A1800 Technical Manual_rev.02.pdf

A1800 ALPHA MeterTechnical Manual Rev.02 10-2011 www.izmerenie.ru Technical manual i Contents Technical manual Contents Contents 1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-1 A1800 ALPHA meter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-1 Standards Compliance . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2 IEC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2 IEEE/ANSI . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2 DIN . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2 Benefits . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-3 Reliability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-3 Maintainability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-3 ANSI standard communication open protocol . . . . . . 1-4 Adaptability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4 Economy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4 Security . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4 Accuracy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4 Meter types . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-5 Meter series . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-6 2 Product description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-1 Physical description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-1 Optical port . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3 LCD . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3 Nameplate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3 Utility information card . . . . . . . . . . . . . . . . . . . . . . . . 2-4 Communications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-4 Battery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-5 Cover tamper detection switches . . . . . . . . . . . . . . . . . 2-5 Terminal configurations . . . . . . . . . . . . . . . . . . . . . . . . 2-6 Communication protocols . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-6 System architecture . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-6 General theory of operation . . . . . . . . . . . . . . . . . . . . . . . . . . 2-7 Power supply . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-7 Main power supply . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-7 Auxiliary power supply . . . . . . . . . . . . . . . . . . . . . . . . 2-7 Current and voltage sensing . . . . . . . . . . . . . . . . . . . . . . 2-7 Meter engine . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-8 Microcontroller . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-8 EEPROM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-8 Billing data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9 Metered energy and demand quantities . . . . . . . . . . . . . 2-9 Average power factor . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9 Demand calculations . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9 Rolling interval . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-10 Block interval . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-10 Thermal time constant . . . . . . . . . . . . . . . . . . . . . . . . 2-11 Maximum demand . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-11 Cumulative maximum demand . . . . . . . . . . . . . . . . . . . 2-11 Continuous cumulative maximum demand . . . . . . . . . 2-11 Coincident demand or power factor . . . . . . . . . . . . . . . 2-12 . . . 4-13 Voltage sags . . . . . . . . . . . . . . 3-3 Display indicators . . . . . . . . . . . . . . . 2-12 TOU data . . . . . . 2-15 Load profiling pulse divisor . . . . . . . . . . 3-4 RESET button . . . . . . . . . . . . . . . . . . . . . 4-5 Initiating service voltage tests . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-7 Alternate mode . . 4-7 Restarting the service voltage test in diagnostic mode 4-9 Service current test . . . . . . . . . . . . 2-12 Primary and secondary metering . 3-2 Energy direction indicators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-12 TRueQ timing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-13 Logs and data sets . . . . . . . . . . . . . . 3-3 Error indicator . . . . . . . . . . . 3-8 Test mode . . . 4-13 . . . . . . . . . 3-9 Demand reset lockout . . . . . . . . 4-10 TRueQ monitoring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-17 Voltage sag log . . . 3-3 Active COM port indicator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-18 3 Operating instructions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1 LCD . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-9 Initiating the service current test . . . . . . . . 2-13 Event log . . . . . 2-17 Physical dimensions and mass . . . . . . 2-15 Instrumentation profiling . . . . . . . 4-12 TRueQ log . . . . . . . . . . . . . 2-14 History log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-3 Low battery indicator . . . . . . . . 3-1 Quantity identifier . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-3 Push buttons . . . . 4-1 System instrumentation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13 Voltage sag counter and timer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-2 Display quantity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-12 TRueQ and relays . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-14 Self reads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-14 Load profiling . . . . . . . . . . . . . . . . . .Technical manual ii Contents Demand forgiveness . . . . . . . . . . . . . . . . . . . . . . . . 3-5 Using the backlight . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-16 TRueQ Log . . . . . . . . . 4-1 System service tests . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-7 Normal mode . . . . . . . . . . . . . . . . . 3-8 Demand reset . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-4 * button . . . . . . . . . . 4-10 System service error codes . . . . . . . . 4-13 TRueQ tests . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-5 Service voltage test . . . . . . . . . . . . . . . . . . . . 4-5 System service locking . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1 Indicators and controls . . 3-3 Alternate display indicator . . . . . . . . . . . . . . . . . 4-12 TRueQ display items . . . . . . . . . . . . 3-2 Phase indicators . . . . . . . . 3-10 Demand reset data area . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-17 User-defined tables . . . . . . . . 3-10 4 Meter tools . . . . . . 3-6 Operating modes . . . . . . . . . . . . . . . 2-12 Power failure data . . . . . . . . . . . . . . . . 3-2 Power/energy units identifier . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-5 Gather necessary data . . . 7-3 Troubleshooting . . . . . . . . . . . . . . . . . . . . . . . . . . 6-9 Meter testing . . . . . . . . . . 6-9 Test equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-15 Testing a meter with compensation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-1 Codes and warnings . 8-5 Calculation example . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-4 LED pulse outputs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-2 Calculate the meter configuration parameters . . . . . . . . . . . . . . . . . . 6-1 Meter self test . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-15 Security . . . . . . . . . . . . . . . 5-1 Relay outputs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-1 Gather necessary data . . . . . 5-3 Using pulse value . . . . . . . . . . . . . . . . . 7-1 Preliminary inspection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-8 Meter shop testing . 8-12 Meter outputs affected by compensation . . . . . . 6-10 7 Installation and removal. . . . . . . 7-6 8 Loss compensation. . . . . . . . . . . . . . . . . . . . . . . . . 4-25 Anti–tampering . . . . . . . 7-6 Removing the battery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-10 Using relay outputs for testing . . . . . . . . . . . . . . . . . . . . . . . 8-2 Calculating line loss . . . . . . . . . . . . . . . . . . . . . . . . . 5-1 Energy pulse outputs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-7 Gather necessary data . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-4 Relay-related alarms . . . . 8-1 Introduction . . . . . . . . . . . . . . . . . . . . 6-9 Test setup . . . . . . . . . . . 7-1 Placing the meter into service . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-25 Meter passwords . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-1 Installing a TOU battery . . . . . . . . . . . . 6-2 Error codes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4 Marking the utility information card . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-5 Communication codes . . . . . . . . . . . . . 7-5 Removing the meter from service . . . . . . . . . . . 4-26 5 Outputs. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-26 Program protection . 5-6 Output specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-1 Availability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4 Initial setup . . . . . . . . . .Technical manual iii Contents TRueQ event counters and timers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-10 Using LCD pulse count for testing . . . . . . . . . . . . . . . . . . . . . . . . . 5-6 6 Testing . . . 5-3 Using pulse divisor . . . . . . . . . . . . . . . . . 8-12 Internal meter calculations . . . . . 8-1 Software support . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-1 What is Loss Compensation? . . . . . . . . . . . . . . 8-1 Calculating the correction values . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-2 Warning codes . . . . . . . . . . . . 8-15 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-8 Enter Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B-4 Status . . . . . . . . . .B-5 Metered quantities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B-8 Coincident demand and power factor . . . . . . . . .B-9 System instrumentation .B-8 Cumulative demand . . . . . . . .E-2 Dimensions and mass . . .B-12 C Nameplate and style number information . . . .B-2 Default display formats . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .E-1 Operating ranges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .C-2 Style number information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B-12 Communication codes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B-3 General meter information . . . . . . . . . . . . . . . . . . . . . .C-3 D Wiring diagrams . . . . . . . . . . . . . . .E-1 Absolute maximums . . . . . . . . . . . . . . D-1 Direct connected . . . . . . . . . . . . . . . . . . . D-2 E Technical specifications . . . . . . . . . . . .E-2 . . . . . . . . . . . . . . . . . . . . . . . . . . . . A-1 B Display table . . . . . . . . .B-3 LCD test . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B-1 Display format . . . . . D-1 CT-connected meters .C-1 Utility information card . . . . . . . . . . . . . . . .C-1 Nameplate . . . . . . . . . . . . . . . . . . . . . . .B-1 Display list items . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B-6 Average power factor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B-9 System service tests . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Technical manual iv Contents A Glossary . . . . . . . . . . . . . . . . . .B-4 Meter configuration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .B-11 Errors and warnings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .E-1 Operating characteristics . . . . . . . . . . . .E-1 General performance characteristics . . . . . . . . . . . . . . . . . . . . recommendations. or claims against the user by its customers from the use of the information. or warranties either expressed or implied. This information should not be considered as all–inclusive or covering all contingencies. and safety notices in this technical manual are based on Elster Metronica. and observe all safety notices and recommendations within this manual. If further information is required. and maintenance of this product can present potentially hazardous conditions (for example. Within this manual. or consequential damage or loss whatsoever. . Caution is used to alert personnel to the presence of a hazard that will or can cause minor personal injury. cost of capital. warnings. high voltages) if safety procedures are not followed. or even death. and cautions contained herein. either expressed or implied. . No warranties. descriptions. To ensure that this product is used safely. In no event will Elster Metronica. OOO be held responsible to the user in contract. equipment damage. operation. other than those specifically set out by any existing contract between the parties. as this manual is intended for use in its entirety. Any such contract states the entire obligation of the seller. The information. commitment. are made regarding the information. incidental. personal injury. including warranties of fitness for a particular purpose or merchantability. indirect. OOO experience and judgment with respect to the operation and maintenance of the described product. safety notices appear preceding the text or step to which they apply. operation. strict liability. cross references and safety notices may be overlooked. If you were to remove or copy individual pages. Inform personnel involved in the installation. recommendations. Elster Metronica. The contents of this technical manual shall not become part of or modify any prior or existing agreement. and maintenance of the product about the safety notices and recommendations contained in this manual. descriptions. Do not remove or copy individual pages from this manual. or warranties arising from the course of dealing or usage of trade. Safety notices are divided into the following four classifications: Notice is used to alert personnel to installation. or property damage if the notice is ignored. operation. or maintenance information that is important but not hazard related. possibly resulting in damage to the equipment. it is important that you: Review. Safety Information Installation. including warranties of merchantability or fitness for a particular purpose. including but not limited to: damage or loss of use of equipment. recommendations. representations. and safety notices contained herein. or otherwise for any special. agreements. OOO should be consulted. in tort (including negligence). loss of profits or revenues. understand.A1800 ALPHA Meter Family Technical Manual v A1800 ALPHA Meter Technical Manual Disclaimer of Warranties and Limitation of Liability There are no understandings. descriptions. or relationship. Danger is used to alert personnel to the presence of a hazard that will cause severe personal injury. equipment damage.A1800 ALPHA Meter Family Technical Manual vi Warning is used to alert personnel to the presence of a hazard that can cause severe personal injury. . death. . death. equipment damage. or property damage if the notice is ignored. or property damage if notice is ignored. 2 S CT A VT V imp/kWh(kVARh) Introduction .and 4-wire configurations for 3 phases.Q L1 L2 L3 COM 0 1 2 T1 T2 T3 T4 T5 T6 T7 T8 EOI LC TC TST T YP E A1800 M ODEL 3x 58/100.277/480V.. Figure 1-1.000 imp/kVarh 0 . See Figure 1-1 for an illustration of an A1800 ALPHA meter.000 imp/kWh 5. 50Hz 1(10)A ELSTERSAMPLE 5. The A1800 ALPHA meter family is a totally electronic polyphase electricity meter and integral register for commercial and industrial applications. The meter is available in 3..Technical manual Technical manual 1-1 1 Introduction A1800 ALPHA meter The A1800 ALPHA meter family provides a platform that supports a variety of metering requirements. A1800 ALPHA meter + Q -P +P . Table 1-1. The A1800 ALPHA meter meets or exceeds the following IEEE/ANSI standards for electricity metering. principal dimensions for polyphase meters.18 1996 Protocol Specification for ANSI Type 2 Optical Port IEEE 1377/ ANSI C12.5 S) 62053-23 2003 1 Particular requirements-static meters for reactive energy (classes 2 and 3) 62053-31 1998 1 Particular requirements-pulse output devices for electromechanical and electronic meters (two wires only) 62053-61 1998 1 Particular requirements-power consumption and voltage requirements 62056-211 2002 1 Electricity metering-data exchange for meter reading. up to 60 A rated maximum current. 1 For meter width and location of lower mounting holes Introduction . IEEE/ANSI.19 1997 Utility Industry End Device Data Tables IEEE 1702/ ANSI C12. Table 1-2. tests and test conditions.21 1999 Protocol Specification for Telephone Modem Communications DIN. tariff and load control-direct local data exchange 62052-21 2004 1 Title Electricity metering-tariff and load controlparticular requirements for time switches Complies with optical port requirements only.Technical manual 1-2 Standards Compliance IEC.0 and 2.2 S and 0. 62053-21 2003 1 Particular requirements-static meters for active energy (Classes 1. and it is intended for use by commercial and industrial utility customers. IEC standards supported by the A1800 ALPHA meter Number Date Edition 62052-11 2003 1 General requirements. Table 1-3. The A1800 ALPHA meter meets or exceeds the following DIN standards for electricity metering. The A1800 ALPHA meter meets or exceeds the following IEC standards for electricity metering. DIN standards supported by the A1800 ALPHA meter1 Number Date Title DIN 43857 Part 2 1978 Watthour meters in moulded insulation case without instrument transformers. IEEE/ANSI standards supported by the A1800 ALPHA meter Number Date Title IEEE 1701/ ANSI C12.0) 62053-22 2003 1 Particular requirements-static meters for active energy (classes 0. The A1800 ALPHA meter. the service life of the lithium battery can exceed the life of the meter. The A1800 ALPHA meter has been designed to function to provide long battery life. The meter can also operate using the auxiliary power supply. The power supply in the meter operates from any available phase.Technical manual 1-3 Benefits Reliability. The meter firmware resides in flash memory. part of the ALPHA line of meters. uses the patented ALPHA meter technology for measurement and accurate calculation of energy quantities. The A1800 ALPHA meter uses nonvolatile memory to store billing and other critical data. The A1800 ALPHA meter can use its internal crystal oscillator or the power line frequency to maintain time and date functions. The data is preserved even if the power fails. A three-phase. four-wire A1800 ALPHA meter maintains operation if the neutral line and any one or two of the line voltages become disconnected. With over 3 million ALPHA polyphase meters in operation throughout the world. which can power the meter from an independent power source in the situation where main power is unavailable. surface-mount technology circuit board. Because of the low current drain. Introduction . The A1800 ALPHA meter is easy to maintain. Meter register functions and communication interfaces are fully integrated on a single. Maintainability. The crystal oscillator can be used when the power line frequency is known to be too unstable for accurate timekeeping. allowing the firmware to be upgraded in the field. the A1800 ALPHA continues the tradition of reliable electronic meters. the main meter circuit board provides selectable. Supporting the ANSI protocols makes it easier to add products to existing systems and provide an open standard for meter data communications. The A1800 ALPHA meter meets or exceeds requirements of IEC standards. Additionally. The A1800 ALPHA meter is tamper-resistant. Most common services and mounting configurations are supported. The low current sensor burden may also improve the accuracy of external current transformers when measuring light loads. As an added feature. . These standards include communication protocols for a wide range of metering products.0 Class 1. the factory-configurable optical port accommodates IEC standard. Configuration IEC 62053-22 /GOST R 52323-2005/ Class 0. Economy. The wide operating range allows installation at any of the common meter voltages. The A1800 ALPHA meter complies with the ANSI C12. and functional upgrades are easily performed as new situations arise.5 S Class 1. It can increase personnel productivity because of the following features: • no user calibration required (factory calibrated) • reduced testing times • fewer styles to learn and maintain • dual serial communications interfaces on the main meter circuit board • automated data retrieval • system service verification • on-site instrumentation displays • tamper restraint and quality monitoring (TRueQ™) tests • event logging Security.21 standards. and C12. They are the basis for common industry data structures and a common protocol for transporting the data structures. Adaptability.18.2 S 1 direct connect transformer-rated 1 Actual  IEC 62053-21 /GOST R 52322-2005/ IEC 62053-231 /GOST R 52425-2005// Class 0. offering a broad range of demand and TOU operations. All A1800 ALPHA meters provide auditing capabilities that can be used to indicate potential meter tampering like terminal cover open detection and per phase outage recording. making it easier to see obvious tampering.0         reactive energy accuracy is substantially better than required by the standard. serial remote interfaces for RS-232 or RS-485 communication. The standard TRueQ feature or the optional instrumentation profiling (or both) can be used to detect possible tampering of energy measurements. Accuracy.19. The meter precisely measures demand and energy across a wide range of voltage and current despite variations in temperature and power factor.0 Class 2. C12. The 16-segment character liquid crystal display (LCD) improves readability and provides flexibility for displaying meter information. independent. Passwords may be specified that prevent unauthorized access to meter data. The A1800 ALPHA meter can be ordered with a partially-transparent terminal cover. The A1800 ALPHA meter saves both time and money.Technical manual 1-4 Introduction ANSI standard communication open protocol. The A1800 ALPHA meter allows configuration for custom TOU rates (tariffs). Technical manual 1-5 Introduction Meter types Different meters within the A1800 ALPHA meter family have specific capabilities (see Table 1-4 and Figure 1-2). the term A1800 ALPHA is used to describe any meter in the meter family.5 accuracy • transformer and line loss compensation (V) • 4-quadrant metering (A) • extended 1 MB memory (X) • instrumentation profiling (L) • load and instrumentation profiling (L) • add 1 communication port • Multi-protocol communications (Modbus.5S • 1 communications port (RS-232 or RS-485) • internal 128 KB (256KB) memory • 4 relays • TRueQ • LCD backlight • Class 0. a specific meter designation will be used to indicate that the description applies to only one meter in the meter family.0) A1805 Large C&I/ Mid C&I 0. 2 Optional features .0) A18101 Small C&I/ Mid C&I 1. DNP 3.5 accuracy • • • • • extended 1 MB memory (X) instrumentation profiling (L) load profiling (L) add 1communication port multitariffs (T) A18213 Small C&I 1. Contact Elster Metronica for DC connected meter availability. Note: Throughout this manual.2S • 1 communications port (RS-232 or RS-485) • internal 128 KB (256KB) memory • auxiliary power supply • 4 relays • TRueQ • multitariffs • LCD backlight • Class 0.2 accuracy • transformer and line loss compensation (V) • 4-quadrant metering (A) • extended 1 MB memory (X) • load and instrumentation profiling (L) • add 1 communication port • Multi-protocol communications (Modbus.0 • 1 communications port (RS-232 or RS-485) • internal 128 KB (256KB) memory • 4 relays • TRueQ • LCD backlight • • • • • extended 1 MB memory (X) instrumentation profiling (L) load profiling (L) add 1communication port multitariffs (T) 1 Standard features Contact Elster Metronica for availability. When necessary. Meter designations of the A1800 ALPHA meter family Meter Market segment Class A1802 Interchange meter/ Large C&I 0.0 • 1 communications port (RS-232 or RS-485) • internal 128 KB (256KB) memory • auxiliary power supply • 4 relays • TRueQ • LCD backlight • multitariffs • transformer and line loss compensation (V) • 4-quadrant metering (A) • extended 1 MB memory (X) • instrumentation profiling (L) • load and instrumentation profiling (L) • add 1communication port A18202 Small C&I 0. 3 Contact Elster Metronica for DC connected meter availability.5S • 1 communications port (RS-232 or RS-485) • internal 128 KB (256KB) memory • auxiliary power supply • 4 relays • TRueQ • multitariffs • LCD backlight • Class 0. DNP 3. Table 1-4. Technical manual 1-6 Figure 1-2. A1800 ALPHA meter family application pyramid A1 80 0A LP HA me ter fam ily Interchange metering A1802 Large C & I A1805 Mid C & I A1810 Light C & I A1810 A1820 Residential Introduction . Product description . The cover assembly of the A1800 ALPHA meter exceeds the environmental requirements of IEC 62053-11. The case of the A1800 ALPHA meter provides an IP54 degree of protection for the meter. The physical components of the A1800 ALPHA meter consist of the following: • terminal cover • long terminal cover (see Figure 2-1) • short terminal cover (see Figure 2-2)1 • partially-transparent terminal cover • meter cover assembly • inner cover assembly • base electronic assembly Figure 2-1. Front view of the A1800 ALPHA meter 1 Contact Elster Metronica for availability.Technical manual Technical manual 2-1 2 Product description Physical description The A1800 ALPHA meter is designed for indoor mounting. Technical manual 2-2 Product description The terminal cover and meter cover assembly are manufactured using a UV-protected polycarbonate plastic. The terminal cover is available in either the long version or the short version. The meter cover assembly has a clear plastic window that allows the meter LCD and nameplates to be viewed. Figure 2-2. Front view of A1800 ALPHA meter with short terminal cover (transformer rated)1 The A1800 ALPHA meter can be sealed using any or all of the following methods: Seal location Purpose Meter cover screws (certification) Prevents access to the meter except for the main connections, relay connections, communication interface connections, and nameplate. Also can prevent reprogramming and recalibration of the meter. Terminal cover screws (utility) Prevents non-utility access to the main connections, relay connections, and utility information card RESET push button Prevents unauthorized manual demand resets The four cover screws can be individually sealed (Figure 2-1). The two terminal cover screws limit access to the main terminals and auxiliary wiring connections only. Therefore, only the terminal cover seals must be broken to access these connections. The two meter cover screws are located on the lower front of the meter under the terminal cover. Sealing these screws seals the main enclosure and limits access to the metering circuit board and sensing elements. For maximum protection of the metering components, seal all four screw seals. 1 Contact Elster Metronica for availability. Technical manual 2-3 Figure 2-3. A1800 ALPHA meter with cover removed (transformer rated) Optical port. The A1800 ALPHA meter provides an optical port that can be ordered with IEC-compliant interface (see Figure 2-4). To use Elster meter support software to read or program the meter through the optical port, an optical probe is required. This probe connects from the serial port of the computer to the optical port on the meter. Figure 2-4. IEC-compliant optical port interface IEC-compliant optical interface Elster Metronica recommends use of the AE-1 optical probe to reliably read the A1800 ALPHA meter. For information on ordering the AE-1 optical probe, visit www.izmerenie.ru or contact your local Elster Metronica representative. LCD. The A1800 ALPHA meter is equipped with a 16-segment character liquid crystal display. See “Indicators and controls” on page 3-1 for details. Nameplate. Elster Metronica installs the nameplate at the factory. See Appendix C, “Nameplate and style number information,” for details on the nameplate. Product description Technical manual 2-4 Product description Utility information card. The utility information card is removable (after the terminal cover has been removed) and allows the utility to enter meter site-specific information. See “Utility information card” on page C-2 for more information. Figure 2-5. Removing the utility information card Communications. The A1800 ALPHA meter (“-G” suffix) provides remote communications interfaces on the main meter circuit board for RS-232 or RS-485 serial communication. Physical outputs exist for both RS-232 and RS-485 interfaces; however, only one can be used at any given time. No configuration is necessary to switch between an RS-232 and RS-485 selection. Additionally, the A1800 ALPHA meter (“-S”, “-B” suffixs) provides a second, independent serial communication port that supports either RS-232 (see Figure 2-6) or RS-485 (see Figure 2-7). See Chapter 5, “Outputs,” for more information on the RS-232 or RS-485 ports. Figure 2-6. A1800 ALPHA meter (-S suffix) with RS-232 as second communication port RS-232 connector (optional)* Pulse output relay (optional) RS-485 terminals RS-232 connector *Present when optional second communication port is installed Cover tamper detection switches. The date and time of the cover removal is logged in the event log. (See Figure 2-8 for an illustration of the terminal cover detection switch. A1800 ALPHA meter (-B suffix) with RS-485 as second communication port RS-485 connector (optional)* Pulse output relay (optional) RS-485 terminals RS-232 connector *Present when optional second communication port is installed Battery. See “Event log” on page 2-14 for more information.Technical manual 2-5 Product description Figure 2-7. Terminal cover detection switch Cover closed Cover opened .) When either detection switch is activated. a detection switch is activated. the meter cover detection switch is similar. When either the terminal cover or the meter cover is opened. Figure 2-8. the TC indicator on the LCD turns on and remains on while the cover is removed. The terminal block has a battery well and connector for the optional TOU battery. See for the meter circuit board block diagram. Meter block diagram Phase A voltage Phase B voltage Non volatile supply 5 V linear power supply Wide input power supply Phase C voltage Battery Precision reference LCD Resistive divider Low power crystal Power Fail Resistive divider 2x Line Freq A Resistive divider Phase A current Current sensor Phase B current Current sensor Phase C current Current sensor Meter engine B C Wh Del Microcontroller Wh Rec varh Del varh Rec Clock Crystal EEPROM Option connector Optical Remote Pulse port port 1/2 outputs . The A1800 ALPHA meter supports the following terminal configurations: • 10 A transformer-rated (sequential) • 100 A direct connect-rated (sequential) System architecture The A1800 ALPHA meter main circuit board contains all the electronics that make up the meter registers and communication interfaces. The circuit board as shown in contains the following: • meter engine • microcontroller • EEPROM • resistive dividers for the 3 phase voltages • load resistors for the 3 current sensors • power supply • high frequency crystal oscillator • 32 kHz low power timekeeping crystal oscillator • optical port components • liquid crystal display (LCD) interface • RS-232 and RS-485 communication interfaces • option board interface • pulse outputs Figure 2-9.Technical manual 2-6 Product description Terminal configurations. The microprocessor processes and stores the data into memory according to the user-specified program. VAh. and the meter engine uses the sampled signals to compute Wh. respectively. The A1800 ALPHA meter can accommodate various tariff structures. The auxiliary power supply accepts the following voltages: • For independent AC power. Auxiliary power supply. The A1800 ALPHA meter can also be connected to both the main power source and auxiliary power source. The meter engine accumulates and recalculates all quantities after every line cycle. At least two lines must be present to power the meter circuitry. Power supply Main power supply. from 57 V rms to 240 V rms (115V nominal) • For independent DC power. The actual sampling frequency is based on whether 50 Hz or 60 Hz1 power systems are being measured. The meter engine samples the input voltages and current 66 to 88 times per cycle. These individual phase quantities are summed. The A1800 ALPHA meter may be ordered with an auxiliary power supply. The output from the power supply is then fed to a low voltage linear regulator to attain the low level voltage. phase angle. Product description . the meter engine calculates root mean square (rms) values of voltage and current. The meter will operate properly without regard to which wire is positive and which wire is negative. This provides the ability to include the effect of harmonics up to and beyond the 33rd harmonic. Further advanced electronic techniques are used to provide extreme stability of accuracy over time and over an exceptionally wide range of operating and load conditions. Current and voltage sensing Power line currents and voltages are sensed using specialized current sensors and resistive dividers. the A1800 ALPHA meter’s auxiliary power supply is polarity independent. Power is supplied to the A1800 ALPHA meter using a wide voltage range power supply that accepts voltages from 49 V to 528 V AC. Multiplication and other calculations are performed using a custom integrated circuit (called the meter engine). from 80 V to 340 V Note: When using independent DC power. data values are available to be displayed and communicated as required by the utility or other meter user. The auxiliary power supply allows the A1800 ALPHA meter to be powered by a separate AC or DC power source. The output from the independent power supply is then fed to a low voltage linear regulator to attain the low level voltage. such as substation’s independent power lines. 1 Contact Elster Metronica for availability. providing uninterrupted power in the event that the main power becomes unavailable.Technical manual 2-7 General theory of operation The A1800 ALPHA meter’s engine receives analog inputs of voltages and current to calculate the desired metered quantities. or point on the load curve. The meter also supports a variety of communication options that allow the meter to be read remotely or manually. Individual harmonics up to and including the 15th harmonic are displayable items and are included in distortion measurements. Using these input signals. The very high sampling rate inherent in the meter engine and the additional over sampling techniques used in the A1800 ALPHA meter results in very high accuracy regardless of harmonic content. relays may be used for pulse outputs of user-selected quantities or for signaling the start of a tariff period. and the totals are transmitted to the microprocessor. Should the main power supply be unavailable. and VArh quantities for each phase. the meter will be fully operational provided the independent power is still available. Once stored. In addition. meter configuration data. The A1800 ALPHA meter is provided with either 128 KB or 256 KB of main board memory. Meter engine Multiplication and other calculations are performed using a custom integrated circuit. using the factory-programmed calibration constants. The A/D converters measure the voltage and current inputs for a given phase. See “Style number information” on page C-3 for information regarding how to identify the amount of main board memory on your meter. This ensures that a linear low level voltage is maintained. and energy measurement values. The meter engine samples the individual phase currents to provide accurate current measurement. Microcontroller The microcontroller performs many different functions. When the microcontroller detects a power failure. EEPROM The A1800 ALPHA meter uses electrically erasable programmable read only memory (EEPROM) for nonvolatile storage of manufacturing data. for example: • communicates with the DSP and EEPROM • provides for serial communication over the optical port • provides for serial communication over the remote ports • generates optical output pulses • controls the LCD • controls any option boards The microcontroller and the meter engine communicate with each other constantly to process voltage and current inputs. The DSP multiplies the signals appropriately. The meter receives each phase voltage through resistive dividers. The meter engine contains the digital signal processor (DSP) with built-in analog-to-digital (A/D) converters capable of sampling each current and voltage input. The meter engine samples the scaled inputs provided by the resistive dividers to provide accurate voltage measurements. it initiates the shutdown and stores billing and status information in EEPROM. It also serves to minimize phase shift over a wide dynamic range.Technical manual 2-8 The meter receives each phase current through a precision-wound current sensor that reduces the line current proportionally. The EEPROM provides storage of all information needed to ensure the integrity of the demand or energy calculations. including the following: • configuration data • billing data • all TOU data • log and profiling data • meter status • constants • energy usage • maximum demand • cumulative demand Product description . called the meter engine. Technical manual 2-9 Billing data Metered energy and demand quantities All A1800 ALPHA meters are capable of measuring delivered and received kWh energy and kW demand. Average power factor is calculated every second. The A1800 ALPHA meters can also measure reactive and apparent energy and demand. In the meter engine. The remaining metered quantities are calculated from 2 or more basic metered quantities. each pulse is equal to one Ke defined as one of the following: • secondary rated Wh per pulse • secondary rated varh per pulse • secondary rated VAh per pulse The following list shows the available metered quantities for the A1800 ALPHA meter.Q2) • • • • • • • • • • • • kvarh delivered (Q1 + Q2)* kvarh net kvarh Q1* kvarh Q2* kvarh Q3* kvarh Q4* kvarh received (Q3 + Q4)* kvarh sum (delivered + received)* kWh delivered* kWh net kWh received* kWh sum* Average power factor The A1800 ALPHA meter can calculate the average power factor (AvgPF) using kWh and kvarh values since the last demand reset. but the value must be evenly divisible into 60 minutes.000. The meter engine samples the voltage and current inputs and sends these measurements to the microcontroller. Metered energy and demand quantities • • • • • • • • • • • • kVAh delivered (Q1 + Q4) kVAh Q1 kVAh Q2 kVAh Q3 kVAh Q4 kVAh received (Q2 + Q3) kVAh sum (delivered + received) kvarh (Q1 . AvgPF  kWh k var h 2  kWh 2 The meter can store up to two average power calculations. the values used in this calculation are set to zero and the AvgPF will be set to 1. The A1800 ALPHA meter supports three different methods for demand calculation: • rolling interval • block interval • thermal time constant An interval is the time over which demand is calculated. Demand calculations Demand is the average value of power over a specified time interval. Basic metered quantities (indicated by * in Table 2-1) can be selected as a source for relay outputs. Product description . Table 2-1. which can be configured in Elster’s meter support software. The length of a demand interval is programmable using Elster meter support software.Q3) kvarh (Q2 + Q3)* kvarh (Q3 . Upon a demand reset. Common demand interval lengths are 15 or 30 minutes.Q4) kvarh (Q1 + Q4)* kvarh (Q2 . Figure 2-11. the A1800 ALPHA meter can be configured for a 15-minute demand interval length and a 5-minute subinterval length.25 h Block interval. The demand is calculated at the end of each subinterval. resulting in overlapping demand intervals (or a “rolling” demand).also specified in minutes and may be any value that is evenly divisible into the interval length Both of these values are configurable by Elster meter support software. Rolling demand interval is defined by two parameters: • the demand interval length . Rolling demand intervals 15-minute interval 15-minute interval 15-minute interval subinterval 0 subinterval 5 subinterval subinterval 10 15 Time (minutes) subinterval 20 25 The rolling interval calculates demand by using the following equation: D total accumulated energy t hours For example. then the demand is 200 kW. the demand is calculated every 5 minutes based on the 3 previous subintervals (see Figure 2-10).Technical manual 2-10 Product description Rolling interval. In this case.specified in minutes and may be any value that is evenly divisible into 60 • subinterval length . Figure 2-10. Block demand intervals 0 interval interval interval interval subinterval subinterval subinterval subinterval 15 30 45 Time (minutes) 60 . if the demand interval is 15 minutes and the total accumulated energy is 50 kWh. D 50 kWh  200 kW 0. Block demand interval is a special case of rolling interval demand in which the subinterval is the same size as the interval (see Figure 2-11). For example. Technical manual 2-11 Thermal time constant. The A1800 ALPHA meter can perform thermal demand emulation. The meter calculates demand based on a logarithmic scale that accurately emulates thermal demand meters. The thermal demand time constants vary depending upon the operational mode of the meter. • Normal mode time constant is 15 minutes. • Test mode time constant is 1 minute. See “Operating modes” on page 3-7 for more information. Maximum demand Maximum demand (also referred to as indicating or peak demand) is the highest demand value that occurs in a billing period. The demand for each demand interval is calculated and compared to an earlier maximum demand value. If the new interval demand exceeds the previous maximum demand, then the new demand is stored as the maximum demand (see Figure 2-12). When a demand reset occurs, the maximum demand is reset to zero. The demand for the first full interval after a demand reset becomes the maximum demand. Figure 2-12. Maximum demand New maximum Earlier maximum demand (9.9 kW) demand (9.9 kW) Earlier maximum demand (9.7 kW) Interval 6 demand (9.2 kW) Interval 7 demand (9.9 kW) Interval 8 demand (9.5 kW) In addition to maximum demand, the A1800 ALPHA meter also stores either the cumulative or continuous cumulative demand. A1800 ALPHA meters can be programmed to trigger the recording of a coincident demand or power factor (see “Coincident demand or power factor” on page 2-12). Cumulative maximum demand Using cumulative maximum demand, a demand reset adds the current maximum demand value to the cumulative maximum demand. This feature is used to calculate the previous maximum demand when the demand may have had an unauthorized reset. Since the cumulative demand is not reset to zero, unauthorized demand resets do not cause a loss of the maximum demand data. To determine the maximum demand for a billing period after a demand reset, subtract the previous cumulative demand from the current cumulative demand. Continuous cumulative maximum demand Continuous cumulative maximum demand works similarly to cumulative maximum demand. Continuous cumulative demand, however, is always equal to the sum of the previous billing period continuous cumulative demand and the current maximum demand. This feature is used to calculate the previous maximum demand when the demand may have had an unauthorized reset. Product description Technical manual 2-12 Coincident demand or power factor The number of coincident values that may be captured by the A1800 ALPHA meter depends on whether or not the 4-quadrant metering (“-A” suffix) option is present. • A1800 ALPHA meters without 4-quadrant metering record 2 coincident values. • A1800 ALPHA meters with 4-quadrant metering record up to 4 coincident values. Coincident demand refers to a demand value that occurs at the same time as another demand reaches its peak value. For example, an electric utility may want to record the kvar demand at the time of a maximum kW demand. This requires that kvar demand be stored and reported during the same interval as the maximum kW demand. Similarly, coincident power factor refers to a power factor that occurs at the same time as a demand value reaches its peak value. For example, an electric utility may want to record the power factor at the time of a maximum kvar demand. This requires the power factor be stored and reported during the same interval as the maximum kvar demand. Coincident PF  kWh kvarh 2  kWh 2 Demand forgiveness Demand forgiveness is the time during which demand is not calculated or stored after a qualified power outage. Demand forgiveness has two programmable settings: • outage time: the number of minutes a power outage must last to qualify for demand forgiveness (0 to 15 minutes) • time: the number of minutes that demand is not calculated or stored (0 to 255 minutes) following a qualified power outage; zero disables demand forgiveness Primary and secondary metering The A1800 ALPHA meter can be programmed for either primary or secondary metering. When configured for primary metering, the A1800 ALPHA meter internally converts the measured energy, demand and instrumentation quantities to primary units using the voltage transformer ratio and the current transformer ratio. These ratios are programmed using Elster meter support software. The metered quantities reflect energy, demand and instrumentation on the primary side of the instrument transformers. When configured for secondary metering, the A1800 ALPHA meter does not use the voltage transformer ratio or the current transformer ratio to adjust the metered quantities. The metered quantities reflect the energy, demand and instrumentation on the secondary side of the instrument transformers even if the voltage and current ratios are programmed into the meter. TOU data All A1800 ALPHA meters store the total (single-rate) data for energy and demand. TOU meters can store the total data and the data for up to 4 rates. TOU rates can be based on any combination of day (up to 4 day types), time (up to 132 switch times), or season (up to 12 seasons). The switch points for energy and demand may be configured independently of each other. All selected metered quantities are stored according to the TOU rate. The meter stores the energy, demand, and average power factor for each rate. Product description Technical manual 2-13 Product description Power failure data The A1800 ALPHA meter monitors and records the total power failure data. The following information is recorded: • cumulative number of minutes of all power failures • start date and time of the most recent power failure • end date and time of the most recent power failure These values can be programmed to display on the LCD. See Appendix B, “Display table,” for more information about displayable items. See “Event log” on page 2-14 for information on loss of phase voltage. Logs and data sets All A1800 ALPHA meters are equipped with EEPROM. As shown in Figure 2-13, a small portion of this main board memory is permanently reserved (called “reserved memory”) by the meter to store the main billing and configuration information. The remainder of the memory (called “shared memory”) is used to store the following logs and data sets: • event log • history log • self reads • load profiling • instrumentation profiling • TRueQ log • voltage sag log All of the logs and data sets share the meter’s memory. Using Elster meter support software, the sizes of each log or data set can be configured to allow more room for a different log or data set. For example, self reads can be configured to store less data so that the load profiling can store more data. Figure 2-13. Allocation of meter memory Main circuit board memory (128 KB or 256 KB) Billing data, Configuration data, Manufacturing info, etc. Reserved memory** Event, History, TRueQ, Voltage sag Extended memory option board (1 MB) Self read, LP,* IP* IP,* LP* Shared memory Notes *Extended memory used only when requested number of days exceeds the capacity of main board memory. If meter support software is set to maximize data storage, then the extended memory option board would always be used for LP and IP data storage. **Size of reserved memory is fixed and may vary with each firmware release. data. extended memory can be used to add shared memory to the A1800 ALPHA meter. In some cases (for example. When the data storage cannot be met with the 256 KB main memory option. Events that can be included in the event log are as follows: • power fail start and stop (2 event log entries) • date and time change information (2 event log entries) • date and time of demand resets (1 event log entry) • date and time of event log reset (1 event log entry) • date and time of test mode activity (2 event log entries) • start and stop time when the current TOU rate is overridden by the alternate TOU rate schedule (2 event log entries) • start and stop time of per phase outage (2 event log entries) • date and time of terminal cover removal (1 event log entry) • date and time of main cover removal (1 event log entry) Note: The meter will detect and log the removal of either the terminal cover or main cover even when the meter is not powered (provided the TOU battery is functioning). The A1800 ALPHA meter stores the date and time that events occur. Event log All A1800 ALPHA meters have an event log.Technical manual 2-14 In most cases. After the maximum number of entries has been stored. more memory may be required. This data can be retrieved later for analysis or billing. maintaining a history of programming changes made to the meter. The history log can be disabled through Elster meter support software. Product description . The A1800 ALPHA meter can store up to 35 self reads can be stored depending on memory requirements for logs. the meter will begin overwriting the oldest entries. If the meter has recorded the maximum number of self reads. The previous billing data copy stores only one copy of billing data at a time and only when a demand reset occurs. After the maximum number of entries has been stored. The event log can be disabled through Elster meter support software. See “Demand reset data area” on page 3-10 for more information. The A1800 ALPHA meter records a sequential listing of records. History log All A1800 ALPHA meters have a history log that stores table information and procedure ID for configuration-altering writes to the meter. A self read captures the current period billing data and stores it in memory. along with the date and time. Self reads All A1800 ALPHA meters can support self reads. the meter will begin overwriting the oldest entries. if extensive instrumentation profiling is desired). the next self read will overwrite the oldest copy. The meter records this information as an audit trail. the 128 KB or 256 KB option is sufficient to meet data logging and profiling requirements. Elster meter support software is used to define and program the number of event log entries that the meter will record. Self reads are events that can be triggered by any of the following: • scheduled calendar events • every demand reset • communication procedure Self reads are different from previous billing data copies. etc. Q2) • • • • • • • • • • • • kvarh delivered (Q1 + Q2) kvarh net kvarh Q1 kvarh Q2 kvarh Q3 kvarh Q4 kvarh received (Q3 + Q4) kvarh sum kWh delivered kWh net kWh received kWh sum Load profiling has its own. and 4 coincident values The first number shows the number of days of load profiling.Technical manual 2-15 Product description Load profiling For meters with load profiling capabilities (designated with an “-L” suffix). Data in Table 2-3 are based on the following settings: • load profiling at 15-minute intervals • no instrumentation profiling • the meter is programmed for 6 metered quantities. assuming all other logs and self reads record the maximum number of entries.767 pulses before overflowing). The length of the load profiling interval must adhere to the following rules: • the length must be between 1 and 60 minutes • the time must be evenly divisible into an 60 minutes Table 2-3 show the number of days of load profiling available. Table 2-3. Load profiling pulse divisor.) Number of channels 1 2 3 4 5 6 7 8 128 KB 199/320 106/171 81/130 60/96 51/81 41/66 37/59 32/51 256 KB 594/714 317/381 242/291 178/214 151/182 124/149 110/133 95/114 1 MB 3177 1696 1294 954 812 664 592 509 Note: The actual number of days stores varies based on meter firmware release and other options programmed using Elster meter support software. 2 average power factors. Table 2-2. These values are estimates and may vary depending on the firmware used in the meter. This allows recording of data that may exceed the maximum number of pulses that can be stored in each load profiling interval (each interval can store 32. See the documentation for the meter support software for more information regarding memory allocation. A pulse divisor is used to scale down the number of pulses recorded in each load profiling interval. Load profiling sources • • • • • • • • • • • • kVAh delivered (Q1 + Q4) kVAh Q1 kVAh Q2 kVAh Q3 kVAh Q4 kVAh received (Q2 + Q3) kVAh sum kvarh (Q1 . The range for the value of the load profiling pulse divisor is 1 (default) to 255. . assuming all other logs and self reads record the minimum number of entries.Q4) kvarh (Q1 + Q4) kvarh (Q2 . the A1800 ALPHA meter is capable of recording 8 channels of information. Estimated days of load profiling storage per number of channels Days of storage (max./ min.Q3) kvarh (Q2 + Q3) kvarh (Q3 . The second number shows the number of days of load profiling. separate interval length that is configured independently from the demand interval length. Technical manual 2-16 Product description Instrumentation profiling In meters with instrumentation profiling, the meter has two sets of instrumentation profiling. Each set can record up to 16 channels from the sources listed in Table 2-4. Also, instrumentation profiling can use the sources listed in Table 2-2 for more extensive load profiling. Table 2-4. Instrumentation profiling sources • • • • • • • • • • • • • • frequency per phase current per phase voltage per phase watts per phase VA per phase voltage angle with respect to line 1 voltage per phase fundamental (1st harmonic) current magnitude per phase fundamental (1st harmonic) voltage magnitude per phase 2nd harmonic current magnitude per phase 2nd harmonic voltage magnitude per phase voltage % total harmonic distortion (THD) per phase current % THD per phase harmonic current (sum of 2nd through 15th) per phase current angle with respect to line 1 voltage • • • • • • • • • • • • • • per phase vars (vectorial) per phase 2nd harmonic voltage % per phase total demand distortion (TDD) per phase PF per phase PF angle system watts system VA (arithmetic) system PF (arithmetic) system PF angle (arithmetic) system vars (vectorial) system VA (vectorial) system var (arithmetic) system PF (vectorial) system PF angle (vectorial) Technical manual 2-17 Each channel can be configured to record the instrumentation profiling using any one of following four algorithms (see Table 2-5): Table 2-5. Instrumentation profiling recording algorithms Item Description Minimum The meter samples the selected quantity over the instrumentation interval. The minimum value of all the samples is recorded. Maximum The meter samples the selected quantity over the instrumentation interval. The maximum value of all the samples is recorded. Average The meter samples the selected quantity over the instrumentation interval. The average value of all the samples is recorded. End The meter samples the selected quantity over the instrumentation interval. The last value of all the samples is recorded. Each set of instrumentation profiling has its own, separate interval length that is configured independently from the demand interval length. The length of the instrumentation profiling interval must adhere to the following rules: • the length must be between 1 and 60 minutes • the time must be evenly divisible into an 60 minutes TRueQ Log The A1800 ALPHA meter has a TRueQ log that records TRueQ test failures. Elster meter support software is used to define and program the number of TRueQ log entries that the meter will record. Elster meter support software is also used to define which tests can record failures in the TRueQ log. The A1800 ALPHA meter can record the following data associated with the TRueQ test: • the date and time when the TRueQ monitor first detects a qualified failure and the identifier of the TRueQ test (1 TRueQ log entry) • the date and time when the TRueQ monitor no longer detects a failure and the identifier of the TRueQ test (1 TRueQ log entry) Note: See “TRueQ event counters and timers” on page 4-15 for information on qualification time For each TRueQ log entry, the meter also records an instrumentation measurement related to the TRueQ test. When the maximum number of entries has been stored, the meter will begin overwriting the oldest entries. See “TRueQ monitoring” on page 4-12 for more information. Voltage sag log The meter has a voltage sag log. The A1800 ALPHA meter records the date, time, and phases of any detected voltage sag. The log records a maximum of 1 entry per second. When the maximum number of entries has been stored, the meter will begin overwriting the oldest entries. See “Voltage sags” on page 4-13 for more information. User-defined tables User defined tables offer specific data retrieval options for A1800 ALPHA meters. User defined table configuration may be requested at the time of purchase, and the specific configuration may be programmed at the factory. An AMR system can then be configured to retrieve the user defined table information from the meter instead of individual table reads. This reduces the total communications time. Product description Technical manual 2-18 Product description Physical dimensions and mass The approximate dimensions of the meter correspond to DIN 43-857 part 2 (excluding the meter hanger). See the following figures for illustrations of the meter and its dimensions. Figure 2-14. A1800 ALPHA meter, standard terminal cover 89 22 204 224* 307 *This represents hanger in center position. 150 5 Approximate dimensions in millimeters 170 Figure 2-15. A1800 ALPHA meter, short terminal cover1 89 22* 213* 224* 240 *This represents hanger in center position 150 170 1 Contact Elster Metronica for availability. 5 Approximate dimensions in millimeters bottom view (direct connect1 and transformer rated) 170 170 6.6 kilograms 1.2 5. A1800 ALPHA meter. back of meter 202 150 Approximate dimensions in millimeters.Technical manual 2-19 Product description Figure 2-16.3 kilograms 3-element 1.3 kilograms 1 Contact Elster Metronica for availability. Table 2-6. A1800 ALPHA meter.7 kilograms 1.4 Ø 10 Direct connect meter Transformer rated meter Approximate dimensions in millimeters. Figure 2-17. . Approximate mass Elements Direct connect Transformer rated 2-element 1. Technical manual 2-20 Product description . 5 + Q -P 7 +P . the LCD is divided into different display regions.5 5 Approximate dimensions in millimeters 2 Viewing area As shown in Figure 3-2.Q L1L2 L3 COM 0 1 2 Alternate mode indicator Display quantity Comm.Technical manual Technical manual 3-1 Operating instructions 3 Operating instructions Indicators and controls LCD The liquid crystal display (LCD) is used to display meter data and status information. port indicator Power/energy units identifier Tariff indicators 1 to 8 (left to right) EOI indicator LC indicator Test mode indicator Cover removed indicator 32 . Figure 3-2. Figure 3-1 shows the dimensions of the LCD. LCD dimensions 85 77 1.Q 27 9. Figure 3-1.4 3. LCD regions Low battery indicator Phase indicators (3) Error/warning indicator Quantity identifier + Q Energy direction indicator -P +P . “Display table. Quantity identifier. The energy direction indicators display the quadrant and direction of the last Wh (active) and varh (reactive) energy flow. then that expected line voltage is either missing or below the defined threshold for voltage sag detection. The displayable digits are definable using Elster meter support software for both energy and demand readings. The state of the indicators correspond to the following: • If the indicators are on.Technical manual 3-2 Operating instructions All A1800 ALPHA meters have a backlight option for the LCD. Line 2. L2. and L3) corresponds to a line voltage (Line 1. See “Using the backlight” on page 3-6 for more information. This 7-digit region identifies the displayed quantity as defined and programmed with Elster meter support software. then all expected line voltages are present. numeric values may be replaced by or mixed with alphabetic characters to better define the value. Each phase indicator (L1. The backlight option must be specified at the time of ordering. • If an indicator is off. respectively) present on the A1800 ALPHA meter connections. the line is not expected for the configured meter type. and Line 3. Energy direction indicators Positive reactive energy Reverse active energy Positive active energy Reverse reactive energy . Figure 3-3 shows the meaning of each energy direction indicator. COM 1. See Appendix B. The LCD can be illuminated by pressing one of the push buttons. Energy direction indicators. This 8-digit display on the LCD shows either metered quantities or other displayable information. An identifier can be assigned to most display quantities in the display sequence. COM 2) For instrumentation values and tests. From 3 to 8 digits with up to 4 decimal places can be used.” for more information. The energy direction indicators turn on to display energy flow direction when any of the meter phases are measuring energy flow (that is. Display quantity.” for more information. while reverse energy flow is energy received from the consumer load. Figure 3-3. Positive energy flow is energy delivered to the consumer load. or E3) • system instrumentation and service test errors (SE) • warnings (W1 or W2) • communication codes (COM 0. These digits are also used to report error codes for the following error conditions: • operational errors (E1. making it easier to read the LCD in no-light or low-light conditions. See Appendix B. • If an indicator is blinking. See “Voltage sags”for more details on momentary voltage sag detection and the phase indicators. when one of the line currents is above the meter starting threshold). depending upon how the A1800 ALPHA meter has been programmed. Phase indicators. “Display table. E2. the corresponding indicator (T1) turns on. The –P indicator is inoperative for this meter configuration (see “Always Positive” on page 2-13 for more information). EOI indicator. Operating instructions .Technical manual 3-3 On meters with the Always Positive option. the quantity will be identified either using the quantity identifier or appending the unit to the display quantity. Alternate display indicator. Note: The manufacturer’s nameplate details the meaning of the display indicators. In some cases. the tariff indicator flashes. Note: The active tariff indicators also turns on during the LCD all-segments test. If the quantity’s tariff is active at the time. the low battery warning display item (if included in the display list) also is displayed. Port codes Code Port COM 0 Optical port COM 1 Remote port 1 COM 2 Remote port 2 See “Communication codes” on page 6-8 for additional details. The low battery indicator is turned on when the TOU battery voltage is low or when the TOU battery is missing. The error indicator flashes when any error condition is present or remains on if a warning condition is present. “Nameplate and style number information. the EOI indicator will be turned on and remain on until the end of the interval. Error indicator. This indicator (*) displays when the A1800 ALPHA meter is operating in alternate mode. tariff 1 total kWh). See “Operating modes” on page 3-7 for more information on the different operating modes. T3. The end-of-interval (EOI) indicator is used to verify the timing of the demand interval. it may not be possible to represent the displayed quantity using the power/energy units identifier. This indicator also displays during the all segment test of the LCD. T2. then the power/energy units identifier will not be used. The 12 display indicators () are used to more precisely identify the information displayed on the meter’s LCD. The power/energy units identifier is used to indicate the unit of measurement for the quantity displayed on the meter’s LCD. Low battery indicator. Note: This indicator also turns on during the LCD all-segments test.” Tariff indicators. Display indicators. Table 3-1. See “System service error codes” on page 4-10 and “Codes and warnings” on page 6-2 for details. Note: This indicator also turns on during the LCD all-segments test. The active COM port indicator indicates that a communication session is in progress and which COM port is being used. When the error indicator is on. See Appendix C. Active COM port indicator. The tariff indicators (T1. Ten seconds before the end of the demand interval. Power/energy units identifier. If this is the case. Instead. Additionally. the +P indicator is on continuously whenever kWh flow of any direction is detected. If the displayed quantity is a TOU item (for example. the LCD will also display the appropriate error or warning code. Note: These identifiers may be shown individually or in combination to describe a particular displayed quantity. and T4) indicate the current tariff. Operating instructions . See “Cover tamper detection switches” on page 2-5 for additional information. After the seal is broken. as shown in Table 3-2. The RESET button performs differently depending on the A1800 ALPHA operating mode. The loss compensation (LC) indicator indicates the meter is currently compensating for transformer and line loss. the EOI indicator turns on for 10 seconds before the end of each subinterval. Push buttons The following push buttons are located on the front of the A1800 ALPHA meter: • RESET (sealable) • * (ALT) If sealed. the RESET button is only accessible after breaking the seal. Test mode indicator. Transformer and line loss compensation indicator. The cover tamper (TC) indicator indicates that either the terminal cover or the meter cover is removed. Pressing the RESET button performs a demand reset (see “Demand reset” on page 3-9 for a description on what happens during a demand reset). Figure 3-4. The test (TST) mode indicator indicates that the meter is currently operating in test mode. This may indicate that tampering has occurred on the meter. Cover tamper indicator.Technical manual 3-4 For rolling demand. The TC indicator turns off when all the covers are in place. See “Test mode” on page 3-8 for details. it may be necessary to break the seal that locks the RESET button in the inactive position. A1800 ALPHA meter push buttons * (ALT) button RESET button (sealable) RESET button. the button is always accessible. To activate the RESET button. rotate the push button 90 ° in either direction and press the push button (see Figure 3-5). Pressing the RESET button will accept and lock the detected service when the service test lock mode has been set to manual and the system service voltage test has just been performed by the A1800 ALPHA meter. therefore the * button can be used to illuminate the display. Note: All the A1800 ALPHA meter have the backlight display option. The * button performs differently depending on the operating mode. See “Manual lock” on page 4-6 for more details. * button. RESET button positions Inactive position RESET button cannot be pressed Active position RESET button can be pressed Using to lock service. RESET button behavior Mode Description Normal Performs a demand reset Alternate Returns to normal mode and performs a demand reset Test Resets test value and remains in test mode To seal the RESET button. See “Using the backlight” on page 3-6 for more information. Pressing the button normally initiates the alternate mode (see “Operating modes” on page 3-7 for more information about the A1800 ALPHA operating modes). rotate the RESET button 90 ° back to the inactive position and apply the seal. as shown in Table 3-3.Technical manual 3-5 Table 3-2. Operating instructions . Using the RESET button to lock the service will not perform a demand reset unless it is pressed a second time. Figure 3-5. Continuous Scrolls quickly through the test mode display list while pressed. locks LCD on a display quantity when released. locks LCD on a display quantity when released. and the RESET and * buttons will operate as specified in Table 3-2 and Table 3-3. Press and release If the LCD is locked on a display quantity. the push buttons will operate as follows: • The RESET button operates as specified in Table 3-2. Pressing either the * button or the RESET button restarts the process. use the following process (see Figure 3-6): 1. LCD displays one cycle of the alternate display list. • The * button operates as specified in Table 3-3. the LCD backlight will always be illuminated. While the LCD is illuminated. respectively. The A1800 ALPHA meter can be ordered with the backlight always turned on. Alternate Continuous Scrolls quickly through the alternate display list while pressed. 2. * button function in different operating modes Mode Press method Description Normal Less than 1 second Enters alternate mode. With this option. 3. Once the backlight is turned on. Press either the * button or the RESET button. beginning with step 1. The backlight will turn off at the end of the illumination time. each press steps to the next quantity in the test display list. The backlight turns on for the specified illumination time. To illuminate the LCD. each press steps to the next quantity in the alternate display list. All the A1800 ALPHA meter have the backlight for the LCD. the LCD will be illuminated for two minutes.Technical manual 3-6 Operating instructions Table 3-3. Test Using the backlight. Press and release If the LCD is locked on a display quantity. and returns to normal mode. . The meter is fully operational in this mode. however. If the self test indicates an error. the meter performs self tests to make sure it is operating normally. Normal mode Normal mode is the default operation mode for the A1800 ALPHA meter. It is generally used to display billing data on the LCD. RESET No Has time expired? No Yes Operating modes The A1800 ALPHA meter operates in one of the following modes: • normal mode • alternate mode • test mode As part of its function. The LCD test will always appear immediately after power is connected to the A1800 ALPHA meter or after a power restoration from an outage. . the meter can be programmed to “lock” the error code on the display. Using the backlight on the A1800 ALPHA meter LCD (default operating mode) Backlight off Any button is pressed Backlight on Enter alternate mode Yes. See “Meter self test” on page 6-1 for more information on self tests and errors. and it will process and store data while the LCD scrolls through the normal display list quantities. The self test ensures that the A1800 ALPHA meter is functioning properly and that its displayed quantities are accurate. the LCD displays the error indicator. In addition. The meter attempts to function normally. the meter data may be suspect.Technical manual 3-7 Operating instructions Figure 3-6. * Perform demand reset Button pressed while LCD lit? Yes. While in test mode. Alternate mode is most often used for displaying non-billing data. the meter returns to normal mode. when power is restored. the test mode indicator (TST) will flash on the meter’s LCD. errors. the optical port transmits test pulses proportional to metered energy (see “LED pulse outputs” on page 5-6). the normal mode display cycle begins with an LCD test which turns on all of the display segments. and warnings) before the meter entered test mode is restored. the meter exits alternate mode after 2 minutes of inactivity. readings taken during test mode will be discarded and present energy usage and billing data values will be restored. Test mode The A1800 ALPHA meter enters test mode by a command through the optical port. the meter exits alternate mode after the last item is displayed. the meter's display is in normal mode. There are several different ways to exit alternate mode. The normal display cycle will scroll through all programmed display quantities before beginning the cycle again. Power failure occurs Exits alternate mode.Technical manual 3-8 Typically. While in normal mode. the LEDs transmit pulses (see “LED pulse outputs” on page 5-6). the LEDs transmit pulses proportional to metered energy. This is recommended because it provides a quick way to determine if the LCD is functioning properly. The status of the meter (including billing data. the meter will exit the alternate mode at midnight. When normal mode is resumed. Shorter demand intervals may be used in test mode to reduce demand test time and will not interfere with billing data. The meter is fully operational while in alternate mode. See “LED pulse outputs” on page 5-6 for details on the LEDs. The LCD test can be disabled using Elster meter support software. While in alternate mode. the alternate display indicator is turned on. profiling data. While in test mode. Press the RESET button Exits alternate mode and performs a demand reset. Operating instructions . At midnight Exits alternate mode at the next midnight crossing. Test mode displays test readings without affecting the present energy usage and billing data values in the A1800 ALPHA meter. This mode is activated in one of the following ways: • pressing the * button on the A1800 ALPHA meter • after power up for one cycle of the alternate display list Note: This feature can be disabled using Elster’s meter support software. Alternate mode Alternate mode can be programmed with Elster meter support software to display a second set of quantities on the LCD. Whenever exiting the alternate mode. Additionally. If the LCD remains on a pulse line cumulative counter. Table 3-4. Exiting alternate mode Method Description Wait for the end of the alternate display list If the meter is scrolling through the alternate display list automatically. Wait for the timeout If the LCD remains on a quantity. but it can be programmed to display any of the available quantities. Exiting test mode Method Description Test mode expires Automatically after a programmable timeout has expired (between 1 and 255 test mode intervals) Send an exit command Using Elster meter support software. the meter performs many different functions. the meter's display is in normal mode. or calendar) • if configured. Automatically after 24 hours Automatically after a programmable timeout (1-255 test mode intervals). and then the billing data’s present maximum demand is reset to zero • the billing data’s dates and times of the maximum demands are reset to zero • the billing data’s present coincident values are reset to zero • all demand calculations are reset to zero and a new demand interval is started • previous interval demands are reset to zero • present interval demands are reset to zero • all average power factor calculations are restarted • pulse line cumulative counters are cleared • current conditions for certain errors or warnings are cleared As a security feature. Demand reset A demand reset can be performed one of three ways: • pressing the RESET button • issuing a command over the optical or remote ports • as a scheduled calendar event Regardless of how the demand was reset. procedure. when power is restored.Technical manual 3-9 Test mode is entered using Elster meter support software. the event log records every demand reset Operating instructions . the meter records these values: • the cumulative number of demand resets (rolls over to zero after 255) • the cumulative number of manual demand resets (pressing the RESET button or issuing a command) • date and time of last demand reset • number of days since the last demand reset • the method of the most recent demand reset (for example. Power failure occurs Exits test mode. The meter exits test mode under any of the following conditions: Table 3-5. button press. send an exit command over the optical port. including the following: • the present billing data is copied to the demand reset data area • the billing data’s present maximum demand is added to the cumulative demand. This data is referred to as the previous billing data because its general purpose is to preserve the data as one billing period ends and the next billing period begins. which can store multiple copies of the billing data. If a power failure occurs during the demand reset lockout period. During the demand reset lockout. the meter copies the present billing data and stores it in the demand reset data area. subsequent demand resets will be ignored by the meter. Operating instructions . See “Self reads” on page 2-15 for more information.Technical manual 3-10 Demand reset lockout Through Elster meter support software. Demand reset data area In all demand reset occurrences. The meter stores only one copy of the previous billing data. accidental or tamper-related demand reset presses). the lockout is released upon power restoration. Previous billing data is different from self reads. a demand reset lockout time can be defined. The next demand reset overwrites whatever is currently stored as the previous billing data. The demand reset lockout can remain in effect for up to 255 minutes after a demand reset (regardless of the method of demand reset). This prevents subsequent demand resets (for example. The quantities that are indicated by a footnote are updated about every second. while billing quantities represent a combination of all present phases.Technical manual Technical manual 4-1 Meter tools 4 Meter tools System instrumentation System instrumentation is a collection of displayable items designed to assist in evaluating a service by providing real time analysis of the conditions present at the A1800 ALPHA installation. Most instrumentation quantities are true root mean square (rms) measurements over an even number of line cycles. or test mode display sequences. Instrumentation quantities can also round or restrict the quantity to a desirable value under certain system conditions.kW 2 The result is then signed based on the kvar direction. Description of system instrumentation quantities Instrumentation quantity Description Frequency1 Measured on line 1 voltage. Compound quantities require multiple measurements at slightly different times with the results calculated from these multiple measurements. System kvar (vectorial) Sum of the per phase kvar (vectorial) . and this is to be expected. Table 4-1. The alternate mode display sequence is recommended because it is generally not necessary for these quantities to be displayed at all times. instrumentation quantities may be placed in normal. Instrumentation quantities are generally provided on a per phase basis. but others are compound quantities. Using Elster meter support software. Instrumentation quantities should not be confused with billing quantities because they are intended for an entirely different purpose. The instrumentation measurements are near instantaneous. See Table 4-1 for more information about how the instrumentation quantities are obtained. the remaining quantities are updated about every 5 seconds.(system kW) 2 System power factor (arithmetic) System kW divided by system kVA (arithmetic) System power factor angle (arithmetic) The arccosine of system power factor (arithmetic) 1 Measured directly by meter engine Phase kW and kVA 1 Phase kvar (vectorial) Calculated using the following equation (where kVA and kW are measured simultaneously): kvar  kVA 2 . System instrumentation quantities are measured instantaneously while billing quantities are measured and averaged over a number of minutes. This can result in discrepancies between similar billing and instrumentation data. System kW The signed sum of the kW measurement on each phase taken only moments apart System kVA (arithmetic) The signed sum of the kVA measurement on each phase taken only moments apart System kvar (arithmetic) Calculated using the following equation: kvar  (system kVAarith ) 2 . alternate. In other words: THC  i 15  HCi 2 i 2 where HCi = ith harmonic current Phase total harmonic distortion percentage (voltage or current) Calculated by using: THD  rms 2 . .00 if phase current is less than the absolute minimum current (twice starting amps). both measured simultaneously.15th harmonic currents squared.fundamental 2 fundamental  100 where: rms represents an unfiltered rms phase voltage or current fundamental represents the fundamental rms phase voltage or current Per phase total demand distortion Calculated by using: i 15  HCi TDD  2 i2 Maximum amps where HCi represents the ith harmonic current. the square root of the sum of the 2nd . 1 Updated about every 1 second. Phase power factor angle1 The power factor angle is the arccosine of the phase power factor Phase 1st harmonic (fundamental) voltage magnitude The per phase magnitude of the fundamental voltage Phase 1st harmonic (fundamental) current magnitude The per phase magnitude of the fundamental current Phase 2nd harmonic voltage magnitude The per phase magnitude of the 2nd harmonic voltage Phase 2nd harmonic current magnitude The per phase magnitude of the 2nd harmonic current Phase 2nd harmonic voltage percentage Per phase.Technical manual 4-2 Meter tools Table 4-1. the 2nd harmonic voltage magnitude divided by the fundamental voltage magnitude Phase total harmonic current magnitude Per phase. Phase power factor is set to 1. Description of system instrumentation quantities Instrumentation quantity System kVA (vectorial) Description Calculated using the following equation: kVAvect  system kW 2  (system kvarvect ) 2 System power factor (vectorial) System kW divided by system kVA (vectorial) System power factor angle (vectorial) The arccosine of system power factor (vectorial) Phase voltages and currents1 True rms values measured by meter engine Phase voltage angle relative to line 1 voltage1 Each voltage angle is measured relative to line 1 voltage zero crossings and rounded to 30° Phase current angle relative to line 1 voltage Each current angle is measured relative to line 1 voltage zero crossings Phase power factor Phase kW divided by phase kVA. Technical manual 4-3 Voltage. System instrumentation quantity identifiers Quantity identifier Description L123 System instrumentation measurements L1 Line 1 measurements L2 Line 2 measurements L3 Line 3 measurements L1 H2-15 Line 1 total harmonic distortion L2 H2-15 Line 2 total harmonic distortion L3 H2-15 Line 3 total harmonic distortion L1 H1 Line 1 1st harmonic L2 H2 Line 2 1st harmonic L3 H2 Line 3 1st harmonic L1 H2 Line 1 2nd harmonic L2 H2 Line 2 2nd harmonic L3 H2 Line 3 2nd harmonic L1 TDD Line 1 total demand distortion L2 TDD Line 2 total demand distortion L3 TDD Line 3 total demand distortion The display quantity will show a measurement and a unit of measure on the A1800 ALPHA meter LCD. See Figure 4-1 and Figure 4-2 for examples showing system instrumentation quantities. as indicated in Table 4-2. See “* button” on page 3-5 for more information on locking the LCD on a desired quantity.25 %. Instrumentation line 1 voltage +P L1 L2 L3 Meter tools . Figure 4-1. If the LCD remains on an instrumentation quantity while in alternate or test mode. current. and kVA instrumentation quantities have an error of less than ±0.” for information about displayable items. Accuracy will diminish as the value of the quantity becomes smaller. The meter’s LCD can be programmed with Elster’s meter support software to display primary instrumentation values. Table 4-2. “Display table. The quantity identifier gives information about the quantity being displayed on the A1800 ALPHA meter LCD. kW. kvar. See Appendix B. the displayed instrumentation quantity updates once per second. the meter begins to measure that quantity. then that display quantity will be skipped automatically.Technical manual 4-4 Figure 4-2. Instrumentation line 2 current in progress +P L1 L2 L3 Figure 4-4. Instrumentation line 2 current measurement (primary) +P L1 L2 L3 If an A1800 ALPHA meter is programmed to display a system measurement quantity for a phase that does not exist (for example. Figure 4-3. Meter tools . If the result of the instrumentation measurement is not immediately available. This allows different meter types to be programmed with similar configurations using Elster meter support software. Line 2 on a two-element meter). Instrumentation system kVA +P L1 L2 L3 Immediately before displaying a system instrumentation quantity. dashes (-) will be shown in the display quantity until the measurement is complete. Instrumentation line 2 current measurement (secondary) +P L1 L2 L3 Figure 4-5. See Figure 4-3 and Figure 4-4 for examples of system instrumentation display quantities while the measurement is in progress and when a result is available. Service voltage test The service voltage test is intended to assist in identifying the following: • incorrectly wired or misapplied voltage transformers • open or missing line fuses The following are validated by this test: • phase voltages • phase voltage angles • phase rotation The meter measures each phase voltage and phase voltage angle and attempts to match the measurements to a stored list of valid services. See “System service error codes” on page 410 for more information about system service error codes. • If the test is not successful. • If the service voltage test is successful. the LCD displays the following (an example is shown in Figure 4-6): • phase rotation (for example. the validated service is shown on the meter’s LCD and the meter will continue to the next display quantity in the sequence. for example: • 1L is a single phase service • 3 is a 3-wire delta service • 4Y is a 4-wire wye service Meter tools . The following conditions can cause the service voltage test to fail: • phase voltage angles not within ±15° of the expected service phase angles • phase voltage magnitudes not within the tolerance of the nominal service voltages programmed into the meter with Elster meter support software System service locking. the LCD will indicate a service error by displaying SE plus a code on the LCD. 120 or 240) • service type showing the number of wires and the service type. it can be locked into the A1800 ALPHA meter memory. A locked valid service is used as a basis for future system service tests and TRueQ tests.Technical manual 4-5 System service tests System service tests can be performed to determine the validity of the electrical service that the A1800 ALPHA meter is metering. Also. The following information will be stored in the meter when the service is locked: • service type identification • nominal service voltage • voltage phase rotation • service voltage and current limits • voltage sag detection threshold The A1800 ALPHA meter can lock a valid service in either of these ways: • smart autolock • manual lock (on default) To indicate that a service voltage test is complete. a warning is set. L1-2-3 or L3-2-1) • voltage magnitude (for example. Once a service voltage test has detected a valid service. The system service tests consist of a service voltage test and a service current test. The new service type can then be detected and manually locked. When the service type has been detected. the phase rotation. Both the voltage magnitude and phase angle of the service are compared to a table of valid relationships stored within the meter memory. the smart autolocked service may lock on a different service. Sample service voltage test result +P L1 L2 L3 The voltage magnitude and service type are surrounded by brackets to indicate that the service is locked (see Figure 4-7). The A1800 ALPHA meter periodically checks the service. The identified service information will also be shown on the LCD. the A1800 ALPHA meter will attempt to lock the service automatically once it is determined to be valid. voltage magnitude. the meter responds in the following manner: • the meter remains locked on the last known valid service • the LCD displays an error code Manual lock. the LCD will alternate between L1-2-3 -----. Once manually locked. the A1800 ALPHA meter will detect and evaluate the service in the same manner as it does when autolock is enabled. To move the A1800 ALPHA meter to a new installation with a different type of service. If a valid service cannot be detected. When configured through Elster meter support software for manual lock. The meter accepts the service that most closely matches one of the stored values in the A1800 ALPHA meter. the service never unlocks automatically. however. valid service is detected. Sample display of locked service voltage +P L1 L2 L3 Smart autolock.and the detected service information until the service has been manually locked. The service voltage test will be performed and the service may be changed in response to the following events: • power up • exit of test mode • after a data-altering communication session If a new. the service must be unlocked using Elster meter support software. and the service type will be displayed on the LCD. If the RESET button is not pressed to accept the service.Technical manual 4-6 Figure 4-6. Meter tools . When smart autolock is enabled through Elster meter support software. Under certain conditions. the RESET button must be pressed in order to lock the detected service (see “Using to lock service” on page 3-5). the meter locks on the new service. This is useful because the meter may have been moved to a new service. Figure 4-7. 3 The meter attempts to match the service. the meter returns to the service test until a valid service is found and locked. The LCD displays the locked valid service. • If a valid service is not found. 1 The meter initiates the service voltage test. • If the service does not match the presently locked service. then the LCD displays the service test error. • The user presses the RESET button to lock the service. • If a valid service is found. the meter displays SE 555000. The meter restarts the service voltage test in diagnostic mode (see “Restarting the service voltage test in diagnostic mode” on page 4-9). the LCD displays SE 555000. • If the service matches the presently locked service. the button is pressed or there is a communications session). a data-altering communications session. the service voltage test is initiated at any of the following times: • after power up. When enabled. or exiting test mode • at midnight Service voltage tests can also be initiated at any of these times. the meter automatically locks on the detected service. the meter remains locked on the last valid service until a new valid service is detected. then the LCD displays the locked valid service. the LCD displays the data for the service it detected. • If a valid service cannot be found. the user can manually lock the service. The meter restarts the service voltage test in diagnostic mode (see “Restarting the service voltage test in diagnostic mode” on page 4-9).Technical manual 4-7 Meter tools Initiating service voltage tests. The LCD displays the locked service. The meter restarts the service voltage test until a valid service is found. • If a valid service is detected. the meter restarts the service voltage test after handling the interruption. If the service voltage test is interrupted (for example. • If the user does not lock the service. 2 The meter attempts to detect a valid service. However. 2 The phase indicator voltage thresholds are set at the default values. data-altering communications session. 3 The meter attempts to detect a valid service. depending on meter configuration: • as a display item • as a TRueQ test (for meters with TRueQ capabilities) The behavior of the service voltage test depends on these factors: • the event that initiates the service voltage test • the state of the service lock After power up. 1 The meter initiates the service voltage test. 4 While a valid service is displayed. The following table explains meter behavior when the service voltage test is performed after any of the following: • power is applied to the meter • data-altering communications session • exiting test mode Smart autolock Manual lock Current state is locked Manual lock Current state is unlocked 1 The meter initiates the service voltage test. 2 The phase indicator voltage threshold levels are based on the currently locked service. . or exiting test mode. Technical manual 4-8 Meter tools At midnight. the LCD continues to the next item in the display sequence. As a TRueQ test. The meter restarts the service voltage test in diagnostic mode (see “Restarting the service voltage test in diagnostic mode” on page 4-9). the service voltage test can be programmed as a displayable quantity in any display sequence. the test is not performed and the LCD displays SE 555000. 3 The meter attempts to match the service. the meter restarts the service test after handling the interruption. then the LCD displays the locked valid service. the LCD continues to the next item in the display sequence. However. the meter displays SE 555000. • If the service matches the presently locked service. If the service is locked. 3 After the LCD displays the locked valid service or the service test error. • If the service detected matches the presently locked service. . 2 The phase indicator voltage threshold levels are based on the currently locked service. The service test is initiated when the service test quantity is displayed on the LCD. • If a valid service is detected. 2 After the LCD displays the valid service or the service test error. 1 The meter initiates the service test. If the service has not been locked. then the LCD displays the locked valid service. • If a valid service cannot be found. 3 The meter attempts to match the service. If the service test is interrupted (for example. The meter restarts the service voltage test in diagnostic mode (see “Restarting the service voltage test in diagnostic mode” on page 4-9). Using Elster meter support software. the LCD displays the valid service. However. As a display item in a display sequence. • If the service matches the presently locked service. the meter checks the service at midnight. the button is pressed or there is a communications session). Smart autolock 1 The meter initiates the service test. then the LCD displays SE 555000. See “Service voltage test” on page 4-5 for more information. • If the service does not match the presently locked service. TRueQ tests are available only on meters with TRueQ capabilities. Manual lock Current state is locked The service test is performed as the autolock. the lock remains on the last valid service until a new valid service is detected. When the service voltage test is programmed as a TRueQ test. then the LCD displays a service test error. then the LCD displays a service test error. • If the service does not match the presently locked service. 2 The meter attempts to match the service. the service test is performed only if the service is locked. Service locking disabled 1 The meter initiates the service test. 2 The phase indicator voltage threshold levels are based on the currently locked service. • If the service does not match the presently locked service. the lock remains on the last valid service until a new valid service is detected. The meter always does the following when the service voltage test is run at midnight: Smart autolock Manual lock Current state is locked 1 The meter initiates the service test. then the LCD displays the locked valid service. 4. See “System service error codes” on page 4-10 for more information.Technical manual 4-9 Restarting the service voltage test in diagnostic mode. Perform service voltage test. the test restarts in diagnostic mode if the test fails. 7. The A1800 ALPHA meter uses the diagnostic mode if the service voltage test was started in these ways: • after power up. Depending on how the service voltage test was started. a warning is set. Otherwise. 10. Also. Service current test The service current test validates system currents and is intended to assist in identifying the following: • incorrectly wired or misapplied current transformers • open or missing load-side fuses If the service current test is successful. Perform the service voltage test. 2. data-altering communications session. Perform service voltage test. as listed below: 1. the meter displays the locked service on the LCD and continues to the next item in the display sequence. the cycle restarts at step 1. Display line 2 voltage. Display line 2 voltage angle. the LCD will indicate a service error by displaying SE and a code. an example of which is shown in Figure 4-9. Display line 3 voltage angle. Display line 3 voltage. See Figure 4-8 for an example of a successful service current test. 9. Perform the service voltage test. 3. 6. Display line 1 voltage. If at any point a valid service is found and locked. The meter will continue to the next item in the display sequence. 8. 5. Service current test successful completion +P L1 L2 L3 If the test is not successful. Perform service voltage test. or exiting test mode • at midnight The diagnostic mode cycles through performing the service voltage test and displaying information about the service that may be useful in determining why the test failed. Figure 4-8. The following conditions can cause the service current test to fail: • current remains on one phase while no current is on any other phase • current on any single phase is below the programmed low current limit • current on any phase is greater than the programmed absolute maximum • current is negative on any phase (reverse power) • power factor on any phase is less than the limit set for leading or lagging power factor Meter tools . L1-2-3 OK is shown on the A1800 ALPHA meter LCD. Table 4-3. The service current test can be initiated in any of the following ways: • the service current test may be placed in any display sequence. the low and missing current failure will not be reported. Table 4-3 and Table 4-4 show all possible system service error codes. no-load condition. the low and zero current warnings will display if the condition exists. The results of the TRueQ test will not be seen on the LCD. • the service current test may be included in the TRueQ tests if the A1800 ALPHA meter is equipped with this feature. Service current test error L1 L2 L3 +P Initiating the service current test. These parameters (configurable with Elster meter support software) include the following: • enable or disable per phase reverse power tests • absolute minimum current • per phase low currents • absolute maximum current • per phase leading and lagging power factor limits System service error codes When SE is shown on the LCD. the displayed quantity is a numeric code representing a system service error. In this case. • the service current test may be programmed to be performed after successful service voltage tests that perform automatically (but not as part of a display list) If the A1800 ALPHA meter does not have a locked service. System service voltage test error codes Error code Service error condition (SE) Voltage phase L1 L2 L3 Low nominal voltage on line 1 1 0 0 0 0 0 Low nominal voltage on line 2 0 1 0 0 0 0 Low nominal voltage on line 3 0 0 1 0 0 0 High nominal voltage on line 1 2 0 0 0 0 0 High nominal voltage on line 2 0 2 0 0 0 0 High nominal voltage on line 3 0 0 2 0 0 0 Unrecognized service 5 5 5 0 0 0 . The service current test will be performed when the quantity is displayed in the display sequence. Parameters regarding the system service current tests can be changed without requiring the meter to be unlocked and then relocked or requiring the meter to be reset. See “TRueQ monitoring” on page 4-12 for more details on TRueQ. Figure 4-9. It is assumed that this is a valid. then the system service current test will be skipped regardless of how the test is initiated. This indicates that there is a service problem detected by the A1800 ALPHA meter.Technical manual 4-10 Meter tools If all phases are below the absolute minimum current threshold. System service voltage test error codes Error code Service error condition (SE) Voltage phase L1 L2 L3 Bad phase angle on line 1 8 0 0 0 0 0 Bad phase angle on line 2 0 8 0 0 0 0 Bad phase angle on line 3 0 0 8 0 0 0 Low voltage & bad phase angle on line 1 9 0 0 0 0 0 Low voltage & bad phase angle on line 2 0 9 0 0 0 0 Low voltage & bad phase angle on line 3 0 0 9 0 0 0 High voltage & bad phase angle on line 1 A 0 0 0 0 0 High voltage & bad phase angle on line 2 0 A 0 0 0 0 High voltage & bad phase angle on line 3 0 0 A 0 0 0 Table 4-4.Technical manual 4-11 Meter tools Table 4-3. System service current test error codes Error code Service error condition (SE) Current phase L1 L2 L3 Missing line 1 current 0 0 0 1 0 0 Missing line 2 current 0 0 0 0 1 0 Missing line 3 current 0 0 0 0 0 1 Low line 1 current 0 0 0 2 0 0 Low line 2 current 0 0 0 0 2 0 Low line 3 current 0 0 0 0 0 2 Missing and low current on line 1 0 0 0 3 0 0 Missing and low current on line 2 0 0 0 0 3 0 Missing and low current on line 3 0 0 0 0 0 3 Low PF on line 1 0 0 0 4 0 0 Low PF on line 2 0 0 0 0 4 0 Low PF on line 3 0 0 0 0 0 4 Reverse power on line 1 0 0 0 5 0 0 Reverse power on line 2 0 0 0 0 5 0 Reverse power on line 3 0 0 0 0 0 5 Low PF & low current on line 1 0 0 0 6 0 0 Low PF & low current on line 2 0 0 0 0 6 0 Low PF & low current on line 3 0 0 0 0 0 6 Reverse power & low current on line 1 0 0 0 7 0 0 Reverse power & low current on line 2 0 0 0 0 7 0 Reverse power & low current on line 3 0 0 0 0 0 7 Excess current on line 1 current 0 0 0 8 0 0 . uses the per phase rms voltage calculation which is part of the voltage sensing process within the meter engine. System service current test error codes Error code Service error condition (SE) Current phase L1 L2 L3 Excess current on line 2 current 0 0 0 0 8 0 Excess current on line 3 current 0 0 0 0 0 8 Excess current & low PF on line 1 0 0 0 C 0 0 Excess current & low PF on line 2 0 0 0 0 C 0 Excess current & low PF on line 3 0 0 0 0 0 C Excess current & reverse power on line 1 0 0 0 d 0 0 Excess current & reverse power on line 2 0 0 0 0 d 0 Excess current & reverse power on line 3 0 0 0 0 0 d If service current errors are present on more than one phase. and any relays will open. The cumulative count and timer for each test can be retrieved through Elster meter support software. Each subsequent test will begin immediately after the previous one has ended. TRueQ monitoring All A1800 ALPHA meters are equipped with the tamper restraint and quality (TRueQ) monitoring features that can monitor circuit parameters on a cyclic basis. The momentary voltage sag test. . For example. A cumulative timer will also be activated and will run for as long as the event is detected. 24 hours a day throughout the billing period. a single error code is displayed to represent all detected errors. TRueQ timing In addition to defining thresholds for each test. a minimum time may also be defined. Using Elster meter support software.Technical manual 4-12 Meter tools Table 4-4. When a failure condition is no long present. these thresholds can be edited. When shipped. TRueQ tests may be turned on or off through Elster meter support software. the failure will be stored and the cumulative count will increment by one. Warning codes can be enabled or disabled on a test-by-test basis using Elster meter support software. SE 000308 indicates missing current on line 1 and excess current on line 3. so the momentary voltage sag test is capable of recognizing any phase voltage deviation that remains below a specified threshold for as few as 2 line cycles. however. Once the monitored parameter falls outside the threshold and remains there longer than the minimum time. TRueQ display items The meter can be programmed to display a warning code on the LCD when a TRueQ test fails. the relay can be programmed to close when the failure occurs. TRueQ tests will recognize any deviation beyond the thresholds. the warning code will automatically clear. TRueQ and relays If one or more relays are installed in the A1800 ALPHA meter. Most TRueQ tests are performed individually so that circuit parameters are not being monitored continuously. the meter is stored with default values for the thresholds. The rms voltages are calculated once every 2 line cycles. The sag times can be configured to a resolution of 8 milliseconds. These values can be reported and can be reset through Elster meter support software.04 seconds. A qualified TRueQ failure causes the W2 020000 warning code to be shown on the LCD. Each counter can accumulate up to 65.9 %. If the condition exceeds the maximum sag time. These tests run separately from the metering functions. The counter and timer for each phase are maintained within the A1800 ALPHA meter memory. the corresponding potential indicator will blink. When a phase voltage drops below the voltage sag threshold.535 before rolling over to zero. it will not be considered a sag event. This monitor can detect any voltage decrease that falls below a programmed threshold for as few as 2 line cycles. The minimum time range can be from 32 milliseconds to 2. Each cumulative timer can record time for 414 days. See “Voltage sag log” on page 2-17 for more information about the log of momentary voltage sag events. A voltage sag event is only counted if the voltage remains below the voltage sag threshold for more than the minimum time and less than the maximum time. and it is not counted by the momentary voltage sag monitor. Meters with TOU capability will also record the date and time of any TRueQ failure in the TRueQ log. The potential indicators on the A1800 ALPHA meter LCD will indicate when voltage is below the sag level threshold. TRueQ tests TRueQ Test name Configuration based upon Test 1 Service voltage test System service voltage test thresholds Test 2 Low voltage test A specified low voltage threshold Test 3 High voltage test A specified high voltage threshold Test 4 Reverse power test & PF Service current test thresholds Meter tools . The momentary voltage sag monitor watches for decreases in voltage that last for a measured number of cycles. A voltage that remains below the voltage sag threshold for longer than the maximum time is considered to be a low voltage condition. TRueQ tests TRueQ tests do not interfere with any meter functions related to energy measurement. See “TRueQ log” on page 2-17 for more information about the TRueQ log. Table 4-5 shows the available tests for TRueQ. The maximum time range can be a time up to 546 seconds. A sag is defined as a drop in phase voltage below the threshold for a duration greater than the sag minimum time and less than the sag maximum time. Voltage sags A momentary sag in voltage can reset process control equipment and computer systems. Each phase voltage has a voltage sag counter and timer associated with it. See “W2 020000: TRueQ test failure warning” on page 6-7 for more details. along with their description.Technical manual 4-13 TRueQ log All A1800 ALPHA meters record TRueQ events in the TRueQ log. Voltage sag counter and timer. Threshold and duration are defined using Elster meter support software. The voltage sag threshold is defined as a percentage of the lowest nominal per phase voltage and recommended to be in the range of 60 % to 99. Table 4-5. TRueQ tests TRueQ Test name Configuration based upon Test 5 Low current test Service current test thresholds Test 6 Power factor (PF) A specified threshold for leading and lagging Test 7 Second harmonic current test A specified current threshold Test 8 % Total harmonic distortion (THD) current Specified THD percentage Test 9 % Total harmonic distortion voltage Specified THD percentage Test 10 Voltage imbalance Minimum high voltage threshold and imbalance threshold Test 11 Current imbalance Minimum high current threshold and imbalance threshold Test 12 % total demand distortion (TDD) Specified TDD percentage The following TRueQ tests are available on all A1800 ALPHA meters programmed with Metercat release 2.3 or later: Table 4-6. Enhanced TRueQ tests TRueQ Test name Configuration based upon Test 13 Low voltage (Line 1) Specified low voltage threshold Test 14 Low voltage (Line 2) Specified low voltage threshold Test 15 Low voltage (Line 3) Specified low voltage threshold Test 16 High voltage (Line 1) Specified high voltage threshold Test 17 High voltage (Line 2) Specified high voltage threshold Test 18 High voltage (Line 3) Specified high voltage threshold Test 19 Low voltage and current present (Line 1) Specified thresholds for low voltage and high current Test 20 Low voltage and current present (Line 2) Specified thresholds for low voltage and high current Test 21 Low voltage and current present (Line 3) Specified thresholds for low voltage and high current Test 22 Current missing (Line 1) Specified thresholds for voltage and current Test 23 Current missing (Line 2) Specified thresholds for voltage and current Test 24 Current missing (Line 3) Specified thresholds for voltage and current Meter tools .Technical manual 4-14 Table 4-5. however. Each TRueQ test has its own event counter associated with it. The momentary voltage sag monitor. The counter and timer for each monitor are maintained within the A1800 ALPHA meter memory.Technical manual 4-15 Meter tools During the low current and reverse power and power factor tests. See “Voltage sag counter and timer” on page 4-13 for details. Figure 4-10. For each TRueQ test. . An event will be detected if any single phase or two phases drop below the programmed threshold for the qualification time. Each counter can accumulate to a maximum of 65. there will be no event detected if all measured line currents drop below the absolute minimum current threshold. Total TRueQ test failure time TRueQ failure Qualification time Remaining time Time recorded by meter An event ends when the condition is no longer present. an event occurring on one phase or across multiple phases is counted as a single event. records counters and timers for each phase.535 before rolling over to zero. This eliminates false detection when the load is dramatically reduced or turned off. the TRueQ test must fail for a period greater than the qualification time. The cumulative timer for each monitor can record time over 20 years. If an event occurs but does not last for the qualification time. then neither the counter nor timer will reflect the event having occurred. These values can be reported and can be reset through Elster meter support software. To increase the cumulative counter or timer. The cumulative timer includes the qualification time for the test (see Figure 4-10). TRueQ event counters and timers. The qualification time is defined as zero to 60 minutes where zero causes the event to be recognized immediately as it is detected. the test fails if any phase voltage exceeds the threshold. The threshold is defined as a percentage of the expected per phase nominal value.9 % Default value 94.0 % Configuration based on A specified high voltage threshold Description This test checks the per phase voltages for values that exceed a specific limit. This allows a more thorough study of the voltage changes. Voltage fluctuations outside the programmed limits are detected and can indicate one of the following: • improper voltage transformer operation • inappropriate transformer tap settings • equipment failure All voltage magnitudes and phase angles must fall within the thresholds for the locked service. This allows a more thorough study of the voltage changes. The test fails if any phase voltage exceeds the threshold. Stored value None Test Formula 2 Name Low voltage test (VL1 or VL2 or VL3 )  Specified low voltage threshold Variable 0 % to 99. Each phase threshold can be set individually and can be set at a value higher or lower than the limits selected for the service voltage test.1 % to 200. The threshold is defined as a percentage of the expected per phase nominal voltage (recommended to be in the range of 60 % to 99. Programming the service voltage as a TRueQ test allows it to continually run and create a log of the results. The threshold values can be set at a value higher or lower than the limits selected for the service voltage test. The percentage for each phase can be individually defined.0 % Default value 106.0 % Configuration based on A specified low voltage threshold Description This test checks the per phase voltages for values that fall below a specified limit.9 %). Stored value Line 1 voltage (even if line 2 or line 3 causes the test to fail) .Technical manual 4-16 Test Formula 1 Name Meter tools Service voltage test (VL1 or VL2 or VL3 )  Specified low voltage threshold Variable Based on service test thresholds Default value Based on service test thresholds Configuration based on System service voltage test thresholds Description This test continually monitors service voltage. Stored value Line 1 voltage (even if line 2 or line 3 causes the test to fail) Test Formula 3 Name High voltage test (VL1 or VL2 or VL3 )  Specified high voltage threshold Variable 100. The percentage for each phase can be individually defined. The thresholds are defined by the service voltage configuration. Testing for reverse power can only be enabled or disabled for all phases simultaneously. The power factor (PF) threshold in this test is typically set to a very low value to detect only abnormal conditions.00 to 1. These settings may be different than those defined in the service current configuration. This test will check for erroneous operation or failure of a current transformer and can detect signs of meter tampering. Each service type can have individual leading and lagging thresholds. This percentage is applied on a per phase basis. The leading and lagging thresholds are individually defined for each phase.20 for minimum lagging power factor (per phase) Configuration based on Specified thresholds for leading and lagging power factors Description This test checks the power factor for any deviation beyond the programmed threshold.Technical manual 4-17 Test 4 Name Meter tools Reverse power test and power factor test Formula Variable Based on service test thresholds Default value Based on service test thresholds Configuration based on Service current test thresholds Description This test recognizes any condition where the current transformer may be wired incorrectly or where may tampering may have occurred.00 to 1. Stored value None Test Formula 5 Name Low current test (I L1 or I L2 or I L3 )  Specified low current threshold Variable Based on service test thresholds Default value Based on service test thresholds Configuration based on Service current test thresholds Description This test checks the service current for values that fall below a specified limit. Stored value None Test 6 Name Power factor test Formula Variable 0. The thresholds are defined by the service current configuration.00 for minimum leading power factor (per phase) 0.00 for minimum lagging power factor (per phase) Default value 0. The PF thresholds are defined with the system service current test definition. If all phase currents fall below the limit on an initial no-load or test condition. Stored value None . Using the service current test definition permits independent PF settings to be set for each service type. then no warning or indication will be provided.20 for minimum leading power factor (per phase) 0. This monitor may be used alone to monitor rate-based conditions or in conjunction with the reverse power test and PF monitor to provide a more thorough analysis of power factor fluctuations. This threshold is defined as a percentage of the A1800 ALPHA meter Class ampere rating from the system service test definition. A warning will be issued when one or more phase currents fall below the threshold value for the qualification time while the remaining phase currents stay above the limits. 25 % of Class amps (per phase) Configuration based on A specified current threshold Description This test checks for the presence of second harmonic current.0 % to 99. The test phases if any phase exceeds the threshold. expressed as a percentage of the fundamental.50 % of Class amps (per phase) Self-contained: 1. The test fails if any phase exceeds the threshold. Stored value Line 1 THD (even if line 2 or line 3 causes the test to fail) Test 9 Name % total harmonic distortion voltage test Formula Variable 00.0 % of the fundamental voltage (per phase) Configuration based on A specified THD percentage Description As the load on electrical systems becomes more saturated with electronic control devices (such as computers and communications systems). The thresholds are defined by the service voltage configuration. The threshold is defined as values in AC amperes according to the meter class.00 % to 100. the recommended qualification time is 15 minutes. is measurement of the power quality of the circuit under these conditions. To prevent the monitor from creating a false alarm from legitimate second harmonic current sources. there is a growing concern with the harmonics that these devices can contribute to the electrical system.0 % of the fundamental current (per phase) Configuration based on A specified THD percentage Description As the load on electrical systems becomes more saturated with electronic control devices (such as computers and communications systems). is a measurement of the power quality of the circuit under these conditions. The second harmonic current may be created by equipment on the line or may indicate the presence of DC on the system. Stored value Line 1 second harmonic magnitude (even if line 2 or line 3 causes the test to fail) Test 8 Name % total harmonic distortion current test Formula Variable 0. Stored value Line 1 THD voltage (even if line 2 or line 3 causes the test to fail) . Total harmonic distortion.9 % of the fundamental current Default value 30. The total harmonic distortion voltage test measures per phase THD voltage and can alert the utility to conditions that may be harmful or dangerous to the system or other equipment. The test fails if any phase exceeds the threshold.00 % Default value Transformer-rated: 2. The threshold is defined as a percentage of the fundamental. The threshold is defined as a percentage of the fundamental. Total harmonic distortion. there is a growing concern with the harmonics that these devices can contribute to the electrical system. The thresholds are defined by the service voltage configuration.0% to 99.9 % of the fundamental voltage Default value 30. expressed as a percentage of the fundamental. The total harmonic distortion current test measures the per phase THD current and can alert the utility to conditions that may be harmful or dangerous to the system or other equipment.Technical manual Test Formula 4-18 7 Name Meter tools Second harmonic current test 2 nd harmonic current  2 nd harmonic current magnitue threshold Variable 0. 00 % of the nominal Imbalance threshold: 0. Stored value None . both the following must exist: • The highest per phase current must be greater than the minimum current threshold • The ratio between the lowest per phase current to the highest (low/high) must be less than the imbalance threshold Using Elster meter support software.00 % to 100. the minimum current threshold is defined as a percentage of Class amperes. Stored value None Test Formula 11 Name Current imbalance test (I L1 or I L2 or I L3 )  minimum current threshold and lowest per phase current  imbalance threshold highest per phase current Variable Minimum current threshold: 0.00 % Default value Minimum voltage threshold: 80.Technical manual Test Formula 4-19 10 Name Meter tools Voltage imbalance test (VL1 or VL2 or VL3 )  minimum voltage threshold and lowest per phase voltage  imbalance threshold highest per phase voltage Variable Minimum voltage threshold: 0. and the imbalance threshold is a fraction (0 to 1). the minimum voltage threshold is defined as a percentage of the nominal voltage. The test first measures and normalizes each per phase voltage.00 % to 100. To qualify as a failure. The voltages are normalized to account for different per phase nominal voltages as specified by the locked service.25 % of the Class amperes Imbalance threshold: 5. both the following conditions must exist: The highest normalized per phase voltage must be greater than the minimum voltage threshold The ratio of the lowest normalized per phase voltage to the highest (low/high) must be less than the imbalance threshold Using Elster meter support software. and the imbalance threshold is a fraction (0 to 1). To qualify as a failure.00 % to 100.00 % Configuration based on Minimum high current threshold and imbalance threshold Description This test checks for an imbalance between phase currents.00 % Default value Minimum current threshold: 1.00 % to 100.00 % of Class amperes Imbalance threshold: 0.00 % of the nominal Imbalance threshold: 90.00 % Configuration based on Minimum high voltage threshold and imbalance threshold Description This test checks for an imbalance between phase voltages. Stored value Line 1 voltage Test Formula 14 Name Low voltage (Line 2) VL 2  Specified voltage threshold Variable 0.0 % to 99.Technical manual Test Formula 4-20 12 Name Meter tools Total demand distortion TDD  threshold Variable 0. Stored value Line 1 % TDD (even if it is line 2 or line 3 that causes the test to fail) Test Formula 13 Name Low voltage (Line 1) VL 1  Specified voltage threshold Variable 0.0 % to 99.00 % of the class amperes (per phase) Default value 10. The threshold is defined as a percentage of the expected Line 1 nominal voltage. The test fails if Line 1 voltage falls below the voltage threshold.00 % of the Class amperes Configuration based on Specified TDD threshold Description This test checks the per phase total demand distortion (TDD) and makes sure that the TDD is less than the threshold.0 % Configuration based on A specified voltage threshold Description This test checks Line 2 voltage for values that fall below a specified limit. The test fails if Line 2 voltage falls below the voltage threshold.9 % of nominal Default value 60. TDD measures the harmonic current distortion on each phase in percentage of the maximum demand load current (Class amperes). Stored value Line 2 voltage .9 % of nominal Default value 60. The threshold is defined as a percentage of the expected Line 2 nominal voltage.00 % to 100.0 % Configuration based on A specified voltage threshold Description This test checks Line 1 voltage for values that fall below a specified limit. Technical manual Test Formula 4-21 15 Name Meter tools Low voltage (Line 3) VL 3  Specified voltage threshold Variable 0.0 % Configuration based on A specified voltage threshold Description This test checks Line 1 voltage for values that exceed a specified limit.9 % of nominal Default value 60.0 % Configuration based on A specified voltage threshold Description This test checks Line 2 voltage for values that exceed a specified limit. The threshold is defined as a percentage of the expected Line 3 nominal voltage.1 % to 200.1 % to 200. The threshold is defined as a percentage of the expected Line 2 nominal voltage. The test fails if Line 3 voltage falls below the voltage threshold. The threshold is defined as a percentage of the expected Line 1 nominal voltage.0 % of nominal Default value 115.0 % Configuration based on A specified voltage threshold Description This test checks Line 3 voltage for values that fall below a specified limit. Stored value Line 2 voltage . The test fails if Line 1 voltage exceeds the voltage threshold. The test fails if Line 2 voltage exceeds the voltage threshold. Stored value Line 3 voltage Test Formula 16 Name High voltage (Line 1) VL 1  Specified voltage threshold Variable 100.0 % to 99.0 % of nominal Default value 115. Stored value Line 1 voltage Test Formula 17 Name High voltage (Line 2) VL 2  Specified voltage threshold Variable 100. 0000 amperes for Line 2 current Default value 78.0000 amperes for Line 1 current Default value 78. The test fails if Line 3 voltage exceeds the voltage threshold.9 % of nominal for Line 2 voltage 0.9 % of nominal for Line 1 voltage 0. and • Voltage on Line 2 is less than a specified voltage threshold Stored value Line 2 voltage .0 % for voltage threshold 0.0 % to 99.0003 to 1000.0 % of nominal Default value 115. and • Voltage on Line 1 is less than a specified voltage threshold Stored value Line 1 voltage Test Formula 20 Name Low voltage and current present (Line 2) VL2  Specified voltage threshold and I L2  Specified high voltage threshold Variable 0.0015 amps for current threshold Configuration based on Specified thresholds for voltage and current Description This test checks voltage and current on Line 2 to detect possible theft or VT problems on Line 2. This test fails if the following conditions are present: • Current on Line 2 is greater than a specified current threshold.0003 to 1000.Technical manual Test Formula 4-22 18 Name Meter tools High voltage (Line 3) VL 3  Specified voltage threshold Variable 100. Stored value Line 3 voltage Test Formula 19 Name Low voltage and current present (Line 1) VL1  Specified voltage threshold and I L1  Specified high voltage threshold Variable 0.1 % to 200. The threshold is defined as a percentage of the expected Line 3 nominal voltage.0 % for voltage threshold 0.0015 amps for current threshold Configuration based on Specified thresholds for voltage and current Description This test checks voltage and current on Line 1 to detect possible theft or VT problems on Line 1.0 % Configuration based on A specified voltage threshold Description This test checks Line 3 voltage for values that exceed a specified limit.0 % to 99. This test fails if the following conditions are present: • Current on Line 1 is greater than a specified current threshold. This test fails if the following conditions are present: • Voltage is present on any phase.0003 to 1000.0 % of nominal for Line 2 voltage threshold 60.0003 A to 1000.0 % of nominal for Line 1 voltage threshold 5.0 % for voltage threshold 0.0000 A for Line 2 current threshold 0.0 % to 100.0 % to 100.0 % to 99. and • Current is at or above a specified threshold on Line 2 or Line 3.0010 A to 1000.0 % of nominal for Line 1 voltage threshold 60.0 % of nominal for Line 2 voltage threshold 5.0750 A for Line 2 current threshold 0.0000 A for Line 1 current threshold 0. This test fails if the following conditions are present: • Current on Line 3 is greater than a specified current threshold. and • Voltage on Line 3 is less than a specified voltage threshold Stored value Line 3 voltage Test Formula 22 Name Current missing (Line 1) (VL1 or VL2 or VL3 )  specified voltage threshold and I L1  specified current threshold and (I L2 or I L3 )  specified current threshold Variable 5.000 A for Line 3 current threshold Default value 60.0015 amps for current threshold Configuration based on Specified thresholds for voltage and current Description This test checks voltage and current on Line 3 to detect possible theft or VT problems on Line 3. and • Current is below a specified threshold on LIne 1 Stored value Line 1 current .0 % of nominal for Line 3 voltage threshold 0.9 % of nominal for Line 3 voltage 0.0 % of nominal for Line 3 voltage threshold 0.0750 A for Line 3 current threshold Configuration based on Specified thresholds for voltage and current Description This test checks voltage and current on all phases to help detect possible theft or CT problems on Line 1.0000 amperes for Line 3 current Default value 78.0010 A to 1000.0015 A for Line 1 current threshold 0.Technical manual Test Formula 4-23 21 Name Meter tools Low voltage and current present (Line 3) VL3  Specified voltage threshold and I L3  Specified high current threshold Variable 0.0 % to 100. 0 % of nominal for Line 2 voltage threshold 5.Technical manual Test Formula 4-24 23 Name Meter tools Current missing (Line 2) (VL1 or VL2 or VL3 )  specified voltage threshold and I L2  specified current threshold and (I L1 or I L3 )  specified current threshold Variable 5.0 % of nominal for Line 3 voltage threshold 0.0015 A for Line 2 current threshold 0.0 % of nominal for Line 1 voltage threshold 60.000 A for Line 3 current threshold Default value 60.0000 A for Line 1 current threshold 0.0750 A for Line 3 current threshold Configuration based on Specified thresholds for voltage and current Description This test checks voltage and current on all phases to help detect possible theft or CT problems on Line 2.0750 A for Line 1 current threshold 0.0 % of nominal for Line 1 voltage threshold 5.0 % of nominal for Line 2 voltage threshold 60.0003 A to 1000.0 % to 100.0 % of nominal for Line 3 voltage threshold 0. This test fails if the following conditions are present: • Voltage is present on any phase. and • Current is below a specified threshold on LIne 2 Stored value Line 2 current .0 % to 100.0 % to 100. and • Current is at or above a specified threshold on Line 1 or Line 3.0010 A to 1000.0010 A to 1000.0000 A for Line 2 current threshold 0. 0 % of nominal for Line 3 voltage threshold 0.0010 A to 1000. the meter will not communicate or perform the commands that it is issued. For more information regarding passwords.0 % of nominal for Line 2 voltage threshold 5. This test fails if the following conditions are present: • Voltage is present on any phase.0 % to 100. Full programming of the meter is allowed.0003 A to 1000. Table 4-7.000 A for Line 3 current threshold Default value 60.0000 A for Line 1 current threshold 0. The A1800 ALPHA meter uses three passwords to control access to the meter. and • Current is below a specified threshold on LIne 3 Stored value Line 3 current Security All A1800 ALPHA meters include features that help prevent unauthorized access to meter data and record events that may indicate meter tampering.0 % of nominal for Line 2 voltage threshold 60.0 % of nominal for Line 1 voltage threshold 5. If the correct password is not supplied. Unrestricted The meter can be read. see the documentation that comes with the Elster meter support software. Passwords help ensure that the meter data is protected and that the programming cannot be altered without proper authorization. When establishing communication with the meter. .0 % to 100.0750 A for Line 2 current threshold 0. A1800 ALPHA meter passwords Password Allowed activity Read only The meter can be read.0 % of nominal for Line 3 voltage threshold 0.0 % of nominal for Line 1 voltage threshold 60.0015 A for Line 3 current threshold Configuration based on Specified thresholds for voltage and current Description This test checks voltage and current on all phases to help detect possible theft or CT problems on Line 3.0 % to 100. No alteration of data or programming is allowed.0010 A to 1000.Technical manual 4-25 Test 24 Formula Name Meter tools Current missing (Line 3) (VL1 or VL2 or VL3 )  specified voltage threshold and I L3  specified current threshold and (I L1 or I L2 )  specified current threshold Variable 5. each password allows different activities that can be performed on the meter.0750 A for Line 1 current threshold 0.0000 A for Line 2 current threshold 0. and • Current is at or above a specified threshold on Line 1 or Line 3. As shown in Table 4-7. Some basic data-altering activity relating to billing functions is allowed. Billing read The meter can be read. Meter passwords Access to the A1800 ALPHA meter is protected through the use of passwords. the meter will request a password. The TC indicator will turn on. 1 On meters with a history log. 5. the password is not encrypted when communicating using the optical port. To temporarily disable program protection: 1. Break the terminal cover seals and remove terminal cover. For more information. Some data and configuration parameters can be altered while in program protection.18. The meter records the number of failed password attempts that were used in trying to access the meter. Anti–tampering All A1800 ALPHA meters provide auditing capabilities that can be used to indicate potential meter tampering. Program protection prevents metrological parameters from being altered. An internal warning will be generated if 10 failed password attempts occur since the last demand reset. Break the meter cover seals and lift the meter cover. In accordance with ANSI C12. 3.1 These alterable items must be specified at ordering and can include the following: • communication parameters • TRueQ parameters • time of day (TOU or load profiling configurations) • switch times (TOU configurations) • special dates list (TOU or load profiling configurations) All other parameter changes require the meter to exit program protect mode. This warning can be used to control a relay output or to trigger an alarm call.21. it may be possible to change certain metrological parameters while in program protection. See “Event log”on page 2-14 for details. At this point. 4. 2. If programmed to do so. .Technical manual 4-26 Meter tools When communicating with the A1800 ALPHA meter remotely. These capabilities can record such items as the following: • programming changes • power outages • number of days since last pulse • number of manually-initiated demand resets • number of days since last demand reset • reverse energy flow • history log • cover removal detection Program protection As a security feature. see “History log”on page 2-14. The TC indicator will turn off. Close the meter cover and install the seals. the A1800 ALPHA meter can be ordered with program protection. you can perform any of the data or program altering operations available using the Elster meter support software. Install the terminal cover and seals. changes in the state of the terminal cover and the meter cover are logged in the event log. the A1800 ALPHA meter supports the password encryption standards in accordance with ANSI C12. 1 A1800 ALPHA meter with RS-232 as second communication port RS-232 connector (optional)* Pulse output relay (optional) RS-485 terminals RS-232 connector *Present when optional second communication port is installed Pulse output relay default values RS-485 connections 4-wire Tx+ A B C RxTx- D Rx+ 2-wire A = Wh del B = varh del C = Wh rec D = varh rec 1 -bias + - +bias RS-232 connector 1 1 2 3 4 5 3 2 6 7 = = = = = NC Rx Tx DTR GND 5 4 8 9 6 7 8 9 = = = = DSR RTS NC NC Support for up to 6 relays on A1800 ALPHA meter is a future option.Technical manual Technical manual 5-1 Outputs 5 Outputs Relay outputs All A1800 meters are equipped with 4 relay outputs. The A1800 ALPHA meter can be ordered with 6 relays. . Contact Elster Metronica for availability. turn on and off) • pulse for a specified length of time Load control The relay closes when the demand exceeds the specified demand threshold. . and it remains closed for the duration of the interval. “Wiring diagrams. The relay will open after the demand remains below the threshold for one full interval. See Appendix D. all relay outputs are fully programmable using Elster meter support software. EOI indication The relay closes for 5 seconds after the end of each interval or subinterval. the relay will do either of the following: • toggle (that is. Source for relay operation and output specifications Relay source Relay output specification Energy pulse For each pulse of the selected basic metered quantity (see “Metered energy and demand quantities” on page 2-10). The output relays on the main circuit board can switch up to 125 VAC or 180 VDC at up to 70 mA. A1800 ALPHA meter with RS-485 as second communication port RS-485 connector (optional)* Pulse output relay (optional) RS-485 terminals RS-232 connector *Present when optional second communication port is installed Pulse output relay default values RS-485 connections 4-wire Tx+ A B C Rx- 1 Rx+ 2-wire -bias + - +bias 1 2 3 4 5 3 2 6 D Tx- A = Wh del B = varh del C = Wh rec D = varh rec RS-232 connector 7 = NC = Rx = Tx = DTR = GND 5 4 8 9 6 = DSR 7 = RTS 8 = NC 9 = NC For more information about relay outputs and communications. see the instructional leaflet (IL) that comes with the option board. Table 5-1.Technical manual 5-2 Outputs Figure 5-1.” With the A1800 ALPHA meter. Sources for relay outputs are listed in Table 5-1. Figure 5-2. Using Elster meter support software. the width can be programmed with a value from 1 millisecond to 255 milliseconds. Pulse period Pulse period On 10 msec. warnings. a relay changes state for each energy pulse received from the meter engine. 10 msec.Technical manual 5-3 Outputs Table 5-1. Pulse Off Pulse period In pulse mode. Using Elster meter support. The relay will open after the demand forgiveness time has expired. each pulse is equal to a specified amount of energy. Energy pulse divisor  Pulse constant Relay constant . Toggle relay output On ½ ½ ½ ½ ½ ½ Pulse Off Pulse period Pulse period Pulse period In toggle mode. Energy pulse outputs When a relay is used to echo energy pulses for a basic metered quantity. warnings. Using pulse divisor. Pulse relay output (default pulse width) 10 msec. or events persist (see “Relay-related alarms” on page 5-4). there are two methods for specifying the weight of each pulse. TRueQ tests failure Relay closes as long as the specified TRueQ tests continue to fail (see “TRueQ monitoring” on page 412). and meter events The relay closes for as long as the specified errors. Source for relay operation and output specifications Relay source Relay output specification Demand forgiveness (cold load pickup) The relay closes while demand forgiveness is in effect. Figure 5-3. a default pulse width of 10 milliseconds is generated for each energy pulse received from the meter engine. TOU switches to a specific tariff The relay closes for the duration of the specified tariffs. Specified errors. Program the energy pulse divisor with an integer value between 1 and 999. you would use an energy pulse value of 0. warnings. End of calendar warning See “W2 200000: End of calendar warning” on page 68. and events that can trigger a relay. If any errors are detected. Using pulse value. Demand overload warning See “W1 100000: Demand overload warning” on page 6-7 EEPROM access error See “E1 010000: EEPROM access error” on page 6-4. Errors. the desired relay constant is 1000 pulses per 1 kWh and the pulse constant is 4000 pulses per 1 kWh: Energy pulse divisor  4000 4 1000 Note: If the energy pulse divisor is not an integer. then the exact desired output is not possible. the desired relay constant is 1000 pulses per 1 kWh and the pulse constant is 40. Table 5-2. Relay-related alarms The A1800 ALPHA meter periodically performs a self test to determine if it is operating properly. program the energy pulse divisor of 40 into the meter. Note: If the energy pulse divisor is not an integer. Event log wrap event The event log has exceeded the maximum number of entries. to have one energy pulse represent 2 Wh (0. Note: The pulse value method is available from the Tools > System Preferences > Programming Options command in Metercat. For example.000001 kWh and 100 kWh to represent the amount of energy per pulse (in kilo units). the meter can respond in any or all of the following ways: • display an error or a warning (see “Codes and warnings” on page 6-2) • initiate a telephone call using a modem • trigger a relay See Table 5-2 for errors.000 pulses per kWh For example. Clock error See “E3 030000: Clock error” on page 6-5.002 kWh). Note: Elster recommends that the pulse value should not be used when verifying meter accuracy. warnings. then the exact desired output is not possible. Crystal oscillator error See “E1 000010: Crystal oscillator error” on page 6-4. and events that can trigger a relay Condition Description Carryover error See “E1 000001: Carryover error” on page 6-3.000 pulses per 1 kWh: Energy pulse divisor  40000  40 1000 Using Elster meter support software. Use the pulse divisor method when verifying meter accuracy. • For direct connect-rated meters: 4000 pulses per kWh For example. Outputs . and the oldest records will be overwritten.Technical manual 5-4 The pulse constant (also known as the meter constant) for the A1800 ALPHA meter is as follows: • For transformer rated meters: 40. Program the energy pulse value with a value between 0.002. Rate override warning The current TOU rate is being overridden by the alternate TOU rate schedule. History log wrap warning The history log has exceeded the maximum number of entries. Power fail data save error See “E2 200000: Power fail data save error” on page 65. Pulse profiling wrap imminent event The pulse profiling log is within 2 days of overflowing. Data will be lost if the pulse profiling log is not read within 2 days. Possible tamper warning This condition indicates possible tampering of the meter because a specified number of invalid passwords used to access the meter has been used (called “tamper detect warning” in this manual). Improper meter engine operation warning See “W1 000010: Improper meter engine operation warning” on page 6-6 Instrumentation profiling set 1 wrap imminent event Set 1 of the instrumentation profiling log is within 2 days of overflowing. and events that can trigger a relay Condition Description General configuration error See “E1 100000: General configuration error” on page 6-4. Data will be lost if the instrumentation profiling log is not read within 2 days. Potential indicator warning See “W1 010000: Potential indicator warning” on page 6-7. Data will be lost if the instrumentation profiling log is not read within 2 days. Internal communication error See “E1 001000: Internal communication error” on page 6-4. This condition does not generate an error or warning code on the LCD. Instrumentation profiling set 2 wrap imminent event Set 2 of the instrumentation profiling log is within 2 days of overflowing.Technical manual 5-5 Table 5-2. Errors. Outputs . no further changes to the meter are allowed until the history log has been read. If the history log is locked. Service current test failure warning See “W2 000002: Service current test failure warning” on page 6-7. Depending on programming. the meter will either lock the history log or start overwriting the oldest records. Reverse energy flow warning See “W1 000100: Reverse energy flow warning” on page 6-7. Low battery warning See “W1 000001: Low battery warning” on page 6-6. warnings. Service voltage test failure warning The service voltage test was unable to find a valid service or the measured service does not match the locked service. indicates alternate (varh/VAh) energy import or export The LEDs emit pulse outputs that can be used to test the A1800 ALPHA meter in the field without removing the meter from service or breaking the seal. Transformer rated meter LED output specifications Operating mode Pulse rate Pulse divisor Normal 5000 pulses/kWh or 5000 pulses/kvarh 8 Alternate 5000 pulses/kWh or 5000 pulses/kvar 8 Test 40.Technical manual 5-6 Outputs LED pulse outputs The A1800 ALPHA meter has two energy light emitting diodes (LEDs).000 pulses/kWh or 40. Depending on the operating mode of the meter. the LEDs are programmed at the factory to emit a pulse as follows: Table 5-3. Figure 5-4. contact your Elster Metronica representative. Direct connect-rated meter LED output specification Operating mode Pulse rate Normal 500 pulses/kWh or 1000 pulses/kvarh 8 Alternate 500 pulses/kWh or 1000 pulses/kvarh 8 Test 4000 pulses/kWh or 4000 pulses/kvarh 1 For alternate pulse rates.indicates active (Wh) energy import or export • alternate LED . LEDs Active energy LED Alternate energy LED Output specifications The LEDs support up to 120 pulses per second. which are permanently configured as follows: • active LED . Pulse divisor .The pulse width is fixed at 8 msec.000 pulses/kvarh 1 Table 5-4. see “Relay-related alarms” on page 5-4. “Meter tools. all of the LCD segments will be turned on briefly before beginning the normal display sequence. Meter self test The A1800 ALPHA meter periodically performs a self test to determine if it is operating properly. and parity checks are made of memory and data locations. • For LCD errors and warnings. Any errors encountered will be displayed on the LCD. The meter self test will be performed automatically under the following conditions: • when the meter is initially installed and after any power restoration • at midnight • immediately after a data-altering communication session The self test incorporates a series of electronic analyses verifying many aspects of the A1800 ALPHA meter. The following is a list of the specific tests performed during a self test: • verification of the configuration data and checksums • confirmation of the crystal oscillator accuracy • detection of low battery voltage • detection of low Read without Power battery voltage • maximum lifetime usage of the Read without Power battery • verification of normal microcontroller function • detection of unexpected meter engine resets (for multiple tariff configurations) • detection and identification of user-defined warning conditions Testing . the system instrumentation and TRueQ features provide valuable information about the meter service. Certain errors may also initiate a telephone call via a modem or trigger a relay. After the meter passes its self test upon power restoration. however. The A1800 ALPHA meter performs its own self tests. Continuity checks and communications checks are made between various key circuits of the electronics.” for more information about the instrumentation and power quality features of the meter. Testing procedures are the same regardless of the type of meter being tested. Additionally. No field calibrations or adjustments are required to ensure accurate operation of the meter. see “Codes and warnings” on page 6-2. The self test ensures that the A1800 ALPHA meter is functioning properly and its displayed quantities are accurate.Technical manual Technical manual 6-1 6 Testing A1800 ALPHA meters are factory calibrated and tested to provide years of trouble-free service. It is normal. • For relay alarms. to test installed A1800 ALPHA meters periodically to ensure accurate billing. See Chapter 4. See “Push buttons” on page 3-4 for information on how the push buttons operate when an error or warning is displayed. Error codes are indicated on the LCD by a group code and a numerical code. Error codes indicate conditions that may be affecting billing data. Communication codes are temporarily displayed on the LCD even when the LCD is “locked” by an error code. Error codes override any other item that is being displayed on the LCD. See Figure 6-1 for a sample error code displayed on the meter LCD. Sample error code displayed on the LCD +P L1 L2 L3 Testing .Technical manual 6-2 Codes and warnings There are 3 types of codes: • error codes • warning codes • communication codes The A1800 ALPHA meter displays error codes and warnings as an indication of a problem that may be adversely affecting its operation. There are exceptions to errors locking the display: • The normal and alternate display sequence can be viewed even when an error code locks the display. Using Elster support software. Warning codes indicate conditions that may be of concern but do not affect the integrity of billing data. some codes provide an indication of the present communication process. See “* button” on page 3-5 for more information. the error code is no longer displayed. It is not recommended to operate the A1800 ALPHA meter for an extended time when it is displaying an error code. The meter will continue to function as normally as possible when displaying an error or warning. Communication codes generally indicate a condition affecting communications with the meter through the optical port or remote port. The numerical code indicates the specific condition that has occurred. LCD returns to showing the error code. preventing other items from being displayed. Not all communication codes indicate potential problems. See “E3 300000: Display locked by warning” on page 6-5 for more information. error codes can be configured to “lock” the display. Figure 6-1. Error codes. After the communication code clears. and the error indicator turns on. The * and RESET buttons operate differently if an error or warning is displayed. When the condition causing the warning code is clear. • Warning codes can be programmed to display an error code. The group code makes it easier to identify the error on the LCD. Table 6-1 through Table 6-3 describe the different error conditions and their codes. this data would be lost. and the error will need to be reset through Elster meter support software. In some cases. the data stored in RAM is lost. Group E3 error conditions and codes Condition Code Clock error 0 3 0 0 0 0 Display locked by warning 3 0 0 0 0 0 Error codes of the same group are displayed in combination (E1 001010. If errors exist in more than one group. Any problems must be corrected before normal operation can continue. When a loss of line voltage occurs. Depending on meter configuration. other data may be stored in RAM. the meter may need to be reprogrammed or returned to the factory for repair or replacement. If both of these fail. Group E1 error conditions and codes Condition Code Carryover error 0 0 0 0 0 1 Crystal oscillator error 0 0 0 0 1 0 Table CRC error 0 0 0 1 0 0 Internal communication error 0 0 1 0 0 0 EEPROM access error 0 1 0 0 0 0 General configuration error 1 0 0 0 0 0 Table 6-2. the meter’s RAM is maintained by the super capacitor and the TOU battery.1 The push buttons and communications ports will function normally. Since shipping can take several days. this error will likely be seen on meters shipped without a connected battery. This code indicates a failure of a RAM checksum test on data stored in the meter’s volatile RAM during a power outage. Group E2 error conditions and codes Condition Code Security configuration error 0 0 0 0 0 2 Password table CRC error 0 0 0 0 2 0 Encryption key table CRC error 0 0 0 2 0 0 ROM fail error 0 2 0 0 0 0 Power fail data save error 2 0 0 0 0 0 Table 6-3. for example). If the error code is still shown after using Elster meter support software. 1 Billing data is always stored in nonvolatile memory. . the meter must be returned to the factory for repair or replacement. the meter will continually cycle through the different groups. If the battery fails. Billing data is stored in nonvolatile EEPROM and will still be available. indicating that more than one error condition has been detected.Technical manual 6-3 Testing Table 6-1. E1 000001: Carryover error. The meter battery may need to be replaced. which uses a battery to preserve memory. The push buttons and optical port will continue to function normally. the A1800 ALPHA meter should be returned to the factory for repair or replacement. E1 010000: EEPROM access error. This code might appear if a communications interruption occurs during meter programming. E2 000200: Encryption key table CRC error. This code indicates a problem with the meter’s configuration or program. Prompt correction of the error will maximize the A1800 ALPHA meter’s security protection. Contact Elster if this error is displayed on the LCD.Technical manual 6-4 E1 000010: Crystal oscillator error. This code indicates the meter had a problem accessing its nonvolatile EEPROM. If this error occurs. Prompt correction of the error will maximize the A1800 ALPHA meter’s security protection. The A1800 ALPHA meter must be returned to the factory for repair or replacement. If the error code is displayed after reprogramming. This codes indicates a problem with the crystal oscillator. E1 001000: Internal communication error. the meter is vulnerable to tampering. Prompt correction of the error will maximize the A1800 ALPHA meter’s security protection. E1 000100: Table CRC error. E2 000020: Password table CRC error. the meter is vulnerable to tampering. The meter can usually be reprogrammed using Elster meter support software to correct the errors. Reprogramming the meter with Elster meter support software may correct the problem. The A1800 ALPHA meter must be returned to the factory for repair or replacement. This code indicates an error is present in the meter’s security configuration. Encryption keys are used for secure access to the meter’s data and configuration through the remote communication port. The A1800 ALPHA meter should be returned to the factory for repair or replacement.21 password configuration table. This code indicates the meter had an internal communication error. billing data may not be reliably accumulated while this error condition exists. E2 000002: Security configuration error.19 encryption key configuration table. This code indicates a possible error in the A1800 ALPHA meter’s programming. If this error occurs. the meter is vulnerable to tampering. Depending on which area of the meter is affected. If this error occurs. Testing . E1 100000: General configuration error. This code indicates a CRC error is present in the meter’s ANSI C12. Contact Elster if this error is displayed on the LCD. This code indicates a CRC error is present in the meter’s ANSI C12. Contact Elster if this error is displayed on the LCD. When the condition is present. TOU features cannot be performed when time is lost. Warning codes are indicated on the LCD by a group code and a numerical code. The numeric code indicates the specific condition that has occurred. Use Elster firmware flash software to attempt repair. Elster meter support software can be used to select individual warnings that will lock the display as an error. E2 200000: Power fail data save error. is removed from the display sequence. If this fails. If the error code is still present. If the condition causing the warning clears. Figure 6-2. Elster meter support software is used to select the individual warnings that will cause this error code to display. the meter must be returned to the factory for repair or replacement. Warning codes. the meter must be returned to the factory for repair or replacement. The A1800 ALPHA meter must be returned to the factory for repair or replacement. E3 300000: Display locked by warning. The group code makes it easier to identify the error on the LCD. Group W1 warning codes Condition Code Low battery warning 0 0 0 0 0 1 Improper meter engine operation warning 0 0 0 0 1 0 Reverse energy flow warning 0 0 0 1 0 0 Potential indicator warning 0 1 0 0 0 0 Demand overload warning 1 0 0 0 0 0 . Warning codes indicate conditions of concern that do not yet affect the integrity of billing data. All meter functionality is halted until this error is resolved. This code indicates an incomplete attempt to flash the meter firmware. See Figure 6-2 for a sample warning code displayed on the LCD. E3 030000: Clock error. Sample warning code +P L1 L2 L3 Table 6-4. When a carryover error occurs (see “E1 000001: Carryover error” on page 6-3).Technical manual 6-5 Testing E2 020000: ROM fail error. Table 6-4 and Table 6-5 describe the different warning conditions and their codes. The meter battery may need to be replaced. This code indicates that the data saved in the nonvolatile EEPROM during a power fail may be invalid. and a self check has discovered an error with the EEPROM data. Previously accumulated data is stored in nonvolatile EEPROM and will still be available. When the condition clears. the error code will also clear. the warning code. and the error will need to be reset through Elster meter support software. reference to real time is lost. This code will exist on the meter if Elster firmware flash software did not complete the upgrade process. a warning code is automatically inserted as the last item in the normal and alternate display sequences. This code indicates that one or more warning codes (see “Warning codes” on page 6-5) has locked the display. This code indicates an error with the meter’s timekeeping ability. See “Error codes” on page 6-2 for more information. This error will be displayed when power is restored to the meter. The A1800 ALPHA meter can be programmed to lock the display if a warning condition is present. If the code continues to be displayed on the LCD.Technical manual 6-6 Testing Table 6-5. W1 000010: Improper meter engine operation warning. the A1800 ALPHA meter should be returned to the factory for repair or replacement. the meter displays each group at the end of the display sequence before returning to the first item in the display sequence. This warning condition is typically triggered when the microcontroller reinitializes the meter engine. Once the new battery has been installed and the meter is energized. For timekeeping configurations. then the warning code will be automatically cleared from the LCD. indicating that one or more warning conditions are present. the code is automatically cleared. Group W2 warning codes Condition Code Service current test failure warning 0 0 0 0 0 2 Demand threshold exceeded warning 0 0 0 2 0 0 Line frequency warning 0 0 2 0 0 0 TRueQ test failure warning 0 2 0 0 0 0 End of calendar warning 2 0 0 0 0 0 Warning codes of the same group are displayed in combination (for example. An unstable or noisy electrical environment at the A1800 ALPHA meter installation can interfere with this operation. the low battery indicator will display on the LCD (see “Low battery indicator” on page 3-3). If the meter engine is successfully reinitialized. the meter should be de-energized and the battery should be replaced. A1800 ALPHA meters having realtime TOU functionality require a battery to maintain date and time over an extended power outage. This warning code indicates a low battery voltage or missing battery. If warnings exist in more than one group. . W2 202000). Note: In addition. This code indicates that the meter engine program may be corrupt or is not executing correctly. See “Removing the battery” on page 7-6 and “Installing a TOU battery” on page 7-3 for instructions on replacing batteries. W1 000001: Low battery warning. further investigation is required. See “Phase indicators” on page 3-2 and “Voltage sags” on page 4-13 for more details on potential indicators and voltage sags. the A1800 ALPHA meter may be reprogrammed with a higher threshold value. The code is automatically cleared when the phase potential returns a value within the programmed thresholds. Testing . If a meter is configured to use the line frequency instead of the crystal oscillator as the time base. it may be necessary to return the A1800 ALPHA meter to the factory for repair or replacement. The code will be automatically cleared once the line frequency returns to within 5 % of the nominal frequency. If the demand overload value has been set lower than appropriate for the installation. If reverse energy flow is expected. This warning will never appear on meters configured for constant timekeeping operation from the internal crystal. It is generally intended to inform a utility when the installation is requiring more power than the service equipment was originally designed to handle. This warning follows the state of any relay programmed for demand threshold operation. The code will be automatically cleared once TRueQ conditions return to a value within the programmed thresholds. In some cases. This code indicates that one or more of the phase potentials are missing or below the defined threshold for voltage sag detection. This warning code indicates that reverse energy flow has been detected equivalent to twice the Kh since the last reset. See “Service current test” on page 4-9 for more information. When this condition occurs. This code indicates that the demand has exceeded one of the programmed demand thresholds. The code is cleared by these methods: • the service current test is performed again and the test does not fail • issuing the clear values and status command through Elster meter support software W2 000200: Demand threshold exceeded warning. This code indicates that the most recently performed service current test has failed. W1 100000: Demand overload warning. It is set once the demand threshold has been exceeded and only cleared after one complete demand interval during which the threshold is not exceeded. This code indicates that one or more TRueQ tests have detected a value outside the programmed thresholds. then this warning code can be disabled through Elster meter support software. W2 020000: TRueQ test failure warning. If the service being metered is not expected to return energy to the utility. This code indicates that the demand value exceeded the programmed overload value. This code will display at the same time as one or more of the potential indicators blink. this code indicates that the line frequency is off by ±5 % of its programmed setting. the meter switches timekeeping to the crystal oscillator. Use the meter system instrumentation displays or Elster meter support software to gain additional information on the specific TRueQ test causing the problem. The code is cleared by these methods: • performing a demand reset • issuing the clear values and status command through Elster meter support software W1 010000: Potential indicator warning.Technical manual 6-7 W1 000100: Reverse energy flow warning. The code is cleared by these methods: • performing a demand reset • issuing the clear values and status command through Elster meter support software W2 000002: Service current test failure warning. It may be an indication of tampering with the A1800 ALPHA meter installation. W2 002000: Line frequency warning. Elster recommends you attempt the communication again. Sample communication code +P L1 L2 L3 Table 6-6. Program a new calendar using Elster meter support software. See Figure 6-3 for a sample communication code displayed on the meter’s LCD. Figure 6-3. Communication codes Condition Code CRC error C 0 0 1 0 1 Syntax error C 0 0 1 0 3 Framing error C 0 0 1 0 4 Timeout error C 0 0 1 0 5 For most communication errors. Communication codes are indicated on the LCD by a port code and a numerical code. If communication errors persist. The numerical code indicates the status of the communication session. This code indicates that the meter calendar has expired or is about to expire. The code is cleared by these methods: • performing a demand reset • issuing the clear values and status command through Elster meter support software Communication codes.Technical manual 6-8 Testing W2 200000: End of calendar warning. The date at which this code appears is configurable using Elster meter support software. . You may need to cycle power to the A1800 ALPHA meter or to reattempt the Elster meter support software function. Communication codes temporarily override any other item that is being displayed on the LCD (including error codes). return the meter to the factory for repair or replacement. The port code identifies the affected port. See Table 6-6 for the communication codes that can be displayed. 002 % accuracy • a precision varh reference standard with ±0. test the meter with In equal to 10 % of Imax. low-power pulse sensor to capture and count pulses from the meter output relay (the pulse sensor should provide a low voltage source to the pulsing relay as well as detect and count contact closures of the output relay) • test equipment for measuring. counting. Note: The A1800 ALPHA meter has a flat. Therefore. with additional test points at 5 %.002 % accuracy • a phantom load device or other loading circuit capable of handling the test current • one of the following: • a photoelectric pickup to sense test pulses from the LED and a device capable of counting pulses • a low voltage (12 VDC to 24 VDC). the entire range of loads is within the required accuracy.5 (60 ° lagging) • a precision Wh reference standard with ±0. For example. and timing pulse outputs • control equipment that can provide switching between the meter source voltage and precision reference standard • precision voltage and current transformers • voltmeters. when allowed by local legislation. a value of approximately 20 % to 25 % of Imax is used for basic tests. check the nameplate for the following: • Meter class for expected accuracy • Test amperes (In or Ib) The specific test ampere value is not critical as long as the applied current does not exceed the Imax current rating of the meter. Historical data from testing the A1800 ALPHA meter confirms that if these test points are within the required accuracy. and any other measuring equipment that might be required Test setup Before testing the A1800 ALPHA meter. meter accuracy testing can be accomplished by checking the meter accuracy at two typical points. the meter can be tested using a lower source voltage if that voltage is within the wide operating voltage range of the A1800 ALPHA meter) • provide a variable load current at unity power factor (PF) • provide a variable load current at a lagging power factor for varh testing. power factor meters. the power supply should be capable of delivering load current at PF = 0.0 (90 ° lagging) or PF = 0. and 100 % of Imax also required by most legal authorities. 10 %. Normally. Below is a list of standard test equipment required for testing the A1800 ALPHA meter: • a stable mounting fixture for the meter and a means to temporarily make the proper power connections to the meter • a reliable power supply that should be able to do the following: • provide a voltage source for energizing the meter at its rated voltage (if desired. at both 100 % and 20 % PF. phase angle meters.Technical manual 6-9 Meter shop testing Test equipment Typically. linear load curve accuracy response. meter shops develop testing procedures specific to their own needs and have the test equipment needed. ammeters. • Operating voltage range • Any other important specifications for the meter being tested Testing . test errors may occur because not enough time is allowed for the test. Using relay outputs for testing. For test shops that do not have photoelectric pulse sensors and related counters and do not want to use relay outputs for testing. Use the LCD pulse count to determine the energy measured during the test cycle and compare it with the energy delivered by precision reference standard.2 accuracy. When testing meters for Class 0. polyphase meters can be tested with single phase loading. When using a lower test In. Typically. testing time should exceed 20 seconds for accurate results at normal test current values of Ib or In. Place the precision Wh or varh reference standard and precision voltage and current transformers (as required) in series with the meter being tested. Testing . for precise test results. meter specifications are verified by checking the meter calibration. The testing time may vary because of the characteristics of the precision reference standard and the amount of power flowing through the test circuits. the LCD can provide a pulse count that reflects the energy measured during a test. “Wiring diagrams. The test voltage should be applied to the meter for at least ten seconds prior to making test measurements. Using LCD pulse count for testing. Some experimentation may be required to determine the testing time needed to reach a stable accuracy level. The preferred test method is to apply full 3-phase voltage and current to both the meter and the precision reference standard. When using the relay outputs for testing. See Appendix D. The accuracy test results for single phase and polyphase loading will be virtually identical and well within A1800 ALPHA meter specifications. if required. 3.” for appropriate wiring diagrams for the A1800 ALPHA meter. If more accurate testing is required. Install the meter in the stable mounting fixture. increase the test time proportionally. use longer testing times. meter testing is done primarily to verify that the meter is operating within its specifications. then the meter source voltage should be placed in parallel with the Wh or VARh reference standards. Connect the measuring equipment for counting the standard’s output pulses. If precision testing is required. Dangerous voltages are present. the relay outputs need to be configured for pulse output. a test cycle time of at least one minute is recommended at In and with PF = 1. 5.0.Technical manual 6-10 Risk of personal injury or death! Use only authorized personnel and proper test procedures to test metering equipment. To do so. If voltage transformers are not required. This allows the power supply circuitry to stabilize. ideally 22 °C (72 °F). Nevertheless. The accuracy of the A1800 ALPHA meter remains consistent over a wide range of ambient temperatures. death. Connect the control equipment for switching the source voltage to the precision reference standard. Meter testing Since no adjustments are required for the A1800 ALPHA meter in the field. 4. testing times should be as long as it takes to attain a stable accuracy level when comparing the meter under test to the precision standard. or equipment damage can result if safety precautions are not followed. Personal injury. Nevertheless. meters should be tested in an environment where the meter and test equipment are at the same ambient temperature. The relay outputs can be used instead of the LED to test meter calibration. Apply the rated test current and voltage to the terminals of the meter. When using current values lower than In for testing. Single phase loading is done by connecting the voltage inputs in parallel and the current sensors in series to combine element operation. To set up the A1800 ALPHA meter for testing: 1. 2. a similar procedure also can be used to test a meter while it is in service at a customer site. personnel injury or death. When testing a meter in service. If a meter is programmed to display energy pulse counts when it is in the alternate display mode. use the meter software to restore the meter to normal mode. follow the safety procedures specified by the utility. After meter testing is complete. Wire a portable precision reference standard into the circuit in series with the billing meter. If high voltage connected current transformers are accidentally open circuited. Testing . To test the meter using the LCD pulse count. the LCD display can be cycled to display the pulse count accumulated during a test cycle. creating an extremely hazardous condition. the meter display must be configured to display a test pulse count. After the portable precision reference standard is in the circuit. If this test method is used while the meter is in alternate mode. leading to possible property damage. any energy consumed by the customer during the test is registered in the normal manner. Use the Elster meter support software to communicate to the meter through the optical port and place it in test mode. the energy value determined from the pulse count displayed on the LCD over the test interval can be compared with the energy value displayed on the portable reference standard. In test mode. using only authorized procedures.Technical manual 6-11 Wiring a portable device into an energized metering circuit must be done with extreme care. the voltages at the secondary open terminals can rise to the primary voltage level. Technical manual 6-12 Testing . and it is ready for installation. Follow proper installation and removal procedures for personal safety and protection of the meter. Equipment damage. Do not connect power to a meter that is suspected to have unknown internal damage. or death can result if circuit-closing devices are not used. Placing the meter into service See Appendix D. death. Dangerous currents and voltages are present if secondaries are open-circuited. Before installing and applying power to the A1800 ALPHA meter. Check for some of the following items: • no broken or missing parts • no missing or broken wiring • no bent or cracked components • no evidence of overheating • check the nameplate to make sure it is appropriate for the service Physical damage to the outside of the A1800 ALPHA meter could indicate potential electronic damage in the inside of the meter.Technical manual Technical manual 7-1 7 Installation and removal Preliminary inspection Circuit-closing devices must be used on current transformer secondaries. or equipment damage can result if circuit-closing devices are not used. a quick inspection of the meter itself is recommended. Contact your local Elster Metronica representative if you suspect your meter may be damaged. personal injury. Circuit-closing devices must be used on current transformer secondaries. Installation and removal . The A1800 ALPHA meter is calibrated and tested at the factory. “Wiring diagrams. Dangerous currents and voltages are present if secondaries are open-circuited. Personal injury.” for illustrations of both internal and connection wiring diagrams. Where possible. If primary current and voltage are present in the current transformers. A1800 ALPHA meter terminals are designed for optimum use with copper wiring. Sliding the hanger down to the hidden position will hide the top supporting screw. Tighten the connections. is in the desired position. Also. use authorized utility procedures to install proper ground connections on all appropriate VT and CT circuits and on the meter ground terminals. Aluminum wiring compound or wiring paste (grease) should be used when attaching the bottomconnected terminals. Dangerous voltages can be present. it is extremely important to verify that safety shorting connections are in place on all secondary winding connections prior to handling CT connections to the meter. be certain that CTs on energized lines are securely short-circuited either with circuit-closing test switches or with properly installed conductors. it is extremely important to use proper aluminum wiring practices. ensure that any current transformers are de-energized with no highvoltage primary voltage connected to their primaries and no primary current circulating through them. follow this procedure: 1. If applicable. Use at least an M6 screw in each of the bottom supporting screws to secure the A1800 ALPHA meter enclosure. the mounting holes are 7. 5.Technical manual 7-2 Make sure to install the correct meter for the service type. To use the A1800 ALPHA meter effectively and safely. 2. making sure it is level. allow them to relax for a few minutes. or damaging fires. Make sure that the meter hanger. death. Use at least an M6 screw for the top supporting position and hang the meter on it. 4. Such adapters also can provide for use or larger aluminum conductors that can be otherwise used in the terminals of the A1800 ALPHA meter. Ensure that primary or system voltages are either disconnected from a power source or that utility safety practices for handling live circuits are strictly followed. 3. Personal injury. Failure to observe correct practices for installing aluminum wiring could lead to overheating of the terminals.28 inches) in diameter.1 mm (0. Elster recommends copper-compatible meter terminals and aluminum wire. Installing inappropriate meters can damage equipment. This will minimize the cold-flow effects of aluminum cable. or equipment damage can result from wiring an ungrounded meter or mishandling improperly grounded metering transformer circuits. but failing to mount the meter in a proper vertical position will place the other mounting holes at the wrong place on the mounting panel. aluminum wiring can be used but if so. Before wiring the meter into the power circuit. then tighten them again. Always verify that the maximum meter voltage and current ratings are equal to or greater than the maximum service voltage and current. equipment failures. maximum current. The meter will operate correctly in any position. and capacity required. Installation and removal . located on the base of the A1800 ALPHA meter. For direct connect-rated meters. Install the ground connections. 6. If the meter has been energized for at least 1 minute during the previous 60 minutes. energize the meter for 1 minute. Installation and removal . proceed to step 2. the A1800 ALPHA meter must have been energized for at least 1 minute within the preceding 60 minutes. For information on communication and relay connections.Technical manual 7-3 7. verify that the LCD is active and functioning. Standard wiring diagrams are shown in Appendix D. To install the battery: 1. The terminal block dimensions on the A1800 ALPHA meter support cable sizes of approximately 5 mm in diameter for transformer rated connections (10 mm in diameter for direct connect). Use only Elsterrecommended TOU batteries. or death can result if safety precautions are not followed. A1800 ALPHA meter mounting screw locations Hanger screw mount Screw mounts Installing a TOU battery The TOU battery is replaceable without breaking the meter seal. “Outputs. If this is not done. see Chapter 5. After wiring the meter and making any communication and relay connections. and equipment damage.” Figure 7-1. Wire the meter using color-coded wire according to locally applicable specifications. The meter should be de-energized before installing the battery. “Wiring diagrams. See your Elster Metronica representative for details. assemble the terminal cover and apply power. If the meter has not been energized for at least 1 minute during the previous 60 minutes. While the meter is powered. Use authorized procedures to install the battery while power is removed from the meter. personal injury. This ensures that the supercapacitor is properly charged and that the battery is not immediately drained upon installation. Dangerous voltages are present. then the battery may be damaged and the meter may not function correctly. Before installing the battery.” 8. Figure 7-2. Slide the battery leads into the connector to the right of the battery well. following the instructions earlier in this section.1 2. Energize the meter and verify that the LCD becomes active and functioning properly. Place the battery firmly in the battery well. If the meter still does not function properly. 8. Other validation information can be obtained using the system instrumentation display quantities. and service type should be indicated on the LCD. If the battery was installed without having the meter properly energized.Technical manual 7-4 Installation and removal 2. Replace the terminal cover. service voltage. verify the following: • The system service voltage test (if enabled) shows the valid service for this installation. Verify that the low battery symbol on the meter LCD is not displayed. display is blank but the meter is powered). In case a battery has been installed correctly and the meter is not functioning properly (for example. 9. De-energize the meter. Troubleshooting. Remove the terminal cover screws and seals. Battery well and connector TOU battery 5. 6. use the following procedure. 7. Not following this procedure can cause the meter to function improperly. . See “Indicators and controls” on page 3-1 for details.5 % of its service life each day. This provides sufficient time for the supercapacitor to discharge and for the microcontroller to shut down. Verify that the LCD becomes active and functioning correctly. Remove the terminal cover to expose the battery well. 3. The phase rotation. 10. 1. De-energize the meter and insert the battery. 4. 1 If the battery was installed with the polarity reversed. De-energize the meter and let it sit without power for 48 to 72 hours. then the battery will lose approximately 8. then it should be returned to the factory. Reprogram the meter or clear the errors (as necessary). the battery should not be damaged. 3. Replace the terminal cover screws and seals. Initial setup After installing and powering the A1800 ALPHA meter. The microcontroller should power up correctly and the supercapacitor will charge. Energize the meter for at least 1 minute. Remove the terminal cover as described above. To remove the utility information: 1. • The LEDs are blinking and the energy direction indicators on the LCD show the correct energy flow direction. Figure 7-3. A blinking indicator means that the phase is missing the required voltage or is below the programmed minimum voltage threshold value. then check for improper installation or wiring. then verify these other areas: • the meter installation matches the meter nameplate • the correct type of A1800 ALPHA meter is installed in the existing service • no evidence of mechanical or electrical damage to either the meter or the installation location • the service voltage falls within the operating range as indicated on the nameplate • the optical port is free of dirt or other obstructions Marking the utility information card The utility information card can be removed without breaking seals and removing the meter cover screws. Grasp the protruding utility information card tab firmly and pull the card out slowly from under the meter cover. If the meter is not working correctly after it has been installed. Removing the utility information card Installation and removal .Technical manual 7-5 • All potential indicators (from L1 to L3 depending on the wiring) are present and are not blinking. 2. • Required meter seals are in place. If the installation and wiring are correct. 3. Mark the card as needed. • Any information (such as registration and location of the meter) has been recorded. Note that the direct connect meter uses a blank card. Technical manual 7-6 Removing the meter from service Use the appropriate procedure when removing an A1800 ALPHA meter from service. Circuit-closing devices must be used on current transformer secondaries. Dangerous voltages are present. Remove the voltage and disconnect the current circuits. and equipment damage. Disconnect the wiring. personal injury. 4. 2. Break the seal holding the A1800 ALPHA meter terminal cover in place. and equipment damage. personal injury. If the removed battery is still in working condition. Dangerous voltages are present. 7. use the following procedure: 1. 2. make sure that the existing meter data has been copied. Remove the terminal cover screws and take off the terminal cover. or electric utility policies. 6. Lift the meter off the top supporting screw. If it becomes necessary to remove an A1800 ALPHA meter from service. Before disconnecting the meter. personal injury. Use the following procedure to remove a battery from an A1800 ALPHA meter: 1. 3. Use authorized utility procedures to remove metering equipment. Remove the lower supporting screws. Replace the terminal cover and ensure the seals are in place. or death can result if safety precautions are not followed. Dangerous currents and voltages are present if secondaries are open-circuited. Installation and removal . or death can result if safety procedures are not followed. 3. regulations. De-energize the meter. Disconnect the battery leads from the connector. Remove the terminal cover to expose the battery well. it can be stored safely for future use. Use authorized procedures to remove the battery while power is removed from the meter. 4. Removing the battery The meter should be de-energized before removing the battery. This applies to CT-connected meters. Non-functioning batteries should be disposed of according to local laws. Firmly grasp the battery and lift it from the well. 5. Equipment damage. 5. either manually or electronically using Elster meter support software. or death can result if circuit-closing devices are not used. . In this case. 16. These losses may be added to. the utility billing point is actually the high voltage side of the transformer. DC: Edison Electric Institute. Parameter Description %LWFe Iron watts correction percentage %LWCu Copper watts correction percentage %LVFe Iron vars correction percentage %LVCu Copper vars correction percentage 1 Edison Electric Institute. These values are site specific and must be uniquely determined for each loss compensation application. Handbook for Electricity Metering. Calculating the correction values To configure the loss compensation feature of an A1800 ALPHA meter you must input the following values into the loss compensation software. Availability The loss compensation functionality is available only on the following CT-connected A1800 ALPHA (“-V” suffix) meter configurations: • 2-element • 3-element Software support A meter with loss compensation must first be programmed with the proper utility rate configuration using Elster meter support software just as you would with any other A1800 ALPHA meter. Washington. Using loss compensation. and iron-core losses. 10th edition. This is done with special Windows-based software titled A1800 ALPHA Meter Loss Compensation Tool. p. a special programming step is performed to load the proper loss constants into the meter.1 For example. 2002.Technical manual Technical manual 8-1 Loss compensation 8 Loss compensation Introduction What is Loss Compensation? The Handbook for Electricity Metering defines loss compensation as follows: A means for correcting the reading of a meter when the metering point and the point of service are physically separated resulting in measurable losses including I2R losses in conductors and transformers. the meter on the low voltage side of the transformer can actively adjust the energy registration to account for the losses in the transformer. it may be desirable to measure the energy usage on the low voltage side of a distribution transformer that serves an industrial customer even though the end-point customer actually owns the transformer and is responsible for any transformer losses. Next. or subtracted from the meter registration. If there are three single phase transformers then test data is needed for all three.for all 2 ½-element meters) Note: There may be one 3-phase transformer or a bank of three single phase transformers. Parameter Description VAphase Per phase VA rating of power transformer Vsec rated Rated secondary voltage of power transformer Isec rated Rated secondary current of power transformer Vpri rated Rated primary voltage of power transformer Ipri rated Rated primary current of power transformer LWFe No load watt loss of power transformer (loss watt iron) Loss compensation . then the rated voltage and rated current used in the calculations must be primary values. • If the meter is located on the primary side of the power transformer. Calculation of loss compensation parameters is dependent on the location of the meter with respect to the power transformer. then the rated voltage and rated current used in the calculations must be secondary values. the characteristics of the primary/secondary conductors at the specific site in question. Calculate the following quantities. if line losses are to be included. Parameter Description KVArated Rated kVA of power transformer Vpri L-L Primary line-to-line voltage of power transformer Vsec L-L Secondary line-to-line voltage of power transformer LWCu Full load watts loss of power transformer (copper or winding losses) LWFe No load watts loss of power transformer (iron or core losses) %EXC Percent excitation current of the power transformer %Z Percent impedance of the power transformer CTR Current transformer ratio for instrument transformers supplying current to the meter VTR Voltage transformer ratio for instrument transformers supplying voltage to the meter Elements Number of meter elements (use 3. • If the meter is located on the secondary side of the power transformer.Technical manual 8-2 Parameter Description Meter current Meter current when power transformer is operating at maximum rating Meter voltage Meter voltage when power transformer is operating at rated voltage These values must be calculated on the basis of the power transformer test report and. Gather necessary data The following information is necessary to calculate the loss compensation configuration parameters. The following sections describe these calculations. The rated voltage and rated current used in the calculations must represent the values on the same side of the power transformer as the meter is located. Calculate the meter configuration parameters Step 1. L V secrated  V secL. 4-wire wye applications Isec rated ( kVArated  1000 ) 3 V secrated  V secL.L 3  VA phase V pri L. 4-wire wye applications Vpri rated For 2 element. 3-wire delta applications For 3 element. LWCu Take directly from power transformer test report. LWFe Take directly from power transformer test report. 3-wire delta applications For 3 element. LVAFe  %EXC  kVArated  1000     100  .L V pri rated  V pri L.L 3 V pri rated  V pri L.L Note: For a bank of three single phase transformers the below calculations should be performed independently for each transformer and then summed to obtain the total losses.L All applications I secrated  Ipri rated All applications I pri rated  3 3  VA phase V secL.Technical manual 8-3 Loss compensation Parameter Description LWCu Full load watt loss of power transformer (loss watt copper) LVAFe No load VA loss of power transformer (loss VA iron) LVACu Full load VA loss of power transformer (loss VA copper) LVFe No load var loss of power transformer (loss var iron) LVCu Full load var loss of power transformer (loss var copper) Parameter Equation VAphase If bank of 3 transformers VA phase  KVArated  1000 If one 3-phase transformer VA phase  Vsec rated For 2 element. LWFe2 LVCu LVCu 2 . the meter voltage. These are the values that must be entered into the loss compensation software to configure the meter properly. and the meter current.Technical manual Parameter LVACu 8-4 Equation  %Z  kVArated  1000     100  LVFe LVAFe2 . • If the meter is on the primary side of the power transformer.LWCu 2 Step 2. Calculate the per element % correction factors. Parameter %LWFe %LWCu Equation LWFe 100 Vrated  I rated  Elements LWCu  LiWTOT  100 V rated  I rated  Elements %LVFe %LVCu LVFe 100 Vrated  I rated  Elements LVCu  LiVTOT  100 Vrated  I rated  Elements Meter current I rated CTR Loss compensation . Parameter Description LiWTOT Total full load watt line loss (line loss watt) LiVTOT Total full load var line loss (line loss var) Step 3. • If the meter is on the secondary side of the power transformer. If it is desired to compensate for line losses then calculate the full load watt line loss and the full load var line loss values (see next section for details on line loss calculation). then Vrated = Vsec rated and Irated = Isec rated. then Vrated = Vpri rated and Irated = Ipri rated. or both depending on the application. and the calculation depends on the wiring configuration.Technical manual Parameter Meter voltage 8-5 Equation V rated VTR Calculating line loss Compensation for line losses may include primary losses. Parameter Description RL Line resistance () XL Line reactance () Deq Geometric mean distance between phase conductors (in meters) DL1. Gather necessary data The following information is necessary to calculate the line losses. Parameter Description f Frequency n Number of conductors L Line length (units compatible with conductor resistance) Conductor resistance (/meter or /kilometer) Ra 1 GMR Geometric mean radius of the phase conductors (in meters) Xa1 Inductive reactance of the conductor at 1ft. secondary losses. The available information determines which is used in the calculations. but not both. The most common configuration is one where the wires are unbundled and the spacing between wires Loss compensation . Step 1.L2 Distance between Line 1 and Line 2 (in meters) DL2.L3 Distance between Line 2 and Line 3 (in meters) DL3.L1 Distance between Line 3 and Line 1 (in meters) Parameter Equation RL L  Ra Calculating the reactive component of the impedance is not as straight forward as the resistance calculation. spacing (/meter or /kilometer) 1 Either GMR or Xa is required. Calculate line resistance and line reactance The equations below should be applied individually to the primary and the secondary conductors. L 2  DL 2 . and Isec rated are the same values as used in calculation of transformer losses (see previous section). Vsec L-L. When compensating for both transformer and line losses: Item LiWsec LiVsec LiWpri LiVpri LiWTOT LiVTOT Equation 2 I sec rated  RL sec  n 2 I sec rated  X L sec  n 2 I pri rated  RL pri  n 2 I pri rated  X L pri  n LiW sec  LiW pri LiV sec  LiV pri Loss compensation . will not be discussed in this document. Calculate the line losses. such as bundled conductors.L 3  DL 3 . Ipri rated.Technical manual 8-6 is uniform.2794     LogDeq    60     where: Deq  3 DL 1. The choice of which equation to use is based on the whether GMR or Xa is available. Other types of wiring.L 1 Step 2. Two equations can be used to calculate line reactance.2794     Log  60   GMR      f  L   X a  0. Item Equation XL If using GMR If using Xa  Deq   f   L  0. Item Description LiWTOT Total full load watt line loss (line loss watt) LiVTOT Total full load var line loss (line loss var) Vpri L-L Primary line-to-line voltage of power transformer Vsec L-L Secondary line-to-line voltage of power transformer Ipri rated Rated primary current of power transformer Isec rated Rated secondary current of power transformer Note: Vpri L-L. 2002. Irated = Ipri rated. Parameter Equation %LWFe 0 %LWCu %LVFe %LVCu Meter current Meter voltage LiWTOT  100 Vrated  I rated  Elements 0 LiVTOT  100 Vrated  I rated  Elements I rated CTR Vrated VTR Calculation example The following example can be used as a guideline. • If the meter is on the secondary side of the power transformer. . If compensating for both transformer and line losses. DC: Edison Electric Institute. Vrated is the nominal voltage seen on the high side of the instrument transformer supplying voltage to the meter. then the values for Ipri rated and Isec rated must be directly specified by the user. • If the meter is on the primary side of the power transformer. “Special Metering.2 Application notes: • The application is a bank of three single-phase power transformers. return to Step 3 of the previous section using the above calculated line losses to help calculate the %LWCu and %LVCu values. Irated = Isec rated. That is. these two values will be inversely proportional to the rated secondary and primary voltages of the power transformer. Handbook for Electricity Metering. I pri rated I secrated  V secrated V pri rated Step 3. This is based on the sample transformer data for loss compensation shown in chapter 10 of the Handbook for Electricity Metering (10th edition). Chap- ter 10.” pp. 2 Edison Electric Institute. If compensating only for line losses use the following equations to calculate the per element % correction factors. Washington.Technical manual 8-7 Loss compensation Note: In the special case that you are compensating only for line loss (no transformer losses). the meter voltage and the meter current for entry in the loss compensation software. Typically. 249-88. tenth edition. Technical manual 8-8 Loss compensation • The metering occurs on the low (secondary) side of a power transformer.06 0.16 8. 2-element delta application: V secL. Parameter Description VAphase bank of three transformers: kVArated  1000  3333  1000  3.91 %Z 8.03 8.333. Gather necessary data Power transformer data (from transformer manufacturer) Parameter Value Line 1 Line 2 Line 3 KVArated 3333 3333 3333 Vpri L-L 115000 115000 115000 Vsec L-L 2520 2520 2520 LWCu 18935 18400 18692 LWFe 9650 9690 9340 %EXC 1. Calculate the quantities Because the metering is on the secondary side of the power transformer. and losses will be added to the measured energy.L  2520 . • There is a delta connection on the secondary of the power transformer and thus a 2element meter will be used to measure the service. all references to rated voltage and rated current refer to the secondary rated values. • Losses are being compensated for the power transformer only (no line losses).12 Instrument transformer data: Parameter Value CTR 3000  600 5 VTR 2400  20 120 Meter data: Parameter Value Elements 2 Step 1.000 Vrated secondary side.00 1. 06  3333  1000     35 .LWCu 2 271.333 .330 2  9690 2  33 .LWFe2 35 .313 Phase 2.973  100  LVFe LVFe2 .Technical manual 8-9 Parameter Description Irated secondary side application: 3 VA phase V secL. Calculations Parameter Value LWFe 9650 LWCu 18935 LVAFe LVACu  %EXC  kVArated  1000     100   1.16  3333  1000     271 . Calculations Parameter Value LWFe 9690 LWCu 18400 LVAFe  % EXC  kVArated  1000     100   1.330  100   %Z  kVArated  1000     100   8.975 LVCu LVACu 2 .935 2  271.84 2520 Phase 1.000  2290.923 2  18 .00  3333  1000     33 .L  3 3 .330  100  Loss compensation . 640  100  LVFe LVAFe2 .692 2  269 .007 Phase 3. Calculations Parameter Value LWFe 9340 LWCu 18.856 LVCu LVACu 2 .330  100   %Z  kVArated  1000     100   8.330 2  9340 2  28 .640 2  18 .400 2  267 .692 LVAFe LVACu  % EXC  kVArated  1000     100   0.03  3333  1000     267 .993 Loss compensation .LWFe2 33 .640  100  LVFe LVAFe2 .LWFe2 35 .LWCu 2 270 .640 2  18 .975 LVCu LVACu 2 .91  3333  1000     30 .Technical manual Parameter LVACu 8-10 Value %Z  kVArated  1000     100   8.LWCu 2 267 .12  3333  1000     270 .330 2  9690 2  33 . 007 + 269.84  2 Meter current I rated 2290.993 = 808.330 + 30.330 + 35.0009 2520  2290.330 = 98.990 LVACu 271. there is no compensating for line losses: Parameter Value LiWTOT 0 LiVTOT 0 Step 3.680  100  0.84  2 %LVFe %LVCu LVFe 100 Vrated  I rated  Elements 94 .640 = 810.313 Step 2.8205 2520  2290.680 LWCu 18.253 LVFe 31. Compensate for line loss (if needed).82 A CTR 600 Loss compensation .84  2 LVCu  LiVTOT  Vrated  I rated  Elements 808 . Now the per element % correction factors may be calculated: Parameter %LWFe %LWCu Value LWFe 100 Vrated  I rated  Elements 28 .692 = 56.027 LVAFe 33.313 + 267.973 + 267. Per the stated assumptions.400 + 18.4853 2520  2290.640 + 270.2484 2520  229084  2 LWCu  LiWTOT  100 Vrated  I rated  Elements 56 .935 + 18.84   3.027  100  0.734  100  0.902 + 33.856 = 94.975 + 28.734 LVCu 271.313  100  7.Technical manual 8-11 From the above: Parameter Value LWFe 9650 + 9690 + 9340 = 28. 2484 Copper watts correction % (%LWCu) 0. kvarh-delivered). additional calculations are performed. The threshold level at which a pulse is generated is known as the meter Ke (energy per pulse). Internal to the meter engine. For a 3-element meter. This drives an internal accumulator in the meter engine that generates a pulse to the microcontroller when a threshold level is reached.4853 Iron vars correction % (%LVFe) 0.8205 Copper vars correction % (%LVCu) 7. When loss compensation is turned on. There are separate calculations.0009 Meter current 3. it is first necessary to understand a little bit about how the A1800 ALPHA meter engine operates. watts and vars are compensated every two line cycles according to the following equations: Compensation W var Equation  G  V   R  I L1 meas2  I L2 meas2  I L3 meas2   B  V 2 L1 meas V 2 L2 meas V 2 c meas  X  I L1 meas2  I L2 meas2  I L3 meas2  4 L1 meas  V L2 meas4  Vc meas4  .Technical manual Parameter Meter voltage 8-12 Loss compensation Value Vrated 2520   126 V VTR 20 Enter Data Summary of calculated values to enter in A1800 ALPHA Meter Loss Compensation Tool Parameter Value Registration Add losses Iron watts correction % (%LWFe) 0. The following equations indicate the compensation terms that are calculated and applied to the normal energy measurements every two line cycles. separate accumulators and separate Ke pulses generated for each measured energy quantity (for example.82 Meter voltage 126 Internal meter calculations To understand the loss compensation calculations. Every two line cycles on each phase. the Vrms and Irms values used in the normal energy calculations are also used to calculate a watt compensation value and a var compensation value. The individual phase measurements are then summed. Vrms and Irms are measured independently on each phase every two line cycles. kWh-delivered. These values are used to perform the normal energy calculations on each phase every two line cycles. the calculated W compensation value is summed with the normal Wh energy calculations. Similarly. Item R G X B Equation %LWCu  Meter voltage Meter current 100 %LWFe  Meter current Meter voltage 100 %LVCu  Meter voltage Meter current 100 %LVFe Meter current Meter voltage3  100 The compensation terms will be either positive or negative depending on whether losses are configured to be added or subtracted from the energy measurements.Technical manual 8-13 Loss compensation For a 2-element meter. and B using the following formulas and then programs these values into the meter. the var . the key difference on meters with loss compensation is that every two line cycles on each phase. watts and vars are compensated every two line cycles according to the following equations: Compensation W var Equation  G  V   R  I L1 meas2  I L3 meas2   B  V 2 L1 meas  Vc meas2  X  I L1 meas2  I L3 meas2  4 L1 meas V 4 c meas  Where: Term Description R Per element resistance G Per element conductance X Per element reactance B Per element susceptance Ixmeas Per phase rms current Vxmeas Per phase rms voltage The A1800 ALPHA Meter Loss Compensation Tool calculates R. X. So. G. the no-load compensation terms are based solely on the measured voltage on each phase (see above formulas).Technical manual 8-14 compensation term is summed per phase every two line cycles with the normal varh energy calculations. in the special case of a meter that is compensating for transformer losses. if line 3 voltage is lost while the meter remains powered. Note regarding two-element meters: Two-element ALPHA meters are unique in that they create an artificial internal reference that is used to measure the phase voltages. line 3 experiences a loss of voltage while the meter remains powered (either from line 1 or from an auxiliary supply) the internal meter engine will still measure a line 3 voltage equal to one-half of the line 1 voltage. The same situation would result if line 1 experiences a loss of voltage. For example. In applications where loss compensation is not applied this has no impact on the measurement of energy because no power will be drawn by the load on line 3. the no load compensation terms for line 3 will be in error because they will be calculated based on onehalf the line 1 voltage. line 3 current equals zero and so the net energy measured on line 3 is accurately calculated as zero. Loss compensation . From that point everything is essentially the same (individual phases are then summed to drive an accumulator). on 2-element ALPHA meters with loss compensation enabled. Therefore. That is. However. all instrumentation values reflect the actual measured values as seen at the meter terminals. all of the following collected data use the compensated values: • all register billing data • all pulse profile data • all KYZ pulse outputs • all test pulses (both in the LCD and on the LED) Compensation does not affect instrumentation values or the meter features that use instrumentation values. Likewise TRueQ functions and instrumentation profiling values are not affected when compensation is active. Utilities may desire to calculate the expected test results of a compensated meter and then test the meter with active compensation to verify that the expected results are obtained. This may or may not be desired depending on utility testing practices. That is. if compensation is turned on then the LEDs will indicate compensated energy. per phase voltage values are not affected (whether displayed on the LCD or reported in meter support software). Because the LED always reflects the state of the compensation it reduces the chance that a meter with active compensation is accidentally installed unknowingly. Using the A1800 ALPHA Meter Loss Compensation Tool.Technical manual 8-15 Meter outputs affected by compensation When loss compensation is enabled on an A1800 ALPHA meter. Loss compensation . Regardless of the status of loss compensation. If compensation is turned off then the LEDs will indicate uncompensated energy. it is possible to configure the meter to automatically turn off compensation whenever the meter enters test mode. For example. Testing a meter with compensation The LEDs on A1800 ALPHA meters always reflect the current measurement algorithm in the meter engine. The loss compensation software also permits the A1800 ALPHA meter loss compensation function to be manually turned off and turned on without altering the loss compensation parameters configured in the meter. Technical manual 8-16 Loss compensation . A typical use of the alternate mode is to display non-billing data as programmed by Elster meter support software. coincident. CTR. May also be referred to as tariff data. It is generally activated by pressing the Q button on the meter. alternate mode. coincident kvar demand is the kvar demand occurring during the interval of peak kW demand. when the meter is not in test mode. For example. using the following formula: AvgPF  kWh kvarh 2  kWh 2 billing data. average power factor. It is the smallest information unit used in data communications and storage. cumulative. 400 A to 5 A would have a current transformer ratio of 400:5 or 80:1. AvgPF. Glossary . The ratio of the primary current to the secondary current of a current transformer. It also can be used to control the scrolling of display quantities in the different operating modes. communication session count.Technical manual Technical manual A-1 A Glossary * button. The push button that activates the alternate mode. see current transformer ratio. Keys allow addition of new functionality to an existing meter for an additional fee. current transformer ratio. the present maximum demand is added to the sum of the previous maximum billing period demand values. see average power factor. For example. Calculated once every second. Short for binary digit. complete LCD test. A system combining hardware and software to upgrade existing A1800 ALPHA meters. Information regarding one parameter occurring at the same time as another. The operating mode in A1800 ALPHA meters used to display a second set of display quantities on the LCD. The number of data-altering communications occurring since the A1800 ALPHA meter was last programmed or a clear of the values and status. This confirms that all segments are operating properly. Upon a demand reset. A display showing 8 in all the display areas and all identifiers on the LCD turned on. Alpha Keys. bit. The measured quantities recorded and stored by the meter for use in billing the consumer. A display technique used with demand calculations and similar to cumulative demand except continuous cumulative demand is updated constantly. A display technique used with demand calculations. continuous cumulative. The average power computed over a specific time. Demand interval must be evenly divisible into 60 minutes. This memory retains all information even when electric power is removed from the circuit. demand forgiveness. demand interval. Power measured over time. demand threshold. Any value available for display on the LCD. demand reset. Used to specify the energy delivered (provided) to an electric service. The number of minutes that demand will not be calculated following a recognized power outage. An EOI indicator is on the LCD and an optional relay can be supplied to provide an EOI indication. The present value of demand which when reached initiates a relay closure or other programmed action.Technical manual A-2 data-altering communication. display quantities read from the meter LCD must be manually multiplied by this value to yield proper readings. event log. EEPROM. display quantity. The time period over which demand is calculated. end of interval. energy. The act of resetting the present maximum demand to zero. demand reset date. Used when the transformer factor is larger than can be stored within the A1800 ALPHA meter. see delivered. The indication that the end of the time interval used to calculate demand has occurred. demand. Acronym for electrically erasable programmable read only memory. The code indicates a condition or conditions that can adversely affect the proper operation of the meter. see end of interval. demand reset count. The method by which the meter displays an error message which consists of E and numeric codes. The date of the last demand reset. The total number of demand resets since the meter was last programmed. Glossary . When programmed with Elster meter support software for an external display multiplier. This provides a time period immediately following the restoration of power during which startup power requirements will not be included in the calculated demand. The event log provides a record of entries that date and time stamp specific events such as: • power outages • demand resets • entering test mode • time changes external display multiplier. delivered. Any communication that performs any of the following actions: • writes to a meter table • clears data • resets log pointers or data set pointers • resets the demand • performs a self read • performs a season change del. error display. EOI. kW overload value. . The LCD allows metered quantities and other information about the A1800 ALPHA meter and installed service to be viewed. four quadrant metering. Meter readings will need to be increased by the transformer ratios to reflect the energy and demand values on the primary side of the instrument transformer. Four quadrant metering quantity relationships kvar Delivered Lag Q2 Q2 Q1 Q1 Q3 Q3 Q4 Q4 Lead kVA Delivered kW Delivered kVA Received kW Received Lag Lead kvar Received IC. see load profile. line frequency. when exceeded. will cause the display of the kW overload warning message. see integrated circuit. liquid crystal display. Display quantities are programmable through Elster meter support software. The frequency of the AC current on the transmission line. On default the line frequency is 50Hz. Generally used to reference the custom meter circuit used in the A1800 ALPHA meter for per phase voltage and current sampling plus energy measurements.Technical manual A-3 Glossary factory default. Used to describe a relay dedicated to operate based upon entering a specific TOU rate period or when a demand threshold is reached. Ke. integrated circuit. see liquid crystal display. The smallest discrete amount of energy available within the meter. LCD. It is the value of a single pulse used between the meter IC and the microcontroller. often used in timekeeping applications in lieu of the internal oscillator. See Figure A-1 for an illustration of energy relationships for delivered and received real power (kW). LP. instrument transformer. see load control. LC. Figure A-1. The kW threshold which. Operating parameters that are programmed into the meter at the factory and assure that the meter is ready for correct energy measurement when installed. A transformer used to reduce current and voltage to a level which does not damage the meter. and reactive power (kVAR). load control. apparent power (kVA). program change date.Technical manual A-4 load profiling. The default operating mode for the A1800 ALPHA meter. Load profiling data provides a 24 hour record of energy usage for each day of the billing period. previous season data. repeated pattern. The date when the meter program was last changed. Pulses per equivalent disk revolution. 1 revolution is equal to 1 Kh period. Used to describe the billing data for the season preceding the present billing season. normal mode displays billing data on the LCD following a programmed sequence. TOU meter. P/R. primary rated. A condition where the energy and demand as measured by the meter are increased by the current and voltage transformer ratios. normal mode. self read. see pulse ratio. See also previous billing data. The highest demand calculated during any demand interval over a billing period. A relay used with the meter to provide output pulses from the meter to an external pulse collector. Each pulse represents a specific amount of energy consumption. received. Typically. Display quantity that shows the cumulative total outage time in minutes. See also self read. microcontroller. A single chip that contains the following components: • main processor • RAM • ROM • clock • I/O control unit nonrecurring dates. optical port. A meter that records energy usage and demand data on a time-of-use basis. pulse ratio. The operating mode of the meter in which full reprogramming of metrological parameters is permitted. previous billing data. TOU. Meter data will reflect the energy and demand actually transferred on the primary side of the instrument transformers. Used to describe the billing data recorded at the demand reset. Holidays or other specific dates that are not based upon a predictable. recurring dates. pulse relay. tariff data. The capturing of current billing data and storing it in memory. every set number of days. A photo-transistor and an LED on the face of the meter that is used to transfer data between a computer and the meter via pulses of light. Used to specify the energy received by the utility at an electric service. outage log. Load profiling records energy usage per a specific time interval while the meter is energized. see time-of-use. or command by Elster meter support software. rec. On ALPHA meters. maximum demand. Self reads are scheduled events that can be triggered by the specific day of month. program mode. Holidays or other special dates that occur on a predictable basis. See billing data. Glossary . see received. transformer-rated. timekeeping. the constant represents the energy equivalent to one revolution of an electromechanical meter.Technical manual A-5 test mode. For example. When test mode is exited. see voltage transformer ratio. See also timekeeping.000 V to 120 V would have a voltage transformer ratio of 100:1. voltage transformer ratio. The maximum current of a transformer-rated A1800 ALPHA meter is typically 10 A. watthour constant. the accumulated test data is discarded and the original billing data is restored. A billing rate that records energy usage and demand data related to specific times during the day. time-of-use. The ability of the meter to keep a real time clock. The TEST identifier will flash while the test mode is active. The ratio of primary voltage to secondary voltage of a transformer. The test mode stores billing data in a secure memory location while the meter measures and displays energy and demand data for testing purposes. including date and time. Glossary . 12. Historically. A meter designed to work with current or voltage transformers. VTR. A meter constant representing the watthours per output pulse on the LED. Technical manual A-6 Glossary . A1800 ALPHA meter LCD Low battery indicator Phase indicators (3) Error/warning indicator Energy direction indicators Quantity identifier Alternate mode indicator Comm. display indicators indicates whether the meter is currently doing the following: • accumulating in tariff (T1 . port indicator Display quantity Power/energy units identifier Tariff indicators 1 to 4 (left to right) Reserved EOI indicator Test mode indicator Cover removed indicator LC indicator Table B-1. See “Indicators and controls” on page 3-1 for more detailed information on the LCD regions. The A1800 ALPHA meter supports up to 64 quantities for display on the LCD.T4) • has reached the end of an interval (EOI) • compensating for transformer line loss (LC) • indicating that either the terminal cover or the meter cover has been removed • is operating in test mode (see “Test mode” on page 3-8) . The LCD can be divided into different regions. an identifier can be assigned to most quantities. or COM 2 power/energy units identifier indicates the unit of measurement for the quantity currently displayed on the LCD. LCD regions Item Description quantity identifier identifies the displayed quantity. COM 1. the identifiers are fixed.Technical manual Technical manual B-1 Display table B Display table Display format Displayable items are described in “Display list items” on page B-2. For instrumentation quantities. Using Elster meter support software. alternate display indicator indicates that the meter is currently displaying items in the alternate display list (see “* button” on page 3-5) active COM port indicators indicates that a communication session is in progress and the communication port that is being used: either COM 0. as described in Table B-1. Figure B-1. • If an indicator is blinking. while reverse energy flow is energy received from the consumer load) error indicator indicates either of the following: • flashes when any error flag is set • remains on if a displayable warning flag is set and no error exists low battery indicator if the indicator is turned on. then that phase voltage is either missing or below the defined threshold for voltage sag detection. and Line 3. L2. • If the indicators are on. and L3 (Line 1. and test mode are programmed from the 64 available items. the battery warning flag has been set. alternate mode. and ] (right bracket) Additional display items may also be available depending upon the version of Elster meter support software. [ (left bracket). These digits are also used to report the following: • operational errors • system instrumentation and service test errors • warnings • communication codes display identifiers more precisely identifies the information presented on the LCD. LCD regions Item Description display quantity Shows metered quantities or other displayable information.Technical manual B-2 Table B-1. From 3 to 8 total digits with up to 9 decimal places can be used. * (asterisk). The A1800 ALPHA meter LCD is capable of supporting the following characters and symbols: • all numbers (0 to 9) • all Latin-based alphabetical characters • symbols such as ° (degree). then all phase voltages are present. See the software documentation for a list of the displayable items. energy direction indicators indicates the directions of active (P) and reactive (Q) energy flow (positive energy flow is energy delivered to the consumer load. Line 2. The display format for all displayable items can be programmed using Elster meter support software. respectively) correspond to a phase voltage present on the A1800 ALPHA meter connections. Displayable items can be grouped into the following categories: • LCD test • general meter information • meter configuration • status • metered quantities • average power factor • coincident demand and power factor Display table . Display list items The display list items for the normal mode. phase indicators L1. a Any alphanumeric character displayable on the LCD. Figure B-2. represents testing in progress * asterisk. etc. represents time in hours (01 to 24) mm Numeric character. LCD all segment test + Q -P +P . represents two digit year (00 to 99) LCD test The A1800 ALPHA meter tests the LCD by displaying all the identifiers. represents month (01 to 12) x Any numeric character. separates time units (hh:mm). Table B-2. See “Display format” on page B-1 for more information. Decimal - hyphen. The following sections describe the default behavior of the A1800 ALPHA meter display. represents time in minutes (00 to 59) MM Numeric character. dd Numeric character.Technical manual B-3 Display table • system instrumentation • system service test • errors and warnings • communication codes Default display formats The display areas on the LCD (such as the display quantity and display identifier) are programmable through Elster meter support software. Characters in display quantity examples Character Represents Blank (space) . ss Numeric character. See Table B-2 for a description of some of the special characters that have been used in the display quantity examples. represents all 16 character segments on : colon. represents day (01 to 31) H Indicates the day type is holiday hh Numeric character. represents time in seconds (00 to 59) YY Numeric character.Q L1 L2 L3 COM 0 1 2 . as shown in Figure B-2. The meter tests the LCD for 3 seconds after power up. Display description Display quantity Quantity ID Identifier String 1 [Account:1] aaaaaaaa ID 1-1 of 4 Identifier String 1 [Account:2] aaaaaaaa ID 1-2 of 4 Identifier String 1 [Account:3] aaaa ID 1-3 of 4 Identifier String 1 [Account:4] ID 1-4 of 4 Identifier String 2 [Meter ID:1] aaaaaaaa ID 2-1 of 4 Identifier String 2 [Meter ID:2] aaaaaaaa ID 2-2 of 4 Identifier String 2 [Meter ID:3] aaaa ID 2-3 of 4 Identifier String 2 [Meter ID:4] Meter type Units ID ID 2-4 of 4 A1800 TYPE Firmware product xxx FW Firmware version xxx FWV Firmware revision xxx FWR Hardware version xxx HDWV Hardware revision xxx HDWR DSP code xxx DSP DSP code revision xxx DSPR Meter Programmer ID xxxxxxxx LCD test [all segment test] ******* ******** [all segments] Display quantity Quantity ID Units ID Program ID xxxxxxxx PRG ID Pulse ratio (P/R) x.Technical manual Display description LCD test [all segment test] B-4 Display table Display quantity Quantity ID Units ID ******* ******** [all segments] General meter information General meter information quantities are items that are not associated with any particular pulse or instrumentation source.xxx imp/kWh Current transformer (CT) ratio xxxxxxxx CT Voltage transformer (VT) ratio xxxxxxxx VT Demand interval .normal mode xxxxxxxx INTERV Demand interval .test mode xxxxxxxx INTERVT Watthours per pulse (Ke) xxxxxxxx Wh/Imp Meter Kh xxxxxxxx Kh Transformer factor (CT × VT) xxxxxxxx CTxVT External multiplier xxx.xxxxx ExtMult Meter configuration Display description .xxxxxxx P/R Pulse output ratio [imp/kWh] xxxxx. Technical manual Display description B-5 Display table Display quantity Quantity ID xxxxx.xxx DmdOvld Display quantity Quantity ID Communication session count (port 1) xxxxxxxx Com1No Communication session count (port 2/optical) xxxxxxxx Com2No Days since demand reset xxxxxxxx ResDays Days since input pulse xxxxxxxx ImpDays Number of manual demand resets xxxxxxxx RstPress Number of all demand resets xxxxxxxx DmdRes Power outage count xxxxxxxx Outages Initial remote baud (port 1) xxxxxxxx COM1bps Initial remote baud (port 2) xxxxxxxx COM2bps Transformer Loss Comp Status xxxxxxxx Demand overload value Units ID Status Display description TRueQ Status (On/Off) On Off Outage Log Program Change Date (port 1) MM:dd:YY Program Change Date (port 2/optical) MM:dd:YY Last Elster configuration change date MM:dd:YY CnfDate Demand reset date MM:dd:YY DmdRes Last power outage start date MM:dd:YY Outage Last power outage start time hh:mm Outage Last power outage end date MM:dd:YY Restore Last power outage end time hh:mm Restore Present date MM:dd:YY Date Present time hh:mm Time Present day of week aaaaaaaa Day Present season aaaaaaaa Season MM:dd:YY TblActv hh:mm Sub Int Pulse count for quantity (Wh-delivered) xxxxxxxx ImpWhD Pulse count for quantity (alternate-delivered) xxxxxxxx ImpE2D Pulse count for quantity (Wh-received) xxxxxxxx ImpWhR Pulse count for quantity (alternate-received) xxxxxxxx ImpE2R Date of last pending table activation Time Left in interval Self Read Date MM:dd:YY Effective Date for Rates/Special Dates MM:dd:YY Number of Write Sessions (port 1) xxxxxxxx Number of Write Sessions (port 2/optical) xxxxxxxx Units ID . Meters with the optional 4-quadrant metering can measure eight quantities. Display description Display ID Display quantity Quantity ID Units ID Current billing. Previous season. the LCD will use the last two characters of the quantity identifier to indicate the last self read number (01 to 35). Previous billing. Last self read Total energy xxxxxxxx Deliver Receive Q1 Q2 Q3 Q4 kWh/kVAh/kvarh Maximum demand xxxxxxxx Del MD Rec MD Q1 MD Q2 MD Q3 MD Q4 MD kW/kVA/kvar Date of maximum demand MM:dd:YY MD Date Time of maximum demand hh:mm MD Time xxxxxxxx Del CMD Rec CMD Q1 CMD Q2 CMD Q3 CMD Q4 CMD kW/kVA/kvar Cumulative demand Tariff 1 energy T1 xxxxxxxx Deliver Receive Q1 Q2 Q3 Q4 kWh/kVAh/kvarh Tariff 1 maximum demand T1 xxxxxxxx Del MD Rec MD Q1 MD Q2 MD Q3 MD Q4 MD kW/kVA/kvar Tariff 1 date of maximum demand T1 MM:dd:YY MD Date Tariff 1 time of maximum demand T1 hh:mm MD Time Tariff 1 cumulative demand T1 xxxxxxxx Del CMD Rec CMD Q1 CMD Q2 CMD Q3 CMD Q4 CMD kW/kVA/kvar . The A1800 ALPHA meter can display the available metered quantities for each meter type. To indicate a self read quantity.Technical manual B-6 Display table Metered quantities A1800 ALPHA meters can measure two quantities. Previous billing.Technical manual B-7 Display description Display ID Display table Display quantity Quantity ID Units ID Current billing. Previous season. Last self read Tariff 2 energy T2 xxxxxxxx Deliver Receive Q1 Q2 Q3 Q4 kWh/kVAh/kvarh Tariff 2 maximum demand T2 xxxxxxxx Del MD Rec MD Q1 MD Q2 MD Q3 MD Q4 MD kW/kVA/kvar Tariff 2 date of maximum demand T2 MM:dd:YY MD Date Tariff 2 time of maximum demand T2 hh:mm MD Time Tariff 2 cumulative demand T2 xxxxxxxx Del CMD Rec CMD Q1 CMD Q2 CMD Q3 CMD Q4 CMD kW/kVA/kvar Tariff 3 energy T3 xxxxxxxx Deliver Receive Q1 Q2 Q3 Q4 kWh/kVAh/kvarh Tariff 3 maximum demand T3 xxxxxxxx Del MD Rec MD Q1 MD Q2 MD Q3 MD Q4 MD kW/kVA/kvar Tariff 3 date of maximum demand T3 MM:dd:YY MD Date Tariff 3 time of maximum demand T3 hh:mm MD Time Tariff 3 cumulative demand T3 xxxxxxxx Del CMD Rec CMD Q1 CMD Q2 CMD Q3 CMD Q4 CMD kW/kVA/kvar Tariff 4 energy T4 xxxxxxxx Deliver Receive Q1 Q2 Q3 Q4 kWh/kVAh/kvarh Tariff 4 maximum demand T4 xxxxxxxx Del MD Rec MD Q1 MD Q2 MD Q3 MD Q4 MD kW/kVA/kvar . meters with the 4-quadrant metering option can measure four coincident quantities.xxx CoinPF kW/kVA/kvar Tariff 2 coincident power factor T2 x.xxx CoinPF kW/kVA/kvar Tariff 3 coincident power factor T3 x.xxx CoinPF kW/kVA/kvar . Display description Display ID Average power factor Tariff 1 average power factor T1 xxxxxxxx AvgPF Tariff 2 average power factor T2 xxxxxxxx AvgPF Tariff 3 average power factor T3 xxxxxxxx AvgPF Tariff 4 average power factor T4 xxxxxxxx AvgPF Coincident demand and power factor The A1800 ALPHA meters can measure two coincident quantities. the following items are available for display. Previous season.Technical manual B-8 Display description Display ID Display table Display quantity Quantity ID Units ID Current billing. the following items is available for display: Display description Display ID Coincident demand Display quantity Quantity ID Units ID xxxxxxxx CoinDmd kW/kVA/kvar Tariff 1 coincident demand T1 xxxxxxxx CoinDmd kW/kVA/kvar Tariff 2 coincident demand T2 xxxxxxxx CoinDmd kW/kVA/kvar Tariff 3 coincident demand T3 xxxxxxxx CoinDmd kW/kVA/kvar Tariff 4 coincident demand T4 xxxxxxxx CoinDmd kW/kVA/kvar x.xxx CoinPF kW/kVA/kvar Coincident power factor Tariff 1 coincident power factor T1 x. Coincident quantities are configurable with Elster meter support software to be any demand or average power factor value captured at the time of a maximum demand value. Additionally. For each coincident value. Previous billing. Last self read Tariff 4 date of maximum demand T4 MM:dd:YY MD Date Tariff 4 time of maximum demand T4 hh:mm MD Time Tariff 4 cumulative demand T4 xxxxxxxx Del CMD Rec CMD Q1 CMD Q2 CMD Q3 CMD Q4 CMD kW/kVA/kvar Display quantity Quantity ID Units ID xxxxxxxx AvgPF Present Interval (current billing only) Previous Interval (current billing only) Average power factor For each average power factor.xxx CoinPF kW/kVA/kvar Tariff 4 coincident power factor T4 x. xx° L3 Line 1 voltage phase angle xxx.x°A L2 Line 3 current phase angle xxx.xxxkV L1 Line 2 voltage (secondary) Line 2 voltage (primary) xxx.xxx L2 kW MW Line frequency Units ID .xx L2 COS Line 3 power factor xx.xxx A xxx.xx°V L1 Line 2 voltage phase angle xxx.xx L1 COS Line 2 power factor xx.x°V L3 Line 1 current phase angle xxx.xxxkA L3 Line 1 power factor xx. Display description Display quantity Quantity ID xx.xx°V L2 Line 3 voltage phase angle xxxx.xx L3 COS Line 1 power factor angle xxx.xxxkV L2 Line 3 voltage (secondary) Line 3 voltage (primary) xxx.xx° L1 Line 2 power factor angle xxx.xxx L1 kW MW Line 2 kW (primary) Line 2 kW (secondary) xxxx.xxxx xxx. See “System instrumentation” on page 4-1 for a listing of the instrumentation quantities that can be displayed.xxHz L123 Line 1 voltage (secondary) Line 1 voltage (primary) xxx.xxx A xxx.xxxkV L3 Line 1 current (secondary) Line 1 current (primary) xxx.xxxkA L2 Line 3 current (secondary) Line 3 current (primary) xxx.xxx V xxx.x°A L1 Line 2 current phase angle xxx.xx° L2 Line 3 power factor angle xxx.xxxkA L1 Line 2 current (secondary) Line 2 current (primary) xxx.xxx V xxx.Technical manual B-9 Display table Cumulative demand The A1800 ALPHA meter records either the cumulative or continuous cumulative demand.x°A L3 Line 1 kW (primary) Line 1 kW (secondary) xxxx. Display description Display ID Cumulative demand Display quantity Quantity ID Units ID xxxxxxxx CumDmd kW/kVA/kvar Tariff 1 cumulative demand T1 xxxxxxxx CumDmd kW/kVA/kvar Tariff 2 cumulative demand T2 xxxxxxxx CumDmd kW/kVA/kvar Tariff 3 cumulative demand T3 xxxxxxxx CumDmd kW/kVA/kvar Tariff 4 cumulative demand T4 xxxxxxxx CumDmd kW/kVA/kvar System instrumentation The A1800 ALPHA meter can display system instrumentation quantities.xxx A xxx.xxx V xxx.xxxx xxx. xxx L123 kVA MVA xx.xxxkA xxx.xx%A L2.xxxx xxx.xxxx xxx.xxx L3 kVA MVA System kW (primary) System kW (secondary) xxxx.COS xx.xxxx xxx.xxx L123 kVA MVA xx.x V L3 H1 Line 1 fundamental current magnitude (primary) Line 1 fundamental current magnitude (secondary) xxx.xxx L123 kvar Mvar System kVA (primary) (vectorial) System kVA (secondary) (vectorial) xxxx.xxx L123 kW MW System kvar (primary) (arithmetic) System kvar (secondary) (arithmetic) xxxx.xxxx xxx.xxxx xxx.xxxkV xxx.xxx V xxx.COS xx.H2-15 Line 1 current % total harmonic distortion (THD) xx.xxxx xxx.xx L123.xx%A L3.xx%V L3.xxx L2 kVA MVA Line 3 kVA (primary) Line 3 kA (secondary) xxxx.xxxx xxx.xxx L1 kVA MVA Line 2 kVA (primary) Line 2 kA (secondary) xxxx.xkV L1 H1 Line 2 fundamental voltage magnitude (primary) Line 2 fundamental voltage magnitude (secondary) xxx.H2-15 Line 2 voltage % total harmonic distortion (THD) xx.x V L2 H1 Line 3 fundamental voltage magnitude (primary) Line 3 fundamental voltage magnitude (secondary) xxx.H2-15 Line 3 voltage % total harmonic distortion (THD) xx.x A L1 H1 System power factor (arithmetic) System power factor angle (arithmetic) System power factor (vectorial) System power factor angle (vectorial) .xxxx xxx.xx A L3 TDD Line 1 fundamental voltage magnitude (secondary) Line 1 fundamental voltage magnitude (primary) xxx.xx%A L1.xx ° L123 Line 1 voltage % total harmonic distortion (THD) xx.xxxx xxx.xxxkV xxx.xx ° L123 System kvar (primary) (vectorial) System kvar (secondary) (vectorial) xxxx.H2-15 Line 2 current % total harmonic distortion (THD) xx.xx A L1 TDD Line 2 total demand distortion (TDD) xx.xxxx xxx.xxx L123 kvar Mvar System kVA (primary) (arithmetic) System kVA (secondary) (arithmetic) xxxx.xx L123.xxx L1 kvar Mvar Line 2 kvar (primary) Line 2 kvar (secondary) xxxx.Technical manual B-10 Display description Display table Display quantity Quantity ID Units ID Line 3 kW (primary) Line 3 kW (secondary) xxxx.H2-15 Line 1 total demand distortion (TDD) xx.xxx L3 kvar Mvar Line 1 kVA (primary) Line 1 kA (secondary) xxxx.H2-15 Line 3 current % total harmonic distortion (THD) xx.xxx L3 kW MW Line 1 kvar (primary) Line 1 kvar (secondary) xxxx.xx A L2 TDD Line 3 total demand distortion (TDD) xx.xxxx xxx.xxxx xxx.xx%V L2.xx%V L1.xxx L2 kvar Mvar Line 3 kvar (primary) Line 3 kvar (secondary) xxxx. 15th) (primary) Line 2 harmonic current distortion (2nd .xxxkA xxx.15th) (primary) Line 1 harmonic current distortion (2nd .15th) (secondary) xxx.xxxkA Units ID xxx.x V L1 H2 Line 2 2nd harmonic voltage magnitude (primary) Line 2 2nd harmonic voltage magnitude (secondary) xxx.xx%V L1 H2 Line 2 2nd harmonic voltage % distortion xx.15th) (secondary) xxx.xxxkV xxx.Technical manual B-11 Display description Display table Display quantity Quantity ID Line 2 fundamental current magnitude (primary) Line 2 fundamental current magnitude (secondary) xxx. Display description Display quantity Quantity ID Service Voltage Test -------- TEST V xxxxxxxx SE Service Current Test OK -------- TEST I System Service Type xxx 4Y xxx 3 xxx 1L L1-2-3 L3-2-1 [xxx 4Y] [xxx 3] [xxx 1L] L1-2-3 L3-2-1 System Test Error Currently locked service Units ID .xxxkA xxx.xxxkA xxx.xxxkV xxx. See “System service tests” on page 4-5 for more information.x V L3 H2 Line 1 2nd harmonic current magnitude (primary) Line 1 2nd harmonic current magnitude (secondary) xxx.xxxkA L1 H2-15 Line 2 harmonic current distortion (2nd .x A L3 H1 Line 1 2nd harmonic voltage magnitude (primary) Line 1 2nd harmonic voltage magnitude (secondary) xxx.x A L3 H2-15 xxx.xx%V L3 H2 Line 1 harmonic current distortion (2nd .xxxkA Line 3 harmonic current distortion (2nd .15th) (secondary) xxx.x V L2 H2 Line 3 2nd harmonic voltage magnitude (primary) Line 3 2nd harmonic voltage magnitude (secondary) xxx.15th) (primary) Line 3 harmonic current distortion (2nd .xxxkV xxx.xxxkA xxx.x A L1 H2 Line 2 2nd harmonic current magnitude (primary) Line 2 2nd harmonic current magnitude (secondary) xxx.x A L2 H1 Line 3 fundamental current magnitude (primary) Line 3 fundamental current magnitude (secondary) xxx.xxxkA xxx.x A L3 H2 Line 1 2nd harmonic voltage % distortion xx.xx%V L2 H2 Line 3 2nd harmonic voltage % distortion xx.x A L2 H2 Line 3 2nd harmonic current magnitude (primary) Line 3 2nd harmonic current magnitude (secondary) xxx.x A System service tests The A1800 ALPHA meter can display the validity of the electricity service where it is installed.x A L2 H2-15 xxx. Communication codes The A1800 ALPHA meter indicates the status of a communication session by displaying it on the LCD. See “Error codes” on page 6-2 and “Warning codes” on page 6-5 for more information. Display table . See “Communication codes” on page 6-8.Technical manual B-12 Errors and warnings The A1800 ALPHA meter displays error codes and warning codes as an indication of a problem that may be affecting its operation. Certification symbols Elster logo Year and place of manufacture .5 (reactive) and TU no. however. Figure C-1 is an illustration of a A1800 ALPHA nameplate for both transformer rated and direct connected meters.2S (active) and GOST no. Isolation Class 2 symbol Accuracy Class 0. Sample nameplates Elster Metronica style number LCD indcator labels LED pulse settings Voltage rating and frequency Nominal (max) current and frequency Accuracy Class 0. Accuracy Class 2 (reactive) and GOST no.Technical manual Technical manual C-1 Nameplate and style number information C Nameplate and style number information Nameplate The nameplate provides important information about the meter. Figure C-1. The nameplate can be configured to meet the needs of the utility company. Number of elements Pulse output settings Current and voltage transformer ratios Customer name or Elster Metronica on default Meter serial number and barcode Elster Metronica style number Voltage rating and frequency Certification symbols Elster logo Year and place of manufacture LCD indcator labels LED pulse settings Nominal (max) current and frequency Isolation Class 2 symbol Number of elements Pulse output settings Customer name or Elster Metronica on default Meter serial number and barcode Accuracy Class 1 (active) and GOST no. Figure C-2 is an example of a utility information card. Figure C-2. VT. Utility information card (direct connect rated) Nameplate and style number information . CT. Utility information card (transformer rated) CT A VT V imp/kWh(kVARh) Figure C-3.).Technical manual C-2 Utility information card The removable utility information card provides a place for the utility to enter meter sitespecific information (for example. etc. 2. If A1800 meter has not "Q" suffix it is instrumentation measurements without standardized error. multi-tariff) Both delivered and received energy metering А Both load and instrumentation profiling L X Extended memory. "W". Contact Elster Metronica for availability. 1 МB Instrumentation measurements with standardized error Q Loss compensation V Theft-resistant measurement of active energy М 02 Class 0. "М". 4-wire. direct connect meters A1800 ALPHA meter R(T) A18 Note: 1. then "В". If A1800 meter has not additional functions such as "А". 3-wire. "L".2S. "D". Style numbers are subject to change without notice.Р6 Pulse output relays (16) Both active and reactive energy metering. If A1800 meter has not RS485. "S" or "E" suffixs should not to be at nameplate. 4 delta) Three-Element (3-phase.5S. then these suffixs shuld not be at nameplate. direct connect meters 21 Class 1. "X". transformer rated meters 05 Class 0. "Q". .Technical manual C-3 Nameplate and style number information Style number information The following table lists the commonly used styles for the A1800 ALPHA meter and the options that are available. transformer rated meters 10 Class 1. multi-tariff (active energy metering only. Table C-2.5S. transformer rated meters 20 Class 0. wye) W Auxiliary Power Supply D LCD Backlight B Second communication port RS485 S Second communication port RS232 E Second communication port Ethernet G First communication port (RS485 or RS232) Р1. RS232 or Ethernet second communication ports. "V". Meter style numbers for the A1800 Alpha meter For example: А1802RALXQVM – Р4GB – DW – 4 А18 02 RALXQVM - P4 G B - D W - 4 3 Two-Element (3-phase. Technical manual C-4 Nameplate and style number information . Technical manual Technical manual D-1 D Wiring diagrams Refer to the wiring diagram on the nameplate of each meter for specific terminal assignments. Direct connected Figure D-1. All connections are equipped with combination-head screws that accept either a slotted or Phillips screwdriver. 4-wire wye or 4-wire delta Figure D-2. 3-wire delta or 3-wire network Wiring diagrams . 2-element. 3-element. transformer connected Figure D-4. sequential connection with 0. 4-wire current transformer. 3-element. 2-element. 3-wire delta.Technical manual D-2 CT-connected meters Figure D-3.4kV Wiring diagrams . Technical manual D-3 Wiring diagrams Figure D-5. sequential connection with grounded neutral . 3-element. sequential connection with insulated neutral and grounded “B” phasel Figure D-6. 4-wire instrument transformer. 4-wire instrument transformer. 3-element. instrument transformer connected with grounded “B” phase . 3-element. 3-wire delta. 3-element.Technical manual D-4 Wiring diagrams Figure D-7. 3-wire delta. transformer connected Figure D-8. 3-wire delta. 3-wire delta. current transformer. 2-element. current transformer.22kV with insulated neutral . 0. 3-element.Technical manual D-5 Wiring diagrams Figure D-9. 0.22kV with insulated neutral Figure D-10. 2-wire. 3-wire delta instrument transformer connected with grounded “B” phase Figure D-12. 3-element.Technical manual D-6 Wiring diagrams Figure D-11. transformer connected . 2-element. Operating characteristics Power supply burden Less than 3 W Per phase current burden Less than 0.2 % (IEC 62053-22) Reactive energy 2. 60 seconds 4 kV 12 kV @ 1.0 % (IEC 62053-23) 1 Actual accuracy is better than 0. 60 Hz1 ± 5 % Temperature range -40 °C to +65 °C Humidity range 0 % to 98% noncondensing 1 Contact Elster Metronica for availability. 50 Hz for 1 minute Continuous at Imax Temporary (0.5 % for 0.01 VA (transformer rated and direct connect-rated) 1 Per phase voltage burden 0.5 seconds) at 2000 % of Imax (transformer rated) ½ cycle at 30 × Imax (direct connect-rated) Operating ranges Voltage Nameplate nominal 58 V to 400 V Operating range 49 V to 528 V Auxiliary power supply range For AC power: 57 V rms to 240 V rms.008 W at 120 V 0.5 kV.5 % (IEC 62053-22) 1.03 W at 240 V 0.2/50 µs 450  (8 kV with option boards) 4 kV.Technical manual E-1 Technical specifications E Technical specifications Absolute maximums Continuous 528 VAC Surge voltage withstand Test performed Oscillatory (IEC 61000-4-12) Fast transient (IEC 61000-4-4) Impulse voltage test (IEC 60060-1) Technical manual Voltage AC voltage (insulation) test Current Results 2.2 % accuracy meters Conforms to IEC 62053-61 (Electricity Metering Equipment.0 % (IEC 62053-21) Accuracy Active energy 0. Power Consumption and Voltage Requirements) .04 W at 480 V 0. 115V (nominal) For DC power: 80 V to 340 V Current 0 A to 10 A (transformer rated) 0 A to 120 A (direct connect rated) Frequency Nominal 50 Hz. 3. The battery is not under load except when supercapacitor is discharged or when a programmed meter is stored for an extended period without line power.000 A (no current) No more than 1 pulse per quantity. Supercapacitor is expected to provide carryover power for all normal power outages for a period of at least 6 hours at +25 °C.800 bps Physical components meet IEC 62056-21 or ANSI C12. while conforming to IEC 62054-21 Outage carryover capacity LiSOCl2 battery rated 800 mAhr. conforming to IEC 62053 requirements Internal clock accuracy Better than 0.5 seconds/day (while powered). 5 years continuous duty at 25 °C. Communications rate Optical port 1200 to 28.6 V and shelf life of 15+ years.Technical manual E-2 Technical specifications General performance characteristics Starting current CT-connected 1 mA Direct-connected < 40 mA (Ib = 10A) Creep 0. . Based on this low duty cycle. see “Physical dimensions and mass” on page 2-18.200 bps Dimensions and mass For the dimensions and mass of the A1800 ALPHA meter.18 Serial ports 1200 bps to 19. the projected life of the battery in normal service is expected to be greater than 20 years. . 730-0281 E-mail: [email protected] Internet: www. Building 3 Moscow. 730-0286 Fax: +7 (495) 730-0283.ru .elster.izmerenie. 111141 Tel.© Elster Metronica OOO 10-2011 Printing in Russia # 22002/E Elster Metronica 1 Proyezd Perova Polya St.. Russia.: +7 (495) 730-0285. 9.