A2 (fr)

Families Citing this family (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2849739B1 (fr) * 2003-01-06 2005-04-15 Gal Claude Le Boitier de mesure adressable
FR2890476B1 (fr) * 2005-09-08 2007-10-19 Woodsys Sa Procede et dispositif pour delivrer de facon controlee de l'energie et/ou au moins un fluide
EP2072958B1 (fr) 2007-12-20 2017-06-07 EFR Europaische Funk-Rundsteuerung GmbH Procédé et système de gestion de données de tarif, de charge et de compteur avec télécommande hertzienne
EP2515082A1 (fr) 2011-04-18 2012-10-24 Nagravision S.A. Système et procédé pour sécuriser un compteur d'énergie
DE102015101375A1 (de) * 2015-01-30 2016-08-04 Weiss+Appetito Communication Gmbh System zur gesteuerten Abgabe von elektrischer Energie, Gas, Wasser oder ähnlichen Medien und Verfahren hierzu
GB201519679D0 (en) * 2015-11-06 2015-12-23 Steama Company Ltd Utilities supply apparatus
ES2723124B2 (es) * 2016-09-30 2022-01-04 Aclara Tech Llc Patrón de lectura de contadores potenciado para mejorar la funcionalidad en el sistema de comunicaciones de los servicios públicos

Family Cites Families (2)

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Publication number Priority date Publication date Assignee Title
US6243693B1 (en) * 1998-02-10 2001-06-05 Merlin Gerin S.A. (Proprietary) Limited Token-operated apparatus for communal prepayment water management
US6327541B1 (en) * 1998-06-30 2001-12-04 Ameren Corporation Electronic energy management system

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See references of WO0237227A2 *

Also Published As

Publication number Publication date
WO2002037227A3 (fr) 2003-01-23
UY27013A1 (es) 2002-06-20
WO2002037227A2 (fr) 2002-05-10
AU2002227238A1 (en) 2002-05-15
AR031294A1 (es) 2003-09-17

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