1、NEMA Standards PublicationNational Electrical Manufacturers AssociationNEMA SG-AMI 1-2009Requirements for Smart Meter UpgradeabilityNEMA Smart Grid Standards Publication SG-AMI 1-2009 Requirements for Smart Meter Upgradeability Published by: National Electrical Manufacturers Association 1300 North 1
2、7th Street, Suite 1752 Rosslyn, Virginia 22209 www.nema.org Copyright 2009 by the National Electrical Manufacturers Association. All rights including translation into other languages, reserved under the Universal Copyright Convention, the Berne Convention for the Protection of Literary and Artistic
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13、 Page i CONTENTS Foreword ii Introduction .iii Section 1 GENERAL . 1 1.1 Scope. 1 Section 2 DEFINITIONS 2 Section 3 UPGRADE PROCESS FUNCTIONAL REQUIREMENTS . 4 3.1 General 4 3.2 Smart Meter. 4 3.3 Metrology. 4 3.4 AMI Applications and Communications. 5 3.5 HAN Applications and Communications 5 3.6 U
14、pgrade Management System 5 Section 4 UPGRADE PROCESS SECURITY REQUIREMENTS. 6 Section 5 REFERENCE DIAGRAM 7 Copyright 2009 by the National Electrical Manufacturers Association. SG-AMI 1-2009 Page ii Foreword Proposed or recommended revisions should be submitted to: Vice President, Technical Services
15、 National Electrical Manufacturers Association 1300 North 17th Street Suite 1752 Rosslyn, Virginia 22209 This Smart Grid Standards Publication is supported by the Electricity Metering Section of the National Electrical Manufacturers Association. Approval of this standard does not necessarily imply t
16、hat all voting classification members voted for its approval or participated in its development. At the time it was approved, the Electricity Metering Section had the following members: Elster ElectricityRaleigh, NC General ElectricAtlanta, GA Itron, Inc.Liberty Lake, WA Landis+GyrLafayette, IN The
17、draft “Requirements for Smart Meter Upgradeability” was developed by a team of meter manufacturers and electric utilities in an effort to provide guidance to utilities, state commissions, and others that want to deploy Advanced Metering Infrastructure prior to completion of the standards work identi
18、fied in the National Institute of Standards and Technology (NIST) Smart Grid Interoperability Roadmap. NEMA would like to thank all the members on the NIST/NEMA Smart Grid Meter Task Team that participated in this effort, including: John Caskey, Team Leader Alabama PowerDerl Rhoades Consumers Energy
19、Wayne Longcore, Matt Gillmore Elster ElectricityEd Beroset, Ed Gray, Mike Longrie EnerNex (contractor to NIST)Aaron Snyder General ElectricRobby Simpson, Steve Richards, Kerry Evans, Mak Tarnoff Georgia PowerTerry Penn Itron, Inc.Michael Garrison Stuber, Ed May, Brent Cain Landis+GyrMichelle Mindala
20、-Freemen, Hassan Ali, Ruben Salazar National Electrical Manufacturers AssociationJohn Caskey, Paul Orr National Institute of Standards and TechnologyTom Nelson Oncor Electric DeliveryMark Carpenter SensusBritton Sanderford, Arlin Rummel, George Uram Southern California EdisonGreg Sheran U.S. Departm
21、ent of Energy, Pacific Northwest National LaboratorySteve Widergren Copyright 2009 by the National Electrical Manufacturers Association. SG-AMI 1-2009 Page iii Introduction Creating a secure, connected, and interoperable Smart Grid is a top national priority. Title XIII (Smart Grid) of The Energy In
22、dependence and Security Act of 2007 requests that the National Institute of Standards and Technology (NIST) develop a Smart Grid Interoperability Roadmap and also coordinate the development of Smart Grid Interoperability standards. NEMA, the National Electrical Manufacturers Association, was request
23、ed to support NIST in the development of the Roadmap as well as Smart Grid standards. As part of the Roadmap process, NIST conducted three workshops to obtain input from Smart Grid stakeholders to help develop the Smart Grid Interoperability Roadmap. This Roadmap will summarize the current state of
24、Smart Gridrelated standards and identify gaps in standards that need to be addressed. The Roadmap will also include a list of standard-related tasks that need to be completed to ensure the interoperability of Smart Grid. The United States Department of Energy (DOE) is also tasked with helping the na
25、tion deploy Smart Grid and through its effort on Modern Grid identified the following characteristics for Smart Grid: Enable consumer participation Accommodate generation and storage Enable new products and services Provide power quality Optimize asset utilization Anticipate and respond to system di
26、sturbances Operate against physical and cyber attacks Several of the tasks identified in the draft Roadmap as well as several of the characteristics noted above directly relate to modifying existing meter and Advanced Metering Infrastructure (AMI) standards. However, it may take years to complete th
27、e tasks associated with Smart Meters and AMI systems. To forward the development and deployment of a Smart Grid, many electric utilities are looking to make their Advanced Metering Infrastructure (AMI) and Smart Meter investments now as a precursor or enabler to additional Smart Grid, energy managem
28、ent, and consumer participation initiatives. One of the critical issues facing these electric utilities and their regulators is determining if technologies or solutions utilities select will forward interoperability and comply with the to-be-established national standards. Further, many utilities wa
29、nt to ensure that the system they select will allow for evolution and growth as Smart Grid standards evolve. An important way to allow for investment in and deployment of smart metering to continue at the aggressive pace the nation demands and industry requires is to build a set of upgradeability re
30、quirements, allowing utilities to mitigate the risk of predicting the future and install a system that allows for flexibility and upgradeability to comply with emerging requirements for the Smart Grid. The following serves as a key set of requirements for Smart Meter upgradeability. These requiremen
31、ts should be used by Smart Meter suppliers, utility customers, and key constituents, such as regulators, to guide both development and decision making as related to Smart Meter upgradeability. The Purpose of this document is to define requirements for Smart Meter Firmware upgradeability in the conte
32、xt of an AMI system for industry stakeholders such as regulators, utilities, and vendors. Copyright 2009 by the National Electrical Manufacturers Association. SG-AMI 1-2009 Page iv Copyright 2009 by the National Electrical Manufacturers Association. SG-AMI 1-2009 Page 1 Section 1 GENERAL 1.1 SCOPE N
33、EMA Smart Grid Standards Publication SG-AMI 1 defines requirements that include secure local and remote upgrades of Smart Meter: Metrology; AMI applications; AMI communications; HAN applications; and HAN communications. Upgrading of devices other than Smart Meters is beyond the scope of this documen
34、t. Copyright 2009 by the National Electrical Manufacturers Association. SG-AMI 1-2009 Page 2 Section 2 DEFINITIONS 2.1 AMIAdvanced Metering Infrastructure. 2.2 AMI ApplicationsThe upper layers of the AMI implementation stack, including features and services provided by the AMI system. 2.3 AMI Commun
35、icationsThe lower layers of the AMI implementation stack, including the Network Layer, the Media Access Control (MAC) Layer, and the Physical Layer. 2.4 Communications ModuleThe sub-component of a Smart Meter responsible for AMI communications between Smart Meters in the field and the Network Manage
36、ment System. The Communications Module may or may not be a separate electronic element, and/or may include the HAN Interface. 2.5 ConfigurationThe settings or parameters persisted within the device that determine its behavior, as distinct from Firmware. Examples of configuration include the interval
37、 size used for load profile data and the schedule used for time-of-use metering. 2.6 FirmwareExecutable binary code embedded within a Smart Meter. Each microprocessor within a Smart Meter may have its own firmware. 2.7 Firmware ImageA specific instance of Firmware suitable for loading into the memor
38、y of microprocessors contained within a Smart Meter. 2.8 HANHome Area Network; for the purpose of this document, “HAN” includes residential, commercial, and industrial services. 2.9 HAN ApplicationsThe upper layers of the HAN implementation stack, including features and services provided by the HAN.
39、 2.10 HAN CommunicationsThe lower layers of the HAN implementation stack, including the Network Layer, the Media Access Control (MAC) Layer, and the Physical Layer. 2.11 HAN InterfaceThe sub-component of a Smart Meter responsible for providing HAN communications. The HAN Interface may or may not be
40、a separate electronic element. 2.12 Integrity CheckValidation of the overall integrity of a given Firmware Image to ensure that neither inadvertent nor intentional changes have been made. Typically, this is done via a mathematical or cryptographic means such as Cyclic Redundancy Checks (CRCs) or has
41、hes. 2.13 Metered DataRevenue metering quantities. 2.14 MetrologyThe sub-component of a Smart Meter responsible for measuring and calculating Metered Data that may be used for register readings, time-of-use readings, load profile data, and other electrical or revenue measurement purposes. The Metrol
42、ogy may or may not be a separate electronic element and may or may not include other electronic elements or interfaces as well. Copyright 2009 by the National Electrical Manufacturers Association. SG-AMI 1-2009 Page 3 2.15 Network ConfigurationThe settings used by the Communications Module to establ
43、ish communications with the AMI network. May include the data by which a device is identified on the network and other communications parameters. 2.16 Network Management SystemThe system that controls and schedules communication on the AMI network, receives and stores information from Smart Meters a
44、nd HAN devices, and sends information, including upgrade information, to devices on the network. 2.17 Smart MeterA device that includes Metrology, Communications Module, and, optionally, HAN interface. These components are typically integrated into a single physical unit suitable for installation in
45、 a standard utility meter socket. Sub-components may or may not be integrated on the printed circuit boards contained within the Smart Meter. 2.18 SoftwarePrograms running on personal computers, servers, or handheld computing devices. NoteSoftware running on embedded devices such as Smart Meters is
46、referred to as “Firmware.” 2.19 Upgrade Management SystemThe hardware and software used to communicate and manage the Upgrade Process. The Upgrade Management System may be included in the Network Management System. 2.20 Upgrade ProcessThe series of steps required to change the Firmware in a Smart Me
47、ter: receive new Firmware, perform Integrity Checks on new Firmware, load new Firmware into the appropriate memory locations with the Smart Meter, and cause the Smart Meter to begin operating with the new Firmware. Copyright 2009 by the National Electrical Manufacturers Association. SG-AMI 1-2009 Pa
48、ge 4 Section 3 UPGRADE PROCESS FUNCTIONAL REQUIREMENTS 3.1 GENERAL The following functional requirements define what can be reasonably and appropriately expected to be upgradeable in a Smart Meter. To be clear, it is not expected that all characteristics or attributes of the Smart Meter are required
49、 to be upgradeable. In fact, there are specific characteristics of a Smart Meter that are not reasonably or appropriately considered upgradeable such as hardware components, like resistor or capacitor values; adding new hardware functions; expanding memory; or altering the basic communication characteristics of a radio. 3.2 SMART METER The functional requirements for the Smart Meter apply to any and all of its components. 3.2.1 Smart Meter shall attest the current version identification of Firmware for each of
