AMHHDC

Asset Metering Half Hourly Data Collector (Qualified)

AMVLP

Asset Metering Virtual Lead Party

BSCCo

Balancing and Settlement Code Company

CDCA

Central Data Collection Agent

CoP

Code of Practice

CT

Current Transformer

CTA

Compliance Testing Agent

HHDC

Half Hourly Data Collector (Qualified)

MD

Maximum Demand

ME

Metering Equipment

MID

Measuring Instruments Directive

MIR

Measuring Instruments Regulations

MOA

Meter Operator Agent

SMETS

Smart Metering Equipment Technical Specifications

SMRS

Supplier Meter Registration Service

SVA

Supplier Volume Allocation

VLP

Virtual Lead Party

WD

Working Day

Applicant

Person applying for Compliance and/or Protocol approval

Asset Meter

means a device for measuring Active Power and/or Active Energy

Asset Metering Equipment

has, for the purposes of this BSCP601, the meaning ascribed to that term in the Balancing and Settlement Code, but excluding voltage and current measurement transformers

BSCCo

The Balancing and Settlement Code Company

Compliance Testing

means the testing of Metering Equipment and Asset Metering Equipment in accordance with this BSCP601 to determine whether it conforms with the relevant Code of Practice to obtain approval from the Panel.

Compliance Testing Agent

The agent responsible for the testing of Metering Equipment and Asset Metering Equipment, accredited against an appropriate (as determined by BSCCo) body such as the UK Accreditation Service (UKAS).

Code of Practice One

means the latest version^§ of Code of Practice One - CODE OF PRACTICE FOR THE METERING OF CIRCUITS WITH A RATED CAPACITY EXCEEDING 100MVA FOR SETTLEMENT.

Code of Practice Two

means the latest version^§ of Code of Practice Two - CODE OF PRACTICE FOR THE METERING OF CIRCUITS WITH A RATED CAPACITY NOT EXCEEDING 100MVA FOR SETTLEMENT PURPOSES.

Code of Practice Three

means the latest version^§ of Code of Practice Three - CODE OF PRACTICE FOR THE METERING OF CIRCUITS WITH A RATED CAPACITY NOT EXCEEDING 10MVA FOR SETTLEMENT PURPOSES.

Code of Practice Five

means the latest version^§ of Code of Practice Five - CODE OF PRACTICE FOR THE METERING OF ENERGY TRANSFERS WITH A MAXIMUM DEMAND OF UP TO (AND INCLUDING) 1MW FOR SETTLEMENT PURPOSES.

Code of Practice Six

means the latest version^§ of Code of Practice Six - CODE OF PRACTICE FOR THE METERING OF ENERGY IMPORTS VIA LOW VOLTAGE CIRCUITS FUSED AT 100 AMPS OR LESS PER PHASE FOR SETTLEMENT PURPOSES.

Code of Practice Ten

means the latest version^§ of Code of Practice Ten - CODE OF PRACTICE FOR METERING OF ENERGY VIA LOW VOLTAGE CIRCUITS FOR SETTLEMENT PURPOSES.

Code of Practice Eleven

means the latest version^§ of Code of Practice Eleven - Code of Practice for the Metering of Balancing Services Assets for Settlement Purposes

Embedded Metering Device

Embedded Metering Device means an Asset Meter, measuring Active Power and/or Active Energy that is embedded within equipment used for other purposes (e.g. an EV charging unit or a small-scale domestic battery storage unit) and is not a dedicated meter, i.e. one whose primary purpose is to measure Active Power and/or Active Energy.

Instation

means a computer based system which sends data to, or receives data from Outstation Systems or Asset Metering Systems on a routine basis.

Interrogation Unit

means a Hand Held Unit “HHU” (also known as Local Interrogation Unit “LIU”) or portable computer which can program Metering Equipment or Asset Metering Equipment parameters and extract information from the Metering Equipment or Asset Metering Equipment and store this for later retrieval.

Metering Equipment

has, for the purposes of this BSCP601, the meaning ascribed to that term in the Balancing and Settlement Code, but excluding voltage and current measurement transformers

person

includes any individual, company, corporation, firm, partnership, joint venture, association, committee, organisation or trust (in each case, whether or not having separate legal personality).

Protocol

means a set of rules or procedures for transmitting data between a Meter, Asset Meter or Outstation and a data collection system used for collecting data from Settlement Metering Systems to exchange information.

Protocol Approval

means a process by which the Protocol implemented in a Qualified HHDC’s (and, where applicable, Qualified AMHHDC’s) data collection system is tested against a known version of the Protocol (e.g. the Meter, Asset Meter or Outstation manufacturer’s software) to confirm it has been correctly implemented in order to collect metered data from a Meter, Asset Meter or Outstation for Settlement purposes. The BSC Panel approves the protocol for use in Settlement in accordance with this BSCP601.

Settlement

has the meaning ascribed to that term in the Balancing and Settlement Code.

Smart Metering Equipment Technical Specifications

As defined in Section X Annex X-1 of the Balancing and Settlement Code.

Test Laboratory

means the testing body so agreed with BSCCo to perform Compliance Testing to this BSCP601

Type Approval

refers to the approval of a given meter types’ pattern or construction under Schedule 7 of the Electricity Act 1989 and supporting regulations, where used for billing. Meters were formally approved against the EU Measuring Instruments Directive (MID). From January 2021 new meter designs are approved under the Measuring Instruments Regulations (MIR). Meters outside the scope of the MID/MIR must be approved by the Office for Product Safety & Standards under national legislation.

UTC

means Co-ordinated Universal Time based on atomic clocks as distinct from Greenwich Mean Time (GMT).

2.1.1

At any time.

Submit Application for Protocol Approval and any supporting documentation.

Applicant

BSCCo

Notification of Metering Equipment or Asset Metering Equipment and HHDC Agent or AMHHDC Agent to be approved.

Form F601/ 03

Fax, Post.

2.1.2

Within 2 WD of receipt of 2.1.1 above.

Validate application.

BSCCo

Internal Process.

2.1.3

Within 5 WD of 2.1.1 above.

Notify Applicant of acceptance or rejection of Application.

If accepted, provide copy of testing schedule and notification of Application reference number.

BSCCo

Applicant

Protocol Approval test schedule and Application reference number.

E-mail, Fax, Post.

2.1.4

Within 10 WD of receipt of 2.1.3 above.

Agree any re-drafting of test schedule.

Applicant

BSCCo

Re-drafted schedule (if required).

E-mail, Fax, Post.

2.1.5

Within 5 WD of 2.1.4 above.

Arrange with nominated HHDC or AMHHDC to conduct testing and liaise with BSCCo to witness testing.

Applicant

HHDC or AMHHDC

BSCCo

As agreed.

2.1.6

Within 10 WD of 2.1.5 above.

Submit 2 Outstations and any software for testing to the nominated HHDC or AMHHDC.

Applicant

HHDC or AMHHDC

As agreed.

2.1.7

Within 10 WD of 2.1.5 above.

Undertake testing of Protocol in accordance with agreed Test Schedule.

HHDC or AMHHDC

BSCCo

Prepare and submit report including test results.

HHDC or AMHHDC

BSCCo

Test Report².

E-mail, Fax, Post.

2.1.8

Within 5 WD of 2.1.7 above and, where the HHDC or AMHHDC is not Qualified, once it is Qualified.

Notify Applicant of test result determination.

If testing successful, update Protocol Approval list (see section 3.2), notify Parties and Party Agents and issue certificate to Applicant.

BSCCo

Applicant

Parties

Party Agents

Form F601/02

Approval details.

Approval details.

E-mail, Fax, Post.

E-mail, Fax, Post, BSC Website.

2.2.1

At any time

Submit Application for Compliance Testing.

Applicant

BSCCo

Form F601/03

E-mail, Fax, Post.

2.2.2

Within 2 WD of receipt of 2.2.1 above.

Validate Application.

BSCCo

Internal Process.

2.2.3

Within 5 WD of 2.2.1 above.

Notify Applicant of acceptance or rejection of Application.

If accepted, provide copy of testing schedule and notification of Application reference number.

BSCCo

Applicant

Compliance test schedule and Application reference number.

E-mail, Fax, Post.

2.2.4

Within 10 WD of receipt of 2.2.3 above.

Agree any re-drafting to test schedule.

Applicant

BSCCo

Re-drafted schedule (if required).

E-mail, Fax, Post.

2.2.5

Within 10 WD of 2.2.4 above.

Agree Compliance Testing Agent with BSCCo.

Liaise with CTA to undertake Compliance testing.

Applicant

BSCCo

CTA

Notification of CTA.

E-mail, Fax, Post.

2.2.6

Within 3 Months of 2.2.5 above.

Undertake testing and submit report to BSCCo.

CTA

BSCCo

Compliance test report³.

E-mail, Fax, Post.

2.2.7

Within 5 WD of 2.2.6 above.

Notify Applicant of test result determination.

If testing successful, update Compliance Approval list (see section 3.2). Notify Parties and Party Agents of new approval and issue certificate of Compliance to Applicant.

BSCCo

Applicant

Parties

Party Agents

Form F601/01.

Approval details.

Approval details.

E-mail, Fax, Post.

E-mail, Fax, Post, BSC Website.

2.3.1

At any time

Submit notification of amendment to Metering Equipment, Asset Metering Equipment or Data Retrieval system for an existing Approval and agree impact of change.

Applicant

BSCCo

Details and impact of change.

E-mail, Fax, Post.

2.3.2

Within 30 WD of 2.3.1 above.

Consult with affected Parties (if required) and determine whether Approval for the amendment to Metering Equipment, Asset Metering Equipment or Data Retrieval system can be given.

BSCCo

Affected Parties

Details and impact of change.

As agreed.

2.3.3

Within 5 WD of 2.3.3 above.

Notify Applicant of determination and if new Approval given, update Approval list (see section 3.2).

BSCCo

Applicant

Parties

Party Agents

BSCCo determination.

Approval details.

Approval details

E-mail, Fax, Post, BSC Website.

REF

WHEN

ACTION

FROM

TO

INFORMATION REQUIRED

METHOD

2.4.1

At any time

Submit notification of approval issue.

Any party

BSCCo

Details and impact of issue.

E-mail, Fax, Post.

2.4.2

Within 30 WD of 2.4.1 above

Clarify and substantiate issue. Consult with and obtain additional information from affected parties (if necessary).

BSCCo

Affected parties

Additional Information.

As agreed.

2.4.3

Within 10 WD of 2.4.2 above

Agree findings with notifying party.

BSCCo

Notifying party

As agreed.

2.4.4

Next opportune meeting.

If issue substantiated, prepare and submit report with recommendations to the Panel.

BSCCo

Panel

Report to the Panel.

Internal Process.

2.4.5

Within 5 WD of 2.4.4 above

Notify Parties and Party Agents of Panel decision and if necessary update Compliance and/or Protocol Approval list.

BSCCo

Parties

Party Agents

Issue and Panel decision.

Circular.

REF

WHEN

ACTION

FROM

TO

INFORMATION REQUIRED

METHOD

2.5.1

At any time

BSCCo becomes aware of an issue related to a Meter Type calibration testing results

BSCCo

Calibration test results and analysis

Internal Process

2.5.2

Within 30 WD of 2.5.2

Clarify and substantiate issue. Consult with and obtain additional information from affected parties (if necessary).

BSCCo

Affected parties

Additional Information.

As agreed.

2.5.3

Within 5 WD of 2.5.2

Where required, notify Office of Product Safety and Standards of nature of issue and Meter Type

BSCCo

OPSS

Email

2.5.4

Following 2.5.3

Notify BSCCo of Office of Product Safety and Standards opinion/decision in relation to the Meter Type

OPSS

BSCCo

Email

2.5.5

Following 2.5.4 and for next opportune meeting.

If issue substantiated, prepare and submit report with recommendations to the Panel.

BSCCo

Panel

Report to the Panel.

Internal Process.

2.5.6

Within 5 WD of 2.5.6

Notify Parties and Party Agents of Panel decision and if necessary update Compliance Approval list.

BSCCo

Parties

Party Agents

Issue and Panel decision.

Circular.

2.6.1

At any time or on an annual basis

For all Metering Equipment and Asset Metering Equipment still manufactured and/or supported on the Compliance Approval list contact relevant manufacturer to confirm if still manufactured, supported and if any timescales to cease either manufacture or support for a product.

BSCCo

Applicant

Metering Equipment and Asset Metering Equipment type.

E-mail

2.6.2

Within 5 WD of 2.6.1.

Submit information requested in 2.6.1 for Metering Equipment and Asset Metering Equipment

Applicant

BSCCo

For each relevant Metering Equipment and Asset Metering Equipment type:

• Confirmation of continued manufacture;

• Confirmation of continued support;

• Proposed end date of manufacture; and

• Proposed end of support.

E-mail.

2.6.3

Within 5 WD of 2.6.2

Analyse information provided by manufacturer and make determination

BSCCo

As per submission in 2.6.2

Internal process

2.6.4

Within 5 WD of 2.6.3.

As required, where manufacturer confirms that Metering Equipment and Asset Metering Equipment is no longer manufactured or supported notify applicant of determination:

Update Compliance Approval list (see section 3.2). Notify Parties and Party Agents of update to approval and status; and where no longer supported confirm transition period to remove unsupported Meter/Outstation types.

BSCCo

Applicant

Parties

Party Agents

Meter/Outstation types

Meter/Outstation types

Transition period dates (if applicable)

E-mail.

2.7.1

As required

Submit notification of Protocol Approval removal request.

Party Agent

BSCCo

Metering Equipment and Asset Metering Equipment type(s) protocol no longer supported.

E-mail

2.7.2

Within 5 WD of 2.7.1

Analyse information provided by Party Agent and make determination

BSCCo

As per submission in 2.7.1

Internal process

2.7.3

Within 5 WD of 2.7.2.

As required, where Party Agent confirms that Protocol for Metering Equipment and Asset Metering Equipment is no longer supported notify Party Agent of determination:

Update Protocol Approval list (see section 3.2). Notify Parties and Party Agents of update to approval.

BSCCo

Party Agent

Parties

Party Agents

Meter/Outstation types

E-mail.

HHDC/ AMHHDC

System or Process⁴

Instation Version

Outstation Version

Section C: REQUEST FOR COMPLIANCE TESTING

Metering Equipment/Asset Metering Equipment Description

Manufacturer

Type

Serial No.

TYPE APPROVAL STATUS

APPROVED

IN PROGRESS

NONE

1

2

3

Note:

For Manufacturers or AMVLPs seeking Compliance Approval for Asset Metering Equipment the Asset Meter Type number (i.e. 1 to 5) must be included in the Applicable Codes of Practice for Metering Equipment and Asset Metering Equipment table.

I intend to provide Settlement Outstation Protocols, Asset Meter Protocols and Configuration Software to relevant Party Agents on request: tick as appropriate

Applicable Codes of Practice for Metering Equipment and Asset Metering Equipment Testing

Code of Practice *

ONE

TWO

THREE

FIVE

Issue

Code of Practice *

SIX

SEVEN

TEN

ELEVEN Asset Meter Type 1, 2, 3, 4, 5

Issue

BS 7856

‘Code of Practice for Design of Alternating Current Watt-Hour Meters for Active Energy (Classes 1 and 2)’

BS EN/IEC 62053-22

Electricity metering equipment (a.c.) - Particular requirements – Part 22: Static meters for active energy (classes 0.2S and 0.5S)

BS EN/IEC 62053-11

Electricity metering equipment (a.c.) - Particular requirements – Part 11: Electromechanical meters for active energy (classes 0.5, 1 and 2)

BS EN/IEC 62053-23

Electricity metering equipment (a.c.) - Particular requirements – Part 23: Static meters for reactive energy (classes 2 and 3)

BS EN/IEC 62056-21

Electricity metering – Data exchange for meter reading, tariff and load control – Part 21: Direct local data exchange

BS EN/IEC 62053-21

‘Alternating current static watt-hour meters for active energy (classes 1 and 2)’

BS EN/IEC 61000-4-3

Electromagnetic Compatibility (EMC) – Part 4-3: Testing and Measurement techniques – Radiated, radio-frequency, electromagnetic field immunity test.

Electricity Act 1989

‘Schedule 7, as amended by Schedule 1, to the Competition and Services (Utilities) Act 1992.’

Statutory Instrument 1998 No. 1565

‘The Meters (Approval of Pattern or Construction and Manner of Installation) Regulations 1998.’

Statutory Instrument 1998 No.1566

‘Electricity – The Meters (Certification) Regulations 1998.’

Statutory Instruments 2016 No.1153

Statutory Instruments 2019 No. 696

‘The Measuring Instruments Regulations 2016, as amended by the Product Safety & Metrology etc (Amendment etc.) Regulations (EU Exit) (SI 2019/696) legislation.’

‘The Product Safety and Metrology etc. (Amendment etc.) (EU Exit) Regulations 2019.’

(a)

i) Establish if the Pulse Multiplier can be of a value other than 1 (under any circumstance); and

ii) Where the value can be other than 1 record the values and circumstances.

001

(b)

establish the number and type of Measured Quantities available on the Meter;

002

(c)

if more than one Measured Quantity configuration is available, list all configurations;

003

(d)

confirm that a cumulative register display is available for each Measured Quantity (see also 3.4.12);

004

(e)

Import Active Energy is measured in kWh;

Import Reactive Energy is measured in kvarh;

005

(f)

Export Active Energy is measured in kWh;

Export Reactive Energy is measured in kvarh; and

006

(g)

confirm that Measured Quantities are available in both kilo and Mega values.

(CoPs 1, 2, 3 and 5)

007

(a)

confirm that a kW value is provided for each Demand Period for each Active Energy Measured Quantity; and kvar value is provided for each Demand Period for each Reactive Energy Measured Quantity.

008

(b)

Confirm that Reactive Import and Export quantities (kvar and kvarh) can be provided separately for both Import and Export Active Power conditions.

(CoP1, 2, 3 and 5)

009

(c)

Confirm that reactive quantities (kvar and kvarh) can be provided cumulatively as both Import and Export regardless of Active Power conditions.

010

(d)

where Active Import and Active Export values are provided confirm that each value is gross and recorded separately. (CoP3, 5, and 10); and

011

(e)

confirm that Demand Values are available in both kilo and Mega values.

(CoPs 1, 2, 3 and 5)

012

Tests shall be carried out at fundamental frequency (50Hz) to verify that the Active Energy measurements are within the limits shown in Table 1 below. The measurement uncertainty at fundamental frequency of the measurement system used shall not be greater than:

±0.01% (CoP1);

±0.05% (CoP2);

±0.1% (CoP3); or

±0.2% (CoP5).

013

Value of Current

(I)

Power factor

(Cos φ)

Percentage error limits¹⁰ for Meters of Class

For whole current Meters

For transformer operated Meters¹¹

0.2S

(CoP1)

0.5S

(CoP2)

0.5

(CoP2)

1

(CoP3)

2

(CoP5)

-

0.01 I_n ≤ I < 0.05I_n

1

±0.4

±1.0

-

-

-

-

0.05 I_n ≤ I ≤ I_max

1

±0.2

±0.5

-

-

-

-

0.02 I_n ≤ I < 0.1I_n

0.5 ind

0.8 cap

±0.5

±0.5

±1.0

±1.0

-

-

-

-

0.1 I_n ≤ I ≤ I_max

0.5 ind

0.8 cap

±0.3

±0.3

±0.6

±0.6

-

-

-

0.05 I_b ≤ I < 0.1 I_b¹²

0.02 I_n ≤ I < 0.05 I_n

1

-

-

±1.0

±1.5

±2.5

0.1 I_b ≤ I ≤ I_max

0.05 I_n ≤ I ≤ I_max

1

-

-

±0.5

±1.0

±2.0

0.1 I_b ≤ I < 0.2 I_b¹³

0.05 I_n ≤ I < 0.1 I_n

0.5 ind

0.8 cap

-

-

±1.3

±1.3

±1.5

±1.5

±2.5

-

0.2 I_b ≤ I ≤ I_max

0.1 I_n ≤ I ≤ I_max

0.5 ind

0.8 cap

-

-

±0.8

±0.8

±1.0

±1.0

±2.0

-

Tests shall be carried out at fundamental frequency (50Hz) to verify that the Reactive Energy measurements are within the limits show in Table 2 below. The measurement uncertainty at fundamental frequency of the measurement system used shall not be greater than ±0.4%.

(CoPs 1, 2, 3 and 5)

014

Value of Current

(I)

Sin φ

Percentage error limits10 for Meters of Class

Applicable BS EN Standard for Test Criteria

For whole current Meters

For transformer operated Meters

2

(CoP1 )

3

(CoPs 2, 3 and 5)

0.05 I_b ≤ I < 0.1 I_b

0.02 I_n ≤ I < 0.05 I_n

1

±2.5

±4.0

BS EN/IEC 62053-23

0.1 I_b ≤ I ≤ I_max

0.05 I_n ≤ I ≤ I_max

1

±2.0

±3.0

0.1 I_b ≤ I < 0.2 I_b

0.05 I_n ≤ I < 0.1 I_n

0.5 ind or cap

±2.5

±4.0

0.2 I_b ≤ I ≤ I_max

0.1 I_n ≤ I ≤ I_max

0.5 ind or cap

±2.0

±3.0

0.2 I_b ≤ I ≤ I_max

0.1 I_n ≤ I ≤ I_max

0.25 ind or cap

±2.5

±4.0

BS EN/IEC 62053-23

0.2 I_b ≤ I ≤ I_b

0.1 I_n ≤ I ≤ I_n

0.25 ind or cap

-

±10.0

BS EN/IEC 62053-23

^† Permission to reproduce extracts from BS EN 62053–22, BS EN 62053–11, BS EN 62053-21 and BS EN 62053–23 is granted by BSI. British Standards can be obtained in PDF or hard copy formats from the BSI online shop: www.bsigroup.com/Shop or by contacting BSI Customer Services https://shop.bsigroup.com/Contact-Us/

• This permission does not cover any other editions.

• On no account shall the extracts used be distributed as part of any other work not permitted under this licence.

• This permission relates to the extracts listed above. Where the standard is updated and/or if there is a requirement for further reproduction of extracts you will need to make a new application.

PERMISSION TO USE THE EXTRACTS LISTED IS GRANTED ONLY ON THE ABOVE CONDITIONS

Record the available range of measurement transformer compensation adjustment provided for both current and voltage measurements.

(CoPs 1, 2, 3 and 5)

015

Record the available range of power transformer compensation adjustment provided. (If this adjustment is recorded as part of test 3.4.9 above then record that no additional adjustment is available)

(CoPs 1, 2, 3 and 5)

016

(a)

record whether the Meter is of a Static or induction disc type;

017

(b)

record whether the Meter has an integral Outstation;

018

(c)

establish that the Active Energy Meter meets the requirements of:

i. CoP1 BS EN/IEC 62053-22 Class 0.2S;

ii. CoP2 BS EN/IEC 62053-22 Class 0.5S or BS EN/IEC 62053-11 Class 0.5;

iii. CoP3 BS EN/IEC 62053-21 Class 1;

iv. CoP5 BS EN/IEC 62053-21 Class 2 and BS 7856 Class 2; or

v. CoP10 SI 1998 No 1566 or SI 2016 No 1153.

019

(d)

establish whether the Import Active Energy Meter meets the requirements of Schedule 7 of the Electricity Act 1989;

020

(e)

establish that the Reactive Energy Meter meets the requirements of;

i. CoP1 BS EN/IEC 62053-23 Class 2;

ii. CoP2 BS EN/IEC 62053-23 Class 3;

iii. CoP3 BS EN/IEC 62053-23 Class 3; or

iv. CoP5 BS EN/IEC 62053-23 Class 3.

021

(f)

establish whether the number of measuring elements is one less or equal to the number of primary system conductors;

022

(g)

record whether provision has been made for the recording of measurement transformer ratios on the Meter’s name plate;

(CoPs 1, 2, 3 and 5)

023

(h)

if the Meter is a static Meter with combined display and/or Outstation, then confirm that the ratios can be displayed and downloaded during the interrogation process;

024

(i)

Also confirm that any compensation factors that have been applied for measurement transformer errors and/or system losses, and where this is a constant factor applied at security Level 3, can be similarly displayed and downloaded;

(CoPs 1, 2, 3 and 5)

025

(j)

confirm that the Meter includes a non-volatile Meter register of cumulative energy for each Measured Quantity;

026

(k)

confirm that the Meter Register(s) do not roll-over more than once within the normal reading cycle [90 days at full load]; and

(CoPs 1, 2, 3 and 5)

027

(l)

where the Meter is to be used with an external Outstation, confirm that the Meter is fitted with at least one output pulse facility for each Measured Quantity (two output pulse facilities are required in the case of CoP1).

(CoPs 1, 2, 3 and 5)

028

(a)

the total cumulative energy values for each Measured Quantity in actual scaled values and that such values are stored in non–volatile memory;

029

(b)

the current time and date;

030

(c)

the CT and/or VT ratios that have been programmed into the Meter;

031

(d)

any compensation factor applied for measurement transformer errors and/or system losses; and

(CoPs 1, 2, 3 and 5)

032

(e)

that, where the Meter is combined with the display and/or Outstation and a constant factor is applied, such factor is applied at security Level 3.

(CoPs 1, 2, 3 and 5)

033

(a)

the Maximum Demand (“MD”) for kW or MW (CoPs 1, 2, 3 and 5) per month;

034

(b)

the Maximum Demand (“MD”) for kW or MW (CoPs 1, 2, 3 and 5) for other programmable charging periods;

035

(c)

the Maximum Demand (“MD”) for kVA or MVA (CoPs 1, 2, 3 and 5) per month can;

036

(d)

the Maximum Demand (“MD”) for kVA or MVA (CoPs 1, 2, 3 and 5) for other programmable charging periods;

037

(e)

twice the kWh or MWh advance from the commencement of the current Demand Period;

(CoPs 1, 2, 3 and 5)

038

(f)

twice the kVAh or MVAh advance from the commencement of the current Demand Period;

(CoPs 1, 2, 3 and 5)

039

(g)

the cumulative Maximum Demand;

040

(h)

the number of Maximum Demand resets;

041

(i)

the multi rate display sequence, for at least 8 rates selectable over the calendar year;

042

(j)

whether a reverse running indication for Active Energy is provided. (CoPs 3 and 5);

043

(k)

the indicated Maximum Demand is re-settable at midnight of the last day of the selected charging period;

044

(l)

the indicated Maximum Demand is re-settable for a part of a charging period; and

045

(m)

any Maximum Demand manual reset button is sealable.

046

Establish whether the Meter is capable of providing different voltage free pulsed outputs for local use.

047

If test 047 is confirmed then confirm that the facilities meet the following requirements as shown in Table 3.

048

Requirement

Code of Practice

1

2

3

5

Number of Outputs

1 per Measured Quantity

1 per Measured Quantity

3 min

(See 3.4.13 (a))

3 min

(See 3.4.13 (a))

Pulse Rate

Min at full load 1000 per Demand Period

Min at full load 1000 per Demand Period

Between 0.1 and 2/ second

Between 0.1 and 2/ second

Nominal Pulse Duration (mS)

80

80

80

80

(a)

confirm that at least two of the outputs can be allocated to the Measured Quantities identified in {5.4.2}. (CoPs 3 and 5); and

049

(b)

confirm that one output can be allocated to the Demand Period reset (usually 30 minutes) within a tolerance of ±0.1% and a duration of between 0.5 and 10 seconds.

050

(a)

The Outstation has a unique Outstation identification code;

051

(b)

For Meters with integral Outstations an auxiliary terminal provides for the Outstation's energisation for remote interrogation purposes (CoP1). For Meters with integral Outstations record whether an auxiliary terminal provides for the Outstation’s energisation for remote interrogation purposes (CoP2);

052

(c)

Facilities are provided to select a relevant demand period from one of the following values: 30, 20, 15, 10 and 5 minutes with, in each case, one demand period ending on the hour.

053

(d)

The Outstation is capable of communicating with more than one Instation (not simultaneously and of similar type or otherwise);

054

(e)

It is possible to repeatedly retrieve data throughout the Outstation data storage period;

055

(f)

Any “read” operation does not alter or delete any stored metered data; and

056

(g)

The Outstation can provide all metered data stored from the time of commencement of any specified date upon request by the Instation during the data storage period of the outstation.

057

(h)

In addition, establish whether the Outstation is capable of sending metering data automatically (CoPs 5 and 10). If this test is satisfied then:

058

(i)

Verify that the metering data sent complies with section 3.4.22 ‘Level 1 Passwords’ of this test specification (CoPs 5 and 10); and

059

(j)

Establish whether the Outstation is capable of sending metering data on a daily basis as a minimum (CoPs 5 and 10).

060

(a)

from the beginning of the current Demand Period, twice the kWh or MWh (CoPs 1, 2, 3 and 5) is being registered in the kW or MW (CoPs 1, 2, 3 and 5) Maximum Demand register; and

061

(b)

from the beginning of the current Maximum Demand period, twice the kVAh or MVAh (CoPs 1, 2, 3 and 5) is being registered in the kVA or MVA (CoPs 1, 2, 3 and 5) Maximum Demand register.

062

(a)

each Demand Value is identifiable to its respective date and time; and

063

(b)

a storage capacity of 48 periods per day in accordance with Table 4 below is available for all Demand Values as integer multiples of kW or MW (CoPs 1, 2, 3 and 5);

064

Code of Practice

Minimum Storage Period(days)

1

90

2

90

3

90

5

90

10

90

(a)

for each of the initial five days, the sum of the Demand Values for each block of 48 half-hour periods are within 0.1% of the advance of the total cumulative register of the associated Meter for the same interval;

065

(b)

the value of any energy measured in a Demand Period, but not stored in that Demand Period are carried forward to the next Demand Period;

066

(c)

for each of the twenty days under test that the contents of the kW or MW (CoPs 1, 2, 3 and 5) data stored facility have been stored correctly; and

067

(d)

for separate Meter/Outstation combinations, that the Outstation registers can be set to match and increment with the Meter registers.

(CoPs 1, 2, 3 and 5)

068

(a)

on reaching maximum memory storage capacity, that any new data overwrites the oldest stored data; and

069

(b)

no other data has been altered or removed.

070

(a)

all stored data has been correctly stored and is not corrupt;

071

(b)

the Metering Equipment internal clock is accurate to within ±10 seconds¹⁴; and

072

(c)

partial Demand Values in which an Outstation supply failure and/or restoration occurs and any zero values associated with the Outstation supply failure are marked so that they can be identified by the Instation.

073

(a)

the Metering Equipment internal time clock is accurate to within ±10 seconds¹⁶; and

074

(b)

the duration of each Demand Period is within ±0.1% of 30 minutes, this being achieved by the comparison of stored energy values or pulse counts in each Demand Period.

075

Set the Metering Equipment internal time clock to five minutes slow with respect to UTC. Then synchronise the internal time clock using the remote Instation and check that the Demand Period has been marked with an alarm indication.

076

Repeat the synchronisation test using the Local Interrogation Unit and check that the Demand Period has been marked with an alarm indication.

077

(a)

disconnect one phase from the Metering Equipment and ensure that a phase failure has occurred and is assigned to the relevant Demand Period;

078

(b)

repeat the disconnection process for each of the remaining phases in separate Demand Periods;

079

(c)

repeat the disconnection process for combinations of multiple phase failure; and

080

(d)

verify phase failure alarm resets on restoration of normal supply after each test.

081

If battery fitted, establish the method of battery monitoring and test for alarms and indications tagged to the relevant Demand Periods, if necessary by disconnecting the battery.

082

For Outstations using other methods of time synchronisation, such as a Radio Teleswitch, confirm that any truncated or extended Demand Period is tagged with a separate alarm indication.

083

Using the Local Interrogation Unit access the local port and change data other than time and/or date. Confirm that the relevant Demand Period is tagged with a separate alarm indication.

084

Using the Instation to access the remote port, change data other than time and/or date. Confirm that the relevant Demand Period is tagged with a separate alarm indication.

085

Where an Active Energy reverse running display is provided, determine that the requirements of BS EN/IEC 62053-21 or BS EN/IEC 62053-22 as appropriate are met. Establish under what conditions the reverse running flag is activated and record those conditions. Tests should include single and polyphase power reversals and set the appropriate flag for the Demand Period affected (CoPs 3 and 5, and if fitted).

086

Test that upon return to normal power flow, the reverse running flag is no longer present in the unaffected Demand Period (CoPs 3 and 5, and if fitted).

087

Verify that two communications ports are available for interrogating the Outstation

088

(a)

The local port provides data to a Local Interrogation Unit via an opto port to BS EN/IEC 62056-21; or

089

(b)

The local port provides data to a Local Interrogation Unit via another type of port; and

090

(c)

Repeat collections of stored data are available throughout the storage period and verify that any “read” operation does not delete or modify any stored metering data.

091

(a)

The remote port is sealable; and

092

(b)

Repeat collections of stored data are available throughout the storage period and verify that any “read” operation does not delete or modify any stored metering data

093

(a)

For separate Outstations establish that a password is required to read or change any data.

(CoPs 1, 2, 3 and 5)

094

(b)

For integral Outstations establish that four¹⁷ discrete password controlled access levels are provided for both local and remote interrogation.

095

(c)

For alpha numeric character passwords, ensure that passwords are no less than six characters and no more than twelve characters long.

Ensure that passwords are formed from case insensitive or sensitive alpha characters (A to Z) and/or digits (0 to 9) and/or the underscore character (_); or

(CoPs 1, 2, 3 and 5)

096

(d)

For hexadecimal character passwords, ensure that passwords are no less than eight characters and no more than twelve characters long.

Ensure that passwords are formed from upper case hexadecimal characters (0 to F).

(CoPs 1, 2, 3 and 5)

097

(a)

Outstation ID;

098

(b)

all programmable Demand Values;

099

(c)

all programmable cumulative Measured Quantities;

100

(d)

the Maximum Demand for kW and/or kVA per programmable charging period;

101

(e)

the multi-rate cumulative Active Energy values;

102

(f)

the VT and CT transformer ratios, where appropriate;

103

(g)

(for combined Meter and Outstation only), the VT and CT transformer error correction factor and/or system loss factor applied as a constant factor to the entire dynamic range;

(CoPs 1, 2, 3 and 5)

104

(h)

all alarm indications; and

105

(i)

Outstation time and date

106

Establish that it is not possible to change any of the above values at Level 1 Password.

107

Using the Level 2 Password, establish that all the data listed at Level 1 can be retrieved and in addition that the following actions can be performed:

108

(a)

changes to time and date; and

109

(b)

resetting of all Maximum Demands.

110

Using the Level 3 Password, establish that all the functionality listed at Level 2 can be performed and in addition that the following programming can be performed:

111

(a)

Displays and Facilities as defined in clauses 3.4.12 ‘Displays {5.4.1}’ and 3.4.13 ‘Facilities {5.4.2}’ of this test specification;

112

(b)

measurement transformer ratios as defined in clause 3.4.11 ‘Meter {5.3}’ of this test specification;

113

(c)

(for combined Meter and Outstation only), the VT and CT transformer error correction factor and/or system loss factor applied as a constant factor to the entire dynamic range; and

(CoPs 1, 2, 3 and 5)

114

(d)

passwords for Levels 1, 2 and 3.

115

(e)

where applicable, confirm it is possible to programme the schedule for automated transfer of Level 1 metering data via Level 3 access (CoPs 5 and 10).

116

Establish that it is possible to read additional information within the Metering Equipment to enable the programmed information to be confirmed.

117

(a)

establish that all the functionality listed at Level 3 can be performed and in addition that the following alterations can be performed:

118

(b)

calibration of the Meter (only where the Meter is integral with the Outstation);

119

(b)

setting the measurement transformer ratios, where appropriate;

120

(d)

setting the measurement transformer error correction and/or system loss factors applied as a complex factor; and

121

(e)

programming the Level 3 & 4 Passwords.

122

(a)

calibration of the Meter (only where the Meter is integral with the Outstation);

123

(b)

setting the measurement transformer ratios, where appropriate; and

124

(c)

setting the measurement transformer error correction and/or system loss factors applied as a complex factor.

125

Using the Approved Protocol¹⁸, verify that the password offered determines the Level of access to the data within the Metering Equipment.

126

(a)

the illegal password counter resets to zero every hour on the hour change; and

127

(b)

after the seventh illegal password attempt entered between counter resets, that access is prohibited at all levels until the counter resets.

128

(a)

any stored data and time/date is not corrupted or has been destroyed; and

129

(b)

the metering accuracy remains within the requirements of clause 3.4.8 ‘Accuracy Requirements {5.3}’ of this test specification.

130

(a)

that without any current in the current circuits and the current terminals open circuit the application of the HF fields shall not produce a change in the Meter Register reading of more than 0.01kWh and the test output shall not produce a signal equivalent to more than 0.01kWh. (Where VT and CT connected Meter(s) is under test, equivalent scaled values should be used taking into account the transformer ratios); and

131

(b)

that with basic current Ib, and power factor equal to 1.0, at sensitive frequencies or frequencies of dominant interest, the variation of error does not exceed 3%.

132

(a)

any stored data is not corrupted or has been destroyed; and

133

(b)

the metering accuracy remains within the requirements of clause 3.4.8 ‘Accuracy Requirements {5. 3}’of this test specification.

134

Ensure that adequate sealing facilities are provided for Settlement requirements.

135

IEC 1334-4-41

Application Protocols: Distribution Line Message.

BS EN/IEC 62053-21

AC Static Watthour Meters for Active Energy (Class 1 and 2)

BS EN/IEC 62056-21

Data Exchange for Meter Reading, Tariff and Load Control. Direct Local Exchange.

Retail Energy Code Metering Operations Schedule

Sealing Requirements

BS EN/IEC 62053-21

Electricity metering equipment - Particular requirements – Part 21: Static meters for AC active energy (classes 0,5, 1 and 2)

BS EN/IEC 62053-22

Electricity metering equipment - Particular requirements - Part 22: Static meters for AC active energy (classes 0,1S, 0,2S and 0,5S)

BS EN 50470-3

Electricity metering equipment (a.c.). Particular requirements. Static meters for active energy (class indexes A, B and C)

BS EN/IEC 61000-4-3

Electromagnetic compatibility (EMC) - Part 4-3: Testing and measurement techniques - Radiated, radio-frequency, electromagnetic field immunity test

BS EN/IEC 62052-11

Electricity Metering Equipment – General Requirements, Tests and Test Conditions – Part 11: Metering equipment

BS EN/IEC 61557-12

Electrical safety in low voltage distribution systems up to 1000 V a.c. and 1500 V d.c. Equipment for testing, measuring or monitoring of protective measures. Performance measuring and monitoring devices (PMD)

BS EN/IEC 60688

Electrical measuring transducers for converting a.c. electrical quantities to analogue or digital signals

BS EN/IEC 62056-21

Electricity metering. Data exchange for meter reading, tariff and load control. Direct local data exchange

(a)

i) Establish if the Pulse Multiplier can be of a value other than 1 (under any circumstance); and

ii) Where the value can be other than 1 record the values and circumstances.

001

(b)

establish the number and type of Measured Quantities available on the Meter;

002

(c)

if more than one Measured Quantity configuration is available, list all configurations;

003

(d)

confirm if a display is fitted

004

(e)

confirm if a cumulative register display is available for each Measured Quantity (see also 3.6.12);

005

(f)

confirm if Import Active Energy is measured in either kWh or MWh;

006

(g)

confirm if Export Active Energy is measured in either kWh or MWh; and

007

(h)

confirm if Measured Quantities are available in kilo values for Asset Metering Type 3, 4 or 5 and Mega values for Asset Metering Type 1 or 2.

008

(a)

Confirm that a kW or MW value is provided for each Demand Period for each Active Energy Measured Quantity;

009

(b)

where Active Import and Active Export values are provided confirm that each value is gross and recorded separately; and

010

(c)

confirm if Demand Values are available in kilo values for Asset Metering Type 3, 4 or 5 and Mega values for Asset Metering Type 1 or 2.

011