northern power - yorkshire 2014

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Northern Powergrid (Yorkshire) plc, Registered Office: Lloyds Court, 78 Grey Street, Newcastle Upon Tyne NE1 6SFRegistered In England And Wales No. 4112320

Statement of Use of System Charging

Northern Powergrid (Yorkshire) plc

Final Notice

Effective from 1st April 2014

Version 1.0


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Version Control Version Date Description of version and any changes made

1.0 1 April 2014 This statement is based on version 7.8 of the common

template developed during 2013.

A change-marked version of this statement can be provided upon request.


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NORTHERN POWERGRID (YORKSHIRE) PLC FEBRUARY 2014– V1.0

Contents

1. Introduction 42. 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 154. 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 16

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

6. Electricity Distribution Rebates 197. Accounting and Administration Services 20

Administration Charge 208. Charges for electrical plant provided ancillary to the grant of Use of System 209. 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 41Annex 4 - Charges applied to LDNOs with LV and HV end-users 42Annex 5 - Schedule of line loss factors 45Annex 6 - Addendum to charging statement detailing charges for new Designated EHV Properties 48


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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 charges 1 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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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 BSCP520 3.

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

2 The Electricity (Unmetered Supply) Regulations 2001 available fromhttp://www.legislation.gov.uk/uksi/2001/3263/made 3 Balancing and Settlement Code Procedures on unmetered supplies are available fromhttp://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 statement 4.

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, forexample 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 Yorkshire - Schedule of charges and other tables – Version 10.7.xlsx


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a capacity charge, pence/kVA/day, for Maximum Import Capacity (MIC) and/orMaximum Export Capacity (MEC);

an excess capacity charge, pence/kVA/day, if a site exceeds its MIC and/or MEC;

unit charges, pence/kWh, more than one unit charge may be applied; and

an excess reactive power charge, pence/kVArh, for each unit in excess of thereactive charge threshold.

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

measurement class C, D or E or CVA will be allocated the relevant charge structure

dependent upon the voltage and location of the metering point.

2.19. Measurement class C, E or CVA charges apply to exit/entry points where HH metering,

or an equivalent meter, is used for settlement purposes.

2.20. Measurement class D charges apply to exit points deemed to be suitable asunmetered supplies as permitted in the Electricity (Unmetered Supply) Regulations

2001 and where operated in accordance with BSCP520.

2.21. Fixed charges are generally levied on a pence per MPAN basis. Where two or more HH

MPANs are located at the same point of connection (as identified in the connection

agreement), with the same LLFC, and registered to the same supplier, only one daily

fixed charge will be applied.

2.22. LV & HV Designated Properties will be charged in accordance with the CDCM and

allocated the relevant charge structure set out in Annex 1.

2.23. Designated EHV Properties will be charged in accordance with the EDCM and allocated

the relevant charge structure set out in Annex 2.

2.24. Where LV and HV Designated Properties or Designated EHV Properties have more than

one point of connection (as identified in the connection agreement) then separate

charges will be applied to each point of connection.

Time periods for half-hourly metered properties

2.25. The time periods for the application of unit charges to LV and HV DesignatedProperties that are HH metered are detailed in Annex 1. Northern Powergrid has not

issued a notice to change the time bands.

2.26. The time periods for the application of unit charges to Designated EHV Properties are

detailed in Annex 2. Northern Powergrid has not issued a notice to change the time

bands.


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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

1RERI,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 M PAN 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 23) 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 ofsuch 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

emb edded in networks within Northern Powergrid’s distribution services area.

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


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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 isavailable 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.

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.

5Energy 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 thedistribution network. This might happen when a customer generates electricity and the produced energy is consumedlocally.

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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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 NorthernPowergrid Yorkshire - 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 varyby 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

e-mail:- [email protected]

6. Electricity Distribution Rebates6.1. Northern Powergrid (Yorkshire) plc 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

£6.10 per domestic unrestricted customer and £8.67 per domestic restricted

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

6.2. Northern Powergrid (Yorkshire) plc 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 ServicesAdministration 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.


21/48

PAGE 21 OF 48


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 fromwww.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 Properties As defined in standard condition 13A of the electricitydistribution licence.

Distributed generator A 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


22/48

PAGE 22 OF 48


Term Definition

Distribution services area The 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 Properties As 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 distributor Any person who is authorised by an electricity distributionlicence to distribute electricity.

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

Embedded network An 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.


23/48

PAGE 23 OF 48


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


24/48

PAGE 24 OF 48


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 (equivalentto measurement class A);

non-half-hourly unmetered supplies (equivalent tomeasurement 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 LDNO A distribution system operator that is responsible for anested network.


25/48

PAGE 25 OF 48


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. hostDNO intermediate LDNO nested LDNO customer).

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 andstanding charges for all similar NHH metered customers.

Supercustomer DUoS Report A 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.

User Someone 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.


26/48

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

Time periodsRed Time

BandGreen 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 08:0022:00 to 24:00

16:00 to 19:3008:00 to 16:0019:30 to 22:00

00:00 to 08:0022:00 to 24:00

Saturday and SundayAll Year

00:00 to 24:00 08:00 to 22:00 00:00 to 08:0022:00 to 24:00

Notes 00:00 to 24:00

DNOs paste value cells A15:I42 from CDCM 3701 into cells A14:J41

O pe n L LF Cs P CsUnit rate 1

p/kWh(red/black)

Unit rate 2p/kWh

(amber/yellow)

Unit rate 3p/kWh(green)

Fixed chargep/MPAN/day

Capacity chargep/kVA/day

Reactive powercharge

p/kVArh

Excess capacitycharge

p/kVA/dayClosed LLFCs

Domestic Unrestricted 100 1 2.263 4.71 101, 400, 401, 999

Domestic Two Rate 120 2 2.829 0.101 4.71 121, 123, 402, 403, 413

Domestic Off Peak (related MPAN) 111 2 0.390 130, 131, 414, 415, 416

Small Non Domestic Unrestricted 240 3 2.254 4.32 241, 404, 405

Small Non Domestic Two Rate 246 4 2.946 0.185 4.32 249, 250, 275, 406, 407, 417, 418

Small Non Domestic Off Peak (related MPAN) 214 4 0.503 268, 419, 420

LV Medium Non-Domestic 290 5-8 2.236 0.063 30.40 280, 287, 408, 409, 421

LV Sub Medium Non-Domestic - 5-8 1.504 0.041 43.66 -

HV Medium Non-Domestic 580 5-8 1.764 0.036 210.59 410

LV HH Metered 281 0 9.377 0.963 0.051 13.06 1.46 0.329 1.46 244, 248, 257, 291, 297

LV Sub HH Metered 471 0 8.256 0.786 0.040 43.66 1.93 0.269 1.93 472

HV HH Metered 581 0 6.522 0.573 0.027 111.03 1.81 0.198 1.81 500, 501, 502, 741, 742, 743, 744

HV Sub HH Metered

NHH UMS category A 814 8 1.107 -

NHH UMS category B 815 1 1.498 -

NHH UMS category C 816 1 2.806 -

NHH UMS category D 817 1 0.855 -

LV UMS (Pseudo HH Metered) 813 & 913 0 21.989 0.847 0.046 -

LV Generation NHH 20 8 ( 0.574) 17, 18, 21, 411, 412

LV Sub Generation NHH 30 8 ( 0.504) -

LV Generation Intermittent 22 0 ( 0.574) 0.134 12, 40

LV Generation Non-Intermittent 24 0 ( 3.423) ( 0.621) ( 0.039) 0.134 -

LV Sub Generation Intermittent 23 0 ( 0.504) 0.128 14

LV Sub Generation Non-Intermittent 25 0 ( 3.007) ( 0.545) ( 0.034) 0.128 -

HV Generation Intermittent 26 0 ( 0.357) 117.36 0.098 15, 41

HV Generation Non-Intermittent 28 0 ( 2.139) ( 0.384) ( 0.024) 117.36 0.098 -

HV Sub Generation Intermittent

HV Sub Generation Non-Intermittent

08:00 to 16:0019:30 to 22:00

Monday to Friday(Including Bank Holidays)November to February Inclusive

Northern Powergrid (Yorkshire) plc - Effective from April 2014 - Final LV and HV charges

Time Bands for Half Hourly Metered Properties Time Bands for Half Hourly Unmetered PropertiesAmber Time Band Time periods

All the above times are in UK Clock time

Monday to Friday(Including Bank Holidays)April to October and MarchInclusive

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

All other times

NORTHERN POWERGRID (YORKSHIRE) PLC 26 of 48 FEBRUARY 2014 - V1.0


27/48

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

ImportUnique

Identifier LLFC Import

MPANs/MSIDsExport Unique

Identifier LLFC Export

MPANs/MSIDsName

ImportSuper Red

unit rate

(p/kWh)

Importfixed charge

(p/day)

Importcapacity rate(p/kVA/day)

Importexceeded capacity rate

(p/kVA/day)

ExportSuper Red

unit rate

(p/kWh)

Exportfixed charge

(p/day)

Exportcapacity rate(p/kVA/day)

Exportexceeded capacity rate

(p/kVA/day)

750 23000005996572336541294017 EHV Site Specific 0.498 9.43 9.43

751

230000070251723000007025262300000702535237655500201023765550020292376555002038

EHV Site Specific 0.074 5,812.23 1.83 1.83

753 2356555555010 90 2394000039650 EHV Site Specific 0.781 6,271.33 2.28 2.28 104.52 0.13 0.13754 2356555554017 82 2394000039660 EHV Site Specific 0.487 9,377.56 1.48 1.48 468.88 0.13 0.13755 2316521850010 76 2394000039641 EHV Site Specific 0.058 4,347.17 2.31 2.31 434.72 0.13 0.13756 2346540436013 75 2394000039679 EHV Site Specific 0.017 5,931.03 1.49 1.49 444.83 0.13 0.13757 2336566756217 95 2394000060226 EHV Site Specific 796.98 2.44 2.44 ( 0.146) 796.98 0.13 0.13758 2366591411116 EHV Site Specific 0.104 7,952.88 0.84 0.84759 MSID 0645 EHV Site Specific 16,521.44 2.59 2.59

760 23000008809662376509001013 6023000002337362300000880975 EHV Site Specific - Generation Exempt

1,810.30 1.24 1.24

761 23000005266862336518071011 EHV Site Specific 0.002 552.57 0.87 0.87

762 2300000457400 62 2300000457410 EHV Site Specific - Generation Exempt 0.062 120.35 1.34 1.34


0.015 829.91 0.76 0.76

764230000023395923000002339682300000233977


765230000045708423900000108402390000010859



215.85 1.18 1.18

767 MSID 7020MSID 7021 67MSID 7020MSID 7021 EHV Site Specific - Generation Exempt

170.52 1.39 1.39

769 2346526241119 EHV Site Specific 0.083 7,952.88 1.99 1.99

770 2366591365115 EHV Site Specific 0.115 7,952.88 1.90 1.90771 2366591376117 92 2394000019176 EHV Site Specific 0.043 1,988.22 0.84 0.84 ( 0.043) 5,964.66 0.13 0.13772 2366591373116 EHV Site Specific 0.058 7,952.88 1.98 1.98773 2366591486111 EHV Site Specific 0.136 7,952.88 2.05 2.05


2.636 230.24 1.21 1.21

775 2380000531989 87 2394000024440 EHV Site Specific 0.051 352.88 0.88 0.88 ( 0.223) 1,347.35 0.13 0.13777 2300000233596 77 2300000233610 EHV Site Specific - Generation Exempt 0.612 9.21 1.04 1.04778 2300000443816 78 2300000443825 EHV Sit e Specif ic - Generation Part Exempt 6 .38 2.30 2.30 414.54 0.13 0.13780 2380000825051 EHV Site Specific 0.011 1,062.64 0.55 0.55781 2300000790540 81 2300000790550 EHV Site Specific - Generation Exempt 147.48 1.05 1.05


783 2300000974268 83 2300000974408 EHV Site Specific - Generation Exempt 0.137 10.23 1.77 1.77784 2300001007247 84 2300001007256 EHV Site Specific - Generation Exempt 0.028 1.37 2.21 2.21785 2380000151720 85 2394000011646 EHV Site Specific - Generation Exempt 0.068 4.08 0.80 0.80

786 2380000148115 86 23911000137042394000011502 EHV Site Specific - Generation Exempt 2.74 0.76 0.76


788 2380000654644 88 2394000027673 EHV Site Specific 0.094 0.71 1.47 1.47 ( 0.313) 1,593.26 0.13 0.13789 2380001118812 89 2394000043364 EHV Site Specific 38.88 1.35 1.35 ( 0.103) 1,555.09 0.13 0.13


16:00 to 19:30

Notes All the above times are in UK Clock time

Northern Powergrid (Yorkshire) plc - Effective from April 2014 - Final EDCM charges

Time Periods for Designated EHV Properties

Time periods Super Red Time Band



28/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs

Export UniqueIdentifier LLFC

ExportMPANs/MSIDs Name

ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)



(p/kVA/day)

ExportSuper Red

unit rate(p/kWh)

Exportfixed charge

(p/day)



(p/kVA/day)

790 2380001476585 94 2394000056790 EHV Site Specific 0.067 12.15 1.28 1.28 816.71 0.13 0.13791 2380001494334 93 2394000058333 EHV Site Specific 0.148 5.38 1.33 1.33 ( 0.338) 270.91 0.13 0.13

793238000125282923800012528382380001767827

91239400004758123940000475902394000047606

EHV Site Specific 0.323 73.36 1.24 1.24 1,796.90 0.13 0.13

794 2380001458911 97 2394000055174 EHV Site Specific 1.519 324.14 1.51 1.51 9,724.21 0.13 0.13

795 23800015321672380001532176 EHV Site Specific 0.079 1,908.51 1.01 1.01

796 2380001635401 98 2394000072198 EHV Site Specific 52.96 0.51 0.51 5,211.58 0.13 0.13


832 2316541311014 73 2300000233587 EHV Site Specific 1.888 84.32 2.78 2.78 ( 1.864) 11.32 0.13 0.13

83323265110150142326511015023 EHV Site Specific 5.522 191.28 4.24 4.24

834230000045690323000005166052326531140128

EHV Site Specific 1.623 286.91 3.91 3.91





839 23000002338332336566356211 68 2300000233898 EHV Si t e Speci f ic 0.168 151.01 2.23 2.23 ( 0.168) 40.27 0.13 0.13


841

2300000539365230000053937423365906600282336590660037






846230000044496223000006013212366531830013





850

2300000647051230000064706023765529200132376552920022


851237655082501323800000005432380000004097





855

238000072419523800010789772380001078986238000107899523800010790012380001079321

EHV Site Specific 573.83 1.41 1.41

856

2380001519750238000151976023800015197792380001519788



858230000083936423265262900162326526290025




29/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs



ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)



(p/kVA/day)

ExportSuper Red

unit rate(p/kWh)

Exportfixed charge

(p/day)



(p/kVA/day)


860233652633201723365263320262300000457057


861

2300000493180230000055212523365521150172336552115026


862

2300000234163230000023417223365907700132336590770022


863

2300000234066230000023407523000002340842336590810010









872

2300000674055230000067406423000006740732366540100010



874 2300000542828 EHV Site Specific 95.64 2.67 2.67875 2366560263119 EHV Site Specific 0.963 191.28 2.77 2.77


877 2366591617013 EHV Site Specific 3.220 191.28 6.65 6.65878 2376501360010 EHV Site Specific 0.495 191.28 3.49 3.49




882 2300000826383 69 2300000930377 EHV Site Specific 5.359 11.27 0.74 0.74 ( 5.359) 84.37 0.13 0.13

8832376503230011237650801001723900000024402390000002459


884 2300000233754 EHV Site Specific 0.016 95.64 2.28 2.28886 2380001187667 EHV Site Specific 0.317 95.64 1.91 1.91887 2380001432843 EHV Site Specific 0.259 95.64 2.19 2.19

888

23800014486112380001448620238000144863023800014486492380001448658


889 2380001564275 70 2394000039590 EHV Site Specific 0.165 2.42 1.59 1.59 ( 0.165) 93.22 0.13 0.13797 2390000079381 99 2394000079398 EHV Site Specific - Generation Exempt 0.470 2.20 1.78 1.78798 2380001746400 61 2394000083311 EHV Site Specific 33.67 1.21 1.21 2,721.33 0.13 0.13799 2380001812550 51 2394000089457 EHV Site Specific 0.282 32.81 1.18 1.18 ( 0.282) 3,281.15 0.13 0.13821 2380001851381 52 2394000093027 EHV Site Specific 0 .286 4.08 3.60 3.60 272.20 0.13 0.13

822 23800018830362380001883045 5323940000958312394000095840 EHV Site Specific

0.286 10.27 3.60 3.60 266.02 0.13 0.13

823 2380001877557 54 2394000097068 EHV Site Specific 0.122 17.40 5.41 5.41 3,754.98 0.13 0.13824 MSID 7275 55 MSID 7275 EHV Site Specific 15.61 2.16 2.16 538.45 0.13 0.13826 2380001874087 57 2394000094590 EHV Site Specific 0.268 28.63 3.79 3.79 3,435.58 0.13 0.13



30/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs



ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)



(p/kVA/day)

ExportSuper Red

unit rate(p/kWh)

Exportfixed charge

(p/day)



(p/kVA/day)


827 2380001838371 58 2394000091952 EHV Site Specific 0.002 2.28 1.19 1.19 ( 0.074) 274.00 0.13 0.13768 2380001882798 59 2394000095804 EHV Site Specific 0 .016 4.26 2.95 2.95 272.03 0.13 0.13801 2380001905070 105 2394000098805 EHV Site Specific 1 .188 2.50 3.21 3.21 316.29 0.13 0.13792 2380001951360 96 2394000102693 EHV Site Specific 19.18 1.26 1.26 1,574.78 0.13 0.13806 TBC 109 TBC EHV Site Specific 0.073 45.72 2.52 2.52 1,973.30 0.13 0.13803 2380001909066 107 2394000099074 EHV Site Specific 14.15 2.08 2.08 1,771.09 0.13 0.13805 TBC 108 TBC EHV Site Specific 0.189 32.93 3.87 3.87 4,621.45 0.13 0.13825 2380002022460 56 2394000110630 EHV Site Specific 0 .087 4.10 2.58 2.58 393.12 0.13 0.13

802 23800019090752380001909084 10623940000990562394000099065 EHV Site Specific

0.162 263.74 1.81 1.81 ( 0.187) 1,776.54 0.13 0.13

807 2380002032360 63 2394000111660 EHV Site Specific 195.18 1.94 1.94 1,717.58 0.13 0.13



31/48

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


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs

Name

ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)


Importexceeded

capacity rate(p/kVA/day)

75023000005996572336541294017


751

230000070251723000007025262300000702535237655500201023765550020292376555002038


753 2356555555010 EHV Site Specific 0.781 6,271.33 2.28 2.28754 2356555554017 EHV Site Specific 0.487 9,377.56 1.48 1.48755 2316521850010 EHV Site Specific 0.058 4,347.17 2.31 2.31756 2346540436013 EHV Site Specific 0.017 5,931.03 1.49 1.49757 2336566756217 EHV Site Specific 796.98 2.44 2.44758 2366591411116 EHV Site Specific 0.104 7,952.88 0.84 0.84759 MSID 0645 EHV Site Specific 16,521.44 2.59 2.59

76023000008809662376509001013

EHV Site Specific - Generation Exempt 1,810.30 1.24 1.24

76123000005266862336518071011


762 2300000457400 EHV Site Specific - Generation Exempt 0.062 120.35 1.34 1.34

76323000007758532376509000010

EHV Site Specific - Generation Exempt 0.015 829.91 0.76 0.76

Notes

Northern Powergrid (Yorkshire) plc - Effective from April 2014 - Final EDCM import charges


Time periods




32/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs

Name

ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)


Importexceeded


764230000023395923000002339682300000233977


765230000045708423900000108402390000010859


76623765080300132376508030022

EHV Site Specific - Generation Exempt 215.85 1.18 1.18

767MSID 7020MSID 7021

EHV Site Specific - Generation Exempt 170.52 1.39 1.39

769 2346526241119 EHV Site Specific 0.083 7,952.88 1.99 1.99770 2366591365115 EHV Site Specific 0.115 7,952.88 1.90 1.90771 2366591376117 EHV Site Specific 0.043 1,988.22 0.84 0.84772 2366591373116 EHV Site Specific 0.058 7,952.88 1.98 1.98773 2366591486111 EHV Site Specific 0.136 7,952.88 2.05 2.05

77423265229100112326522910020

EHV Site Specific - Generation Exempt 2.636 230.24 1.21 1.21

775 2380000531989 EHV Site Specific 0.051 352.88 0.88 0.88777 2300000233596 EHV Site Specific - Generation Exempt 0.612 9.21 1.04 1.047 78 2 300 0004 438 16 EHV Site Speci fic - Genera tion Part Exem pt 6.38 2.30 2.30780 2380000825051 EHV Site Specific 0.011 1,062.64 0.55 0.55781 2300000790540 EHV Site Specific - Generation Exempt 147.48 1.05 1.05

78223000010162882300001016297


783 2300000974268 EHV Site Specific - Generation Exempt 0 .137 10.23 1.77 1.77784 2300001007247 EHV Site Specific - Generation Exempt 0.028 1.37 2.21 2.21785 2380000151720 EHV Site Specific - Generation Exempt 0.068 4.08 0.80 0.80786 2380000148115 EHV Site Specific - Generation Exempt 2.74 0.76 0.76

78723800001234212380000123430


788 2380000654644 EHV Site Specific 0.094 0.71 1.47 1.47789 2380001118812 EHV Site Specific 38.88 1.35 1.35790 2380001476585 EHV Site Specific 0 .067 12.15 1.28 1.28791 2380001494334 EHV Site Specific 0.148 5.38 1.33 1.33



33/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs

Name

ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)


Importexceeded


793238000125282923800012528382380001767827

EHV Site Specific 0 .323 73.36 1.24 1.24


7952380001532167

2380001532176EHV Site Specific 0.079 1,908.51 1.01 1.01


83123165303051102316530305129


832 2316541311014 EHV Site Specific 1 .888 84.32 2.78 2.78

83323265110150142326511015023


834230000045690323000005166052326531140128


83523000004736252336505790019


83623000004736162336506255013


83723000004736342336526022010


83823000005849252336559992019


83923000002338332336566356211



841

2300000539365230000053937423365906600282336590660037


84223000005393562336593810110


84323000005414342336593980114


84423565303300142356530330023





34/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs

Name

ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)


Importexceeded


846230000044496223000006013212366531830013



8482300000457377

2366560264112EHV Site Specific 0.963 191.28 8.88 8.88

84923000006522922376503256010


850

2300000647051230000064706023765529200132376552920022


851237655082501323800000005432380000004097



85323800004288372380000428846



855

238000072419523800010789772380001078986238000107899523800010790012380001079321


856

2380001519750238000151976023800015197792380001519788



858230000083936423265262900162326526290025


85923365257110112336525711020


860233652633201723365263320262300000457057




35/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs

Name

ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)


Importexceeded


861

2300000493180230000055212523365521150172336552115026


862

2300000234163230000023417223365907700132336590770022


863

2300000234066230000023407523000002340842336590810010



86523465300350172346530035026


86723465344330192346534433028


86823565300300152356530030024


86923565303210102356530321029


87023565306202102356530620229


87123665400610172366540061026


8722300000674055230000067406423000006740732366540100010


87323000007775302366540110116


874 2300000542828 EHV Site Specific 95.64 2.67 2.67875 2366560263119 EHV Site Specific 0.963 191.28 2.77 2.77

87623000006995652366591250015


877 2366591617013 EHV Site Specific 3.220 191.28 6.65 6.65878 2376501360010 EHV Site Specific 0.495 191.28 3.49 3.49



36/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs

Name

ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)


Importexceeded


87923765021950112390000003986



88123000006344152376552766015



883

2376503230011237650801001723900000024402390000002459


884 2300000233754 EHV Site Specific 0 .016 95.64 2.28 2.28886 2380001187667 EHV Site Specific 0 .317 95.64 1.91 1.91887 2380001432843 EHV Site Specific 0 .259 95.64 2.19 2.19

888

23800014486112380001448620238000144863023800014486492380001448658


889 2380001564275 EHV Site Specific 0.165 2.42 1.59 1.59797 2390000079381 EHV Site Specific - Generation Exempt 0.470 2.20 1.78 1.78798 2380001746400 EHV Site Specific 33.67 1.21 1.21799 2380001812550 EHV Site Specific 0 .282 32.81 1.18 1.18821 2380001851381 EHV Site Specific 0.286 4.08 3.60 3.60

82223800018830362380001883045 EHV Site Specific 0 .286 10.27 3.60 3.60

823 2380001877557 EHV Site Specific 0 .122 17.40 5.41 5.41824 MSID 7275 EHV Site Specific 15.61 2.16 2.16826 2380001874087 EHV Site Specific 0 .268 28.63 3.79 3.79

86623465344000132346534400022


827 2380001838371 EHV Site Specific 0.002 2.28 1.19 1.19768 2380001882798 EHV Site Specific 0.016 4.26 2.95 2.95801 2380001905070 EHV Site Specific 1.188 2.50 3.21 3.21792 2380001951360 EHV Site Specific 19.18 1.26 1.26806 TBC EHV Site Specific 0 .073 45.72 2.52 2.52803 2380001909066 EHV Site Specific 14.15 2.08 2.08



37/48


ImportUnique

Identifier LLFC

ImportMPANs/MSIDs

Name

ImportSuper Red

unit rate(p/kWh)

Importfixed charge

(p/day)


Importexceeded


805 TBC EHV Site Specific 0.189 32.93 3.87 3.87


80223800019090752380001909084





38/48

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


ExportUnique

Identifier LLFC

ExportMPANs/MSIDs

Name

ExportSuper Red

unit rate(p/kWh)

Exportfixed charge

(p/day)


Exportexceeded


90 2394000039650 EHV Site Specific 104.52 0.13 0.1382 2394000039660 EHV Site Specific 468.88 0.13 0.1376 2394000039641 EHV Site Specific 434.72 0.13 0.1375 2394000039679 EHV Site Specific 444.83 0.13 0.1395 2394000060226 EHV Site Specific ( 0.146) 796.98 0.13 0.13

6023000002337362300000880975

EHV Site Specific - Generation Exempt

62 2300000457410 EHV Site Specific - Generation Exempt

8023000009489042300000948913


66 23000002339122300000996990


67MSID 7020MSID 7021


92 2394000019176 EHV Site Specific ( 0.043) 5,964.66 0.13 0.13

7423940000029252394100008408


87 2394000024440 EHV Site Specific ( 0.223) 1,347.35 0.13 0.1377 2300000233610 EHV Site Specific - Generation Exempt78 2 300 0004 438 25 EHV Site Speci fic - Genera tion Part Exem pt 414.54 0.13 0.1381 2300000790550 EHV Site Specific - Generation Exempt83 2300000974408 EHV Site Specific - Generation Exempt84 2300001007256 EHV Site Specific - Generation Exempt

Notes

Northern Powergrid (Yorkshire) plc - Effective from April 2014 - Final EDCM export charges


Time periods




39/48


ExportUnique

Identifier LLFC

ExportMPANs/MSIDs

Name

ExportSuper Red

unit rate(p/kWh)

Exportfixed charge

(p/day)


Exportexceeded


85 2394000011646 EHV Site Specific - Generation Exempt

8623911000137042394000011502


88 2394000027673 EHV Site Specific ( 0.313) 1,593.26 0.13 0.1389 2394000043364 EHV Site Specific ( 0.103) 1,555.09 0.13 0.13

94 2394000056790 EHV Site Specific 816.71 0.13 0.1393 2394000058333 EHV Site Specific ( 0.338) 270.91 0.13 0.13

91239400004758123940000475902394000047606

EHV Site Specific 1,796.90 0.13 0.13

97 2394000055174 EHV Site Specific 9,724.21 0.13 0.1398 2394000072198 EHV Site Specific 5,211.58 0.13 0.1373 2300000233587 EHV Site Specific ( 1.864) 11.32 0.13 0.1368 2300000233898 EHV Site Specific ( 0.168) 40.27 0.13 0.1371 2394000016040 EHV Site Specific - Generation Exempt72 2394000022132 EHV Site Specific - Generation Exempt69 2300000930377 EHV Site Specific ( 5.359) 84.37 0.13 0.1370 2394000039590 EHV Site Specific ( 0.165) 93.22 0.13 0.1399 2394000079398 EHV Site Specific - Generation Exempt61 2394000083311 EHV Site Specific 2,721.33 0.13 0.1351 2394000089457 EHV Site Specific ( 0.282) 3,281.15 0.13 0.1352 2394000093027 EHV Site Specific 272.20 0.13 0.13

5323940000958312394000095840 EHV Site Specific 266.02 0.13 0.13

54 2394000097068 EHV Site Specific 3,754.98 0.13 0.1355 MSID 7275 EHV Site Specific 538.45 0.13 0.1357 2394000094590 EHV Site Specific 3,435.58 0.13 0.1358 2394000091952 EHV Site Specific ( 0.074) 274.00 0.13 0.1359 2394000095804 EHV Site Specific 272.03 0.13 0.13

105 2394000098805 EHV Site Specific 316.29 0.13 0.1396 2394000102693 EHV Site Specific 1,574.78 0.13 0.13

109 TBC EHV Site Specific 1,973.30 0.13 0.13107 2394000099074 EHV Site Specific 1,771.09 0.13 0.13108 TBC EHV Site Specific 4,621.45 0.13 0.13



40/48


ExportUnique

Identifier LLFC

ExportMPANs/MSIDs

Name

ExportSuper Red

unit rate(p/kWh)

Exportfixed charge

(p/day)


Exportexceeded



10623940000990562394000099065

EHV Site Specific ( 0.187) 1,776.54 0.13 0.13

63 2394000111660 EHV Site Specific 1,717.58 0.13 0.13



41/48

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 chargep/MPAN/day

Domestic U nrestricted 101, 400, 401, 999 1 2.263 4.71

Domestic Two Rate 121, 123, 402, 403, 413 2 2.829 0.101 4.71

Domestic Off Peak (related MPAN) 130, 131, 414, 415, 416 2 0.390

Small Non D omestic Unrestricted 241, 404, 405 3 2.254 4.32

Small Non Domestic Two Rate 249, 250, 275, 406, 407, 417, 418 4 2.946 0.185 4.32

Small Non Domestic Off Peak (relatedMPAN) 268, 419, 420 4 0.503

LV Medium Non-Domestic 280, 287, 408, 409, 421 5-8 2.236 0.063 30.40

HV Medium Non-Domestic 410 5-8 1.764 0.036 210.59

LV Generation NHH 17, 18, 21, 411, 412 8 ( 0.574)

Closed LLFCs PCsUnit rate 1

p/kWh(red/black)

Unit rate 2p/kWh

(amber/yellow)

Unit rate 3p/kWh(green)

Fixed chargep/MPAN/day

Capacity chargep/kVA/day

Reactive powercharge

p/kVArh

Excess Capacitychargep/kVA

LV HH Metered 244, 248, 257, 291, 297 0 9.377 0.963 0.051 13.06 1.46 0.329 1.46

LV Sub HH Metered 472 0 8.256 0.786 0.040 43.66 1.93 0.269 1.93

HV HH Metered 500, 501, 502, 741, 742, 743, 744 0 6.522 0.573 0.027 111.03 1.81 0.198 1.81

LV Generation Intermittent 12, 40 0 ( 0.574) 0.134

LV Sub Generation Intermittent 14 0 ( 0.504) 0.128

HV Generation Intermittent 15, 41 0 ( 0.357) 117.36 0.098

Notes:

Northern Powergrid (Yorkshire) plc - Effective from April 2014 - Final LV and HV tariffs

NHH preserved charges/additional LLFCs

All NHH tariffs detailed above are clo