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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 1 April 2013

Version 1.0

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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2013 PAGE 2

Annex 5 – Schedule of Line Loss Factors 29

Annex 6 - Un-scaled [nodal /network group] costs 32

Annex 7 – Addendum to charging statement detailing Charges for New Designated EHV Properties 33


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 LV/HV Designated Properties and the EHV

Distribution Charging Methodology (EDCM) for Designated EHV Properties.

The application of charges to a premise can be referenced using the Line Loss

Factor Class (LLFC) contained in the charge tables.

1.3. 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]

1.4. 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

e-mail:- [email protected]

1 Charges can be positive or negative.

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2.9. 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.

2.10. To determine the appropriate charge rate for each SSC/TPR a look-up table is

provided in the ENA spreadsheet that accompanies this statement2.

2.11. 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

2.12. Site-specific billing and payment applies to Metering Points registered as Half

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

System billing makes use of HH metering data received through Settlement.

2.13. Invoices are calculated on a periodic basis and sent to each User, for whom

Northern Powergrid is transporting electricity through its Distribution System.

Where an account 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.

2.14. The charges are applied on the basis of the Line Loss Factor Classes (LLFCs)

assigned to the MPAN (or the MSID for CVA sites), and the units consumed

within the time periods specified in this statement. All LLFCs are assigned at

the sole discretion of Northern Powergrid. 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. The charges in

this document are shown exclusive of VAT.

Site-Specific Billed Charges

2.15. Site-Specific billed charges may include the following components:

A fixed charge pence/MPAN/day;

A capacity charge, pence/kVA/day, for agreed Maximum Import Capacity (MIC) and/or Maximum Export Capacity (MEC);

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

Unit charges, pence/kWh, for transportation of electricity over the system; and

2 Northern Powergrid Northeast - Schedule of charges and other tables - Version7.xlsx


An excess reactive power charge, pence/kVArh, for each unit in excess of the reactive charge threshold.

2.16. These charges apply to Exit/Entry Points where HH metering, or an equivalent

meter, is used for Settlement purposes.

2.17. Users who wish to supply electricity to Customers whose Metering System is

Measurement Class C or E or CVA will be allocated the relevant charge

structure dependent upon the voltage and location of the Metering Point.

2.18. 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.

2.19. LV & HV Designated Properties as calculated using the CDCM will be allocated

the relevant charge structure set out in Annex 1.

2.20. Designated EHV Properties as calculated using the EDCM will be allocated the

relevant charge structure set out in Annex 2.

Time Periods for Half Hourly Metered Properties

2.21. The time periods for the application of unit charges to LV & HV Designated

Properties, which are HH metered are as follows:

All times are UK clock time.

Northern Powergrid Northeast has not issued a notice to change the time bands.

2.22. The time periods for the application of unit charges to Designated EHV

Properties are as follows:

Unit charges to LV & HV Designated Properties which are HH metered

Monday to Friday (Including Bank

Holidays) Saturday Sunday

Red Unit Rate 1 Apr - Mar 16:00 to 19:30 N/A

Amber Unit Rate 2 Apr - Mar 08:00 to 16:00 19:30 to 22:00

N/A

Green Unit Rate 3 Apr - Mar 00:00 to 08:00 22:00 to 24:00

00:00 to 24:00


Unit charges to Designated EHV Properties

Monday to Friday (Including Bank

Holidays) Saturday Sunday

Super Red

Unit Rate 1 Nov to Feb 16:00 to 19:30 N/A


Northern Powergrid Northeast has not issued a notice to change the time bands

Charges for Unmetered Supplies

2.23. Users who wish to supply electricity to Customers whose Metering System is

Measurement Class B or Measurement Class D will be allocated the relevant

charge structure in Annex 1.

2.24. These charges are available to Exit Points which Northern Powergrid deems to

be suitable as Unmetered Supplies as permitted in the Electricity (Unmetered

Supply) Regulations 20013 and where operated in accordance with BSCP5204.

Time Periods for Half Hourly Unmetered Properties

2.25. The time periods for the application of unit charges to connections which are

pseudo HH metered are the same area as follows:

Unit charges for pseudo HH unmetered supplies

Monday to Friday Saturday Sunday

Black Unit Rate 1 Nov to Feb 16:00 to 19:30 N/A

Yellow Unit Rate 2

Apr to Oct and Mar

16:00 to 19:30 N/A

Apr to Mar 08:00 to 16:00 19:30 to 22:00

N/A

Green Unit Rate 3 Apr to Mar 00:00 to 08:00 22:00 to 24:00

00:00 to 24:00


Northern Powergrid Northeast has not issued a notice to change the time bands

3 The Electricity (Unmetered Supply) Regulations 2001 available from: http://www.legislation.gov.uk/uksi/2001/3263/made 4 Balancing and Settlement Code Procedures on unmetered supplies and available from: http://www.elexon.co.uk/pages/bscps.aspx


Use of System Charges Out of Area

2.26. Northern Powergrid does not operate networks outside its Distribution Service

Area.

Application of Capacity Charges

Chargeable Capacity

2.27. The Chargeable Capacity is, for each billing period, the highest of the MIC/MEC

or the actual capacity, calculated as detailed below.

2.28. 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 1.4.

2.29. 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 cost.

Demand Chargeable Capacity

)MIC,)RE,RImax(AIMax(2 Capacity Chargeable Demand 22

Where:

AI = Import consumption in kWh

RI = Reactive import in kVArh

RE = Reactive export in kVArh

MIC = Maximum Import Capacity in kVA

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

the billing period is captured.

2.31. Only kVArh Import and kVArh Export values occurring at times of kWh Import

are used.


Generation Chargeable Capacity

)MEC,)RE,RImax(AEMax(2 Capacity Chargeable Generation 22

Where:

AE = Export Production in kWh

RI = Reactive import in kVArh

RE = Reactive export in kVArh

MEC = Maximum Export Capacity in kVA

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

the billing period is captured.

2.33. Only kVArh Import and kVArh Export values occurring at times of kWh Export

are used.

Standby Capacity for Additional Security on Site

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

rate as that applied to normal MIC.

Exceeded Capacity

2.35. 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.

This will be charged for the duration of the full month in which the breach

occurs.

Minimum Capacity Levels

2.36. There is no minimum capacity threshold.

Application of charges for excess reactive power

2.37. The excess reactive power charge applies when a site’s reactive power

(measured in kVArh) exceeds 33% of total active power (measured in kWh) in

any half-hourly period. 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.

2.38. Power Factor is calculated as follows:


Cos θ = Power Factor

2.39. 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

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

the billing period.

2.41. Only kVArh Import and kVArh Export values occurring at times of kWh Import

are used.

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

Generation Chargeable Reactive Power

Where:

AE = Active Export in kWh

RI = Reactive Import in kVArh

RE = Reactive Export in kVArh

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

the billing period.

2.44. Only kVArh Import and kVArh Export values occurring at times of kWh Export

are used.

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

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Export charges for pre-2005 Designated EHV Properties

2.46. Designated EHV Properties that were connected to the distribution system

under a pre-2005 connection charging policy are eligible for exemption from

Export Use of System charges unless one of the following criteria has been

met;

• 25 years have passed since their first energisation/connection date; or

• The Designated EHV Property has provided notice to Northern Powergrid that

they wish to opt in to Export Use of System charges.

Designated EHV Properties with energisation/connection agreements dated

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

energisation/connection date will receive Export Use of System charges from

the next charging year (starting 1st April) following the expiry of their 25 years

exemption.

If a notice to opt-in has been provided there will be no opportunity in the future

to opt-out.

2.47. Furthermore if an exempt customer makes a significant alteration to their export

requirement (due to, for example, increased export capacity) the incremental

increase in export capacity will be treated as non-exempt and will be liable to

Export Use of System charges.

Provision of billing data

2.48. Where HH metering data is required for Use of System 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 the 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 provided

in a comma separated text file in the format of D0036 MRA data flow (as agreed

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

[email protected]

2.49. Northern Powergrid requires reactive consumption or production to be provided

for all Measurement Class C (mandatory HH metered) sites and for


Measurement Class E (elective HH metered sites). Northern Powergrid

reserves the right to levy a charge on Users who fail to provide such reactive

data.

Licensed Distributor Network Operator (LDNO) charges

2.50. LDNO charges are applied to LDNOs who operate Embedded Networks within

Northern Powergrid’s area.

2.51. The charge structure for LV and HV Designated Properties end users

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.

2.52. 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.

2.53. The charge structure for Designated EHV Properties end-users embedded in

Networks operated by LDNOs will be calculated individually using the EDCM.

2.54. For Nested Networks the Host DNO charges (or pays) the Nested LDNO on the

basis of discounted charges for the voltage of connection of the Intermediate

LDNO to the Host DNO, irrespective of the connection of the Nested LDNO to

the Intermediate LDNO. Additional arrangements might exist between the

Nested LDNO and the Intermediate LDNO; these arrangements are not

covered in this statement.

NORTHE

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registering and using the portal can be downloaded from

https://www.bsccentralservices.com/index.php/userguide/download.

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Term Definition

Distribution System

The system consisting (wholly or mainly) of:

electric lines owned or operated by an authorised distributor that is used for the distribution of electricity from grid supply points or generation sets or other Entry Points to the points of delivery to Customers or Users; or

any transmission licensee in its capacity as operator of that licensee’s transmission system or the GB transmission system;

and includes any remote transmission assets (owned by a transmission licensee within England and Wales) that are operated by that authorised distributor and any electrical plant, electricity meters, and Metering Equipment owned or operated by it in connection with the distribution of electricity, but does not include any part of the GB transmission system.

EDCM The EHV Distribution Charging Methodology used for calculating charges to Designated EHV Properties as required by standard licence condition 13B of the Electricity Distribution Licence..

Electricity Distributor

Any person who is authorised by an Electricity Distribution Licence to distribute electricity.

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

Embedded Network

An electricity Distribution System operated by an LDNO and embedded within another distribution network.

Entry Point

A boundary point at which electricity is exported onto a Distribution System to a connected installation or to another Distribution System, not forming part of the total system ( boundary point and total system having the meaning given to those terms in the BSC)

Exit Point A point of connection at which a supply of electricity may flow from the Distribution System to the Customer’s Installation or User’s Installation or the Distribution System of another person.

Extra High Voltage (EHV)

Nominal voltages of 22kV and above.

Gas and Electricity Markets Authority (GEMA) (the Authority)

As established by the Utilities Act.

Grid Supply Point A metered connection between the National Grid Electricity Transmission (NGET) system and The licensee’s Distribution System at which electricity flows to or from the Distribution System.

GSP Group Grid Supply Point Group; a distinct electrical system, that is supplied from one or more Grid Supply Points for which total supply into the GSP Group can be determined for each half-hour.

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


Term Definition

Host DNO A distribution network operator that is responsible for a Distribution Services Area as defined in Standard conditions of the Electricity Distribution Licence

Intermediate LDNO

An embedded licenced distribution network operator that is responsible for a Distribution System between a Host DNO and another Embedded Distribution System.

Invalid Settlement Combination

A Settlement combination that is not recognised as a valid combination in Market Domain Data. http://mddonline.elexon.co.uk/default.aspx

kVA Kilovolt amperes

kVArh Kilovolt ampere reactive hour

kW Kilowatt

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

LDNO Licensed Distribution Network Operator.

Line Loss Factor Class (LLFC)

An identifier assigned to an SVA Metering System which is used to assign the LLF and Use of System Charges.

Line Loss Factor (LLF)

The factor which is used in Settlement to adjust the Metering System volumes to take account of losses on the Distribution System.

Low Voltage (LV) Nominal voltages below 1kV

Market Domain Data (MDD)

Market Domain Data is a central repository of reference data used by all Users involved in Settlement. It is essential to the operation of Supplier Volume Allocation (SVA) Trading Arrangements.

Maximum Export Capacity (MEC)

The Maximum Export Capacity of apparent power expressed in kVA that has been agreed can flow through the Entry Point to the Distribution System from the Customer’s installation as specified in the connection agreement.

Maximum Import Capacity (MIC)

The Maximum Import Capacity of apparent power expressed in kVA that has been agreed can flow through the Exit Point from the Distribution System to the Customer’s installation as specified in the connection agreement.

Measurement Class

A classification of Metering Systems which indicates how Consumption 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 above 100kW Premises (equivalent to Measurement Class “C”)

Half Hourly Unmetered Supplies (equivalent to Measurement Class “D”)

Half Hourly Metering Equipment at below 100kW Premises (equivalent to Measurement Class “E”).


Term Definition

Metering Point

The point at which electricity is exported to or imported from the licensee’s Distribution System is measured, is deemed to be measured, or is intended to be measured and which is registered pursuant to the provisions of the MRA. (For the purposes of this statement Grid Supply Points are not ‘Metering Points’)

Metering System Particular commissioned metering equipment installed for the purposes of measuring the quantities of Exports and Imports at the Boundary Point.

MPAN Metering Point Administration Number. A number relating to a Metering Point under the MRA.

MRA The Master Registration Agreement.

MTC

Meter Timeswitch Codes (MTCs) are three digit codes allowing Suppliers to identify the metering installed in Customers’ premises. They indicate whether the meter is single or multi rate, pre-payment or credit, or whether it is ‘related’ to another meter.

Nested LDNO A distribution system operator that is responsible for a Nested Network.

Nested Networks This refers to a situation where there is more than one level of Embedded Network and therefore nested distribution systems between LDNOs (e.g. Host DNOintermediate LDNOnested LDNOCustomer).

Ofgem Office of Gas and Electricity Markets – Ofgem is governed by GEMA and is responsible for the regulation of the distribution companies.

Profile Class (PC) A categorisation applied to NHH MPANs and used in Settlement to group customers with similar consumption patterns to enable the calculation of consumption profiles.

Settlement The determination and settlement of amounts payable in respect of charges (including reconciling charges) in accordance with the Balancing and Settlement Code

Settlement Class (SC)

The combination of Profile Class, Line Loss Factor Class, Time Pattern Regime and Standard Settlement Configuration, by Supplier within GSP Group and used for Settlement.

Standard Settlement Configuration (SSC)

A standard metering configuration relating to a specific combination of TPRs.

Supercustomer The method of billing Users for Use of System on an aggregated basis, grouping consumption and standing charges for all similar NHH metered Customers together.

Supercustomer DUoS Report

A report of profiled data by Settlement Class providing counts of MPANs and units consumed.

Supplier An organisation with a Supply License which can register itself as supplying electricity to a Metering Point.


Term Definition

Supplier Volume Allocation (SVA)

As defined in the Balancing and Settlement Code.

Supplier Volume Allocation Agent (SVAA)

The agency which uses aggregated consumption data from the Data Aggregator to calculate Supplier purchases by Settlement Class for each Settlement day, and then passes this information to the relevant distributors and Suppliers across the national data transfer network.

Time Pattern Regime (TPR)

The pattern of switching behaviour though time that one or more meter registers follow.

Use of System Charges

Charges for demand and generation Customers which are connected to and utilising the distribution network.

User/s Someone who has a use of system agreement with the DNO e.g. A Supplier, Generator or LDNO.


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

Open LLFCs PCsUnit rate 1

p/kWhUnit rate 2 p/kWh

Unit rate 3 p/kWh

Fixed charge p/MPAN/day

Capacity charge

p/kVA/day

Reactive power charge p/kVArh

Excess Capacity charge(p/kVA)

Closed LLFCs

Domestic Unrestricted 1 1 2.467 4.42 5, 21, 25, 998, 999

Domestic Two Rate 2 2 2.969 0.188 4.42 6, 16, 22, 26, 36

Domestic Off Peak (related MPAN) 12 2 0.356 . 8, 28, 32

Small Non Domestic Unrestricted 203 3 2.322 4.06 202, 222, 223

Small Non Domestic Two Rate 204 4 2.877 0.243 4.06 201, 221, 224

Small Non Domestic Off Peak (related MPAN) 205 4 0.419 . 225

LV Medium Non-Domestic 257 5-8 2.132 0.163 23.02256, 267, 268, 276,

277, 287, 288

LV Sub Medium Non-Domestic 265 5-8 2.085 0.191 55.47 264, 284, 285

HV Medium Non-Domestic 304 5-8 1.594 0.101 185.30 303, 323, 324

LV HH Metered 251 0 9.072 1.097 0.121 12.30 1.40 0.344 1.40 253, 655

LV Sub HH Metered 293 0 8.417 0.889 0.089 41.10 2.05 0.283 2.05 -

HV HH Metered 301 0 6.743 0.627 0.057 104.51 1.83 0.215 1.83 610, 666, 674, 677

HV Sub HH Metered

NHH UMS category A 506 8 1.445 504, 505

NHH UMS category B 507 1 1.894 504, 505

NHH UMS category C 508 1 3.440 504, 505

NHH UMS category D 509 1 1.145 504, 505

LV UMS (Pseudo HH Metered) 554 & 555 0 25.830 1.239 0.143 -

LV Generation NHH 774 8 ( 0.634)772, 773, 775, 800,

801

LV Sub Generation NHH 776 8 ( 0.557) -

LV Generation Intermittent 792 0 ( 0.634) 0.151705, 716, 720, 722, 724, 725, 733, 736,

746, 758, 770

LV Generation Non-Intermittent 794 0 ( 2.762) ( 0.889) ( 0.117) 0.151713, 739, 740, 744,

790

LV Sub Generation Intermittent 793 0 ( 0.557) 0.143 -

LV Sub Generation Non-Intermittent 795 0 ( 2.414) ( 0.784) ( 0.102) 0.143 -

HV Generation Intermittent 796 0 ( 0.365) 110.48 0.109

702, 703, 706, 715, 717, 723, 726, 730, 734, 749, 750, 752, 754, 755, 756, 771

HV Generation Non-Intermittent 798 0 ( 1.544) ( 0.531) ( 0.065) 110.48 0.109

707, 708, 712, 721, 731, 732, 735, 743, 745, 747, 751, 753,

791

HV Sub Generation Non-Intermittent

HV Sub Generation Intermittent

The unmetered supplies tariffs detailed above reflects the methodology approved by Ofgem in DCP 130 which introduces seasonal time of day tariffs for Pseudo HH metered and addresses the discrepancy between HH and NHH unmetered tariffs.

Northern Powergrid (Northeast) - Effective from April 2013 - Final LV/HV Charges

Notes: Generally NHH DUoS charges are only available to premises with maximum demand less than 100 kW.

Generally domestic DUoS charges are available only to premises:a) used exclusively as a single private residence; orb) comprising more than one private residence where the estimated maximum demand of the supply does not exceed 25 kW

Northern Powergrid uses a default tariff for invalid settlement combinations these will be charged at the Domestic Unrestricted rates. Default charges will apply where a supplier registers an invalid combination of PC, MTC and SSC against an LLFC for a given metering point.

LV Sub applies to customers connected to the licensee's distribution system at a voltage of less than 1 kV at a substation with a primary voltage (the highest operating voltage present at the substation) of at least 1 kV and less that 22kV, where the current transformer used for the customer's settlement metering is located at the substation.


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

Import LLFC - Unique Identifier

Export LLFC - Unique Identifier

Import MPANs / MSIDs Export MPANs / MSIDs NameImport 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)

601 70115920010057701592101005776

15740002161351594001005774

EHV Site Specific - Generation Exempt 1,355.05 0.74 0.74

603 1592001051182 EHV Site Specific 7,207.57 1.61 1.61

604 727 1570000223279 1574000223285 EHV Site Specific 78.00 0.82 0.82 1,638.08 0.08 0.08

605 1592001092676 EHV Site Specific 0.571 3,841.99 1.58 1.58




609 1592001046085 EHV Site Specific 512.27 2.80 2.80


612 704 1592001073112 1594001073116 EHV Site Specific 0.770 93.72 1.33 1.33 ( 0.892) 1,312.10 0.08 0.08

613 1592001116013 EHV Site Specific 0.593 153.68 3.68 3.68

614 709 1592001055257 1594001055250 EHV Site Specific - Generation Exempt 4,425.40 0.78 0.78

615 & 61615920010552391592001055248

EHV Site Specific 0.437 2,843.59 1.52 1.52



619 710 1570000150382 1594000000038 EHV Site Specific - Generation Exempt 0.037 34.71 1.52 1.52



622 711 1592001036574 1594001036578 EHV Site Specific - Generation Exempt 0.143 1,172.52 1.49 1.49


625 748 1592001006890 1594001006893 EHV Site Specific - Generation Exempt 1.249 104.93 2.15 2.15

627 729 1570000199077 1574000199083 EHV Site Specific - Generation Exempt 1,308.23 0.71 0.71







637 728 1592001141543 1594001141547 EHV Site Specific - Generation Exempt 0.028 3,024.62 1.38 1.38

680 759 1580000675845 1574000275033 EHV Site Specific 8.061 5.41 1.88 1.88 216.57 0.08 0.08

681 760 1580000872387 1574000283735 EHV Site Specific 0.141 87.33 1.22 1.22 3,493.10 0.08 0.08

761 1594000000047 EHV Site Specific - Generation Exempt 0.71 0.71



683 763 1570000166434 1594000000029 EHV Site Specific - Generation Exempt 16.47 1.40 1.40

69215800009117991580000867554

EHV Site Specific 0.579 153.68 3.52 3.52



69515800009181721580000918163

EHV Site Specific 153.68 3.40 3.40


685 765 1580001132432 1574000302403 EHV Site Specific 46.07 1.41 1.41 1,451.11 0.08 0.08

686 76615800011505661580001150575

15740003039401574000303959

EHV Site Specific 260.42 1.12 1.12 16,927.11 0.08 0.08

687 TBC EHV Site Specific 1,824.10 1.49 1.49




540 783 1580001190763 1574000307917 EHV Site Specific 0.002 9.94 2.21 2.21 ( 0.035) 835.29 0.08 0.08


542 785 TBC TBC EHV Site Specific 269.61 2.10 2.10 498.78 0.08 0.08

543 TBC EHV Site Specific 2,561.33 3.81 3.81

Northern Powergrid (Northeast) - Effective from April 2013 - Final EDCM Charges


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 Unrestricted 5, 21, 25, 998, 999 1 2.467 . 4.42

Domestic Two Rate 6, 16, 22, 26, 36 2 2.969 0.188 4.42

Domestic Off Peak (related MPAN)

8, 28, 32 2 0.356 . .

Small Non Domestic Unrestricted

202, 222, 223 3 2.322 . 4.06

Small Non Domestic Two Rate 201, 221, 224 4 2.877 0.243 4.06

Small Non Domestic Off Peak (related MPAN)

225 4 0.419 . .

LV Medium Non-Domestic 256, 267, 268, 276, 277, 287, 288 5-8 2.132 0.163 23.02

LV Sub Medium Non-Domestic 264, 284, 285 5-8 2.085 0.191 55.47

HV Medium Non-Domestic 303, 323, 324 5-8 1.594 0.101 185.30

LV Generation NHH 772, 773, 775, 800, 801 8 ( 0.634) . .

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

Capacity charge

p/kVA/day


Excess Capacity charge(p/kVA)

LV HH Metered 253, 655 0 9.072 1.097 0.121 12.30 1.40 0.344 1.40

HV HH Metered 610, 666, 674, 677 0 6.743 0.627 0.057 104.51 1.83 0.215 1.83

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

746, 758, 7700 ( 0.634) . . . . 0.151 .

LV Generation Non-Intermittent

713, 739, 740, 744, 790 0 ( 2.762) ( 0.889) ( 0.117) . . 0.151 .

HV Generation Intermittent702, 703, 706, 715, 717, 723, 726, 730, 734, 749, 750, 752, 754, 755, 756, 771

0 ( 0.365) . . 110.48 . 0.109 .

HV Generation Non-Intermittent

707, 708, 712, 721, 731, 732, 735, 743, 745, 747, 751, 753, 791

0 ( 1.544) ( 0.531) ( 0.065) 110.48 . 0.109 .

Details of the relevant time periods can be found in the LC14 Charging Statement

Northern Powergrid (Northeast) - Effective from April 2013 - Final LV/HV Tariffs

NHH Preserved Charges/Additional LLFC Classes

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 connections will be required to be half-hourly metered

Details of the relevant time periods can be found in the LC14 Charging Statement

Notes:

HH Preserved Charges/Additional LLFC Classes

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

Following a change to the boundary definition, all CDCM - HV Sub tariffs have now been closed. All "Designated EHV properties" have been moved to the EDCM. Customers who do not meet the definition of "Designated EHV properties" will be moved to HV network from 1 April 2013.

Notes:


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

Unique billing identifier

PCs Unit rate 1 p/kWh Unit rate 2 p/kWh Unit rate 3 p/kWhFixed charge p/MPAN/day

Capacity charge p/kVA/day


Excess capacity charge(p/kVA)

LDNO LV: Domestic Unrestricted 150 1 1.606 2.88

LDNO LV: Domestic Two Rate 151 2 1.932 0.122 2.88

LDNO LV: Domestic Off Peak (related MPAN) 152 2 0.232

LDNO LV: Small Non Domestic Unrestricted 153 3 1.511 2.64

LDNO LV: Small Non Domestic Two Rate 154 4 1.873 0.158 2.64

LDNO LV: Small Non Domestic Off Peak (related MPAN) 155 4 0.273

LDNO LV: LV Medium Non-Domestic 156 5-8 1.388 0.106 14.98

LDNO LV: LV HH Metered 157 0 5.905 0.714 0.079 8.01 0.91 0.224 0.91

LDNO LV: NHH UMS category A 37 8 0.940

LDNO LV: NHH UMS category B 38 1 1.233

LDNO LV: NHH UMS category C 39 1 2.239

LDNO LV: NHH UMS category D 40 1 0.745

LDNO LV: LV UMS (Pseudo HH Metered) 170 0 16.812 0.806 0.093

LDNO LV: LV Generation NHH 172 8 ( 0.634)

LDNO LV: LV Generation Intermittent 173 0 ( 0.634) 0.151

LDNO LV: LV Generation Non-Intermittent 174 0 ( 2.762) ( 0.889) ( 0.117) 0.151

LDNO HV: Domestic Unrestricted 158 1 0.946 1.69

LDNO HV: Domestic Two Rate 159 2 1.138 0.072 1.69

LDNO HV: Domestic Off Peak (related MPAN) 160 2 0.136

LDNO HV: Small Non Domestic Unrestricted 161 3 0.890 1.56

LDNO HV: Small Non Domestic Two Rate 162 4 1.103 0.093 1.56

LDNO HV: Small Non Domestic Off Peak (related MPAN) 163 4 0.161 .

LDNO HV: LV Medium Non-Domestic 164 5-8 0.817 0.062 8.83

LDNO HV: LV HH Metered 165 0 3.478 0.421 0.046 4.72 0.54 0.132 0.54

LDNO HV: LV Sub HH Metered 166 0 5.227 0.552 0.055 25.52 1.27 0.176 1.27

LDNO HV: HV HH Metered 167 0 5.007 0.466 0.042 77.61 1.36 0.160 1.36

LDNO HV: NHH UMS category A 41 8 0.554

LDNO HV: NHH UMS category B 42 1 0.726

LDNO HV: NHH UMS category C 43 1 1.319

LDNO HV: NHH UMS category D 44 1 0.439

LDNO HV: LV UMS (Pseudo HH Metered) 171 0 9.904 0.475 0.055

LDNO HV: LV Generation NHH 175 8 ( 0.634)

LDNO HV: LV Sub Generation NHH 176 8 ( 0.557)

LDNO HV: LV Generation Intermittent 177 0 ( 0.634) 0.151

LDNO HV: LV Generation Non-Intermittent 178 0 ( 2.762) ( 0.889) ( 0.117) 0.151

LDNO HV: LV Sub Generation Intermittent 179 0 ( 0.557) 0.143

LDNO HV: LV Sub Generation Non-Intermittent 180 0 ( 2.414) ( 0.784) ( 0.102) 0.143

LDNO HV: HV Generation Intermittent 181 0 ( 0.365) 0.109

LDNO HV: HV Generation Non-Intermittent 182 0 ( 1.544) ( 0.531) ( 0.065) 0.109

LDNO HVplus: Domestic Unrestricted 50 1 0.724 1.30

LDNO HVplus: Domestic Two Rate 51 2 0.872 0.055 1.30

LDNO HVplus: Domestic Off Peak (related MPAN) 52 2 0.105

LDNO HVplus: Small Non Domestic Unrestricted 53 3 0.682 1.19

LDNO HVplus: Small Non Domestic Two Rate 54 4 0.845 0.071 1.19

LDNO HVplus: Small Non Domestic Off Peak (related MPAN) 55 4 0.123

LDNO HVplus: LV Medium Non‐Domestic 56 5-8 0.626 0.048 6.76

LDNO HVplus: LV Sub Medium Non‐Domestic

LDNO HVplus: HV Medium Non‐Domestic

LDNO HVplus: LV HH Metered 57 0 2.664 0.322 0.036 3.61 0.41 0.101

LDNO HVplus: LV Sub HH Metered 58 0 4.000 0.422 0.042 19.53 0.97 0.134

LDNO HVplus: HV HH Metered 59 0 3.875 0.360 0.033 60.06 1.05 0.124

LDNO HVplus: NHH UMS category A 45 8 0.424

LDNO HVplus: NHH UMS category B 46 1 0.556

LDNO HVplus: NHH UMS category C 47 1 1.010

LDNO HVplus: NHH UMS category D 48 1 0.336

LDNO HVplus: LV UMS (Pseudo HH Metered) 61 0 7.585 0.364 0.042

LDNO HVplus: LV Generation NHH 62 8 ( 0.301) .

LDNO HVplus: LV Sub Generation NHH 63 8 ( 0.320) .

LDNO HVplus: LV Generation Intermittent 64 0 ( 0.301) . 0.072

LDNO HVplus: LV Generation Non‐Intermittent 65 0 ( 1.312) ( 0.422) ( 0.056) . 0.072

LDNO HVplus: LV Sub Generation Intermittent 66 0 ( 0.320) . 0.082

LDNO HVplus: LV Sub Generation Non‐Intermittent 67 0 ( 1.387) ( 0.451) ( 0.059) . 0.082

LDNO HVplus: HV Generation Intermittent 68 0 ( 0.365) 110.48 0.109

LDNO HVplus: HV Generation Non‐Intermittent 69 0 ( 1.544) ( 0.531) ( 0.065) 110.48 0.109

Northern Powergrid (Northeast) - Effective from April 2013 - Final LDNO Tariffs







LDNO EHV: Domestic Unrestricted 70 1 0.507 0.91

LDNO EHV: Domestic Two Rate 71 2 0.610 0.039 0.91

LDNO EHV: Domestic Off Peak (related MPAN) 72 2 0.073

LDNO EHV: Small Non Domestic Unrestricted 73 3 0.477 0.83

LDNO EHV: Small Non Domestic Two Rate 74 4 0.592 0.050 0.83

LDNO EHV: Small Non Domestic Off Peak (related MPAN) 75 4 0.086

LDNO EHV: LV Medium Non‐Domestic 76 5-8 0.438 0.034 4.73

LDNO EHV: LV Sub Medium Non‐Domestic

LDNO EHV: HV Medium Non‐Domestic

LDNO EHV: LV HH Metered 77 0 1.865 0.226 0.025 2.53 0.29 0.071

LDNO EHV: LV Sub HH Metered 78 0 2.801 0.296 0.030 13.68 0.68 0.094

LDNO EHV: HV HH Metered 79 0 2.713 0.252 0.023 42.06 0.74 0.087

LDNO EHV: NHH UMS category A 183 8 0.297

LDNO EHV: NHH UMS category B 184 1 0.389

LDNO EHV: NHH UMS category C 185 1 0.707

LDNO EHV: NHH UMS category D 186 1 0.235

LDNO EHV: LV UMS (Pseudo HH Metered) 81 0 5.311 0.255 0.029

LDNO EHV: LV Generation NHH 82 8 ( 0.211) .

LDNO EHV: LV Sub Generation NHH 83 8 ( 0.224) .

LDNO EHV: LV Generation Intermittent 84 0 ( 0.211) . 0.050

LDNO EHV: LV Generation Non‐Intermittent 85 0 ( 0.919) ( 0.296) ( 0.039) . 0.050

LDNO EHV: LV Sub Generation Intermittent 86 0 ( 0.224) . 0.058

LDNO EHV: LV Sub Generation Non‐Intermittent 87 0 ( 0.971) ( 0.315) ( 0.041) . 0.058

LDNO EHV: HV Generation Intermittent 88 0 ( 0.256) 77.36 0.076

LDNO EHV: HV Generation Non‐Intermittent 89 0 ( 1.081) ( 0.372) ( 0.046) 77.36 0.076

LDNO 132kV/EHV: Domestic Unrestricted 90 1 0.341 0.61

LDNO 132kV/EHV: Domestic Two Rate 91 2 0.410 0.026 0.61

LDNO 132kV/EHV: Domestic Off Peak (related MPAN) 92 2 0.049

LDNO 132kV/EHV: Small Non Domestic Unrestricted 93 3 0.321 0.56

LDNO 132kV/EHV: Small Non Domestic Two Rate 94 4 0.397 0.034 0.56

LDNO 132kV/EHV: Small Non Domestic Off Peak (related MPAN) 95 4 0.058

LDNO 132kV/EHV: LV Medium Non‐Domestic 96 5-8 0.294 0.023 3.18

LDNO 132kV/EHV: LV Sub Medium Non‐Domestic

LDNO 132kV/EHV: HV Medium Non‐Domestic

LDNO 132kV/EHV: LV HH Metered 97 0 1.252 0.151 0.017 1.70 0.19 0.047

LDNO 132kV/EHV: LV Sub HH Metered 98 0 1.880 0.199 0.020 9.18 0.46 0.063

LDNO 132kV/EHV: HV HH Metered 99 0 1.822 0.169 0.015 28.23 0.49 0.058

LDNO 132kV/EHV: NHH UMS category A 187 8 0.199

LDNO 132kV/EHV: NHH UMS category B 188 1 0.261

LDNO 132kV/EHV: NHH UMS category C 189 1 0.475

LDNO 132kV/EHV: NHH UMS category D 190 1 0.158

LDNO 132kV/EHV: LV UMS (Pseudo HH Metered) 101 0 3.566 0.171 0.020

LDNO 132kV/EHV: LV Generation NHH 102 8 ( 0.142) .

LDNO 132kV/EHV: LV Sub Generation NHH 103 8 ( 0.150) .

LDNO 132kV/EHV: LV Generation Intermittent 104 0 ( 0.142) . 0.034

LDNO 132kV/EHV: LV Generation Non‐Intermittent 105 0 ( 0.617) ( 0.199) ( 0.026) . 0.034

LDNO 132kV/EHV: LV Sub Generation Intermittent 106 0 ( 0.150) . 0.039

LDNO 132kV/EHV: LV Sub Generation Non‐Intermittent 107 0 ( 0.652) ( 0.212) ( 0.028) . 0.039

LDNO 132kV/EHV: HV Generation Intermittent 108 0 ( 0.172) 51.94 0.051

LDNO 132kV/EHV: HV Generation Non‐Intermittent 109 0 ( 0.726) ( 0.250) ( 0.031) 51.94 0.051

LDNO 132kV: Domestic Unrestricted 110 1 0.179 0.32

LDNO 132kV: Domestic Two Rate 111 2 0.216 0.014 0.32

LDNO 132kV: Domestic Off Peak (related MPAN) 112 2 0.026

LDNO 132kV: Small Non Domestic Unrestricted 113 3 0.169 0.29

LDNO 132kV: Small Non Domestic Two Rate 114 4 0.209 0.018 0.29

LDNO 132kV: Small Non Domestic Off Peak (related MPAN) 115 4 0.030

LDNO 132kV: LV Medium Non‐Domestic 116 5-8 0.155 0.012 1.67

LDNO 132kV: LV Sub Medium Non‐Domestic

LDNO 132kV: HV Medium Non‐Domestic

LDNO 132kV: LV HH Metered 117 0 0.659 0.080 0.009 0.89 0.10 0.025

LDNO 132kV: LV Sub HH Metered 118 0 0.989 0.104 0.010 4.83 0.24 0.033

LDNO 132kV: HV HH Metered 119 0 0.958 0.089 0.008 14.85 0.26 0.031

LDNO 132kV: NHH UMS category A 191 8 0.105

LDNO 132kV: NHH UMS category B 192 1 0.138

LDNO 132kV: NHH UMS category C 193 1 0.250

LDNO 132kV: NHH UMS category D 194 1 0.083

LDNO 132kV: LV UMS (Pseudo HH Metered) 121 0 1.876 0.090 0.010

LDNO 132kV: LV Generation NHH 122 8 ( 0.075) .

LDNO 132kV: LV Sub Generation NHH 123 8 ( 0.079) .

LDNO 132kV: LV Generation Intermittent 124 0 ( 0.075) . 0.018

LDNO 132kV: LV Generation Non‐Intermittent 125 0 ( 0.325) ( 0.104) ( 0.014) . 0.018

LDNO 132kV: LV Sub Generation Intermittent 126 0 ( 0.079) . 0.020

LDNO 132kV: LV Sub Generation Non‐Intermittent 127 0 ( 0.343) ( 0.111) ( 0.014) . 0.020

LDNO 132kV: HV Generation Intermittent 128 0 ( 0.090) 27.32 0.027

LDNO 132kV: HV Generation Non‐Intermittent 129 0 ( 0.382) ( 0.131) ( 0.016) 27.32 0.027







LDNO 0000: Domestic Unrestricted 130 1 0.065 0.12

LDNO 0000: Domestic Two Rate 131 2 0.078 0.005 0.12

LDNO 0000: Domestic Off Peak (related MPAN) 132 2 0.009

LDNO 0000: Small Non Domestic Unrestricted 133 3 0.061 0.11

LDNO 0000: Small Non Domestic Two Rate 134 4 0.076 0.006 0.11

LDNO 0000: Small Non Domestic Off Peak (related MPAN) 135 4 0.011

LDNO 0000: LV Medium Non‐Domestic 136 5-8 0.056 0.004 0.61

LDNO 0000: LV Sub Medium Non‐Domestic

LDNO 0000: HV Medium Non‐Domestic

LDNO 0000: LV HH Metered 137 0 0.239 0.029 0.003 0.32 0.04 0.009

LDNO 0000: LV Sub HH Metered 138 0 0.359 0.038 0.004 1.76 0.09 0.012

LDNO 0000: HV HH Metered 139 0 0.348 0.032 0.003 5.40 0.09 0.011

LDNO 0000: NHH UMS category A 195 8 0.038

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 0.030

LDNO 0000: LV UMS (Pseudo HH Metered) 141 0 0.682 0.033 0.004

LDNO 0000: LV Generation NHH 142 8 ( 0.027) .

LDNO 0000: LV Sub Generation NHH 143 8 ( 0.029) .

LDNO 0000: LV Generation Intermittent 144 0 ( 0.027) . 0.006

LDNO 0000: LV Generation Non‐Intermittent 145 0 ( 0.118) ( 0.038) ( 0.005) . 0.006

LDNO 0000: LV Sub Generation Intermittent 146 0 ( 0.029) . 0.007

LDNO 0000: LV Sub Generation Non‐Intermittent 147 0 ( 0.125) ( 0.040) ( 0.005) . 0.007

LDNO 0000: HV Generation Intermittent 148 0 ( 0.033) 9.93 0.010

LDNO 0000: HV Generation Non‐Intermittent 149 0 ( 0.139) ( 0.048) ( 0.006) 9.93 0.010


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 – 07:3000:00 – 00:30 20:00 – 24:00

Monday – Friday (Dec – Feb)

16:30 – 18:3007:30 – 16:30 18:30 – 20:00

00:30 – 07:3000:00 – 00:30 20:00 – 24:00

Monday – Friday (Mar) 00:30 – 07:3000:00 – 00:30 07:30 – 24:00

Saturday – Sunday All Year

00:30 – 07:3000:00 – 00:30 07:30 – 24:00

Notes

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

Low Voltage Network 1.098 1.089 1.069 1.077

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 1.041 1.040 1.041 1.039264, 265, 284, 285, 293,

793, 795

High Voltage Network 1.027 1.025 1.019 1.022

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 1.016 1.015 1.013 1.014

294, 691, 692, 693, 694, 695, 696, 697, 698, 699, 700, 777, 778, 779, 780,

781, 797, 799

Greater than 22kV connected - generation

1.010 1.010 1.008 1.009

766, 767, 768, 769, 782, 783, 784, 785, 786, 787, 788, 789, 802, 803, 804,

805

Greater than 22kV connected - demand

1.010 1.010 1.008 1.009540, 541, 542, 543, 544, 545, 546, 547, 548, 549, 686, 687, 688, 689, 690

Northern Powergrid (Northeast) - Effective from April 2013 - Final LLF Time Periods

Time periods

Generic Demand and Generation LLFs

Metered voltage, respective periods and associated LLFCs

All the above times are in UK Clock time


Site Period 1 Period 2 Period 3 Period 4 Associated LLFC

Site 1 1.002 1.002 1.002 1.002 601

Site 2 1.002 1.002 1.002 1.002 603

Site 3 1.001 1.002 1.003 1.003 604

Site 4 1.011 1.011 1.015 1.012 605

Site 5 1.018 1.020 1.055 1.021 606

Site 6 1.020 1.020 1.051 1.021 607

Site 7 1.022 1.019 1.037 1.021 608

Site 8 1.004 1.004 1.005 1.005 609

Site 9 1.015 1.013 1.015 1.016 611

Site 10 1.005 1.005 1.004 1.005 612

Site 11 1.011 1.011 1.009 1.010 613

Site 12 1.004 1.004 1.006 1.006 614

Site 13 1.005 1.005 1.004 1.005 615

Site 14 1.005 1.005 1.003 1.004 616

Site 15 1.006 1.007 1.006 1.006 617

Site 16 1.011 1.011 1.011 1.011 618

Site 17 1.013 1.012 1.008 1.010 619

Site 18 1.008 1.008 1.008 1.008 620

Site 19 1.006 1.006 1.008 1.007 621

Site 20 1.023 1.020 1.022 1.018 622

Site 21 1.007 1.008 1.007 1.007 624

Site 22 1.016 1.017 1.015 1.016 625

Site 23 1.155 1.089 1.027 1.037 626

Site 24 1.000 1.000 1.002 1.002 627

Site 25 1.021 1.020 1.014 1.016 628

Site 26 1.010 1.010 1.008 1.009 630

Site 27 1.004 1.005 1.005 1.005 631

Site 28 1.006 1.006 1.006 1.006 632

Site 29 1.040 1.038 1.031 1.034 633

Site 30 1.004 1.004 1.004 1.004 637

Site 31 1.032 1.030 1.024 1.027 680

Site 32 1.008 1.010 1.007 1.007 681

Site 33 1.000 1.004 1.003 1.004 682

Site 34 1.011 1.011 1.010 1.011 683

Site 35 1.005 1.005 1.007 1.006 684

Site 36 1.010 1.010 1.008 1.009 685

EHV Site Specific LLFs

Demand


Site Period 1 Period 2 Period 3 Period 4 Associated LLFC

Site 1 0.995 0.995 0.995 0.995 701

Site 2 1.007 1.007 1.003 1.005 704

Site 3 0.996 0.996 0.995 0.994 709

Site 4 1.019 1.017 1.007 1.013 710

Site 5 0.986 0.988 0.983 0.989 711

Site 6 0.997 0.998 0.998 0.998 727

Site 7 1.000 1.000 1.000 0.998 728

Site 8 0.994 0.995 0.995 0.995 729

Site 9 1.008 1.007 1.003 1.007 748

Site 10 1.048 1.044 1.030 1.037 759

Site 11 0.999 0.999 0.995 0.997 760

Site 12 0.995 0.996 0.996 0.996 761

Site 13 1.007 1.006 1.003 1.005 762

Site 14 0.981 0.979 0.978 0.979 763

Site 15 1.000 0.999 0.995 0.997 764

Site 16 1.010 1.010 1.008 1.009 765

Generation

EHV Site Specific LLFs


Annex 6 - Un-scaled [nodal /network group] costs

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


Annex 7 – Addendum to charging statement detailing Charges for New Designated EHV Properties

Not applicable but can be found in the spread sheet that accompanies this statement.

statement of use of system charging northern … · tering poin e time per le discretio wn exclus...

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