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Northern Powergrid (Northeast) Ltd Registered Office: Lloyds Court, 78 Grey Street, Newcastle upon Tyne, NE1 6AF
Registered in England and Wales no. 2906593
Statement of Use of System Charging
Northern Powergrid (Northeast) Ltd
Final Notice
Effective from 1st April 2014
Version 1.0
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 (NORTHEAST) LTD FEBRUARY 2014 – V1.0
Contents
1. Introduction 4
2. Charge Application and Definitions 6
Supercustomer Billing and Payment 6 Supercustomer Charges 6 Site-Specific Billing and Payment 7 Site-Specific Billed Charges 7 Time periods for half-hourly metered properties 8 Time periods for half-hourly unmetered properties 9 Application of Capacity Charges 9 Chargeable Capacity 9 Exceeded capacity 9 Demand exceeded capacity 9 Generation exceeded capacity 10 Standby Capacity for Additional Security on Site 10 Minimum Capacity Levels 10 Application of charges for excess reactive power 10 Demand chargeable reactive power 11 Generation chargeable reactive power 11 Generation charges for pre-2005 Designated EHV Properties 12 Provision of billing data 12 Use of System Charges Out of Area 13 Licensed Distributor Network Operator (LDNO) charges 13 Third party access from exempt distribution networks 13
3. Schedule of Charges for use of the Distribution System 15
4. Schedule of Line Loss Factors 16
Role of Line Loss Factors in the Supply of Electricity 16 Calculation of Line Loss Factors 16 Line Loss Factor time periods 16 Line Loss Factor tables 17
5. Notes for Designated EHV Properties 18
EDCM nodal costs 18 Charges for New Designated EHV Properties 18 Charges for amended Designated EHV Properties 18 Demand Side Management 18
6. Electricity Distribution Rebates 19
7. Accounting and Administration Services 20
Administration Charge 20
8. Charges for electrical plant provided ancillary to the grant of Use of System 20
9. Glossary of Terms 21
Annex 1 - Schedule of charges for use of the distribution system by LV and HV Designated Properties 26 Annex 2 - Schedule of charges for use of the distribution system by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-users) 27 Annex 3 - Schedule of charges for use of the distribution system by preserved/additional LLF classes 32 Annex 4 - Charges applied to LDNOs with LV and HV end-users 33 Annex 5 - Schedule of line loss factors 36 Annex 6 - Addendum to charging statement detailing charges for new Designated EHV Properties 39
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1. Introduction
1.1. This statement has been prepared in order to discharge Northern Powergrid’s
obligation under Standard Licence Condition 14 of our Electricity Distribution Licence.
It contains information on our charges1 and charging principles for use of our
Distribution System. It also contains information on our Line Loss Factors.
1.2. The charges in this statement are calculated using the Common Distribution Charging
Methodology (CDCM) for Low-Voltage and High-Voltage (LV and HV) Designated
Properties and the Extra-High Voltage Distribution Charging Methodology (EDCM) for
Designated Extra-High Voltage (EHV) Properties (for Metering Point Administration
Numbers/Metering System Identifiers (MPANs/MSIDs) connected to our designated
distribution services area). The application of charges to a premise can usually be
referenced using the Line Loss Factor Class (LLFC) contained in the charge tables.
1.3. All charges in this statement are shown exclusive of VAT.
1.4. The annexes that form part of this statement are also provided for additional
convenience in spreadsheet format. This spreadsheet also contains supplementary
information used for charging purposes but which is not required to be provided in
accordance with Standard Licence Condition 14. This spreadsheet can be downloaded
from:
http://www.northernpowergrid.com/downloads/system.cfm
1.5. If you have any questions about this statement please contact us at the address
shown below:
Charges Manager
Northern Powergrid
98 Aketon Road
Castleford
WF10 5DS
e-mail:- [email protected]
1 Charges can be positive or negative.
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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
1.6. All enquiries regarding connection agreements and changes to maximum capacities
should be addressed to:
Connection Record Maintenance
Northern Powergrid
Manor House
Station Road
New Penshaw
Houghton-le-Spring
DH4 7LA
e-mail:- [email protected]
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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
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 20012 and
where operated in accordance with BSCP5203.
2.8. Identification of the appropriate charge can be made by cross reference to the LLFC.
2 The Electricity (Unmetered Supply) Regulations 2001 available from
http://www.legislation.gov.uk/uksi/2001/3263/made 3 Balancing and Settlement Code Procedures on unmetered supplies are available from
http://www.elexon.co.uk/pages/bscps.aspx
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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
2.9. Valid settlement profile class/standard settlement configuration/meter timeswitch
code (PC/SSC/MTC) combinations for these LLFCs are detailed in Market Domain Data
(MDD).
2.10. Where an MPAN has an invalid settlement combination, the ‘Domestic Unrestricted’
fixed and unit charge will be applied as default until the invalid combination is
corrected. Where there are multiple SSC - time pattern regime (TPR) combinations,
the default ‘Domestic Unrestricted’ fixed and unit charge will be applied for each
invalid TPR combination.
2.11. The time periods for the charge rates are as specified by the SSC. To determine the
appropriate charge rate for each SSC/TPR a look-up table is provided in the ENA
spreadsheet that accompanies this statement4.
2.12. The ‘Domestic Off-Peak’ and ‘Small Non-Domestic Off-Peak’ charges are
supplementary to either an unrestricted or a two-rate charge.
Site-Specific Billing and Payment
2.13. Site-specific billing and payment applies to metering points settled as Half Hourly
(HH) metered. The site-specific billing and payment approach to Use of System (UoS)
billing makes use of HH metering data received through settlement.
2.14. Invoices are calculated on a periodic basis and sent to each user, for whom Northern
Powergrid is transporting electricity through its distribution system. Where 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.
2.15. The charges are applied on the basis of the LLFC assigned to the MPAN (or the MSID
for Central Volume Allocation (CVA) sites), and the units consumed within the time
periods specified in this statement.
2.16. All LLFCs are assigned at the sole discretion of Northern Powergrid. Where an
incorrectly applied LLFC is identified, Northern Powergrid, may at its sole discretion
apply the correct LLFC and/or charges. Where MPANs have not been associated, for
example when multiple connections are fed from different sources, the relevant
number of fixed charges will be applied.
Site-Specific Billed Charges
2.17. Site-specific billed charges may include the following components:
a fixed charge pence/MPAN/day or pence/MSID/day;
4 Northern Powergrid Northeast - Schedule of charges and other tables – Version 10.7.xlsx
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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
a capacity charge, pence/kVA/day, for 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, more than one unit charge may be applied; and
an excess reactive power charge, pence/kVArh, for each unit in excess of the reactive 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 as
unmetered 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 Designated
Properties 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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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
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(2 capacity exceeded Demand 2 02 MICRERIAI
Where:
AI = Active Import (kWh)
RI = Reactive import (kVArh)
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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
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(2 capacity exceeded Generation 02 MECRERIAE 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
data for two or more MPANs is aggregated for billing purposes the HH consumption
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
0,1
95.0
1RERI,maxmax kVArh Chargeable Demand
2AI
0,AE1
95.0
1RERI,maxmax kVArh Chargeable Generation
2
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2.45. 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 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:
2.51. Northern Powergrid requires details of reactive power imported or exported to be
provided for all measurement class C (mandatory HH metered) sites and for
measurement class E (elective HH metered sites). It is also required for CVA sites and
exempt distribution network boundaries with difference metering. Northern
Powergrid reserves the right to levy a charge on users who fail to provide such
reactive data.
Use of System Charges Out of Area
2.52. Northern Powergrid does not operate networks outside its distribution service area.
Licensed Distributor Network Operator (LDNO) charges
2.53. Licenced distribution network operator (LDNO) charges are applied to LDNOs who
operate embedded networks within Northern Powergrid’s distribution services area.
2.54. The charge structure for LV and HV Designated Properties embedded in networks
operated by LDNOs will mirror the structure of the ‘all-the-way’ charge and is
dependent upon the voltage of connection of each embedded network to the host
DNO’s network. The same charge elements will apply as those that match the LDNO’s
end customer charges. The relevant charge structures are set out in Annex 4.
2.55. Where an MPAN has an invalid settlement combination, the ‘LDNO HV: Domestic
Unrestricted’ fixed and unit charge will be applied as default until the invalid
combination is corrected. Where there are multiple SSC-TPR combinations, the
default ‘LDNO HV: Domestic Unrestricted’ fixed and unit charge will be applied for
each invalid TPR combination.
2.56. The charge structure for Designated EHV Properties embedded in networks operated
by LDNOs will be calculated individually using the EDCM. The relevant charge
structures are set out in Annex 2.
2.57. For nested networks the relevant charging principles set out in DCUSA Schedule 21
will apply.
Third party access from exempt distribution networks
2.58. Where one of our MPANs (prefix 15) is embedded within an exempt distribution
network connected to one of Northern Powergrid’s distribution systems, and a
dispensation for difference metering is in place for settlement purposes, we will
continue to charge the supplier of the boundary MPAN of the connection, based on
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gross measurement for UoS. No charges will be levied directly to the customer or
supplier of the embedded MPAN(s) connected within the exempt distribution network.
2.59. Northern Powergrid requires that gross metered data for the boundary of the
connection is provided to them. Until a new flow is introduced for the sending of
such gross data, gross metered data shall:
be sent using the D0036 or D0275 MRA data flow; and
the D0036 or D0275 shall contain the metering reference specified by Northern Powergrid 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 Powergrid in 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 by Northern Powergrid followed by a hyphen and followed by a timestamp in the format YYYYMMDDHHMMSS and followed by “.txt”;
and the title of the email should contain the phrase “gross data for difference metered private network”.
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3. Schedule of Charges for use of the Distribution System
3.1. Tables listing the charges for the distribution of electricity for UoS are published in
annexes to this document.
3.2. These charges are also listed in a spreadsheet which is published with this statement
and can be downloaded from:
http://www.northernpowergrid.com/downloads/system.cfm
3.3. Annex 1 contains charges to LV and HV Designated Properties.
3.4. Annex 2 contains the charges to Designated EHV Properties and charges applied to
LDNOs with Designated EHV Properties/end-users embedded in networks within
Northern Powergrid’s area.
3.5. Annex 3 contains details of any preserved and additional charges that are valid at this
time. Preserved charges are mapped to an appropriate charge and are closed to new
customers.
3.6. Annex 4 contains the charges applied to LDNOs with LV and HV Designated Properties
embedded in networks within Northern Powergrid’s distribution services area.
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4. Schedule of Line Loss Factors
Role of Line Loss Factors in the Supply of Electricity
4.1. Electricity entering or exiting the DNOs’ networks is adjusted to take account of
energy that is lost5 as it is distributed through the network.
4.2. This adjustment is made to ensure that energy bought or sold by a user, from/to a
customer, accounts for energy lost as part of distributing energy to and from the
customer’s premises.
4.3. DNOs are responsible for calculating the Line Loss Factors (LLFs) and providing these
factors to Elexon. Elexon manage the Balancing and Settlement Code (BSC). The code
covers the governance and rules for the balancing and settlement arrangements.
4.4. Annex 5 provides the LLFs which must be used to adjust the metering system volumes
to take account of losses on the distribution network.
Calculation of Line Loss Factors
4.5. LLFs are calculated in accordance with BSC Procedure (BSCP) 128, which determines
the principles that DNOs must comply with when calculating LLFs.
4.6. LLFs are either calculated using a generic method or a site-specific method. The
generic method is used for sites connected at LV or HV and the site-specific method is
used for sites connected at EHV or where a request for site-specific LLFs has been
agreed. Generic LLFs will be applied to all new EHV sites until sufficient data is
available for a site-specific calculation.
4.7. The Elexon website:
(http://www.elexon.co.uk/reference/technicaloperations/losses/) contains more
information on LLFs. This page also has links to BSC Procedure (BSCP) 128 and to our
LLF methodology.
Line Loss Factor time periods
4.8. LLFs are calculated for a set number of time periods during the year and are detailed
in Annex 5.
5 Energy can be lost for technical and non-technical reasons and losses normally occur by heat dissipation through power
flowing in conductors and transformers. Losses can also reduce if a customer’s action reduces power flowing in the
distribution network. This might happen when a customer generates electricity and the produced energy is consumed
locally.
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Line Loss Factor tables
4.9. When using the LLF tables in Annex 5 reference should be made to the LLFC allocated
to the MPAN to find the appropriate LLF.
4.10. The Elexon portal website, https://www.elexonportal.co.uk, contains the LLFs in
standard industry data format (D0265). A user guide with details on registering and
using the portal can be downloaded from: www.elexonportal.co.uk/userguide
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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
5. Notes for Designated EHV Properties
EDCM nodal costs
5.1. A table is provided in the accompanying spreadsheet which shows the unscaled LRIC
nodal costs used to calculate the current EDCM charges. This spreadsheet Northern
Powergrid Northeast - Schedule of charges and other tables – Version10.7.xlsx is
available to download from Northern Powergrid’s website.
5.2. These are illustrative of the modelled costs at the time that this statement was
published. A new connection will result in changes to current network utilisations
which will then form the basis of future prices, the charge determined in this
statement will not necessarily be the charge in subsequent years because of the
interaction between new and existing network connections and any other changes
made to Northern Powergrid’s distribution system which may affect charges.
Charges for New Designated EHV Properties
5.3. Charges for any new Designated EHV Properties calculated after publication of the
current statement will be published in an addendum to that statement as and when
necessary.
5.4. The form of the addendum is detailed in Annex 6 of this statement.
5.5. The addendum will be sent to relevant DCUSA parties and published as a revised
“Schedule of Charges and other tables” spreadsheet on our website. The addendum
will include charge information that under enduring circumstances would be found in
Annex 2 and line loss factors that would normally be found in Annex 5.
5.6. The new Designated EHV Properties charges will be added to Annex 2 in the next full
statement released.
Charges for amended Designated EHV Properties
5.7. Where an existing Designated EHV Property is modified and energised in the charging
year, Northern Powergrid may revise its EDCM charges for the modified Designated
EHV Property. If revised charges are appropriate, an addendum will be sent to
relevant 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.
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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
5.9. DSM arrangements are based on a formal commitment by the customer to materially
reduce their MIC in certain time periods, as determined by Northern Powergrid, for
active network management purposes other than normal planned or unplanned
outages.
5.10. For new connections the customer must make an express statement in their
application that they have an interest in some, or all, of the import capacity for their
intended connection or modified connection being interruptible for active network
management purposes.
5.11. Where the customer enters into a DSM agreement by agreeing to reduce their MIC to
meet the defined parameters in the agreement, reduced use of system charges will
apply. The chargeable capacity will be equal to the MIC minus the capacity that is
subject to restrictions under the DSM agreement. The scale of the reduction will vary
by site and is linked to the LRIC element of the charge in line with the approved
charging methodology.
5.12. Any reduction in use of system charges applicable to the customer will be assessed on
a site-specific basis by Northern Powergrid. Any customers who wish to enquire
whether they can take advantage of DSM should in the first instance contact:
Connection Record Maintenance
Manor House
Station Road
New Penshaw
Houghton-le-Spring
DH4 7LA
e-mail:- [email protected]
6. Electricity Distribution Rebates
6.1. Northern Powergrid (Northeast) Ltd issued a use of system rebate to energy suppliers
in December 2013. Its intention was to facilitate the Department for Energy and
Climate Change’s announcement early that month that network operators were
willing to take voluntary action to reduce network costs. The rebates amounted to
£10.54 per domestic unrestricted customer and £14.98 per domestic restricted
customer and were based on the number of traded MPANs (excluding related MTCs).
6.2. Northern Powergrid (Northeast) Ltd is not proposing to make further rebates in the
2014/15 charging year.
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NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
6.3. The tariffs within this statement do not attempt to recover any of the revenue
associated with the rebate and are identical to those tariffs that would have been
published had the rebate not been issued.
7. Accounting and Administration Services
Administration Charge
7.1. Where a user has failed to settle a DUoS invoice or notify Northern Powergrid of a
bona fide dispute, in accordance with the Use of System agreement an account
review charge of £75.00 may be made to cover the associated credit control,
administration, invoicing and collection costs. This is in addition to the interest
charge that will be made in accordance with clause 23.3 of the Distribution
Connection and Use of System Agreement (DCUSA).
8. Charges for electrical plant provided ancillary to the grant of Use of System
8.1. Northern Powergrid has no charges applicable to this section.
PAGE 21 OF 39
NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
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 for electricity balancing and settlement in Great Britain. An overview document is available from
www.elexon.co.uk/ELEXON Documents/trading_arrangements.pdf.
CDCM
The common distribution charging methodology used for calculating charges to Designated Properties as required by standard licence condition 13A of the electricity distribution licence.
Central volume allocation (CVA) As defined in the BSC.
Customer
A person to whom a user proposers to supply, or for the time being supplies, electricity through an exit point, or from who, a user or any relevant exempt supplier, is entitled to recover charges, compensation or an account of profits in respect of electricity supplied though an exit point;
Or A person from whom a user purchases, or proposes to purchase, electricity, at an entry point (who may from time to time be supplied with electricity as a customer of that user (or another electricity supplier) through an exit point).
Designated Properties As defined in standard condition 13A of the electricity distribution licence.
Distributed generator A generator directly connected or embedded within the distribution system.
Distribution Connection and Use of System Agreement (DCUSA)
The DCUSA is a multi-party contract between the licensed electricity distributors, suppliers, generators and Offshore Transmission Owners (OFTOs) of Great Britain.
It is a requirement that all licensed electricity distributors and suppliers become parties to the DCUSA.
Distribution network operator (DNO)
An electricity distributor who operates one of the 14 distribution services areas and in whose electricity distribution licence the requirements of Section B of the standard conditions of that licence have effect.
PAGE 22 OF 39
NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
Term Definition
Distribution services area The area specified by the authority within which each DNO must provide specified distribution services.
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 Great Britain (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.
Designated EHV Properties As defined in standard condition 13B of the electricity distribution licence.
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 distribution licence The electricity distribution licence granted or treated as granted pursuant to section 6(1) of the Electricity Act 1989.
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 from a connected installation or from 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.
PAGE 23 OF 39
NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
Term Definition
Gas and Electricity Markets Authority (GEMA) (the Authority)
As established by the Utilities Act 2000.
Grid supply point (GSP)
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 A distinct electrical system that is supplied from one or more GSPs 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.
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 - see https://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 network operator (LDNO)
The holder of a licence in respect of distribution activities in Great Britain.
Line loss factor (LLF) The factor that is used in settlement to adjust the metering 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 is used 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 reference data used by all users involved in settlement. It is essential to the operation of SVA trading arrangements.
PAGE 24 OF 39
NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
Term Definition
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 or above 100kW premises (equivalent to measurement class C);
half-hourly unmetered supplies (equivalent to measurement class D); and
half-hourly metering equipment below 100kw premises (equivalent to measurement class E).
Metering point
The point at which electricity that 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, GSPs are not ‘metering points’.
Metering system Particular commissioned metering equipment installed for the purposes of measuring the quantities of exports and/or imports at the exit point or entry point.
Metering point administration number (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 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.
PAGE 25 OF 39
NORTHERN POWERGRID (NORTHEAST) LTD FEBRUARY 2014 – V1.0
Term Definition
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 BSC.
Settlement class (SC)
The combination of profile class, line loss factor class, time pattern regime and standard settlement configuration, by supplier within a 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 together consumption and standing charges for all similar NHH metered customers.
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 being responsible for electricity supplied to and/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 charges Charges applicable to demand and generation connections which are connected to and utilise the distribution network.
User Someone that has a use of system agreement with the DNO e.g. a supplier, generator or other DNO.
Unmetered Supplies
Exit points deemed to be suitable as unmetered supplies as permitted in the Electricity (Unmetered Supply) Regulations 2001 and where operated in accordance with BSCP520.
Annex 1 - Schedule of Charges for use of the Distribution System by LV and HV Designated Properties
Time periods Red Time Band Green Time Band Black Time Band Yellow Time Band Green Time Band
Monday to Friday
(Including Bank Holidays)
All Year
16:00 to 19:3000:00 to 08:00
22:00 to 24:0016:00 to 19:30
08:00 to 16:00
19:30 to 22:00
00:00 to 08:00
22:00 to 24:00
Saturday and Sunday
All Year00:00 to 24:00 08:00 to 22:00
00:00 to 08:00
22:00 to 24:00
Notes 00:00 to 24:00
DNOs paste value cells A15:I42 from CDCM 3701 into
cells A14:J41Open LLFCs PCs
Unit rate 1
p/kWh
(red/black)
Unit rate 2
p/kWh
(amber/yellow)
Unit rate 3
p/kWh
(green)
Fixed charge
p/MPAN/day
Capacity charge
p/kVA/day
Reactive power
charge
p/kVArh
Excess capacity
charge
p/kVA/day
Closed LLFCs
Domestic Unrestricted 1 1 2.792 4.83 5, 21, 25, 998, 999
Domestic Two Rate 2 2 3.401 0.184 4.83 6, 16, 22, 26, 36
Domestic Off Peak (related MPAN) 12 2 0.355 8, 28, 32
Small Non Domestic Unrestricted 203 3 2.771 4.43 202, 222, 223
Small Non Domestic Two Rate 204 4 3.335 0.256 4.43 201, 221, 224
Small Non Domestic Off Peak (related MPAN) 205 4 0.462 225
LV Medium Non-Domestic 257 5-8 2.528 0.166 24.58256, 267, 268, 276, 277,
287, 288
LV Sub Medium Non-Domestic 265 5-8 2.576 0.194 59.18 264, 284, 285
HV Medium Non-Domestic 304 5-8 2.002 0.104 206.18 303, 323, 324
LV HH Metered 251 0 11.950 0.984 0.124 13.63 1.46 0.304 1.46 253, 655
LV Sub HH Metered 293 0 10.973 0.777 0.092 45.56 2.09 0.241 2.09 -
HV HH Metered 301 0 8.868 0.547 0.061 115.85 1.87 0.183 1.87 610, 666, 674, 677
HV Sub HH Metered
NHH UMS category A 506 8 1.638 -
NHH UMS category B 507 1 2.348 -
NHH UMS category C 508 1 4.293 -
NHH UMS category D 509 1 1.143 -
LV UMS (Pseudo HH Metered) 554 & 555 0 33.481 1.063 0.139 -
LV Generation NHH 774 8 ( 0.704) 772, 773, 775, 800, 801
LV Sub Generation NHH 776 8 ( 0.626) -
LV Generation Intermittent 792 0 ( 0.704) 0.137705, 716, 720, 722, 724,
725, 733, 736, 746, 758,
770
LV Generation Non-Intermittent 794 0 ( 3.855) ( 0.766) ( 0.107) 0.137 713, 739, 740, 744, 790
LV Sub Generation Intermittent 793 0 ( 0.626) 0.131 -
LV Sub Generation Non-Intermittent 795 0 ( 3.446) ( 0.678) ( 0.094) 0.131 -
HV Generation Intermittent 796 0 ( 0.431) 122.46 0.099
702, 703, 706, 715, 717,
723, 726, 730, 734, 749,
750, 752, 754, 755, 756,
771
HV Generation Non-Intermittent 798 0 ( 2.442) ( 0.453) ( 0.059) 122.46 0.099
707, 708, 712, 721, 731,
732, 735, 743, 745, 747,
751, 753, 791
HV Sub Generation Intermittent
HV Sub Generation Non-Intermittent
08:00 to 16:00
19:30 to 22:00
Monday to Friday
(Including Bank Holidays)
November to February Inclusive
Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final LV and HV charges
Time Bands for Half Hourly Metered Properties Time Bands for Half Hourly Unmetered Properties
Amber Time Band Time periods
All the above times are in UK Clock time
Monday to Friday
(Including Bank Holidays)
April to October and March
Inclusive
All the above times are in UK Clock time Saturday and Sunday
All other times
NORTHERN POWERGRID (NORTHEAST) LTD 26 of 39 FEBRUARY 2014 - V1.0
Annex 2 - Schedule of Charges for use of the Distribution System by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-users)
3 4 5 6 6 7 8 9
Import
Unique
Identifier
LLFCImport
MPANs/MSIDs
Export Unique
IdentifierLLFC
Export
MPANs/MSIDsName
Import
Super Red
unit rate
(p/kWh)
Import
fixed charge
(p/day)
Import
capacity rate
(p/kVA/day)
Import
exceeded capacity rate
(p/kVA/day)
Export
Super Red
unit rate
(p/kWh)
Export
fixed charge
(p/day)
Export
capacity rate
(p/kVA/day)
Export
exceeded capacity rate
(p/kVA/day)
6011592001005770
1592101005776701
1574000216135
1594001005774EHV Site Specific - Generation Exempt 1,519.93 0.65 0.65
603 1592001051182 EHV Site Specific 8,084.56 2.21 2.21
604 1570000223279 727 1574000223285 EHV Site Specific 91.66 0.65 0.65 1,833.23 0.09 0.09
605 1592001092676 EHV Site Specific 0.603 4,309.47 1.86 1.86
606 1592001092719 EHV Site Specific 0.439 5,745.96 2.06 2.06
607 1592001092728 EHV Site Specific 0.701 5,745.96 3.32 3.32
608 1592001092737 EHV Site Specific 5,745.96 1.97 1.97
609 1592001046085 EHV Site Specific 574.60 3.34 3.34
611 1592001111628 EHV Site Specific 4,684.89 5.86 5.86
612 1592001073112 704 1594001073116 EHV Site Specific 0.896 105.13 1.11 1.11 ( 1.037) 1,471.75 0.09 0.09
613 1592001116013 EHV Site Specific 0.649 172.38 5.11 5.11
614 1592001055257 709 1594001055250 EHV Site Specific - Generation Exempt 4,963.87 0.87 0.87
615 & 6161592001055239
1592001055248EHV Site Specific 0.420 3,189.59 2.61 2.61
617 1592001110572 EHV Site Specific 12,363.03 1.94 1.94
618 1592001094308 EHV Site Specific 1.212 3,577.58 4.79 4.79
619 1570000150382 710 1594000000038 EHV Site Specific - Generation Exempt 0.063 38.93 1.78 1.78
620 1592001007476 EHV Site Specific 1,149.19 5.29 5.29
621 1592001007494 EHV Site Specific 0.078 172.38 3.39 3.39
622 1592001036574 711 1594001036578 EHV Site Specific - Generation Exempt 0.175 1,315.19 1.56 1.56
624 1592001063540 EHV Site Specific 0.015 7,485.56 2.81 2.81
625 1592001006890 748 1594001006893 EHV Site Specific - Generation Exempt 1.041 117.70 1.31 1.31
627 1570000199077 729 1574000199083 EHV Site Specific - Generation Exempt 1,467.41 0.89 0.89
626 1592001005637 EHV Site Specific 0.346 2,827.01 3.77 3.77
628 1592001111405 EHV Site Specific 0.651 957.19 4.88 4.88
631 1592001110216 EHV Site Specific 172.38 3.22 3.22
632 1592001007467 EHV Site Specific 0.471 497.98 4.25 4.25
633 1580000363558 EHV Site Specific 3.193 5,503.03 5.68 5.68
637 1592001141543 728 1594001141547 EHV Site Specific - Generation Exempt 0.057 3,392.64 1.82 1.82
680 1580000675845 759 1574000275033 EHV Site Specific 8.970 6.07 2.63 2.63 242.92 0.09 0.09
681 1580000872387 760 1574000283735 EHV Site Specific 0.136 97.95 1.17 1.17 3,918.13 0.09 0.09
544 1570000124531 761 1594000000047 EHV Site Specific - Generation Exempt 18.66 0.80 0.80
682 1580000909309 762 1574000285644 EHV Site Specific 0.897 631.25 0.83 0.83 ( 1.038) 3,443.20 0.09 0.09
691 1592101007746 EHV Site Specific 0.011 86.19 4.72 4.72
683 1570000166434 763 1594000000029 EHV Site Specific - Generation Exempt 18.48 1.73 1.73
6921580000867554
1580000911799EHV Site Specific 0.381 172.38 3.40 3.40
693 1592001074941 EHV Site Specific 1.534 86.19 3.61 3.61
694 1570000190631 EHV Site Specific 1.097 172.38 6.41 6.41
6951580000918163
1580000918172EHV Site Specific 172.38 4.36 4.36
684 1580001085400 764 1574000298500 EHV Site Specific 0.005 535.13 1.21 1.21 ( 0.111) 3,860.53 0.09 0.09
685 1580001132432 765 1574000302403 EHV Site Specific 51.67 0.69 0.69 1,627.68 0.09 0.09
6861580001150566
1580001150575766
1574000303940
1574000303959EHV Site Specific 292.10 1.70 1.70 18,986.73 0.09 0.09
687 TBC EHV Site Specific 2,046.05 1.11 1.11
688 1580001208659 767 1574000309384 EHV Site Specific 24.77 2.68 2.68 1,411.72 0.09 0.09
689 1580001208668 768 1574000309375 EHV Site Specific 77.34 2.68 2.68 3,338.05 0.09 0.09
690 1580001174414 782 1574000306374 EHV Site Specific 0.803 60.05 4.62 4.62 2,161.72 0.09 0.09
540 1580001190763 783 1574000307917 EHV Site Specific 0.003 11.15 2.72 2.72 ( 0.053) 936.93 0.09 0.09
541 1580001197945 784 1574000308405 EHV Site Specific 0.896 274.40 2.28 2.28 ( 1.038) 3,658.70 0.09 0.09
542 1580001278406 785 1574000315040 EHV Site Specific 302.42 1.97 1.97 559.47 0.09 0.09
543 1580001278415 EHV Site Specific 2,872.98 2.81 2.81
16:00 to 19:30
All the above times are in UK Clock time
Time periods
Monday to Friday
(Including Bank Holidays)
November to February Inclusive
Notes
Time Periods for Designated EHV Properties
Super Red Time Band
Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final EDCM charges
NORTHERN POWERGRID (NORTHEAST) LTD 27 of 39 FEBRUARY 2014 - V1.0
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
All the above times are in UK Clock time
Import
Unique
Identifier
LLFCImport
MPANs/MSIDsName
Import
Super Red
unit rate
(p/kWh)
Import
fixed charge
(p/day)
Import
capacity rate
(p/kVA/day)
Import
exceeded
capacity rate
(p/kVA/day)
6011592001005770
1592101005776EHV Site Specific - Generation Exempt 1,519.93 0.65 0.65
603 1592001051182 EHV Site Specific 8,084.56 2.21 2.21
604 1570000223279 EHV Site Specific 91.66 0.65 0.65
605 1592001092676 EHV Site Specific 0.603 4,309.47 1.86 1.86
606 1592001092719 EHV Site Specific 0.439 5,745.96 2.06 2.06
607 1592001092728 EHV Site Specific 0.701 5,745.96 3.32 3.32
608 1592001092737 EHV Site Specific 5,745.96 1.97 1.97
609 1592001046085 EHV Site Specific 574.60 3.34 3.34
611 1592001111628 EHV Site Specific 4,684.89 5.86 5.86
612 1592001073112 EHV Site Specific 0.896 105.13 1.11 1.11
613 1592001116013 EHV Site Specific 0.649 172.38 5.11 5.11
614 1592001055257 EHV Site Specific - Generation Exempt 4,963.87 0.87 0.87
615 & 6161592001055239
1592001055248EHV Site Specific 0.420 3,189.59 2.61 2.61
617 1592001110572 EHV Site Specific 12,363.03 1.94 1.94
618 1592001094308 EHV Site Specific 1.212 3,577.58 4.79 4.79
619 1570000150382 EHV Site Specific - Generation Exempt 0.063 38.93 1.78 1.78
620 1592001007476 EHV Site Specific 1,149.19 5.29 5.29
621 1592001007494 EHV Site Specific 0.078 172.38 3.39 3.39
Notes
Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final EDCM import charges
Time Periods for Designated EHV Properties
Time periods
Monday to Friday
(Including Bank Holidays)
November to February Inclusive
NORTHERN POWERGRID (NORTHEAST) LTD 28 of 39 FEBRUARY 2014 - V1.0
Annex 2a - Schedule of Import Charges for use of the Distribution System by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-
users)
Import
Unique
Identifier
LLFCImport
MPANs/MSIDsName
Import
Super Red
unit rate
(p/kWh)
Import
fixed charge
(p/day)
Import
capacity rate
(p/kVA/day)
Import
exceeded
capacity rate
(p/kVA/day)
622 1592001036574 EHV Site Specific - Generation Exempt 0.175 1,315.19 1.56 1.56
624 1592001063540 EHV Site Specific 0.015 7,485.56 2.81 2.81
625 1592001006890 EHV Site Specific - Generation Exempt 1.041 117.70 1.31 1.31
627 1570000199077 EHV Site Specific - Generation Exempt 1,467.41 0.89 0.89
626 1592001005637 EHV Site Specific 0.346 2,827.01 3.77 3.77
628 1592001111405 EHV Site Specific 0.651 957.19 4.88 4.88
631 1592001110216 EHV Site Specific 172.38 3.22 3.22
632 1592001007467 EHV Site Specific 0.471 497.98 4.25 4.25
633 1580000363558 EHV Site Specific 3.193 5,503.03 5.68 5.68
637 1592001141543 EHV Site Specific - Generation Exempt 0.057 3,392.64 1.82 1.82
680 1580000675845 EHV Site Specific 8.970 6.07 2.63 2.63
681 1580000872387 EHV Site Specific 0.136 97.95 1.17 1.17
544 1570000124531 EHV Site Specific - Generation Exempt 18.66 0.80 0.80
682 1580000909309 EHV Site Specific 0.897 631.25 0.83 0.83
691 1592101007746 EHV Site Specific 0.011 86.19 4.72 4.72
683 1570000166434 EHV Site Specific - Generation Exempt 18.48 1.73 1.73
6921580000867554
1580000911799EHV Site Specific 0.381 172.38 3.40 3.40
693 1592001074941 EHV Site Specific 1.534 86.19 3.61 3.61
694 1570000190631 EHV Site Specific 1.097 172.38 6.41 6.41
6951580000918163
1580000918172EHV Site Specific 172.38 4.36 4.36
684 1580001085400 EHV Site Specific 0.005 535.13 1.21 1.21
685 1580001132432 EHV Site Specific 51.67 0.69 0.69
6861580001150566
1580001150575EHV Site Specific 292.10 1.70 1.70
687 TBC EHV Site Specific 2,046.05 1.11 1.11
688 1580001208659 EHV Site Specific 24.77 2.68 2.68
689 1580001208668 EHV Site Specific 77.34 2.68 2.68
690 1580001174414 EHV Site Specific 0.803 60.05 4.62 4.62
540 1580001190763 EHV Site Specific 0.003 11.15 2.72 2.72
541 1580001197945 EHV Site Specific 0.896 274.40 2.28 2.28
542 1580001278406 EHV Site Specific 302.42 1.97 1.97
543 1580001278415 EHV Site Specific 2,872.98 2.81 2.81
NORTHERN POWERGRID (NORTHEAST) LTD 29 of 39 FEBRUARY 2014 - V1.0
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
All the above times are in UK Clock time
Export
Unique
Identifier
LLFCExport
MPANs/MSIDsName
Export
Super Red
unit rate
(p/kWh)
Export
fixed charge
(p/day)
Export
capacity rate
(p/kVA/day)
Export
exceeded
capacity rate
(p/kVA/day)
7011574000216135
1594001005774EHV Site Specific - Generation Exempt
727 1574000223285 EHV Site Specific 1,833.23 0.09 0.09
704 1594001073116 EHV Site Specific ( 1.037) 1,471.75 0.09 0.09
709 1594001055250 EHV Site Specific - Generation Exempt
710 1594000000038 EHV Site Specific - Generation Exempt
711 1594001036578 EHV Site Specific - Generation Exempt
748 1594001006893 EHV Site Specific - Generation Exempt
729 1574000199083 EHV Site Specific - Generation Exempt
728 1594001141547 EHV Site Specific - Generation Exempt
759 1574000275033 EHV Site Specific 242.92 0.09 0.09
760 1574000283735 EHV Site Specific 3,918.13 0.09 0.09
761 1594000000047 EHV Site Specific - Generation Exempt
762 1574000285644 EHV Site Specific ( 1.038) 3,443.20 0.09 0.09
763 1594000000029 EHV Site Specific - Generation Exempt
764 1574000298500 EHV Site Specific ( 0.111) 3,860.53 0.09 0.09
765 1574000302403 EHV Site Specific 1,627.68 0.09 0.09
7661574000303940
1574000303959EHV Site Specific 18,986.73 0.09 0.09
767 1574000309384 EHV Site Specific 1,411.72 0.09 0.09
768 1574000309375 EHV Site Specific 3,338.05 0.09 0.09
782 1574000306374 EHV Site Specific 2,161.72 0.09 0.09
Notes
Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final EDCM export charges
Time Periods for Designated EHV Properties
Time periods
Monday to Friday
(Including Bank Holidays)
November to February Inclusive
NORTHERN POWERGRID (NORTHEAST) LTD 30 of 39 FEBRUARY 2014 - V1.0
Annex 2b - Schedule of Export Charges for use of the Distribution System by Designated EHV Properties (including LDNOs with Designated EHV Properties/end-
users)
Export
Unique
Identifier
LLFCExport
MPANs/MSIDsName
Export
Super Red
unit rate
(p/kWh)
Export
fixed charge
(p/day)
Export
capacity rate
(p/kVA/day)
Export
exceeded
capacity rate
(p/kVA/day)
783 1574000307917 EHV Site Specific ( 0.053) 936.93 0.09 0.09
784 1574000308405 EHV Site Specific ( 1.038) 3,658.70 0.09 0.09
785 1574000315040 EHV Site Specific 559.47 0.09 0.09
NORTHERN POWERGRID (NORTHEAST) LTD 31 of 39 FEBRUARY 2014 - V1.0
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 2.792 4.83
Domestic Two Rate 6, 16, 22, 26, 36 2 3.401 0.184 4.83
Domestic Off Peak (related MPAN) 8, 28, 32 2 0.355
Small Non Domestic Unrestricted 202, 222, 223 3 2.771 4.43
Small Non Domestic Two Rate 201, 221, 224 4 3.335 0.256 4.43
Small Non Domestic Off Peak (related
MPAN)225 4 0.462
LV Medium Non-Domestic 256, 267, 268, 276, 277, 287, 288 5-8 2.528 0.166 24.58
LV Sub Medium Non-Domestic 264, 284, 285 5-8 2.576 0.194 59.18
HV Medium Non-Domestic 303, 323, 324 5-8 2.002 0.104 206.18
LV Generation NHH 772, 773, 775, 800, 801 8 ( 0.704)
Closed LLFCs PCs
Unit rate 1
p/kWh
(red/black)
Unit rate 2
p/kWh
(amber/yellow)
Unit rate 3
p/kWh
(green)
Fixed charge
p/MPAN/day
Capacity charge
p/kVA/day
Reactive power
charge
p/kVArh
Excess Capacity
charge
p/kVA
LV HH Metered 253, 655 0 11.950 0.984 0.124 13.63 1.46 0.304 1.46
HV HH Metered 610, 666, 674, 677 0 8.868 0.547 0.061 115.85 1.87 0.183 1.87
LV Generation Intermittent705, 716, 720, 722, 724, 725, 733, 736,
746, 758, 7700 ( 0.704) 0.137
LV Generation Non-Intermittent 713, 739, 740, 744, 790 0 ( 3.855) ( 0.766) ( 0.107) 0.137
HV Generation Intermittent702, 703, 706, 715, 717, 723, 726, 730,
734, 749, 750, 752, 754, 755, 756, 7710 ( 0.431) 122.46 0.099
HV Generation Non-Intermittent707, 708, 712, 721, 731, 732, 735, 743,
745, 747, 751, 753, 7910 ( 2.442) ( 0.453) ( 0.059) 122.46 0.099
Notes:
Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final LV and HV tariffs
NHH preserved charges/additional LLFCs
All NHH tariffs detailed above are closed to new customers, the charges are mapped to the relevant active tariff in Annex 1
HV Medium Non-Domestic - this tariff if no longer available and all new HV connections will be required to be half-hourly metered
Notes:
HH preserved charges/additional LLFCs
All HH tariffs detailed above are closed to new customers, the charges are mapped to the relevant active tariff in Annex 1
Details of the relevant time periods can be found on Annex 1
NORTHERN POWERGRID (NORTHEAST) LTD 32 of 39 FEBRUARY 2014 - V1.0
Annex 4 - Charges applied to LDNOs with HV/LV end users
Time periods Red Time Band Amber Time Band Green Time Band Black Time Band Yellow Time Band Green Time Band
Monday to Friday
(Including Bank Holidays)
All Year
16:00 to 19:3008:00 to 16:00
19:30 to 22:00
00:00 to 08:00
22:00 to 24:0016:00 to 19:30
08:00 to 16:00
19:30 to 22:00
00:00 to 08:00
22:00 to 24:00
Saturday and Sunday
All Year00:00 to 24:00 08:00 to 22:00
00:00 to 08:00
22:00 to 24:00
Notes 00:00 to 24:00
Copy from CDCM table 3701 "Tariffs!D43:I81" and paste
values into D14
Unique billing
identifierPCs
Unit rate 1
p/kWh
(red/black)
Unit rate 2
p/kWh
(amber/yellow)
Unit rate 3
p/kWh
(green)
Fixed charge
p/MPAN/day
Capacity charge
p/kVA/day
Reactive power
charge
p/kVArh
Excess capacity
charge
p/kVA
LDNO LV: Domestic Unrestricted 150 1 1.784 3.09
LDNO LV: Domestic Two Rate 151 2 2.174 0.118 3.09
LDNO LV: Domestic Off Peak (related MPAN) 152 2 0.227
LDNO LV: Small Non Domestic Unrestricted 153 3 1.771 2.83
LDNO LV: Small Non Domestic Two Rate 154 4 2.132 0.164 2.83
LDNO LV: Small Non Domestic Off Peak (related MPAN) 155 4 0.295
LDNO LV: LV Medium Non-Domestic 156 5-8 1.616 0.106 15.71
LDNO LV: LV HH Metered 157 0 7.638 0.629 0.079 8.71 0.93 0.194 0.93
LDNO LV: NHH UMS category A 37 8 1.047
LDNO LV: NHH UMS category B 38 1 1.501
LDNO LV: NHH UMS category C 39 1 2.744
LDNO LV: NHH UMS category D 40 1 0.731
LDNO LV: LV UMS (Pseudo HH Metered) 170 0 21.399 0.679 0.089
LDNO LV: LV Generation NHH 172 8 ( 0.704)
LDNO LV: LV Generation Intermittent 173 0 ( 0.704) 0.137
LDNO LV: LV Generation Non-Intermittent 174 0 ( 3.855) ( 0.766) ( 0.107) 0.137
LDNO HV: Domestic Unrestricted 158 1 0.934 1.62
LDNO HV: Domestic Two Rate 159 2 1.138 0.062 1.62
LDNO HV: Domestic Off Peak (related MPAN) 160 2 0.119
LDNO HV: Small Non Domestic Unrestricted 161 3 0.927 1.48
LDNO HV: Small Non Domestic Two Rate 162 4 1.116 0.086 1.48
LDNO HV: Small Non Domestic Off Peak (related MPAN) 163 4 0.155 .
LDNO HV: LV Medium Non-Domestic 164 5-8 0.846 0.056 8.22
LDNO HV: LV HH Metered 165 0 3.999 0.329 0.041 4.56 0.49 0.102 0.49
LDNO HV: LV Sub HH Metered 166 0 6.074 0.430 0.051 25.22 1.16 0.133 1.16
LDNO HV: HV HH Metered 167 0 6.025 0.372 0.041 78.71 1.27 0.124 1.27
LDNO HV: NHH UMS category A 41 8 0.548
LDNO HV: NHH UMS category B 42 1 0.786
LDNO HV: NHH UMS category C 43 1 1.436
LDNO HV: NHH UMS category D 44 1 0.382
LDNO HV: LV UMS (Pseudo HH Metered) 171 0 11.203 0.356 0.047
LDNO HV: LV Generation NHH 175 8 ( 0.704)
LDNO HV: LV Sub Generation NHH 176 8 ( 0.626)
LDNO HV: LV Generation Intermittent 177 0 ( 0.704) 0.137
LDNO HV: LV Generation Non-Intermittent 178 0 ( 3.855) ( 0.766) ( 0.107) 0.137
LDNO HV: LV Sub Generation Intermittent 179 0 ( 0.626) 0.131
LDNO HV: LV Sub Generation Non-Intermittent 180 0 ( 3.446) ( 0.678) ( 0.094) 0.131
LDNO HV: HV Generation Intermittent 181 0 ( 0.431) 0.099
LDNO HV: HV Generation Non-Intermittent 182 0 ( 2.442) ( 0.453) ( 0.059) 0.099
LDNO HVplus: Domestic Unrestricted 50 1 0.795 1.38
LDNO HVplus: Domestic Two Rate 51 2 0.969 0.052 1.38
LDNO HVplus: Domestic Off Peak (related MPAN) 52 2 0.101
LDNO HVplus: Small Non Domestic Unrestricted 53 3 0.789 1.26
LDNO HVplus: Small Non Domestic Two Rate 54 4 0.950 0.073 1.26
LDNO HVplus: Small Non Domestic Off Peak (related MPAN) 55 4 0.132
LDNO HVplus: LV Medium Non-Domestic 56 5-8 0.720 0.047 7.00
All the above times are in UK Clock time
All the above times are in UK Clock time
Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final LDNO tariffs
Copy from EDCM table 6005 "LDNORev!B513:G637" and paste values into D54
Time Bands for Half Hourly Unmetered Properties
Time periods
Monday to Friday
(Including Bank Holidays)
November to February Inclusive
Monday to Friday
(Including Bank Holidays)
April to October and March Inclusive
Saturday and Sunday
All other times
Time Bands for Half Hourly Metered Properties
NORTHERN POWERGRID (NORTHEAST) LTD 33 of 39 FEBRUARY 2014 - V1.0
Annex 4 - Charges applied to LDNOs with HV/LV end users
Copy from CDCM table 3701 "Tariffs!D43:I81" and paste
values into D14
Unique billing
identifierPCs
Unit rate 1
p/kWh
(red/black)
Unit rate 2
p/kWh
(amber/yellow)
Unit rate 3
p/kWh
(green)
Fixed charge
p/MPAN/day
Capacity charge
p/kVA/day
Reactive power
charge
p/kVArh
Excess capacity
charge
p/kVA
LDNO HVplus: LV Sub Medium Non-Domestic - 5-8 1.199 0.090 27.54
LDNO HVplus: HV Medium Non-Domestic - 5-8 1.133 0.059 116.66
LDNO HVplus: LV HH Metered 57 0 3.403 0.280 0.035 3.88 0.42 0.087 0.42
LDNO HVplus: LV Sub HH Metered 58 0 5.106 0.362 0.043 21.20 0.97 0.112 0.97
LDNO HVplus: HV HH Metered 59 0 5.018 0.310 0.035 65.55 1.06 0.104 1.06
LDNO HVplus: NHH UMS category A 45 8 0.466
LDNO HVplus: NHH UMS category B 46 1 0.669
LDNO HVplus: NHH UMS category C 47 1 1.223
LDNO HVplus: NHH UMS category D 48 1 0.326
LDNO HVplus: LV UMS (Pseudo HH Metered) 61 0 9.535 0.303 0.040
LDNO HVplus: LV Generation NHH 62 8 ( 0.328)
LDNO HVplus: LV Sub Generation NHH 63 8 ( 0.354)
LDNO HVplus: LV Generation Intermittent 64 0 ( 0.328) 0.064
LDNO HVplus: LV Generation Non-Intermittent 65 0 ( 1.794) ( 0.356) ( 0.050) 0.064
LDNO HVplus: LV Sub Generation Intermittent 66 0 ( 0.354) 0.074
LDNO HVplus: LV Sub Generation Non-Intermittent 67 0 ( 1.950) ( 0.384) ( 0.053) 0.074
LDNO HVplus: HV Generation Intermittent 68 0 ( 0.431) 122.46 0.099
LDNO HVplus: HV Generation Non-Intermittent 69 0 ( 2.442) ( 0.453) ( 0.059) 122.46 0.099
LDNO EHV: Domestic Unrestricted 70 1 0.553 0.96
LDNO EHV: Domestic Two Rate 71 2 0.673 0.036 0.96
LDNO EHV: Domestic Off Peak (related MPAN) 72 2 0.070
LDNO EHV: Small Non Domestic Unrestricted 73 3 0.549 0.88
LDNO EHV: Small Non Domestic Two Rate 74 4 0.660 0.051 0.88
LDNO EHV: Small Non Domestic Off Peak (related MPAN) 75 4 0.091
LDNO EHV: LV Medium Non-Domestic 76 5-8 0.500 0.033 4.87
LDNO EHV: LV Sub Medium Non-Domestic - 5-8 0.833 0.063 19.14
LDNO EHV: HV Medium Non-Domestic - 5-8 0.787 0.041 81.10
LDNO EHV: LV HH Metered 77 0 2.366 0.195 0.025 2.70 0.29 0.060 0.29
LDNO EHV: LV Sub HH Metered 78 0 3.550 0.251 0.030 14.74 0.68 0.078 0.68
LDNO EHV: HV HH Metered 79 0 3.488 0.215 0.024 45.57 0.74 0.072 0.74
LDNO EHV: NHH UMS category A 183 8 0.324
LDNO EHV: NHH UMS category B 184 1 0.465
LDNO EHV: NHH UMS category C 185 1 0.850
LDNO EHV: NHH UMS category D 186 1 0.226
LDNO EHV: LV UMS (Pseudo HH Metered) 81 0 6.628 0.210 0.028
LDNO EHV: LV Generation NHH 82 8 ( 0.228)
LDNO EHV: LV Sub Generation NHH 83 8 ( 0.246)
LDNO EHV: LV Generation Intermittent 84 0 ( 0.228) 0.044
LDNO EHV: LV Generation Non-Intermittent 85 0 ( 1.247) ( 0.248) ( 0.035) 0.044
LDNO EHV: LV Sub Generation Intermittent 86 0 ( 0.246) 0.052
LDNO EHV: LV Sub Generation Non-Intermittent 87 0 ( 1.355) ( 0.267) ( 0.037) 0.052
LDNO EHV: HV Generation Intermittent 88 0 ( 0.300) 85.13 0.069
LDNO EHV: HV Generation Non-Intermittent 89 0 ( 1.698) ( 0.315) ( 0.041) 85.13 0.069
LDNO 132kV/EHV: Domestic Unrestricted 90 1 0.367 0.63
LDNO 132kV/EHV: Domestic Two Rate 91 2 0.447 0.024 0.63
LDNO 132kV/EHV: Domestic Off Peak (related MPAN) 92 2 0.047
LDNO 132kV/EHV: Small Non Domestic Unrestricted 93 3 0.364 0.58
LDNO 132kV/EHV: Small Non Domestic Two Rate 94 4 0.438 0.034 0.58
LDNO 132kV/EHV: Small Non Domestic Off Peak (related MPAN) 95 4 0.061
LDNO 132kV/EHV: LV Medium Non-Domestic 96 5-8 0.332 0.022 3.23
LDNO 132kV/EHV: LV Sub Medium Non-Domestic - 5-8 0.553 0.042 12.70
LDNO 132kV/EHV: HV Medium Non-Domestic - 5-8 0.522 0.027 53.79
LDNO 132kV/EHV: LV HH Metered 97 0 1.569 0.129 0.016 1.79 0.19 0.040 0.19
LDNO 132kV/EHV: LV Sub HH Metered 98 0 2.354 0.167 0.020 9.78 0.45 0.052 0.45
LDNO 132kV/EHV: HV HH Metered 99 0 2.314 0.143 0.016 30.22 0.49 0.048 0.49
LDNO 132kV/EHV: NHH UMS category A 187 8 0.215
LDNO 132kV/EHV: NHH UMS category B 188 1 0.308
LDNO 132kV/EHV: NHH UMS category C 189 1 0.564
LDNO 132kV/EHV: NHH UMS category D 190 1 0.150
LDNO 132kV/EHV: LV UMS (Pseudo HH Metered) 101 0 4.396 0.140 0.018
NORTHERN POWERGRID (NORTHEAST) LTD 34 of 39 FEBRUARY 2014 - V1.0
Annex 4 - Charges applied to LDNOs with HV/LV end users
Copy from CDCM table 3701 "Tariffs!D43:I81" and paste
values into D14
Unique billing
identifierPCs
Unit rate 1
p/kWh
(red/black)
Unit rate 2
p/kWh
(amber/yellow)
Unit rate 3
p/kWh
(green)
Fixed charge
p/MPAN/day
Capacity charge
p/kVA/day
Reactive power
charge
p/kVArh
Excess capacity
charge
p/kVA
LDNO 132kV/EHV: LV Generation NHH 102 8 ( 0.151)
LDNO 132kV/EHV: LV Sub Generation NHH 103 8 ( 0.163)
LDNO 132kV/EHV: LV Generation Intermittent 104 0 ( 0.151) 0.029
LDNO 132kV/EHV: LV Generation Non-Intermittent 105 0 ( 0.827) ( 0.164) ( 0.023) 0.029
LDNO 132kV/EHV: LV Sub Generation Intermittent 106 0 ( 0.163) 0.034
LDNO 132kV/EHV: LV Sub Generation Non-Intermittent 107 0 ( 0.899) ( 0.177) ( 0.025) 0.034
LDNO 132kV/EHV: HV Generation Intermittent 108 0 ( 0.199) 56.46 0.046
LDNO 132kV/EHV: HV Generation Non-Intermittent 109 0 ( 1.126) ( 0.209) ( 0.027) 56.46 0.046
LDNO 132kV: Domestic Unrestricted 110 1 0.186 0.32
LDNO 132kV: Domestic Two Rate 111 2 0.227 0.012 0.32
LDNO 132kV: Domestic Off Peak (related MPAN) 112 2 0.024
LDNO 132kV: Small Non Domestic Unrestricted 113 3 0.185 0.30
LDNO 132kV: Small Non Domestic Two Rate 114 4 0.223 0.017 0.30
LDNO 132kV: Small Non Domestic Off Peak (related MPAN) 115 4 0.031
LDNO 132kV: LV Medium Non-Domestic 116 5-8 0.169 0.011 1.64
LDNO 132kV: LV Sub Medium Non-Domestic - 5-8 0.281 0.021 6.46
LDNO 132kV: HV Medium Non-Domestic - 5-8 0.266 0.014 27.36
LDNO 132kV: LV HH Metered 117 0 0.798 0.066 0.008 0.91 0.10 0.020 0.10
LDNO 132kV: LV Sub HH Metered 118 0 1.197 0.085 0.010 4.97 0.23 0.026 0.23
LDNO 132kV: HV HH Metered 119 0 1.177 0.073 0.008 15.37 0.25 0.024 0.25
LDNO 132kV: NHH UMS category A 191 8 0.109
LDNO 132kV: NHH UMS category B 192 1 0.157
LDNO 132kV: NHH UMS category C 193 1 0.287
LDNO 132kV: NHH UMS category D 194 1 0.076
LDNO 132kV: LV UMS (Pseudo HH Metered) 121 0 2.236 0.071 0.009
LDNO 132kV: LV Generation NHH 122 8 ( 0.077)
LDNO 132kV: LV Sub Generation NHH 123 8 ( 0.083)
LDNO 132kV: LV Generation Intermittent 124 0 ( 0.077) 0.015
LDNO 132kV: LV Generation Non-Intermittent 125 0 ( 0.421) ( 0.084) ( 0.012) 0.015
LDNO 132kV: LV Sub Generation Intermittent 126 0 ( 0.083) 0.017
LDNO 132kV: LV Sub Generation Non-Intermittent 127 0 ( 0.457) ( 0.090) ( 0.012) 0.017
LDNO 132kV: HV Generation Intermittent 128 0 ( 0.101) 28.72 0.023
LDNO 132kV: HV Generation Non-Intermittent 129 0 ( 0.573) ( 0.106) ( 0.014) 28.72 0.023
LDNO 0000: Domestic Unrestricted 130 1 0.059 0.10
LDNO 0000: Domestic Two Rate 131 2 0.072 0.004 0.10
LDNO 0000: Domestic Off Peak (related MPAN) 132 2 0.008
LDNO 0000: Small Non Domestic Unrestricted 133 3 0.059 0.09
LDNO 0000: Small Non Domestic Two Rate 134 4 0.071 0.005 0.09
LDNO 0000: Small Non Domestic Off Peak (related MPAN) 135 4 0.010
LDNO 0000: LV Medium Non-Domestic 136 5-8 0.054 0.004 0.52
LDNO 0000: LV Sub Medium Non-Domestic - 5-8 0.089 0.007 2.05
LDNO 0000: HV Medium Non-Domestic - 5-8 0.084 0.004 8.68
LDNO 0000: LV HH Metered 137 0 0.253 0.021 0.003 0.29 0.03 0.006 0.03
LDNO 0000: LV Sub HH Metered 138 0 0.380 0.027 0.003 1.58 0.07 0.008 0.07
LDNO 0000: HV HH Metered 139 0 0.373 0.023 0.003 4.88 0.08 0.008 0.08
LDNO 0000: NHH UMS category A 195 8 0.035
LDNO 0000: NHH UMS category B 196 1 0.050
LDNO 0000: NHH UMS category C 197 1 0.091
LDNO 0000: NHH UMS category D 198 1 0.024
LDNO 0000: LV UMS (Pseudo HH Metered) 141 0 0.709 0.023 0.003
LDNO 0000: LV Generation NHH 142 8 ( 0.024)
LDNO 0000: LV Sub Generation NHH 143 8 ( 0.026)
LDNO 0000: LV Generation Intermittent 144 0 ( 0.024) 0.005
LDNO 0000: LV Generation Non-Intermittent 145 0 ( 0.133) ( 0.027) ( 0.004) 0.005
LDNO 0000: LV Sub Generation Intermittent 146 0 ( 0.026) 0.006
LDNO 0000: LV Sub Generation Non-Intermittent 147 0 ( 0.145) ( 0.029) ( 0.004) 0.006
LDNO 0000: HV Generation Intermittent 148 0 ( 0.032) 9.11 0.007
LDNO 0000: HV Generation Non-Intermittent 149 0 ( 0.182) ( 0.034) ( 0.004) 9.11 0.007
NORTHERN POWERGRID (NORTHEAST) LTD 35 of 39 FEBRUARY 2014 - V1.0
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 – 18:30
07:30 – 16:30
18:30 – 20:0000:30 – 07:30
00:00 – 00:30
20:00 – 24:00
Monday – Friday (Mar) 00:30 – 07:3000:00 – 00:30
07:30 – 24:00
Saturday and Sunday
All Year00:30 – 07:30
00:00 – 00:30
07:30 – 24:00
Notes
5 6 7 8 4
Metered voltage Period 1 Period 2 Period 3 Period 4 Associated LLFC
Low Voltage Network 1.086 1.078 1.064 1.070
1, 2, 5, 6, 8, 12, 16, 21, 22,
25, 26, 28, 32, 36, 201, 202,
203, 204, 205, 221, 222,
223, 224, 225, 251, 253,
256, 257, 267, 268, 276,
277, 287, 288, 506, 507,
508, 509, 554, 555, 655,
705, 713, 716, 720, 722,
724, 725, 733, 736, 739,
740, 744, 746, 758, 770,
772, 776, 792, 794, 773,
774, 775, 790, 800, 801,
998, 999
Low Voltage Substation 1.039 1.038 1.040 1.038264, 265, 284, 285, 293,
793, 795
High Voltage Network 1.024 1.023 1.018 1.021
301, 303, 304, 323, 324,
610, 666, 674, 677, 702,
703, 706, 707, 708, 712,
715, 717, 721, 723, 726,
730, 731, 732, 734, 735,
743, 745, 747, 749, 750,
751, 752, 753, 754, 755,
756, 771, 791, 796, 798
High Voltage Substation 1.014 1.014 1.013 1.013
294, 691, 692, 693, 694,
695, 696, 697, 698, 699,
700, 777, 778, 779, 780,
781, 797, 799
Greater than 22kV connected -
generation1.009 1.009 1.007 1.008
769, 785, 786, 787, 788,
789, 802, 803, 804, 805
Greater than 22kV connected -
demand1.009 1.009 1.007 1.008
542, 543, 545, 546, 547,
548, 549
All the above times are in UK Clock time
Northern Powergrid (Northeast) Ltd - Effective from April 2014 - Final LLF Time Periods
Time periods
Generic demand and generation LLFs
Metered voltage, respective periods and associated LLFCs
NORTHERN POWERGRID (NORTHEAST) LTD 36 of 39 FEBRUARY 2014 - V1.0
Annex 5 – Schedule of Line Loss Factors
Site Period 1 Period 2 Period 3 Period 4 Associated LLFC
Site 1 1.006 1.006 1.009 1.007 540
Site 2 1.009 1.009 1.007 1.008 541
Site 3 1.001 1.002 1.002 1.002 544
Site 4 1.000 1.000 1.002 1.002 601
Site 5 1.002 1.002 1.002 1.002 603
Site 6 1.000 1.000 1.001 1.001 604
Site 7 1.011 1.011 1.014 1.011 605
Site 8 1.018 1.020 1.058 1.022 606
Site 9 1.020 1.021 1.051 1.021 607
Site 10 1.025 1.024 1.049 1.027 608
Site 11 1.004 1.004 1.005 1.004 609
Site 12 1.016 1.015 1.014 1.014 611
Site 13 1.005 1.005 1.004 1.005 612
Site 14 1.011 1.010 1.009 1.010 613
Site 15 1.006 1.004 1.006 1.007 614
Site 16 1.005 1.005 1.004 1.005 615
Site 17 1.005 1.005 1.003 1.004 616
Site 18 1.006 1.006 1.006 1.006 617
Site 19 1.011 1.011 1.011 1.011 618
Site 20 1.013 1.012 1.008 1.010 619
Site 21 1.000 1.000 1.000 1.000 620
Site 22 1.006 1.006 1.008 1.007 621
Site 23 1.022 1.019 1.025 1.021 622
Site 24 1.007 1.007 1.007 1.007 624
Site 25 1.016 1.016 1.015 1.016 625
Site 26 1.114 1.064 1.058 1.071 626
Site 27 1.002 1.002 1.003 1.003 627
Site 28 1.021 1.020 1.014 1.017 628
Site 29 1.005 1.006 1.006 1.006 631
Site 30 1.006 1.006 1.006 1.006 632
Site 31 1.038 1.037 1.031 1.034 633
Site 32 1.003 1.003 1.004 1.004 637
Site 33 1.031 1.030 1.024 1.027 680
Site 34 1.007 1.008 1.009 1.008 681
Site 35 1.005 1.005 1.003 1.004 682
Site 36 1.011 1.016 1.015 1.008 683
Site 37 1.005 1.005 1.005 1.005 684
Site 38 1.003 1.003 1.002 1.002 685
Site 39 1.009 1.009 1.007 1.008 686
Site 40 1.001 1.001 1.001 1.001 687
Site 41 1.009 1.009 1.007 1.008 688
Site 42 1.009 1.009 1.007 1.008 689
Site 43 1.015 1.016 1.015 1.015 690
EHV site specific LLFs
Demand
NORTHERN POWERGRID (NORTHEAST) LTD 37 of 39 FEBRUARY 2014 - V1.0
Annex 5 – Schedule of Line Loss Factors
Site Period 1 Period 2 Period 3 Period 4 Associated LLFC
Site 1 0.995 0.996 0.996 0.996 701
Site 2 1.007 1.007 1.003 1.005 704
Site 3 0.994 0.996 0.994 0.993 709
Site 4 1.019 1.018 1.006 1.014 710
Site 5 0.987 0.989 0.981 0.987 711
Site 6 0.997 0.997 0.996 0.996 727
Site 7 1.000 1.000 1.000 1.000 728
Site 8 0.994 0.995 0.995 0.995 729
Site 9 1.010 1.011 1.003 1.009 748
Site 10 1.046 1.044 1.030 1.038 759
Site 11 0.998 0.999 0.995 0.997 760
Site 12 0.996 0.996 0.997 0.996 761
Site 13 1.007 1.007 1.003 1.005 762
Site 14 0.973 0.973 0.973 0.974 763
Site 15 1.001 0.999 0.996 0.998 764
Site 16 0.999 0.998 0.997 0.997 765
Site 17 1.009 1.009 1.007 1.008 766
Site 18 1.009 1.009 1.007 1.008 767
Site 19 1.009 1.009 1.007 1.008 768
Site 20 1.009 1.010 1.001 1.005 782
Site 21 1.000 1.000 1.000 0.999 783
Site 22 1.009 1.009 1.007 1.008 784
Generation
EHV sites specific LLFs
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