ISO/IEC TR 15067-3:2000
(Main)Information technology — Home Electronic Systems (HES) application model — Part 3: Model of an energy management system for HES
Information technology — Home Electronic Systems (HES) application model — Part 3: Model of an energy management system for HES
Technologies de l'information — Modèle d'application des systèmes électroniques domotiques (HES) — Partie 3: Modèle de systèmes de gestion d'énergie pour HES
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TECHNICAL ISO/IEC
REPORT
TR 15067-3
First edition
2000-10
Information technology –
Home Electronic System (HES) application model –
Part 3:
Model of an energy management system
for HES
Reference number
ISO/IEC TR 15067-3:2000(E)
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TECHNICAL ISO/IEC
REPORT – TYPE 3
TR 15067-3
First edition
2000-10
Information technology –
Home Electronic System (HES) application model –
Part 3:
Model of an energy management system
for HES
ISO/IEC 2000
All rights reserved. Unless otherwise specified, no part of this publication may be reproduced or utilized in any form or by any
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CONTENTS
Page
FOREWORD . 4
INTRODUCTION .5
Clause
1 Scope . 6
2 References . 6
3 Abbreviations. 6
4 The Evolution of energy management . 6
5 Load control. 7
5.1 Responding to pricing . 7
5.2 Local control . 7
5.3 Direct control . 7
5.4 Distributed control. 8
6 Value-added services. 9
7 The utility gateway. 10
8 The HES energy management model . 11
8.1 Logical and physical models . 11
8.2 Energy management use cases . 13
8.2.1 Structure of use cases . 13
8.2.2 Case 1: Local control . 13
8.2.3 Case 2: Direct control . 14
8.2.4 Case 3: Direct control with supervision. 15
8.2.5 Case 4: Distributed control. 16
8.2.6 Case 5: Advanced distributed control . 17
8.3 Case 6: Distributed control for intelligent appliances. 18
8.3.1 Case 7: Utility telemetry services . 19
8.4 HES messages for energy management . 20
8.4.1 HES messages overview. 20
8.4.2 HES message list. 20
9 Suggestions for the HES application language. 23
Figure 1 – A Distributed load control example . 9
Figure 2 – EPRI Customer communications gateway. 10
Figure 3 – Physical HES energy management model. 11
Figure 4 – Logical model for HES energy management . 11
Figure 5 – Logical model of minimal HES energy management. 12
Figure 6 – Case 1: Physical model . 13
Figure 7 – Case 1: Logical model . 13
Figure 8 – Case 2: Physical model . 14
Figure 9 – Case 2: Logical model . 14
Figure 10 – Case 3: Physical model . 15
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TR 15067-3 © ISO/IEC:2000(E) – 3 –
Figure 11 – Case 3: Logical model . 15
Figure 12 – Energy management controller parameters. 16
Figure 13 – Case 7: Physical model . 19
Figure 14 – Case 7: Logical model . 19
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INFORMATION TECHNOLOGY –
HOME ELECTRONIC SYSTEM (HES) APPLICATION MODEL –
Part 3: Model of an energy management system for HES
FOREWORD
1) ISO (International Organization for Standardization) and IEC (International Electrotechnical Commission) form
the specialized system for worldwide standardization. National bodies that are members of ISO or IEC
participate in the development of International Standards through technical committees established by the
respective organization to deal with particular fields of technical activity. ISO and IEC technical committees
collaborate in fields of mutual interest. Other international organizations, governmental and non-governmental,
in liaison with ISO and IEC, also take part in the work.
2) In the field of information technology, ISO and IEC have established a joint technical committee,
ISO/IEC JTC 1. Draft International Standards adopted by the joint technical committee are circulated to national
bodies for voting. Publication as an International Standard requires approval by at least 75 % of the national
bodies casting a vote.
3) Attention is drawn to the possibility that some of the elements of this Technical Report may be the subject of
patent rights. ISO and IEC shall not be held responsible for identifying any or all such patent rights.
The main task of IEC and ISO technical committees is to prepare International Standards. In
exceptional circumstances, a technical committee may propose the publication of a technical
report of one of the following types:
• type 1, when the required support cannot be obtained for the publication of an
International Standard, despite repeated efforts;
• type 2, when the subject is still under technical development or where, for any other
reason, there is the future but not immediate possibility of an agreement on an
International Standard;
• type 3, when the technical committee has collected data of a different kind from that which
is normally published as an International Standard, for example ‘state of the art’.
Technical reports of types 1 and 2 are subject to review within three years of publication to
decide whether they can be transformed into International Standards. Technical reports of
type 3 do not necessarily have to be reviewed until the data they provide are considered to be
no longer valid or useful.
ISO/IEC 15067-3, which is a technical report of type 3, was prepared by subcommittee 25:
Interconnection of information technology equipment, of ISO/IEC joint technical committee 1:
Information technology.
This publication was drafted in accordance with ISO/IEC directives, Part 3.
This document is not to be regarded as an International Standard. Comments on the content
of this document should be sent to IEC Central Office.
ISO/IEC 15067 currently consists of four parts:
Part 1: Application services and protocol (under consideraton)
Part 2: Lighting model for HES
Part 3: Model of an energy management system for HES
Part 4: Model of a security system for HES (under consideration)
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TR 15067-3 © ISO/IEC:2000(E) – 5 –
INTRODUCTION
This model of an energy management system for residences extends the set of HES (Home
Electronic System) application models. Models for lighting and security have already been
developed and accepted. These models should facilitate the validation of the language
specified for HES in ISO/IEC 15067-1.
These models have been developed to foster interoperability among products from competing
or complementary manufacturers. Product interoperability is essential when using home
control standards, such as HES. This document defines a typical security system and
describes the communications services needed. A high-level model for an energy
management system using HES is presented.
ISO and IEC would appreciate comments by developers of energy management systems
regarding possible enhancements to this model.
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INFORMATION TECHNOLOGY –
HOME ELECTRONIC SYSTEM (HES) APPLICATION MODEL –
Part 3: Model of an energy management system for HES
1 Scope
The model for energy management presented in this Technical Report is generic and
representative of a wide range of situations. Since one model cannot be completely
comprehensive other models or operating modes may be more appropriate for certain
applications.
This model for energy management accommodates a range of load control strategies.
Examples of implementations that could be described with this model include:
– the CELECT Intelligent Load Management System in the United Kingdom. The utility
transmits electricity cost data and forecasted outdoor air temperatures to residential
heater controllers;
– the “bleu, blanc, rouge” technique used by Electricité de France to announce price tiers
one day in advance. The tier signal is displayed using a blue, white or red light to alert the
customer;
– real-time pricing experiments by Consolidated Edison of New York and by Pacific Gas and
Electric, both in the United States.
2 Reference documents
ISO/IEC 15067-1: Information technology – Home Electronic System (HES) Application Model
– Part 1: Application Services and Protocol (under consideration)
3 Abbreviations
DSM Demand-Side Management
EPRI Electric Power Research Institute (Palo Alto, California, U.S.A.)
4 Evolution of energy management
Electricity consumption patterns have high peaks. During weather extremes of heat and cold
the demand for electricity rises sharply. In the United States the average rate of power
generation is only about 46 % of the peak generation that occurs during these situations.
Ideally, the utilities would like to maintain the supply of electricity sufficiently high to meet any
demand. This has been achieved in some regions of developed countries. However, this is
becoming less practical because of public pressure and government rules. Therefore, utilities
have developed many methods of Demand-Side Management (DSM) for influencing the
demand to match the available supply.
DSM tools enable utilities to modify the cumulative demand for energy, known as the load
shape when plotted over a one-day interval. Utilities have developed a variety of DSM
programs to manipulate the load shape. Different programs have different load shape goals,
with the majority intended for peak clipping.
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TR 15067-3 © ISO/IEC:2000(E) – 7 –
DSM programs initially focused on providing incentives for using electricity more efficiently.
Customer cooperation may be obtained by offering a financial incentive, such as an up-front
rebate, a loan guarantee, a lower rate for electricity, or free energy efficient planning and
evaluation services. Some programs offer rebates for switching from tungsten to fluorescent
lights, for adding building insulation, and for purchasing energy efficient appliances.
Utilities have developed more deterministic methods for influencing the demand through load
control. The more innovative methods of load control depend on market forces for exerting
control by varying the price of electricity. In the United States, almost 20 million customers out
of a total of 130 million participate in some DSM program. About 30 % of these programs are
load control.
5 Load control
5.1 Responding to pricing
In North America electricity traditionally has been sold at a flat rate or a volume-sensitive rate.
New pricing schemes are adding time as a factor. Time-of-use rates vary the price according
to the time of day. Typically, on-peak and off-peak rates are announced. The hours for each
rate are fixed for each day, or at least for work days, similar to telephone rates. Rates that
change dynamically with one-day or even no advance notice constitute real-time pricing.
Most load control programs by utilities have been limited to local control and direct control.
However, the most innovative load control uses a combination called distributed control.
These varieties of DSM help users respond effectively to utility price variations.
5.2 Local control
The utility publishes an electricity tariff that has between two and four different rates
depending on the time of day. Customers with time-of-use pricing for electricity are
encouraged to operate heavy power consuming appliances at off peak pricing times. In order
to maximize the savings, the customer must know the rates, know the power requirements of
the appliance, and know the cost of operating the appliance. Then the customer can decide if
it is convenient to defer the operation or spend the money during the peak cost time.
A few utilities have instituted a tariff that discourages a peak load. The consumer pays a
special charge called a demand charge if the total electricity consumed during a short interval
(typically 15 or 30 min) exceeds a preset limit.
Control equipment in the house can assist in determining when to operate some appliances.
For example, a programmable thermostat could lower the temperature setting for a furnace
during a period of higher priced electricity. If the consumer is subject to demand charges,
special equipment could measure the power drawn, and cut off selected appliances, such as
an air conditioner, as the demand limit is approached.
5.3 Direct control
Whereas local control depends entirely on voluntary cooperation by customers, direct control
forces a shift in the customer demand for electricity. When direct control is activated at times
of peak consumption, the utility interrupts the operation of appliances, such as the water
heater and air conditioner. This requires prior arrangements with customers for permission
and equipment installation. Many customers in the U.S. are offered rebates of up to $ 10 a
month for participating in direct load control. More than 90 % of load control programs in the
U.S. are based on direct control.
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The utility operates these switches by remote control. They may use signals sent over the
power line, over a cable television channel, over the telephone line, or via radio waves. A
typical pattern of control would occur during the peak usage on a very hot afternoon:
– the air conditioner is cycled off periodically for 15 min, then 15 min on. Half of the
customers are on while the other half is off;
– the water heater is cycled off for two hours, then on for two hours.
5.4 Distributed control
Distributed control is a relatively new method of load control. It is a combination of local and
direct control with much increased flexibility. The utility has the opportunity to change prices
at will by following the wholesale market price of electricity to reflect actual utility costs.
Distributed control has the potential to satisfy both the utility and the consumer:
– the utility can price power to reflect costs and supply. Changes can occur quickly, as
needed;
– the customer makes the fundamental choice of comfort and convenience of operating
certain electric appliances versus the cost of electricity.
It should be noted that some countries do not presently permit residential users to be offered
fully flexible real-time pricing. Utilities may be permitted tariffs with two or more price tiers to
reflect their costs of energy generation and distribution. As these innovative pricing schemes
lower the peak demand, utility costs are reduced.
Some utilities are capable of accurately forecasting the cost of energy in the near future,
typically 24 hours in advance, and supplying this information to the residential consumer.
Forecasted pricing enables the consumer, or an intelligent energy management system, to
“draw forward” on consumption in anticipation of peak pricing. This may involve comparatively
simple measures such as ensuring that heat storage devices, water heaters, and similar are
fully charged when the peak price period starts. The supply of such forecast pricing enables
peaks in demand to be smoothed both forward and backward in time, thereby reducing the
impact of such measures on consumer comfort and convenience.
There are two important problems for effective use of the changing cost of power. First, the
price data must be delivered to the customer in a timely fashion. Second, the customer must
interpret the data and apply it to appliance operation. Since most customers do not
understand electricity measures, such as kilowatthours, they are not likely to use this data
correctly. Here is where home control technology can benefit the consumer and the utility.
Figure 1 shows a possible distributed load control residential implementation. Electricity price
data are sent to all houses in real-time over a wide area network, such as radio, telephone, or
cable television. An energy management controller in the house receives the electricity rate
information via a home control communications network. The controller combines this
information with stored data about appliance power requirements and customer information.
The customer might enter preferences in some implementations for appliance operation and
budget limitations for electricity expenditures. Having processed this information, the
controller issues signals that are distributed over a home control network in the house to the
relevant appliances.
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TR 15067-3 © ISO/IEC:2000(E) – 9 –
Utility power
Intelligent
meter Energy
Water
management
heater
HVAC
controller
Meter
Utility
data
Home control network
Dish
Refrigerator
washer
Utility
Wide area
gateway
network
Inside
Figure 1 – A Distributed load control example
The energy management controller may not necessarily be a separate component. It could be
combined with a security controller, an ISDN telephone decoder, or a cable television
converter/decoder, or the functionality could be distributed among other components. Also,
intelligent appliances may contain much or all of the functionality of an energy management
controller. The location of energy management functions among a dedicated controller and
appliances depends on the future market for appliances designed for integration with
distributed control.
6 Value-added services
Communications between utilities and customers has been used on a very limited scale to
implement load control for effective DSM. Typically, one-way communication is employed for
switching customer loads. Utilities are now considering additional services that can be
delivered using upgraded versions of these communications facilities. The objective is to
retain customers with innovative services and to generate additional revenue with offering
ancillary to power. Collectively, these are known as value-added services. Some governments
have mandated that utilities, which traditionally were granted monopolies, start planning for
competition. Therefore, utilities are seeking value-added services to make their products more
attractive to customers.
Potential value-added services for electric utilities beyond load control are listed. The services
preceded by a check-mark (9) may be sold for additional revenue beyond the usual energy
charges.
Automatic meter reading
9Offer bills with details about consumption by major appliances
Monitor power delivery
9Monitor power quality
9Offer load profiles
Control customer access when customers move or don't pay bills
Stagger power restoration in a neighborhood after a power failure
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Detect tampering
9Diagnose appliances’ problems and notify the customer
9Offer information and telemetry services
7 The utility gateway
Utilities use a variety of communications protocols for wide area network communications.
These communication protocols are often different from the protocols used for home control.
Communication gateways are required to link utility networks to home control networks when
the protocols differ.
There is a multi-million dollar effort among some U.S. utilities to unify utility communications
with a limited set of international standards. This project is the Utility Communications
1)
Architecture, sponsored by the Electric Power Research Institute (EPRI). This new protocol
and existing utility protocols are different from home control protocols. Therefore, a
communications gateway will be needed to link utility networks with home control networks for
load control and value-added services data.
Utilities have many options for implementing and locating the customer gateway. EPRI has
defined the Customer Communications Gateway for linking utility signals to customer
equipment. This gateway is located near the electric meter at each house or building. As
shown in Figure 2, it links the utility wide area network with a local area network in the house.
It is designed to accommodate a variety of home control networks. Also, it provides a
communications port for an electric meter. In some gateway designs the meter is accessible
from both the utility and home networks.
Electric
meter
Customer
Utility External
Utility Customer
communications
plant premises
access
gateway
Electric utility Interface Home
wide area network local area network
Figure 2 – EPRI Customer communications gateway
The gateway is responsible for converting the electrical signal from the wide area network
format to that of the local area network. There may be differences in communications media,
connectors, electrical waveforms, and timing. Data rate disparities on the two networks may
require buffering and flow control in the gateway to avoid losing data. Also, the formats for
commands and data are likely to be different and require translation.
–––––––––
1)
Many investor-owned utilities support EPRI (Palo Alto, California). EPRI uses member utility funds to sponsor
research projects. Utilities outside the United States may join EPRI as foreign affiliates.
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TR 15067-3 © ISO/IEC:2000(E) – 11 –
8 The HES energy management model
8.1 Logical and physical models
The physical elements of the HES energy management model are shown in Figure 3. The
components have been described in clauses 5 to 7. The logical relationship among these
components is illustrated in Figure 4. To accommodate prevalent practices of direct control, a
logical model with minimal functionality is proposed in Figure 5. In this case, the energy
management controller has been eliminated because the utility controls the appliances by a
direct signal. A user interface is included because some implementations allow the user to
over-ride a direct load control signal. A cost penalty is usually assessed for over-rides.
Energy
Utility
A
A U
management
gateway
controller
A A M
Home control system medium
Other
Components
system
controller
A appliance
M utility meter
U user interface
HES interface
Figure 3 – Physical HES energy management model
User
interface
Appliance
Energy
Utility
management
Appliance
meter
controller
Appliance
Utility
gateway
Links to other
Utility wide
subsystems
area network
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Figure 4 – Logical model for HES energy management
User
interface
Appliance
Utility
Appliance
gateway
Appliance
Utility wide
area network
Figure 5 – Logical model of minimal HES energy management
Energy management is one of many subsystems possible in a home control network. As
shown in Figure 4 the energy management controller may be linked to other home control
systems or to a home control coordinator. The coordinator might be responsible for providing
common scheduling and subsystem interaction. This coordination function may be distributed
among the system controllers through sophisticated software, thereby eliminating the
coordinating controller.
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TR 15067-3 © ISO/IEC:2000(E) – 13 –
8.2 Energy management use cases
8.2.1 Structure of use cases
This clause shows examples of energy management applications. Each application is
explained in words and illustrated with physical and logical models. These models are based
on the components of the HES Energy Management Model. In the following cases, reference
is made to power and kilowatts. With a change of terminology, these cases can apply to other
utilities, such as gas, water, fuel oil, or heat flow (for district or central heating).
8.2.2 Case 1: Local control
See Figures 6 and 7.
U
Utility
gateway
Home control system medium
Components
U user interface
HES interface
Figure 6 – Case 1: Physical model
User
interface
Utility
gateway
Figure 7 – Case 1: Logical model
Most local control schemes currently involve no communications to the customer. Typically, a
static two tier rate is announced by the utility to customers. In more sophisticated local control
the utility may establish:
− peak and off-peak rates that change with appropriate notice;
− times for peak and off-peak rates;
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− multiple rate levels, such as time periods for low rates, medium rates, high rates, and
emergency rates. The latter rate may be unusually high to indicate an emergency
condition.
NOTE As the number of pricing tiers grows and the time of transition becomes variable, local control becomes
similar to distributed control.
In all of these variations of local control, the possible communications between the utility and
the customer consists of an indication of which price level is in effect. Therefore, signals flow
from the utility via the gateway to a user interface. The user interface may consist of indicator
lamps on a special unit with markings to indicate whether peak or off-peak or any intermediate
rates are in effect.
8.2.3 Case 2: Direct control
See Figures 8 and 9.
Utility
AA
gateway
A
A
Home control system medium
Components
A appliance
HES interface
Figure 8 – Case 2: Physical model
Appliance
Utility
Appliance
gateway
Appliance
Utility wide
area network
Figure 9 – Case 2: Logical model
The utility enables or disables the operation of specific appliances. This case is repre-
sentative of present direct load control. Most present direct control consists of one-way
communications from the utility to the customer appliances. The utility does not know if the
control signal actually reached the appliance or if the appliance was operating.
The utility messages are usually limited to specifying which appliance is to be turned off or to
be restored to operating status.
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TR 15067-3 © ISO/IEC:2000(E) – 15 –
8.2.4 Case 3: Direct control with supervision
See Figures 10 and 11.
Utility
AA
U
gateway
A A
Components
A appliance
U user interface
HES Interface
Figure 10 – Case 3: Physical model
User
interface
Appliance
Utility
Appliance
gateway
Appliance
Utility wide
area network
Figure 11 – Case 3: Logical model
Case 3 accommodates more advanced direct control with two-way communications. This case
allows the utility to verify that specific appliances are responding to control. Also, the utility
can determine the effectiveness of load shedding and, therefore, can detect free-riders. For
these customers the controlled load never attempts to use energy during the controlled time
period. Typically, these customers are not at home and the appliances are not operating
during the controlled period.
Case 3 also allows the utility to institute control over the demand for power by setting a limit
on kilowatts during a specified interval. The following expanded set of messages supports
case 3.
8.2.4.1 Utility messages
– Which app
...
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