northern power - northeast 2014

8/9/2019 Northern Power - Northeast 2014

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Northern Powergrid (Northeast) Ltd Registered Office: Lloyds Court, 78 Grey Street, Newcastle upon Tyne, NE1 6AF

Registered in England and Wales no. 2906593

Statement of Use of System Charging

Northern Powergrid (Northeast) Ltd

Final Notice

Effective from 1st April 2014

Version 1.0


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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0

Contents

1. Introduction 4

2. Charge Application and Definitions 6

Supercustomer Billing and Payment 6Supercustomer Charges 6Site-Specific Billing and Payment 7Site-Specific Billed Charges 7Time periods for half-hourly metered properties 8Time periods for half-hourly unmetered properties 9Application of Capacity Charges 9Chargeable Capacity 9Exceeded capacity 9Demand exceeded capacity 9Generation exceeded capacity 10

Standby Capacity for Additional Security on Site 10Minimum Capacity Levels 10Application of charges for excess reactive power 10Demand chargeable reactive power 11Generation chargeable reactive power 11Generation charges for pre-2005 Designated EHV Properties 12Provision of billing data 12Use of System Charges Out of Area 13Licensed Distributor Network Operator (LDNO) charges 13Third party access from exempt distribution networks 13

3. Schedule of Charges for use of the Distribution System 15

4. Schedule of Line Loss Factors 16

Role of Line Loss Factors in the Supply of Electricity 16Calculation of Line Loss Factors 16Line Loss Factor time periods 16Line Loss Factor tables 17

5. Notes for Designated EHV Properties 18

EDCM nodal costs 18Charges for New Designated EHV Properties 18Charges for amended Designated EHV Properties 18Demand Side Management 18

6. Electricity Distribution Rebates 19

7. Accounting and Administration Services 20

Administration Charge 20

8. Charges for electrical plant provided ancillary to the grant of Use of System 20

9. Glossary of Terms 21

Annex 1 - Schedule of charges for use of the distribution system by LV and HV DesignatedProperties 26Annex 2 - Schedule of charges for use of the distribution system by Designated EHV Properties(including LDNOs with Designated EHV Properties/end-users) 27Annex 3 - Schedule of charges for use of the distribution system by preserved/additional LLFclasses 32Annex 4 - Charges applied to LDNOs with LV and HV end-users 33Annex 5 - Schedule of line loss factors 36Annex 6 - Addendum to charging statement detailing charges for new Designated EHV Properties 39


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1. Introduction

1.1. This statement has been prepared in order to discharge Northern Powergrid’s

obligation under Standard Licence Condition 14 of our Electricity Distribution Licence.

It contains information on our charges1 and charging principles for use of our

Distribution System. It also contains information on our Line Loss Factors.

1.2. The charges in this statement are calculated using the Common Distribution Charging

Methodology (CDCM) for Low-Voltage and High-Voltage (LV and HV) Designated

Properties and the Extra-High Voltage Distribution Charging Methodology (EDCM) for

Designated Extra-High Voltage (EHV) Properties (for Metering Point Administration

Numbers/Metering System Identifiers (MPANs/MSIDs) connected to our designated

distribution services area). The application of charges to a premise can usually be

referenced using the Line Loss Factor Class (LLFC) contained in the charge tables.

1.3. All charges in this statement are shown exclusive of VAT.

1.4. The annexes that form part of this statement are also provided for additional

convenience in spreadsheet format. This spreadsheet also contains supplementary

information used for charging purposes but which is not required to be provided in

accordance with Standard Licence Condition 14. This spreadsheet can be downloaded

from:

http://www.northernpowergrid.com/downloads/system.cfm

1.5. If you have any questions about this statement please contact us at the address

shown below:

Charges Manager

Northern Powergrid

98 Aketon Road

Castleford

WF10 5DS

e-mail:- [email protected]

1 Charges can be positive or negative.

http://www.northernpowergrid.com/downloads/system.cfmmailto:[email protected]:[email protected]:[email protected]:[email protected]://www.northernpowergrid.com/downloads/system.cfm


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1.6. All enquiries regarding connection agreements and changes to maximum capacities

should be addressed to:

Connection Record Maintenance

Northern Powergrid

Manor House

Station Road

New Penshaw

Houghton-le-Spring

DH4 7LA


mailto:[email protected]:[email protected]:[email protected]:[email protected]


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2. Charge Application and Definitions

Supercustomer Billing and Payment

2.1.Supercustomer billing and payment applies to Metering Points registered as Non-Half

Hourly (NHH) metered or NHH unmetered. The Supercustomer approach makes use of

aggregated data obtained from the ‘Supercustomer Distribution Use of System (DUoS)

Report’.

2.2. Invoices are calculated on a periodic basis and sent to each user, for whom Northern

Powergrid is transporting electricity through its distribution system. Invoices are

reconciled, over a period of approximately 14 months, to ensure the cash positions of

users and Northern Powergrid are adjusted to reflect later and more accurate

consumption figures.

2.3. The charges are applied on the basis of the LLFC assigned to the Metering Point

Administration Number (MPAN), and the units consumed within the time periods

specified in this statement. All LLFCs are assigned at the sole discretion of Northern

Powergrid. Invoices take account of previous settlement runs and include VAT.

Supercustomer Charges

2.4. Supercustomer charges are generally billed through the following components:

a fixed charge - pence/MPAN/day, there will only be one fixed charge applied to

each MPAN; and

unit charges - pence/kilowatt-hour (kWh), more than one kWh charge may be

applied.

2.5. Users who wish to supply electricity to customers whose metering system is

measurement class A and settled on profile classes (PC) 1 through to 8 will be

allocated the relevant charge structure set out in Annex 1.

2.6. Measurement class A charges apply to exit/entry points where NHH metering is used

for settlement.

2.7. Measurement class B charges apply to exit points deemed to be suitable as unmetered

supplies as permitted in the Electricity (Unmetered Supply) Regulations 2001 2 and

where operated in accordance with BSCP5203.

2.8. Identification of the appropriate charge can be made by cross reference to the LLFC.

2 The Electricity (Unmetered Supply) Regulations 2001 available from

http://www.legislation.gov.uk/uksi/2001/3263/made 3 Balancing and Settlement Code Procedures on unmetered supplies are available from

http://www.elexon.co.uk/pages/bscps.aspx

http://www.legislation.gov.uk/uksi/2001/3263/madehttp://www.legislation.gov.uk/uksi/2001/3263/madehttp://www.elexon.co.uk/pages/bscps.aspxhttp://www.elexon.co.uk/pages/bscps.aspxhttp://www.elexon.co.uk/pages/bscps.aspxhttp://www.legislation.gov.uk/uksi/2001/3263/made


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2.9. Valid settlement profile class/standard settlement configuration/meter timeswitch

code (PC/SSC/MTC) combinations for these LLFCs are detailed in Market Domain Data

(MDD).

2.10. Where an MPAN has an invalid settlement combination, the ‘Domestic Unrestricted’

fixed and unit charge will be applied as default until the invalid combination is

corrected. Where there are multiple SSC - time pattern regime (TPR) combinations,

the default ‘Domestic Unrestricted’ fixed and unit charge will be applied for each

invalid TPR combination.

2.11. The time periods for the charge rates are as specified by the SSC. To determine the

appropriate charge rate for each SSC/TPR a look-up table is provided in the ENA

spreadsheet that accompanies this statement4.

2.12. The ‘Domestic Off -Peak’ and ‘Small Non-Domestic Off-Peak’ charges are

supplementary to either an unrestricted or a two-rate charge.

Site-Specific Billing and Payment

2.13. Site-specific billing and payment applies to metering points settled as Half Hourly

(HH) metered. The site-specific billing and payment approach to Use of System (UoS)

billing makes use of HH metering data received through settlement.

2.14. Invoices are calculated on a periodic basis and sent to each user, for whom Northern

Powergrid is transporting electricity through its distribution system. Where anaccount is based on estimated data, the account shall be subject to any adjustment

which may be necessary following the receipt of actual data from the user.

2.15. The charges are applied on the basis of the LLFC assigned to the MPAN (or the MSID

for Central Volume Allocation (CVA) sites), and the units consumed within the time

periods specified in this statement.

2.16. All LLFCs are assigned at the sole discretion of Northern Powergrid. Where an

incorrectly applied LLFC is identified, Northern Powergrid, may at its sole discretion

apply the correct LLFC and/or charges. Where MPANs have not been associated, for

example when multiple connections are fed from different sources, the relevant

number of fixed charges will be applied.

Site-Specific Billed Charges

2.17. Site-specific billed charges may include the following components:

a fixed charge pence/MPAN/day or pence/MSID/day;

4 Northern Powergrid Northeast - Schedule of charges and other tables – Version 10.7.xlsx


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Time periods for half-hourly unmetered properties

2.27. The time periods for the application of unit charges to connections that are pseudo

HH metered are detailed in Annex 1. Northern Powergrid has not issued a notice to

change the time bands.

Application of Capacity Charges

2.28. The following sections explain the application of capacity charges and exceeded

capacity charges.

Chargeable Capacity

2.29. The chargeable capacity is, for each billing period, the MIC/MEC, as detailed below.

2.30. The MIC/MEC will be agreed with Northern Powergrid at the time of connection or

pursuant to a later change in requirements. Following such an agreement (be it at

the time of connection or later) no reduction in MIC/MEC will be allowed for a period

of one year. In the absence of an agreement the chargeable capacity, save for error

or omission, will be based on the last MIC and/or MEC previously agreed by the

distributor for the relevant premises’ connection. A customer can seek to agree or

vary the MIC and/or MEC by contacting Northern Powergrid using the contact details

in paragraph 1.6.

2.31. Reductions to the MIC/MEC may only be permitted once in a 12 month period and no

retrospective changes will be allowed. Where MIC/MEC is reduced the new lower

level will be agreed with reference to the level of the customer’s maximum demand.

It should be noted that, where a new lower level is agreed, the original capacity may

not be available in the future without the need for network reinforcement and

associated charges.

Exceeded capacity

2.32. Where a customer takes additional unauthorised capacity over and above the

MIC/MEC, the excess will be classed as exceeded capacity. The exceeded portion of

the capacity will be charged at the excess capacity charge p/kVA/day rate, based on

the difference between the MIC/MEC and the actual capacity used. This will be

charged for the full duration of the month in which the breach occurs.

Demand exceeded capacity

),),max(max(2capacityexceededDemand 2 02 MIC RE RI AI

Where:

AI = Active Import (kWh)

RI = Reactive import (kVArh)


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RE = Reactive export (kVArh)

MIC = Maximum import capacity (kVA)

2.33. Only RI and RE values occurring at times of AI are used in the calculation. Where data

for two or more MPANs is aggregated for billing purposes the HH consumption values

are summated prior to the calculation above.

2.34. This calculation is completed for every half hour and the maximum value from the

billing period is applied.

Generation exceeded capacity

),),max(max(2capacityexceededGeneration 02 MEC RE RI AE 2

Where:

AE = Active Export (kWh)

RI = Reactive import (kVArh)

RE = Reactive export (kVArh)

MEC = Maximum export capacity (kVA)

2.35. Only RI and RE values occurring at times of AE are used in the calculation. Where

data for two or more MPANs is aggregated for billing purposes the HH consumption

values occurring at times of kWh export are summated prior to the calculation

above.

2.36. This calculation is completed for every half hour and the maximum value from the

billing period is applied.

Standby Capacity for Additional Security on Site

2.37. Where standby capacity charges are applied, the charge will be set at the same rate

as that applied to normal MIC.

Minimum Capacity Levels

2.38. There is no minimum capacity threshold.

Application of charges for excess reactive power

2.39. When an individual HH metered MPAN’s reactive power (measured in kVArh) at LV and

HV Designated Properties exceeds 33% of total active power (measured in kWh),

excess reactive power charges will apply. This threshold is equivalent to an average

power factor of 0.95 during the period. Any reactive units in excess of the 33%

threshold are charged at the rate appropriate to the particular charge.

2.40. Power Factor is calculated as follows:


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Cos θ = Power Factor

2.41. The chargeable reactive power is calculated as follows:

Demand chargeable reactive power

Where:

AI = Active Import in (kWh)

RI = Reactive Import in (kVArh)

RE = Reactive Export in (kVArh)

2.42. Only RI and RE values occurring at times of AI are used in the calculation. Where


values are summated prior to the calculation above.

2.43. The square root calculation will be to two decimal places.

2.44. This calculation is completed for every half hour and the values summated over the

billing period.

Generation chargeable reactive power

Where:

AE = Active Export in (kWh)

RI = Reactive Import in (kVArh)

RE = Reactive Export in (kVArh)

kWh

kVArh

θ

0,195.0

1

RERI,maxmaxkVArhChargeable Demand 2 AI

0, AE1

95.0

1RERI,maxmaxkVArhChargeableGeneration

2


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2.45. Only RI and RE values occurring at times of AE are used in the calculation. Where


values are summated prior to the calculation above.

2.46. The square root calculation will be to two decimal places.

2.47. This calculation is completed for every half hour and the values summated over the

billing period.

Generation charges for pre-2005 Designated EHV Properties

2.48. Designated EHV Properties that were connected to the distribution system under a

pre-2005 connection charging policy are eligible for exemption from generation UoS

charges unless one of the following criteria has been met:

25 years have passed since their first energisation/connection date (i.e.Designated EHV Properties with energisation/connection agreements dated prior

to 1st April 2005, and for which 25 years has passed since their first

energisation/connection date will receive generation UoS charges from the next

charging year following the expiry of their 25 years exemption, (starting 1st

April), or

the person responsible for the Designated EHV Property has provided notice to

Northern Powergrid that they wish to opt in to generation UoS charges.

If a notice to opt in has been provided there will be no further opportunity to opt out.

2.49. Furthermore, if an exempt customer makes an alteration to its export requirement

then the customer may be eligible to be charged for the additional capacity required

or energy imported or exported. For example, where a generator increases its export

capacity the incremental increase in export capacity will attract UoS charges as other

non-exempt generators.

Provision of billing data

2.50. Where HH metering data is required for UoS charging and this is not provided through

settlement processes, such metering data shall be provided by the user of the system

to Northern Powergrid in respect of each calendar month within 5 working days of the

end of that calendar month. The metering data shall identify the amount consumed

and/or produced in each half hour of each day and shall separately identify active

and reactive import and export. Metering data provided to Northern Powergrid shall

be consistent with that received through the metering equipment installed. Metering

data shall be provided in an electronic format specified by Northern Powergrid from

time to time, and in the absence of such specification, metering data shall be


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provided in a comma-separated text file in the format of D0275 MRA data flow (as

agreed with Northern Powergrid). The data shall be e-mailed to:

[email protected]

2.51. Northern Powergrid requires details of reactive power imported or exported to be

provided for all measurement class C (mandatory HH metered) sites and for

measurement class E (elective HH metered sites). It is also required for CVA sites and

exempt distribution network boundaries with difference metering. Northern

Powergrid reserves the right to levy a charge on users who fail to provide such

reactive data.

Use of System Charges Out of Area

2.52. Northern Powergrid does not operate networks outside its distribution service area.

Licensed Distributor Network Operator (LDNO) charges

2.53. Licenced distribution network operator (LDNO) charges are applied to LDNOs who

operate embedded networks within Northern Powergrid’s distribution services area.

2.54. The charge structure for LV and HV Designated Properties embedded in networks

operated by LDNOs will mirror the structure of the ‘all -the-way’ charge and is

dependent upon the voltage of connection of each embedded network to the host

DNO’s network. The same charge elements will apply as those that match the LDNO’s

end customer charges. The relevant charge structures are set out in Annex 4.

2.55. Where an MPAN has an invalid settlement combination, the ‘LDNO HV: Domestic

Unrestricted’ fixed and unit charge will be applied as default until the invalid

combination is corrected. Where there are multiple SSC-TPR combinations, the

default ‘LDNO HV: Domestic Unrestricted’ fixed and unit charge will be applied for

each invalid TPR combination.

2.56. The charge structure for Designated EHV Properties embedded in networks operated

by LDNOs will be calculated individually using the EDCM. The relevant charge

structures are set out in Annex 2.

2.57. For nested networks the relevant charging principles set out in DCUSA Schedule 21

will apply.

Third party access from exempt distribution networks

2.58. Where one of our MPANs (prefix 15) is embedded within an exempt distribution

network connected to one of Northern Powergrid’s distribution systems, and a

dispensation for difference metering is in place for settlement purposes, we will

continue to charge the supplier of the boundary MPAN of the connection, based on

mailto:[email protected]:[email protected]:[email protected]


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gross measurement for UoS. No charges will be levied directly to the customer or

supplier of the embedded MPAN(s) connected within the exempt distribution network.

2.59. Northern Powergrid requires that gross metered data for the boundary of the

connection is provided to them. Until a new flow is introduced for the sending of

such gross data, gross metered data shall:

be sent using the D0036 or D0275 MRA data flow; and

the D0036 or D0275 shall contain the metering reference specified by NorthernPowergrid in place of the boundary settlements MPAN.

2.60. For the avoidance of doubt the reduced difference metered measurement data for

the boundary connection that is to enter settlements should continue to be sent using

the settlements MPAN.

2.61. Where the data collector is unable to send the D0036 or D0275 MRA data flow due to

system constraints, gross metered data shall;

be provided in a text file in the format of the D0036 or D0275 MRA data flow;

the text file shall contain the metering reference specified by Northern Powergridin place of the settlements MPAN;

the text file shall be emailed to [email protected];

the text filename shall be formed of the metering reference specified byNorthern Powergrid followed by a hyphen and followed by a timestamp in theformat YYYYMMDDHHMMSS and followed by “.txt”;

and the title of the email should contain the phrase “gross data for differencemetered private network”.

mailto:[email protected]:[email protected]:[email protected]


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3. Schedule of Charges for use of the Distribution System

3.1. Tables listing the charges for the distribution of electricity for UoS are published in

annexes to this document.

3.2. These charges are also listed in a spreadsheet which is published with this statement

and can be downloaded from:

http://www.northernpowergrid.com/downloads/system.cfm

3.3. Annex 1 contains charges to LV and HV Designated Properties.

3.4. Annex 2 contains the charges to Designated EHV Properties and charges applied to

LDNOs with Designated EHV Properties/end-users embedded in networks within

Northern Powergrid’s area.

3.5. Annex 3 contains details of any preserved and additional charges that are valid at this

time. Preserved charges are mapped to an appropriate charge and are closed to new

customers.

3.6. Annex 4 contains the charges applied to LDNOs with LV and HV Designated Properties

embedded in networks within Northern Powergrid’s distribution services area.

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4. Schedule of Line Loss Factors

Role of Line Loss Factors in the Supply of Electricity

4.1. Electricity entering or exiting the DNOs’ networks is adjusted to take account of

energy that is lost5

as it is distributed through the network.

4.2. This adjustment is made to ensure that energy bought or sold by a user, from/to a

customer, accounts for energy lost as part of distributing energy to and from the

customer’s premises.

4.3. DNOs are responsible for calculating the Line Loss Factors (LLFs) and providing these

factors to Elexon. Elexon manage the Balancing and Settlement Code (BSC). The code

covers the governance and rules for the balancing and settlement arrangements.

4.4. Annex 5 provides the LLFs which must be used to adjust the metering system volumes

to take account of losses on the distribution network.

Calculation of Line Loss Factors

4.5. LLFs are calculated in accordance with BSC Procedure (BSCP) 128, which determines

the principles that DNOs must comply with when calculating LLFs.

4.6. LLFs are either calculated using a generic method or a site-specific method. The

generic method is used for sites connected at LV or HV and the site-specific method is

used for sites connected at EHV or where a request for site-specific LLFs has been

agreed. Generic LLFs will be applied to all new EHV sites until sufficient data is

available for a site-specific calculation.

4.7. The Elexon website:

(http://www.elexon.co.uk/reference/technicaloperations/losses/) contains more

information on LLFs. This page also has links to BSC Procedure (BSCP) 128 and to our

LLF methodology.

Line Loss Factor time periods

4.8. LLFs are calculated for a set number of time periods during the year and are detailedin Annex 5.

5 Energy can be lost for technical and non-technical reasons and losses normally occur by heat dissipation through power

flowing in conductors and transformers. Losses can also reduce if a customer’s action reduces power flowing in the

distribution network. This might happen when a customer generates electricity and the produced energy is consumed

locally.

http://www.elexon.co.uk/reference/technicaloperations/losses/http://www.elexon.co.uk/reference/technicaloperations/losses/http://www.elexon.co.uk/reference/technicaloperations/losses/http://www.elexon.co.uk/reference/technicaloperations/losses/


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Line Loss Factor tables

4.9. When using the LLF tables in Annex 5 reference should be made to the LLFC allocated

to the MPAN to find the appropriate LLF.

4.10. The Elexon portal website, https://www.elexonportal.co.uk , contains the LLFs in

standard industry data format (D0265). A user guide with details on registering and

using the portal can be downloaded from: www.elexonportal.co.uk/userguide

https://www.bsccentralservices.com/https://www.bsccentralservices.com/https://www.bsccentralservices.com/


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5. Notes for Designated EHV Properties

EDCM nodal costs

5.1. A table is provided in the accompanying spreadsheet which shows the unscaled LRIC

nodal costs used to calculate the current EDCM charges. This spreadsheet Northern

Powergrid Northeast - Schedule of charges and other tables – Version10.7.xlsx is

available to download from Northern Powergrid’s website.

5.2. These are illustrative of the modelled costs at the time that this statement was

published. A new connection will result in changes to current network utilisations

which will then form the basis of future prices, the charge determined in this

statement will not necessarily be the charge in subsequent years because of the

interaction between new and existing network connections and any other changes

made to Northern Powergrid’s distribution system which may affect charges.

Charges for New Designated EHV Properties

5.3. Charges for any new Designated EHV Properties calculated after publication of the

current statement will be published in an addendum to that statement as and when

necessary.

5.4. The form of the addendum is detailed in Annex 6 of this statement.

5.5. The addendum will be sent to relevant DCUSA parties and published as a revised

“Schedule of Charges and other tables” spreadsheet on our website. The addendum

will include charge information that under enduring circumstances would be found in

Annex 2 and line loss factors that would normally be found in Annex 5.

5.6. The new Designated EHV Properties charges will be added to Annex 2 in the next full

statement released.

Charges for amended Designated EHV Properties

5.7. Where an existing Designated EHV Property is modified and energised in the charging

year, Northern Powergrid may revise its EDCM charges for the modified Designated

EHV Property. If revised charges are appropriate, an addendum will be sent torelevant DCUSA parties and published as a revised 'Schedule of charges and other

table' spreadsheet on http://www.northernpowergrid.com/downloads/system.cfm.

The modified Designated EHV property charges will be added to Annex 2 in the next

full statement released.

Demand Side Management

5.8. For those premises where use of system is charged under the EDCM, some customers

may be able to benefit from entering into a Demand Side Management (DSM)

agreement with Northern Powergrid.

http://www.northernpowergrid.com/downloads/system.cfm.Thttp://www.northernpowergrid.com/downloads/system.cfm.Thttp://www.northernpowergrid.com/downloads/system.cfm.T


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5.9. DSM arrangements are based on a formal commitment by the customer to materially

reduce their MIC in certain time periods, as determined by Northern Powergrid, for

active network management purposes other than normal planned or unplanned

outages.

5.10. For new connections the customer must make an express statement in their

application that they have an interest in some, or all, of the import capacity for their

intended connection or modified connection being interruptible for active network

management purposes.

5.11. Where the customer enters into a DSM agreement by agreeing to reduce their MIC to

meet the defined parameters in the agreement, reduced use of system charges will

apply. The chargeable capacity will be equal to the MIC minus the capacity that is

subject to restrictions under the DSM agreement. The scale of the reduction will vary

by site and is linked to the LRIC element of the charge in line with the approved

charging methodology.

5.12. Any reduction in use of system charges applicable to the customer will be assessed on

a site-specific basis by Northern Powergrid. Any customers who wish to enquire

whether they can take advantage of DSM should in the first instance contact:

Connection Record Maintenance

Manor House

Station Road

New Penshaw

Houghton-le-Spring

DH4 7LA


6. Electricity Distribution Rebates

6.1. Northern Powergrid (Northeast) Ltd issued a use of system rebate to energy suppliers

in December 2013. Its intention was to facilitate the Department for Energy and

Climate Change’s announcement early that month that network operators were

willing to take voluntary action to reduce network costs. The rebates amounted to

£10.54 per domestic unrestricted customer and £14.98 per domestic restricted

customer and were based on the number of traded MPANs (excluding related MTCs).

6.2. Northern Powergrid (Northeast) Ltd is not proposing to make further rebates in the

2014/15 charging year.

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6.3. The tariffs within this statement do not attempt to recover any of the revenue

associated with the rebate and are identical to those tariffs that would have been

published had the rebate not been issued.

7. Accounting and Administration Services

Administration Charge

7.1. Where a user has failed to settle a DUoS invoice or notify Northern Powergrid of a

bona fide dispute, in accordance with the Use of System agreement an account

review charge of £75.00 may be made to cover the associated credit control,

administration, invoicing and collection costs. This is in addition to the interest

charge that will be made in accordance with clause 23.3 of the Distribution

Connection and Use of System Agreement (DCUSA).

8. Charges for electrical plant provided ancillary to the grant of Use ofSystem

8.1. Northern Powergrid has no charges applicable to this section.


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9. Glossary of Terms

9.1. The following definitions, which can extend to grammatical variations and cognate

expressions, are included to aid understanding:

Term Definition

All-the-way charge A tariff applicable to an end user rather than an LDNO.

Balancing and Settlement Code(BSC)

The BSC contains the governance arrangements forelectricity balancing and settlement in Great Britain. Anoverview document is available from

www.elexon.co.uk/ELEXONDocuments/trading_arrangements.pdf .

CDCM

The common distribution charging methodology used forcalculating charges to Designated Properties as requiredby standard licence condition 13A of the electricitydistribution licence.

Central volume allocation (CVA) As defined in the BSC.

Customer

A person to whom a user proposers to supply, or for thetime being supplies, electricity through an exit point, orfrom who, a user or any relevant exempt supplier, isentitled to recover charges, compensation or an accountof profits in respect of electricity supplied though an exitpoint;

Or

A person from whom a user purchases, or proposes topurchase, electricity, at an entry point (who may fromtime to time be supplied with electricity as a customer ofthat user (or another electricity supplier) through an exitpoint).

Designated PropertiesAs defined in standard condition 13A of the electricitydistribution licence.

Distributed generatorA generator directly connected or embedded within thedistribution system.

Distribution Connection and Useof System Agreement (DCUSA)

The DCUSA is a multi-party contract between the licensedelectricity distributors, suppliers, generators and OffshoreTransmission Owners (OFTOs) of Great Britain.

It is a requirement that all licensed electricity distributorsand suppliers become parties to the DCUSA.

Distribution network operator(DNO)

An electricity distributor who operates one of the 14distribution services areas and in whose electricitydistribution licence the requirements of Section B of thestandard conditions of that licence have effect.

http://elinkfp01/data1/Governance%20Services/DCMF/Administration/Meetings/LC14%20Review%20Group/www.elexon.co.uk/ELEXON%20Documents/trading_arrangements.pdfhttp://elinkfp01/data1/Governance%20Services/DCMF/Administration/Meetings/LC14%20Review%20Group/www.elexon.co.uk/ELEXON%20Documents/trading_arrangements.pdfhttp://elinkfp01/data1/Governance%20Services/DCMF/Administration/Meetings/LC14%20Review%20Group/www.elexon.co.uk/ELEXON%20Documents/trading_arrangements.pdfhttp://elinkfp01/data1/Governance%20Services/DCMF/Administration/Meetings/LC14%20Review%20Group/www.elexon.co.uk/ELEXON%20Documents/trading_arrangements.pdfhttp://elinkfp01/data1/Governance%20Services/DCMF/Administration/Meetings/LC14%20Review%20Group/www.elexon.co.uk/ELEXON%20Documents/trading_arrangements.pdf


22/39

PAGE 22 OF 39


Term Definition

Distribution services areaThe area specified by the authority within which each DNOmust provide specified distribution services.

Distribution system

The system consisting (wholly or mainly) of:

electric lines owned or operated by an authoriseddistributor that is used for the distribution ofelectricity from grid supply points or generationsets or other entry points to the points of deliveryto customers or users; or

any transmission licensee in its capacity asoperator of that licensee’s transmission system orthe Great Britain (GB) transmission system

and includes any remote transmission assets (owned by atransmission licensee within England and Wales) that areoperated by that authorised distributor and any electricalplant, electricity meters, and metering equipment ownedor operated by it in connection with the distribution ofelectricity, but does not include any part of the GBtransmission system.

Designated EHV PropertiesAs defined in standard condition 13B of the electricitydistribution licence.

EDCM

The EHV distribution charging methodology used forcalculating charges to Designated EHV Properties asrequired by standard licence condition 13B of theelectricity distribution licence.

Electricity distribution licenceThe electricity distribution licence granted or treated asgranted pursuant to section 6(1) of the Electricity Act1989.

Electricity distributorAny person who is authorised by an electricity distributionlicence to distribute electricity.

Embedded LDNOThis refers to an LDNO operating a distribution networkwhich is embedded within another distribution network.

Embedded networkAn electricity distribution system operated by an LDNOand embedded within another distribution network.

Entry point

A boundary point at which electricity is exported onto adistribution system from a connected installation or fromanother distribution system, not forming part of the totalsystem (boundary point and total system having themeaning given to those terms in the BSC).

Exit point

A point of connection at which a supply of electricity mayflow from the distribution system to the customer’sinstallation or user’s installation or the distribution systemof another person.

Extra-high voltage (EHV) Nominal voltages of 22kV and above.


23/39

PAGE 23 OF 39


Term Definition

Gas and Electricity MarketsAuthority (GEMA) (the

Authority)

As established by the Utilities Act 2000.

Grid supply point (GSP)

A metered connection between the National GridElectricity Transmission (NGET) system and the licensee’sdistribution system at which electricity flows to or fromthe distribution system.

GSP groupA distinct electrical system that is supplied from one ormore GSPs for which total supply into the GSP group canbe determined for each half hour.

High voltage (HV) Nominal voltages of at least 1kV and less than 22kV.

Host DNOA distribution network operator that is responsible for adistribution services area as defined in standard conditionsof the electricity distribution licence.

Intermediate LDNOAn embedded licenced distribution network operator thatis responsible for a distribution system between a hostDNO and another embedded distribution system.

Invalid settlement combinationA settlement combination that is not recognised as a validcombination in market domain data - seehttps://www.elexonportal.co.uk/MDDVIEWER.

kVA Kilovolt amperes.

kVArh Kilovolt ampere reactive hour.

kW Kilowatt.

kWh Kilowatt hour (equivalent to one “unit” of electricity).

Licensed distribution networkoperator (LDNO)

The holder of a licence in respect of distribution activitiesin Great Britain.

Line loss factor (LLF)The factor that is used in settlement to adjust themetering system volumes to take account of losses on the

distribution system.

Line loss factor class (LLFC)An identifier assigned to an SVA metering system which isused to assign the LLF and use of system charges.

Low voltage (LV) Nominal voltages below 1kV.

Market domain data (MDD)Market domain data is a central repository of referencedata used by all users involved in settlement. It isessential to the operation of SVA trading arrangements.

https://www.elexonportal.co.uk/MDDVIEWERhttps://www.elexonportal.co.uk/MDDVIEWER


24/39

PAGE 24 OF 39


Term Definition

Maximum export capacity (MEC)

The maximum export capacity of apparent powerexpressed in kVA that has been agreed can flow through

the entry point to the distribution system from thecustomer’s installation as specified in the connectionagreement.

Maximum import capacity (MIC)

The maximum import capacity of apparent powerexpressed in kVA that has been agreed can flow throughthe exit point from the distribution system to thecustomer’s installation as specified in the connectionagreement.

Measurement class

A classification of metering systems which indicates howconsumption is measured, i.e.:

non-half-hourly metering equipment (equivalent

to measurement class A); non-half-hourly unmetered supplies (equivalent to

measurement class B);

half-hourly metering equipment at or above100kW premises (equivalent to measurement classC);

half-hourly unmetered supplies (equivalent tomeasurement class D); and

half-hourly metering equipment below 100kwpremises (equivalent to measurement class E).

Metering point

The point at which electricity that is exported to or

imported from the licensee’s distribution system ismeasured, is deemed to be measured, or is intended to bemeasured and which is registered pursuant to theprovisions of the MRA. For the purposes of this statement,GSPs are not ‘metering points’.

Metering systemParticular commissioned metering equipment installed forthe purposes of measuring the quantities of exportsand/or imports at the exit point or entry point.

Metering point administrationnumber (MPAN)

A number relating to a metering point under the MRA.

MRA The Master Registration Agreement.

Meter timeswitch code (MTC)

MTCs are three digit codes allowing suppliers to identifythe metering installed in customers’ premises. Theyindicate whether the meter is single or multi-rate, pre-payment or credit, or whether it is ‘related’ to anothermeter.

Nested LDNOA distribution system operator that is responsible for anested network.


25/39

PAGE 25 OF 39


Term Definition

Nested networks

This refers to a situation where there is more than onelevel of embedded network and therefore nested

distribution systems between LDNOs (e.g. hostDNOintermediate LDNOnested LDNOcustomer).

OfgemOffice of Gas and Electricity Markets – Ofgem is governedby GEMA and is responsible for the regulation of thedistribution companies.

Profile class (PC)

A categorisation applied to NHH MPANs and used insettlement to group customers with similar consumptionpatterns to enable the calculation of consumptionprofiles.

Settlement

The determination and settlement of amounts payable in

respect of charges (including reconciling charges) inaccordance with the BSC.

Settlement class (SC)

The combination of profile class, line loss factor class,time pattern regime and standard settlementconfiguration, by supplier within a GSP group and used forsettlement.

Standard settlementconfiguration (SSC)

A standard metering configuration relating to a specificcombination of TPRs.

SupercustomerThe method of billing users for use of system on anaggregated basis, grouping together consumption and

standing charges for all similar NHH metered customers.

Supercustomer DUoS ReportA report of profiled data by settlement class providingcounts of MPANs and units consumed.

SupplierAn organisation with a supply license which can registeritself as being responsible for electricity supplied toand/or exported from a metering point.

Supplier volume allocation (SVA) As defined in the BSC.

Time pattern regime (TPR)The pattern of switching behaviour through time that one

or more meter registers follow.

Use of system chargesCharges applicable to demand and generation connectionswhich are connected to and utilise the distributionnetwork.

UserSomeone that has a use of system agreement with theDNO e.g. a supplier, generator or other DNO.

Unmetered Supplies

Exit points deemed to be suitable as unmetered suppliesas permitted in the Electricity (Unmetered Supply)Regulations 2001 and where operated in accordance withBSCP520.


26/39

Annex 1 - Schedule of Charges for use of the Distribution System by LV and HV Designated Properties

Time periods Red Time Band Green Time Band Black Time Band Yellow Time Band Green Time Band

Monday to Friday

(Including Bank Holidays)

All Year

16:00 to 19:3000:00 to 08:00

22:00 to 24:0016:00 to 19:30

08:00 to 16:00

19:30 to 22:00

00:00 to 08:00

22:00 to 24:00

Saturday and Sunday

All Year 00:00 to 24:00 08:00 to 22:00

00:00 to 08:00

22:00 to 24:00

Notes 00:00 to 24:00

DNOs paste value cells A15:I42 from CDCM 3701 into

cells A14:J41Open LLFCs PCs

Unit rate 1

p/kWh

(red/black)

Unit rate 2

p/kWh

(amber/yellow)

Unit rate 3

p/kWh

(green)

Fixed charge

p/MPAN/day

Capacity charge

p/kVA/day

Reactive power

charge

p/kVArh

Excess capacity

charge

p/kVA/day

Closed LLFCs

Domestic Unrestricted 1 1 2.792 4.83 5, 21, 25, 998, 999

Domestic Two Rate 2 2 3.401 0.184 4.83 6, 16, 22, 26, 36

Domestic Off Peak (related MPAN) 12 2 0.355 8, 28, 32

Small Non Domestic Unrestricted 203 3 2.771 4.43 202, 222, 223

Small Non Domestic Two Rate 204 4 3.335 0.256 4.43 201, 221, 224

Small Non Domestic Off Peak (related MPAN) 205 4 0.462 225

LV Medium Non-Domestic 257 5-8 2.528 0.166 24.58256, 267, 268, 276, 277,

287, 288

LV Sub Medium Non-Domestic 265 5-8 2.576 0.194 59.18 264, 284, 285

HV Medium Non-Domestic 304 5-8 2.002 0.104 206.18 303, 323, 324

LV HH Metered 251 0 11.950 0.984 0.124 13.63 1.46 0.304 1.46 253, 655

LV Sub HH Metered 293 0 10.973 0.777 0.092 45.56 2.09 0.241 2.09 -

HV HH Metered 301 0 8.868 0.547 0.061 115.85 1.87 0.183 1.87 610, 666, 674, 677

HV Sub HH Metered

NHH UMS category A 506 8 1.638 -

NHH UMS category B 507 1 2.348 -

NHH UMS category C 508 1 4.293 -

NHH UMS category D 509 1 1.143 -

LV UMS (Pseudo HH Metered) 554 & 555 0 33.481 1.063 0.139 -

LV Generation NHH 774 8 ( 0.704) 772, 773, 775, 800, 801

LV Sub Generation NHH 776 8 ( 0.626) -

LV Generation Intermittent 792 0 ( 0.704) 0.137, , , , ,

725, 733, 736, 746, 758,

LV Generation Non-Intermittent 794 0 ( 3.855) ( 0.766) ( 0.107) 0.137 713, 739, 740, 744, 790

LV Sub Generation Intermittent 793 0 ( 0.626) 0.131 -

LV Sub Generation Non-Intermittent 795 0 ( 3.446) ( 0.678) ( 0.094) 0.131 -

HV Generation Intermittent 796 0 ( 0.431) 122.46 0.099

702, 703, 706, 715, 717,

723, 726, 730, 734, 749,750, 752, 754, 755, 756,

771

HV Generation Non-Intermittent 798 0 ( 2.442) ( 0.453) ( 0.059) 122.46 0.099707, 708, 712, 721, 731,

732, 735, 743, 745, 747,

751, 753, 791

HV Sub Generation Intermittent

HV Sub Generation Non-Intermittent

08:00 to 16:00

19:30 to 22:00

Monday to Friday


November to February Inclusive

Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final LV and HV charges

Time Bands for Half Hourly Metered Properties Time Bands for Half Hourly Unmetered Properties

Amber Time Band Time periods

All the above times are in UK Clock time

Monday to Friday


April to October and March

Inclusive

All the above times are in UK Clock time Saturday and Sunday

All other times

NORTHERN POWERGRID (NORTHEAST) LTD 26 of 39 FEBRUARY 2014 - V1.0


27/39

Annex 2 - Schedule of Charges for use of the Distribution System by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-users)

3 4 5 6 6 7 8 9

Import

Unique

Identifier

LLFCImport

MPANs/MSIDs

Export Unique

Identifier LLFC

Export

MPANs/MSIDsName

Import

Super Red

unit rate

(p/kWh)

Import

fixed charge

(p/day)

Import

capacity rate

(p/kVA/day)

Import

exceeded capacity rate

(p/kVA/day)

Export

Super Red

unit rate

(p/kWh)

Export

fixed charge

(p/day)

Export

capacity rate

(p/kVA/day)

Export

exceeded capacity rate

(p/kVA/day)

6011592001005770

1592101005776701

1574000216135

1594001005774EHV Site Specific - Generation Exempt 1,519.93 0.65 0.65

603 1592001051182 EHV Site Specific 8,084.56 2.21 2.21

604 1570000223279 727 1574000223285 EHV Site Specific 91.66 0.65 0.65 1,833.23 0.09 0.09605 1592001092676 EHV Site Specific 0.603 4,309.47 1.86 1.86

606 1592001092719 EHV Site Specific 0.439 5,745.96 2.06 2.06



609 1592001046085 EHV Site Specific 574.60 3.34 3.34


612 1592001073112 704 1594001073116 EHV Site Specific 0.896 105.13 1.11 1.11 ( 1.037) 1,471.75 0.09 0.09

613 1592001116013 EHV Site Specific 0.649 172.38 5.11 5.11

614 1592001055257 709 1594001055250 EHV Site Specific - Generation Exempt 4,963.87 0.87 0.87

615 & 6161592001055239

1592001055248EHV Site Specific 0.420 3,189.59 2.61 2.61



619 1570000150382 710 1594000000038 EHV Site Specific - Generation Exempt 0 .063 38.93 1.78 1.78



622 1592001036574 711 1594001036578 EHV Site Specific - Generation Exempt 0.175 1,315.19 1.56 1.56


625 1592001006890 748 1594001006893 EHV Site Specific - Generation Exempt 1.041 117.70 1.31 1.31

627 1570000199077 729 1574000199083 EHV Site Specific - Generation Exempt 1,467.41 0.89 0.89






637 1592001141543 728 1594001141547 EHV Site Specific - Generation Exempt 0.057 3,392.64 1.82 1.82

680 1580000675845 759 1574000275033 EHV Site Specific 8 .970 6.07 2.63 2.63 242.92 0.09 0.09

681 1580000872387 760 1574000283735 EHV Site Specific 0.136 97.95 1.17 1.17 3,918.13 0.09 0.09

544 1570000124531 761 1594000000047 EHV Site Specific - Generation Exempt 18.66 0.80 0.80


691 1592101007746 EHV Site Specific 0 .011 86.19 4.72 4.72

683 1570000166434 763 1594000000029 EHV Site Specific - Generation Exempt 18.48 1.73 1.73

6921580000867554

1580000911799EHV Site Specific 0.381 172.38 3.40 3.40

693 1592001074941 EHV Site Specific 1 .534 86.19 3.61 3.61


6951580000918163

1580000918172EHV Site Specific 172.38 4.36 4.36


685 1580001132432 765 1574000302403 EHV Site Specific 51.67 0.69 0.69 1,627.68 0.09 0.09

6861580001150566

1580001150575766

1574000303940

1574000303959EHV Site Specific 292.10 1.70 1.70 18,986.73 0.09 0.09

687 TBC EHV Site Specific 2,046.05 1.11 1.11



690 1580001174414 782 1574000306374 EHV Site Specific 0.803 60.05 4.62 4.62 2,161.72 0.09 0.09

540 1580001190763 783 1574000307917 EHV Site Specific 0 .003 11.15 2.72 2.72 ( 0.053) 936.93 0.09 0.09


542 1580001278406 785 1574000315040 EHV Site Specific 302.42 1.97 1.97 559.47 0.09 0.09


16:00 to 19:30


Time periods

Monday to Friday



Notes

Time Periods for Designated EHV Properties

Super Red Time Band

Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final EDCM charges



28/39

Annex 2a - Schedule of Import Charges for use of the Distribution System by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-

users)

Super Red Time Band

16:00 to 19:30


Import

Unique

Identifier

LLFCImport

MPANs/MSIDsName

Import

Super Red

unit rate

(p/kWh)

Import

fixed charge

(p/day)

Import

capacity rate

(p/kVA/day)

Import

exceeded

capacity rate

(p/kVA/day)

6011592001005770

1592101005776EHV Site Specific - Generation Exempt 1,519.93 0.65 0.65









612 1592001073112 EHV Site Specific 0.896 1 05.13 1.11 1.11613 1592001116013 EHV Site Specific 0.649 1 72.38 5.11 5.11

614 1592001055257 EHV Site Specific - Generation Exempt 4,963.87 0.87 0.87

615 & 6161592001055239

1592001055248EHV Site Specific 0.420 3,189.59 2.61 2.61

617 1592001110572 EHV Site Specific 12,363.03 1.94 1.9 4


619 1570000150382 EHV Site Specific - Generation Exempt 0.063 38.93 1.78 1.78


621 1592001007494 EHV Site Specific 0.078 1 72.38 3.39 3.39

Notes

Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final EDCM import charges


Time periods

Monday to Friday





29/39

Annex 2a - Schedule of Import Charges for use of the Distribution System by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-

users)

Import

Unique

Identifier

LLFCImport

MPANs/MSIDsName

Import

Super Red

unit rate

(p/kWh)

Import

fixed charge

(p/day)

Import

capacity rate

(p/kVA/day)

Import

exceeded

capacity rate

(p/kVA/day)

622 1592001036574 EHV Site Specific - Generation Exempt 0.175 1,315.19 1.56 1.56


625 1592001006890 EHV Site Specific - Generation Exempt 1.041 1 17.70 1.31 1.31

627 1570000199077 EHV Site Specific - Generation Exempt 1,467.41 0.89 0.89






637 1592001141543 EHV Site Specific - Generation Exempt 0.057 3,392.64 1.82 1.82



544 1570000124531 EHV Site Specific - Generation Exempt 18.66 0.80 0.80



683 1570000166434 EHV Site Specific - Generation Exempt 18.48 1.73 1.73

6921580000867554

1580000911799EHV Site Specific 0.381 1 72.38 3.40 3.40



6951580000918163




6861580001150566


687 TBC EHV Site Specific 2,046.05 1.11 1.11










30/39

Annex 2b - Schedule of Export Charges for use of the Distribution System by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-

users)

Super Red Time Band

16:00 to 19:30


Export

Unique

Identifier

LLFCExport

MPANs/MSIDsName

Export

Super Red

unit rate

(p/kWh)

Export

fixed charge

(p/day)

Export

capacity rate

(p/kVA/day)

Export

exceeded

capacity rate

(p/kVA/day)

7011574000216135

1594001005774EHV Site Specific - Generation Exempt


704 1594001073116 EHV Site Specific ( 1.037) 1,471.75 0.09 0.09

709 1594001055250 EHV Site Specific - Generation Exempt













7661574000303940

1574000303959EHV Site Specific 18,986.73 0.09 0.09




Notes

Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final EDCM export charges


Time periods

Monday to Friday





31/39

Annex 2b - Schedule of Export Charges for use of the Distribution System by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-

users)

Export

Unique

Identifier

LLFCExport

MPANs/MSIDsName

Export

Super Red

unit rate

(p/kWh)

Export

fixed charge

(p/day)

Export

capacity rate

(p/kVA/day)

Export

exceeded

capacity rate

(p/kVA/day)

783 1574000307917 EHV Site Specific ( 0.053) 936.93 0.09 0.09





32/39

Annex 3 - Schedule of Charges for use of the Distribution System to Preserved/Additional LLFC Classes

Closed LLFCs PCs Unit rate 1 p/kWh Unit rate 2 p/kWh Unit rate 3 p/kWhFixed charge

p/MPAN/day

Domestic U nrestricted 5, 21, 25, 998, 999 1 2.792 4.83

Domestic Two Rate 6, 16, 22, 26, 36 2 3.401 0.184 4.83

Domestic Off Peak (related MPAN) 8, 28, 32 2 0.355

Small Non D omestic Unrestricted 202, 222, 223 3 2.771 4.43

Small Non Domestic Two Rate 201, 221, 224 4 3.335 0.256 4.43

Small Non Domestic Off Peak (related

MPAN)225 4 0.462

LV Medium Non-Domestic 256, 267 , 2 68, 276, 277 , 2 87, 288 5-8 2.528 0.166 24.58

LV Sub Medium Non-Domestic 264, 284, 285 5-8 2.576 0.194 59.18

HV Medium Non-Domestic 303, 323, 324 5-8 2.002 0.104 206.18

LV Generation NHH 772, 773, 775, 800, 801 8 ( 0.704)

Closed LLFCs PCs

Unit rate 1

p/kWh

(red/black)

Unit rate 2

p/kWh

(amber/yellow)

Unit rate 3

p/kWh

(green)

Fixed charge

p/MPAN/day

Capacity charge

p/kVA/day

Reactive power

charge

p/kVArh

Excess Capacity

charge

p/kVA

LV HH Metered 253, 655 0 11.950 0.984 0.124 13.63 1.46 0.304 1.46

HV HH Metered 610, 666, 674, 677 0 8.868 0.547 0.061 115.85 1.87 0.183 1.87

LV Generation Intermittent705, 716, 720, 722, 724, 725, 733, 736,

746, 758, 7700 ( 0 .704) 0.137

LV Generation Non-Intermittent 713, 739, 740, 744, 790 0 ( 3.855) ( 0.766) ( 0.107) 0.137

HV Generation Intermittent702, 703, 706, 715, 717, 723, 726, 730,

734, 749, 750, 752, 754, 755, 756, 7710 ( 0.431) 122.46 0.099

HV Generation Non-Intermittent707, 708, 712, 721, 731, 732, 735, 743,

745, 747, 751, 753, 7910 ( 2.442) ( 0.453) ( 0.059) 122.46 0.099

Notes:

Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final LV and HV tariffs

NHH preserved charges/additional LLFCs

All NHH tariffs detailed above are closed to new customers, the charges are mapped to the relevant active tariff in Annex 1

HV Medium Non-Domestic - this tariff if no longer available and all new HV c onnections will be required to be half-hourly metered

Notes:

HH preserved charges/additional LLFCs

All HH tariffs detailed above are closed to new customers, the charges are mapped to the relevant active tariff in Annex 1

Details of the relevant time periods can be found on Annex 1



33/39


34/39

Annex 4 - Charges applied to LDNOs with HV/LV end users

Copy from CDCM table 3701 "Tariffs!D43:I81" and paste

values into D14

Unique billing

identifier PCs

Unit rate 1

p/kWh

(red/black)

Unit rate 2

p/kWh

(amber/yellow)

Unit rate 3

p/kWh

(green)

Fixed charge

p/MPAN/day

Capacity charge

p/kVA/day

Reactive power

charge

p/kVArh

Excess capacity

charge

p/kVA

LDNO HVplus: LV Sub Medium Non-Domestic - 5-8 1.199 0.090 27.54

LDNO HVplus: HV Medium Non-Domestic - 5-8 1.133 0.059 116.66

LDNO HVplus: LV HH Metered 57 0 3.403 0.280 0.035 3.88 0.42 0.087 0.42

LDNO HVplus: LV Sub HH Metered 58 0 5.106 0.362 0.043 21.20 0.97 0.112 0.97

LDNO HVplus: HV HH Metered 59 0 5.018 0.310 0.035 65.55 1.06 0.104 1.06

LDNO HVplus: NHH UMS category A 45 8 0.466

LDNO HVplus: NHH UMS category B 46 1 0.669

LDNO HVplus: NHH UMS category C 47 1 1.223

LDNO HVplus: NHH UMS category D 48 1 0.326

LDNO HVplus: LV UMS (Pseudo HH Metered) 61 0 9.535 0.303 0.040

LDNO HVplus: LV Generation NHH 62 8 ( 0.328)

LDNO HVplus: LV Sub Generation NHH 63 8 ( 0.354)

LDNO HVplus: LV Generation Intermittent 64 0 ( 0.328) 0.064

LDNO HVplus: LV Generation Non-Intermittent 65 0 ( 1.794) ( 0.356) ( 0.050) 0.064

LDNO HVplus: LV Sub Generation Intermittent 66 0 ( 0.354) 0.074

LDNO HVplus: LV Sub Generation Non-Intermittent 67 0 ( 1.950) ( 0.384) ( 0.053) 0.074

LDNO HVplus: HV Generation Intermittent 68 0 ( 0.431) 122.46 0.099

LDNO HVplus: HV Generation Non-Intermittent 69 0 ( 2.442) ( 0.453) ( 0.059) 122.46 0.099

LDNO EHV: Domestic Unrestricted 70 1 0.553 0.96

LDNO EHV: Domestic Two Rate 71 2 0.673 0.036 0.96

LDNO EHV: Domestic Off Peak (related MPAN) 72 2 0.070

LDNO EHV: Small Non Domestic Unrestricted 73 3 0.549 0.88

LDNO EHV: Small Non Domestic Two Rate 74 4 0.660 0.051 0.88

LDNO EHV: Small Non Domestic Off Peak (related MPAN) 75 4 0.091

LDNO EHV: LV Medium Non-Domestic 76 5-8 0.500 0.033 4.87

LDNO EHV: LV Sub Medium Non-Domestic - 5-8 0.833 0.063 19.14

LDNO EHV: HV Medium Non-Domestic - 5-8 0.787 0.041 81.10

LDNO EHV: LV HH Metered 77 0 2.366 0.195 0.025 2.70 0.29 0.060 0.29

LDNO EHV: LV Sub HH Metered 78 0 3.550 0.251 0.030 14.74 0.68 0.078 0.68

LDNO EHV: HV HH Metered 79 0 3.488 0.215 0.024 45.57 0.74 0.072 0.74

LDNO EHV: NHH UMS category A 183 8 0.324

LDNO EHV: NHH UMS category B 184 1 0.465

LDNO EHV: NHH UMS category C 185 1 0.850

LDNO EHV: NHH UMS category D 186 1 0.226

LDNO EHV: LV UMS (Pseudo HH Metered) 81 0 6.628 0.210 0.028

LDNO EHV: LV Generation NHH 82 8 ( 0.228)

LDNO EHV: LV Sub Generation NHH 83 8 ( 0.246)

LDNO EHV: LV Generation Intermittent 84 0 ( 0.228) 0.044

LDNO EHV: LV Generation Non-Intermittent 85 0 ( 1.247) ( 0.248) ( 0.035) 0.044

LDNO EHV: LV Sub Generation Intermittent 86 0 ( 0.246) 0.052

LDNO EHV: LV Sub Generation Non-Intermittent 87 0 ( 1.355) ( 0.267) ( 0.037) 0.052

LDNO EHV: HV Generation Intermittent 88 0 ( 0.300) 85.13 0.069

LDNO EHV: HV Generation Non-Intermittent 89 0 ( 1.698) ( 0.315) ( 0.041) 85.13 0.069

LDNO 132kV/EHV: Domestic Unrestricted 90 1 0.367 0.63

LDNO 132kV/EHV: Domestic Two Rate 91 2 0.447 0.024 0.63

LDNO 132kV/EHV: Domestic Off Peak (related MPAN) 92 2 0.047

LDNO 132kV/EHV: Small Non Domestic Unrestricted 93 3 0.364 0.58

LDNO 132kV/EHV: Small Non Domestic Two Rate 94 4 0.438 0.034 0.58

LDNO 132kV/EHV: Small Non Domestic Off Peak (related MPAN) 95 4 0.061

LDNO 132kV/EHV: LV Medium Non-Domestic 96 5-8 0.332 0.022 3.23

LDNO 132kV/EHV: LV Sub Medium Non-Domestic - 5-8 0.553 0.042 12.70

LDNO 132kV/EHV: HV Medium Non-Domestic - 5-8 0.522 0.027 53.79

LDNO 132kV/EHV: LV HH Metered 97 0 1.569 0.129 0.016 1.79 0.19 0.040 0.19

LDNO 132kV/EHV: LV Sub HH Metered 98 0 2.354 0.167 0.020 9.78 0.45 0.052 0.45

LDNO 132kV/EHV: HV HH Metered 99 0 2.314 0.143 0.016 30.22 0.49 0.048 0.49

LDNO 132kV/EHV: NHH UMS category A 187 8 0.215

LDNO 132kV/EHV: NHH UMS category B 188 1 0.308

LDNO 132kV/EHV: NHH UMS category C 189 1 0.564

LDNO 132kV/EHV: NHH UMS category D 190 1 0.150

LDNO 132kV/EHV: LV UMS (Pseudo HH Metered) 101 0 4.396 0.140 0.018



35/39

Annex 4 - Charges applied to LDNOs with HV/LV end users

Copy from CDCM table 3701 "Tariffs!D43:I81" and paste

values into D14

Unique billing

identifier PCs

Unit rate 1

p/kWh

(red/black)

Unit rate 2

p/kWh

(amber/yellow)

Unit rate 3

p/kWh

(green)

Fixed charge

p/MPAN/day

Capacity charge

p/kVA/day

Reactive power

charge

p/kVArh

Excess capacity

charge

p/kVA

LDNO 132kV/EHV: LV Generation NHH 102 8 ( 0.151)

LDNO 132kV/EHV: LV Sub Generation NHH 103 8 ( 0.163)

LDNO 132kV/EHV: LV Generation Intermittent 104 0 ( 0.151) 0.029

LDNO 132kV/EHV: LV Generation Non-Intermittent 105 0 ( 0.827) ( 0.164) ( 0.023) 0.029

LDNO 132kV/EHV: LV Sub Generation Intermittent 106 0 ( 0.163) 0.034

LDNO 132kV/EHV: LV Sub Generation Non-Intermittent 107 0 ( 0.899) ( 0.177) ( 0.025) 0.034

LDNO 132kV/EHV: HV Generation Intermittent 108 0 ( 0.199) 56.46 0.046

LDNO 132kV/EHV: HV Generation Non-Intermittent 109 0 ( 1.126) ( 0.209) ( 0.027) 56.46 0.046

LDNO 132kV: Domestic Unrestricted 110 1 0.186 0.32

LDNO 132kV: Domestic Two Rate 111 2 0.227 0.012 0.32

LDNO 132kV: Domestic Off Peak (related MPAN) 112 2 0.024

LDNO 132kV: Small Non Domestic Unrestricted 113 3 0.185 0.30

LDNO 132kV: Small Non Domestic Two Rate 114 4 0.223 0.017 0.30

LDNO 132kV: Small Non Domestic Off Peak (related MPAN) 115 4 0.031

LDNO 132kV: LV Medium Non-Domestic 116 5-8 0.169 0.011 1.64

LDNO 132kV: LV Sub Medium Non-Domestic - 5-8 0.281 0.021 6.46

LDNO 132kV: HV Medium Non-Domestic - 5-8 0.266 0.014 27.36

LDNO 132kV: LV HH Metered 117 0 0.798 0.066 0.008 0.91 0.10 0.020 0.10

LDNO 132kV: LV Sub HH Metered 118 0 1.197 0.085 0.010 4.97 0.23 0.026 0.23

LDNO 132kV: HV HH Metered 119 0 1.177 0.073 0.008 15.37 0.25 0.024 0.25

LDNO 132kV: NHH UMS category A 191 8 0.109

LDNO 132kV: NHH UMS category B 192 1 0.157

LDNO 132kV: NHH UMS category C 193 1 0.287

LDNO 132kV: NHH UMS category D 194 1 0.076

LDNO 132kV: LV UMS (Pseudo HH Metered) 121 0 2.236 0.071 0.009

LDNO 132kV: LV Generation NHH 122 8 ( 0.077)

LDNO 132kV: LV Sub Generation NHH 123 8 ( 0.083)

LDNO 132kV: LV Generation Intermittent 124 0 ( 0.077) 0.015

LDNO 132kV: LV Generation Non-Intermittent 125 0 ( 0.421) ( 0.084) ( 0.012) 0.015

LDNO 132kV: LV Sub Generation Intermittent 126 0 ( 0.083) 0.017

LDNO 132kV: LV Sub Generation Non-Intermittent 127 0 ( 0.457) ( 0.090) ( 0.012) 0.017

LDNO 132kV: HV Generation Intermittent 128 0 ( 0.101) 28.72 0.023

LDNO 132kV: HV Generation Non-Intermittent 129 0 ( 0.573) ( 0.106) ( 0.014) 28.72 0.023

LDNO 0000: Domestic Unrestricted 130 1 0.059 0.10

LDNO 0000: Domestic Two Rate 131 2 0.072 0.004 0.10

LDNO 0000: Domestic Off Peak (related MPAN) 132 2 0.008

LDNO 0000: Small Non Domestic Unrestricted 133 3 0.059 0.09

LDNO 0000: Small Non Domestic Two Rate 134 4 0.071 0.005 0.09

LDNO 0000: Small Non Domestic Off Peak (related MPAN) 135 4 0.010

LDNO 0000: LV Medium Non-Domestic 136 5-8 0.054 0.004 0.52

LDNO 0000: LV Sub Medium Non-Domestic - 5-8 0.089 0.007 2.05

LDNO 0000: HV Medium Non-Domestic - 5-8 0.084 0.004 8.68

LDNO 0000: LV HH Metered 137 0 0.253 0.021 0.003 0.29 0.03 0.006 0.03

LDNO 0000: LV Sub HH Metered 138 0 0.380 0.027 0.003 1.58 0.07 0.008 0.07

LDNO 0000: HV HH Metered 139 0 0.373 0.023 0.003 4.88 0.08 0.008 0.08

LDNO 0000: NHH UMS category A 195 8 0.035

LDNO 0000: NHH UMS category B 196 1 0.050

LDNO 0000: NHH UMS category C 197 1 0.091

LDNO 0000: NHH UMS category D 198 1 0.024

LDNO 0000: LV UMS (Pseudo HH Metered) 141 0 0.709 0.023 0.003

LDNO 0000: LV Generation NHH 142 8 ( 0.024)

LDNO 0000: LV Sub Generation NHH 143 8 ( 0.026)

LDNO 0000: LV Generation Intermittent 144 0 ( 0.024) 0.005

LDNO 0000: LV Generation Non-Intermittent 145 0 ( 0.133) ( 0.027) ( 0.004) 0.005

LDNO 0000: LV Sub Generation Intermittent 146 0 ( 0.026) 0.006

LDNO 0000: LV Sub Generation Non-Intermittent 147 0 ( 0.145) ( 0.029) ( 0.004) 0.006

LDNO 0000: HV Generation Intermittent 148 0 ( 0.032) 9.11 0.007

LDNO 0000: HV Generation Non-Intermittent 149 0 ( 0.182) ( 0.034) ( 0.004) 9.11 0.007



36/39

Annex 5 – Schedule of Line Loss Factors

Period 1 Period 2 Period 3 Period 4

Winter Peak Other Winter Weekday Night All other times

Monday – Friday (Apr-Oct) 00:30 – 07:3000:00 – 00:30

07:30 – 24:00

Monday – Friday (Nov) 07:30 – 20:00 00:30 – 07:30 00:00 – 00:3020:00 – 24:00

Monday – Friday (Dec –

Feb)16:30 – 18:30

07:30 – 16:30

18:30 – 20:0000:30 – 07:30

00:00 – 00:30

20:00 – 24:00

Monday – Friday (Mar) 00:30 – 07:3000:00 – 00:30

07:30 – 24:00

Saturday and Sunday

All Year 00:30 – 07:30

00:00 – 00:30

07:30 – 24:00

Notes

5 6 7 8 4

Metered voltage Period 1 Period 2 Period 3 Period 4 Associated LLFC

Low Voltage Network 1.086 1.078 1.064 1.070

1, 2, 5, 6, 8, 12, 16, 21, 22,

25, 26, 28, 32, 36, 201, 202,

203, 204, 205, 221, 222,

223, 224, 225, 251, 253,

256, 257, 267, 268, 276,

277, 287, 288, 506, 507,

508, 509, 554, 555, 655,

705, 713, 716, 720, 722,

724, 725, 733, 736, 739,

740, 744, 746, 758, 770,

772, 776, 792, 794, 773,

774, 775, 790, 800, 801,

998, 999

Low Voltage Substation 1.039 1.038 1.040 1.038264, 265, 284, 285, 293,

793, 795

High Voltage Network 1.024 1.023 1.018 1.021

301, 303, 304, 323, 324,610, 666, 674, 677, 702,

703, 706, 707, 708, 712,

715, 717, 721, 723, 726,

730, 731, 732, 734, 735,

743, 745, 747, 749, 750,

751, 752, 753, 754, 755,

756, 771, 791, 796, 798

High Voltage Substation 1.014 1.014 1.013 1.013

294, 691, 692, 693, 694,

695, 696, 697, 698, 699,

700, 777, 778, 779, 780,

781, 797, 799

Greater than 22kV connected -

generation1.009 1.009 1.007 1.008

769, 785, 786, 787, 788,

789, 802, 803, 804, 805

Greater than 22kV connected -

demand1.009 1.009 1.007 1.008

542, 543, 545, 546, 547,

548, 549


Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final LLF Time Periods

Time periods

Generic demand and generation LLFs

Metered voltage, respective periods and associated LLFCs



37/39


Site Period 1 Period 2 Period 3 Period 4 Associated LLFC

Site 1 1.006 1.006 1.009 1.007 540

Site 2 1.009 1.009 1.007 1.008 541

Site 3 1.001 1.002 1.002 1.002 544

Site 4 1.000 1.000 1.002 1.002 601

Site 5 1.002 1.002 1.002 1.002 603

Site 6 1.000 1.000 1.001 1.001 604

Site 7 1.011 1.011 1.014 1.011 605

Site 8 1.018 1.020 1.058 1.022 606

Site 9 1.020 1.021 1.051 1.021 607

Site 10 1.025 1.024 1.049 1.027 608

Site 11 1.004 1.004 1.005 1.004 609

Site 12 1.016 1.015 1.014 1.014 611

Site 13 1.005 1.005 1.004 1.005 612

Site 14 1.011 1.010 1.009 1.010 613

Site 15 1.006 1.004 1.006 1.007 614

Site 16 1.005 1.005 1.004 1.005 615

Site 17 1.005 1.005 1.003 1.004 616

Site 18 1.006 1.006 1.006 1.006 617

Site 19 1.011 1.011 1.011 1.011 618

Site 20 1.013 1.012 1.008 1.010 619

Site 21 1.000 1.000 1.000 1.000 620

Site 22 1.006 1.006 1.008 1.007 621

Site 23 1.022 1.019 1.025 1.021 622

Site 24 1.007 1.007 1.007 1.007 624

Site 25 1.016 1.016 1.015 1.016 625

Site 26 1.114 1.064 1.058 1.071 626

Site 27 1.002 1.002 1.003 1.003 627

Site 28 1.021 1.020 1.014 1.017 628

Site 29 1.005 1.006 1.006 1.006 631

Site 30 1.006 1.006 1.006 1.006 632

Site 31 1.038 1.037 1.031 1.034 633

Site 32 1.003 1.003 1.004 1.004 637

Site 33 1.031 1.030 1.024 1.027 680

Site 34 1.007 1.008 1.009 1.008 681

Site 35 1.005 1.005 1.003 1.004 682

Site 36 1.011 1.016 1.015 1.008 683

Site 37 1.005 1.005 1.005 1.005 684

Site 38 1.003 1.003 1.002 1.002 685

Site 39 1.009 1.009 1.007 1.008 686

Site 40 1.001 1.001 1.001 1.001 687

Site 41 1.009 1.009 1.007 1.008 688

Site 42 1.009 1.009 1.007 1.008 689

Site 43 1.015 1.016 1.015 1.015 690

EHV site specific LLFs

Demand



38/39


Site Period 1 Period 2 Period 3 Period 4 Associated LLFC

Site 1 0.995 0.996 0.996 0.996 701

Site 2 1.007 1.007 1.003 1.005 704

Site 3 0.994 0.996 0.994 0.993 709

Site 4 1.019 1.018 1.006 1.014 710

Site 5 0.987 0.989 0.981 0.987 711

Site 6 0.997 0.997 0.996 0.996 727

Site 7 1.000 1.000 1.000 1.000 728

Site 8 0.994 0.995 0.995 0.995 729

Site 9 1.010 1.011 1.003 1.009 748

Site 10 1.046 1.044 1.030 1.038 759

Site 11 0.998 0.999 0.995 0.997 760

Site 12 0.996 0.996 0.997 0.996 761

Site 13 1.007 1.007 1.003 1.005 762

Site 14 0.973 0.973 0.973 0.974 763

Site 15 1.001 0.999 0.996 0.998 764

Site 16 0.999 0.998 0.997 0.997 765

Site 17 1.009 1.009 1.007 1.008 766

Site 18 1.009 1.009 1.007 1.008 767

Site 19 1.009 1.009 1.007 1.008 768

Site 20 1.009 1.010 1.001 1.005 782

Site 21 1.000 1.000 1.000 0.999 783

Site 22 1.009 1.009 1.007 1.008 784

Generation

EHV sites specific LLFs



39/39

Annex 6 - Addendum to charging statement detailing charges for newDesignated EHV Properties

Nodal cost can be found in the spread sheet that accompanies this statement.