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BSC Section X-2: Technical Glossary

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ANNEX X-2: TECHNICAL GLOSSARY

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12/01/23

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06/08/21

23/02/23

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23/11/22

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52.0

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13/01/22

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24/02/21

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03/02/21

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18/06/18

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12/12/19

27/02/20

47.0

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13/06/19

07/11/19

46.0

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14/06/18

27/06/19

45.0

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24/09/18

29/03/19

44.0

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24/08/18

28/02/19

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27/02/19

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23/02/12

23/02/12

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18/11/10

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29/08/03

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17/12/02

28/09/03

14.0

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12/08/02

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09/09/02

11/03/03

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22/11/02

11/03/03

12.0

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02/01/03

23/01/03

11.0

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24/07/02

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10.0

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23/09/02

30/09/02

9.0

P33

07/12/01

30/09/02

9.0

P2

16/10/01

30/09/02

9.0

P12

10/05/02

02/07/02

8.0

P46

14/05/02

22/05/02

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P37

10/05/02

20/05/02

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P22

07/12/01

01/04/02

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P67

01/03/02

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25/09/01

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11/05/01

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Section X-2

Version 54.0

Effective Date: 02 November 2023

ANNEX X-2: TECHNICAL GLOSSARY

1. GENERAL

1.1 Introduction

1.1.1 This Annex to Section X sets out:

(a) technical definitions and acronyms applicable in the Code other than in relation to Section S;

(b) technical definitions and acronyms applicable only in relation to Section S;

(c) conventions applicable to the Code, including timing conventions, the use of superscripts/subscripts with variables, summations and mathematical operators; and

(d) the method of interpolation of variables.

1.2 Use of Mathematical Operators

1.2.1 The mathematical operators and conventions employed in the formulae and other algebraic expressions contained in the Code shall be construed in accordance with the following:

(a) the symbol * requires multiplication to be effected;

(b) in respect of any data items, the symbol ∈ refers to belonging to or falling within. For example a∈p denotes those Energy Accounts 'a' that belong to Party ‘p’, and j∈D denotes those Settlement Periods ‘j’ falling within Settlement Day ‘D’;

(c) the number 0 (zero) shall be treated as a positive whole number;

(d) the convention |FUNC| refers to the absolute value of the expression ‘FUNC’, that is the positive value whether the value obtained is positive or negative;

(e) Where in the Code the minimum value ('min') of a set of numbers is to be selected, then for the avoidance of doubt, the value selected shall be the negative number in that set with the greatest magnitude, or in the absence of any such negative number, the positive number in that set with the lowest magnitude. Where in the Code the maximum value ('max') of a set of numbers is to be selected, then for the avoidance of doubt, the value selected shall be the positive number in that set with the greatest magnitude, or in the absence of any such positive number, the negative number in that set with the lowest magnitude.

2. TECHNICAL TERMS AND INTERPRETATION APPLYING EXCEPT IN RELATION TO SECTION S

2.1 Introduction

2.1.1 Unless the context otherwise requires the provisions of this paragraph 2 as to the use, interpretation or definition of terms, expressions, acronyms, and subscripts and summations shall apply in relation to the Code except in Section S.

2.2 Use of Subscripts and Other Expressions

2.2.1 The subscripts and superscripts employed in the formulae and other algebraic expressions contained in the Code shall bear the respective meanings set out in Table X-1.

2.3 Glossary of Terms

2.3.1 Unless the context otherwise requires, and subject as provided in Table X-2, in the Code the words, expressions and acronyms set out in Table X-2 shall bear the respective meanings therein set out.

2.3.2 Table X-3 sets out for convenience the acronyms employed in the formulae and other algebraic expressions contained in the Code in alphabetical order of acronym name.

2.4 Sign Convention - Active Energy and Active Power

2.4.1 Subject to paragraph 2.4.2, the sign convention adopted in the Code is that all variables representing Active Energy or Active Power are:

(a) positive in any Settlement Period for which they represent Active Energy or Active Power delivered on to the Total System or (at any Systems Connection Points(s)) the Transmission System; and

(b) negative in any Settlement Period for which they represent Active Energy or Active Power off-taken from the Total System or (at any Systems Connection Points(s)) the Transmission System.

2.4.2 Paragraph 2.4.1 shall not apply in relation to:

(a) GSP Group Take;

(b) Offer Non-Delivery Volume, Period BM Unit Non-Delivery Offer Volume and any other variable representing Active Energy or Active Power derived by calculation undertaken pursuant to Section T,

which shall, for the avoidance of doubt, be positive, negative or zero as determined in accordance with the algebraic determination of such variable pursuant to the Code.

2.5 Sign Convention - Cashflows

2.5.1 The sign convention adopted in the Code in relation to amounts payable in respect of Trading Charges is explained in Section T1.2.3 and T1.2.4.

2.6 Use of Summations

2.6.1 Variables being summated are indicated by the use of the indices placed in preceding or following superscript or subscript position on the summation sign Σ, for example:

(a) Σc FUNCc means the sum of the values of FUNCc over all values of c.

(b) Σd FUNCd means a sum of the values of FUNCd over all values of d.

(c) ΣcΣdFUNCcd means a sum of the values of FUNCcd over all values of d, and c.

(d) ΣdRFUNCd means a sum of the values of FUNCd over values of d belonging to the set R.

2.6.2 In some instances, where the summation over a particular variable is restricted to a subset of the possible values of such a variable as in paragraph 2.6.1(d), instead adopting of the convention in that paragraph, an equivalent result is achieved by limiting the summation in context, for example:

dFUNCd;

Where Σd represents a sum over all values of d belonging to the set R."

This is equivalent to ΣdRFUNCd.

2.6.3 In some instances, for convenience certain summations deviate from the above conventions and are further defined in context, for example:

dFUNCd;

Where Σd represents a sum over all values of d belonging to the set R."

Again, this is equivalent to ΣdRFUNCd.

3. TECHNICAL TERMS AND INTERPRETATION APPLYING IN RELATION TO SECTION S

3.1 Introduction

3.1.1 Unless the context otherwise requires the provisions of this paragraph 3 as to the use, interpretation or definition of terms, expressions, acronyms, and subscripts and summations shall apply only in relation to Section S.

3.2 Use of Subscripts and Other Expressions

3.2.1 The subscripts and superscripts employed in the formulae and other algebraic expressions contained in the Code shall bear the respective meanings set out in Table X-4.

3.3 Use of Summations

3.3.1 The summations employed in the formulae and other algebraic expressions contained in the Code shall bear the respective meanings set out in Table X-5.

3.4 Glossary of Terms

3.4.1 Unless the context otherwise requires, in the Code the words, expressions and acronyms set out in Table X-6 shall bear the respective meanings therein set out.

3.4.2 Table X-7 sets out for convenience the acronyms employed in the formulae and other algebraic expressions contained in the Code in alphabetical order of acronym name.

3.5 Consumption Component Classes

3.5.1 Table X-8 sets out the valid Consumption Component Classes as at the Code Effective Date.

3.5.2 The Panel may from time to time amend the list of valid Consumption Component Classes.

3.6 Linear Interpolation of Variables

3.6.1 In Section S of the Code, unless the context otherwise requires, whenever linear interpolation is referred to, the procedures set out in paragraphs 3.6.2 to 3.6.4 shall be followed.

3.6.2 Where the relationship between two variables, x and y, is defined only for a set of related pairs of spot values, (x1, y1), (x2, y2) ... (xn, yn), and where a value for y, yi, is to be calculated by linear interpolation for a value of x, xi, which is not a spot value contained in the set of related pairs, but which lies within the range of x spanned by the set of related pairs, the following formula shall be applied:

yi = y0 + ((y1 - y0) * (xi - x0)/(x1 - x0))

where x0 refers to the value of x in that related pair in the set of related pairs in which x is less than xi, and where the x of the related pair is the closest x to xi;

x1 refers to the value of x in that related pair in the set of related pairs in which x is greater than xi, and where the x of the related pair is the closest x to xi;

y0 refers to the value of y related to x0; and

y1 refers to the value of y related to x1.

3.6.3 Where xi lies outside the range of x spanned by the set of related pairs, yi shall be set equal to the value of y in that related pair in which the value of x is closest to xi.

3.6.4 Where xi is a value of x referred to in a related pair, yi shall be set equal to the value of y contained in that related pair.

3.7 Sign Convention

        1. With the exception of BM Unit Allocated Demand Volume, for the purposes of collecting and aggregating metered data as part of Supplier Volume Allocation pursuant to Section S, metered data, whether in respect of an Import (or aggregation of Imports) or an Export (or aggregation of Exports), will be held as the magnitude of the quantity which such metered data represents.

3.7.2 BM Unit Allocated Demand Volume shall be positive in any Settlement Period for which it represents Active Energy offtaken from the Total System and negative in any Settlement Period for which it represents Active Energy delivered to the Total System.

4. TIMING CONVENTIONS

4.1 Introduction

4.1.1 A number of variables within the Code are expressed as differing functions of time. This paragraph 4 defines the nomenclature used in such expressions.

4.1.2 Paragraphs 4.1 to 4.3 apply in relation to the Code including Section S but paragraphs 4.4 to 4.6 do not apply in relation to Section S.

4.2 Spot Time

4.2.1 Many input variables and calculated values are given for spot times within the Code.

4.2.2 Spot times are an instant in time, and have no duration.

4.3 Settlement Period Times

4.3.1 Settlement Period j starts at the spot time occurring at the beginning of the half hour and ends at the spot time occurring exactly thirty minutes later. The spot time at the beginning of one period therefore coincides with the spot time at the end of the previous period.

4.3.2 For the avoidance of doubt the first Settlement Period of a Settlement Day begins at the spot time 00:00 on the current Settlement Day (D), and ends at the spot time of 00:30 for the current Settlement Day D.

4.3A Quarter Hour Times

4.3A.1 Quarter Hours start at the spot time occurring at the beginning of the quarter hour and ends at the spot time occurring exactly fifteen minutes later. The spot time at the beginning of one Quarter Hour period therefore coincides with the spot time at the end of the previous Quarter Hour period.

4.4 Point Variables

4.4.1 Where variables are determined in relation to spot times, they are termed ‘point’ variables. The values of point variables and their associated spot times are converted (as provided in Section T3.1) from data provided by the NETSO in a different format. There is a restriction on the resolution of the pre-conversion data, such that values of point variables to which this data is converted may only be for spot times expressed in a whole number of minutes.

4.4.2 Point variables are given the subscript 't', where 't' denotes the spot time to which the point variable applies. As point variables must be submitted in a whole number of minutes, there are 31 spot times for which point data may be submitted for any Settlement Period. Up to two point variables may be submitted for a single spot time. This is to accommodate step changes in the associated variable. As the first and last spot times for any Settlement Period coincide with the adjoining Settlement Periods, only one value may be submitted for these spot times. Thus for example for the period 12:30 – 13:00, only one value of point FPN may be submitted for spot times 12:30 and 13:00 (and up to 2 values for any other spot time which is a whole number of minutes and falls within the Settlement Period).

4.4.3 Whether or not step changes are expected depends upon the variable in question. For example, as FPN Data may normally be expected to comply with dynamic parameters, step changes (especially for generation) might not normally be expected. However, a Party’s view of their operating level may change significantly from one Gate Closure to the next, and step changes may be expected at the start of a Settlement Period.

4.4.4 Where two point values are submitted for the same spot time, the Point Variable Identification Number (f) is used to determine the sequence of the two values (as explained further in paragraph 4.5.4).

4.4.5 An example of a set of Point FPN data for Settlement Period (e.g. 12:30 – 13:00) is as follows:

Spot time, t

Point fFPNijt (MW)

12:30

200

12:37

235

12:57

245

13:00

245

4.4.6 The use of the subscript j is retained to represent the fact that the spot values are being submitted for spot times that fall within a particular Settlement Period.

4.5 Interpolation of Values of Point Variables Between Spot Times Supplied

4.5.1 For certain spot variables it may be necessary to evaluate values applicable to any spot time within a Settlement Period from the discrete point variables supplied. These are:

Name

Acronym

Units

Calculated from point variable:

Acceptance Volume

qAkij(t)

MW

fqAkijt

Accepted Bid Volume

qABknij(t)

MW

fqABknijt

Accepted Bid-Offer Volume

qABOknij(t)

MW

fqABOknijt

Accepted Offer Volume

qAOknij(t)

MW

fqAOknijt

Bid-Offer Volume

qBOnij(t)

MW

fqBOnijt

FPN

FPNij(t)

MW

fFPNijt

Deemed Standard Product Shape

qDSPJij(t)

MW

fDSPJijt

4.5.2 Point variables for a particular parameter are normally used to calculate an associated function that is defined for all spot times in a Settlement Period, or in the time interval between such Point Variables. Such associated functions are expressed as a function of time F(t) and are calculated by linear interpolation from the point variables.

4.5.3 Whenever linear interpolation is referred to, the procedures set out in paragraphs 4.5.4 shall be followed.

4.5.4 Where for the purposes of the Code, a function of time F(t) is to be established by linear interpolation from a set of related pairs of spot values with point identification numbers and associated spot times t (each being a whole number of minutes) the following interpretation shall apply:

(a) For a spot time ti which is not a spot value contained in the set of related pairs, but which lies within the range of t spanned by the set of related pairs, the following formula shall be applied:

F(ti) = HFt0 + (LFt1HFt0)*(ti – t0)/(t1–t0)

where

t0 refers to the value of t in that related pair in the set of related pairs in which t is less than ti, and where the t of the related pair is the closest t to ti.

t1 refers to the value of t in that related pair in the set of related pairs in which t is greater than ti, and where the t of the related pair is the closest t to ti.

HFt0 refers to the value of fFt related to t0 with the highest value of f; and

LFt1 refers to the value of fFt related to t1 with the lowest value of f.

(b) For a spot time ti that is a value of t referred to in a related pair where a single value of fFt exists, the value of F(ti) shall be set to fFti contained in that related pair.

(c) For a spot time ti that is a value of t referred to in a related pair where two values of fFt exist, the value of F(ti) shall (subject to 4.6.1(a)) and 4.6.1(b)) below) remain undefined for that time ti.

4.6 Evaluation of Period Variables from Supplied and Interpolated Spot Variables

4.6.1 Period Variables represent the integrated MWh value over the Settlement Period j. Period variables are evaluated as follows:

The value of the Period Variable Fj for Settlement Period j, is determined by integrating the associated function of time F(t) with respect to time across the Settlement Period.

(a) Where the spot time ti is the first spot time of the Settlement Period, the value of F(ti) shall be set to the value of HFti for the purposes of evaluating the integral.

(b) Where the spot time ti is the last spot time of the Settlement Period, the value of F(ti) shall be set to the value of LFti for the purposes of evaluating the integral.

(c) Where for one or more spot time(s) (t1, t2 … tn) falling within the Settlement Period, the value of F(ti) remains undefined because two values of fFti exist for those spot times, and the spot times are neither the first nor last spot times in the Settlement Period, the integral will be evaluated pursuant to 4.6.2.

4.6.2 The integral shall be evaluated as the sum of:

(a) the integral for the period from the first spot time of the Settlement Period to the spot time immediately preceding the first such spot time; plus

(b) the integral from the spot time immediately succeeding the last such spot time to the last spot time of the Settlement Period; plus

(c) the integrals for each of the other periods within the Settlement Period, if any, defined by the interval between the spot time immediately succeeding any such spot time and the spot time immediately preceding the next such spot time.

Table X–1 –

Use of Subscripts and Superscripts Applying Except in Relation to Section S

The following subscripts and superscripts are used in the formulae and other algebraic expressions contained in the Code to refer to the following:

Symbol

Parameter

a

Energy Account / Virtual Balancing Account

b

Energy Account

c

Demand Control Instruction

d

Day

e

A particular order number of a ranked System Action

f

Point Value Identification Number

g

A particular System Action

H

The higher of two Point Value Identification Numbers f, specified at the same time t for function fF(t)

i

BM Unit

j

Settlement Period

J

Quarter Hour

k

Bid-Offer Acceptance Number

L

The lower of two Point Value Identification Numbers f, specified at time t for function fF(t)

m

Calendar month (except in Section T)

Balancing Services Adjustment Action (in Section T)

n

Bid-Offer Pair Number

N

Node

p

Trading Party, Contract Trading Party, Imbalance Party or Virtual Lead Party as the case may be

q

The order number of a Ranked Bid Volume or Ranked Offer Volume

r

Trading Unit

s

Market Index Data Provider

S

BSC Season

t

STOR Action Number

u

The Non-Delivery Order Number

v

A particular order number of a ranked System Action

w

System Action, or the order number of a ranked System Action

x

The order number of a Ranked Priced Offer

y

BSC Year

z

Energy Contract Volume Notification or Metered Volume Reallocation Notification as the case may be.

Z

Zone

Table X–2 –

Terms and Expressions Applying Except in Relation to Section S

1. Subject to paragraph 2, unless the context otherwise requires, in the Code the words, expressions and acronyms set out in this Table shall bear the respective meanings set out therein.

2. In the fourth column of this Table, words in italics are explanatory only and shall not affect the interpretation of any term in the Table or otherwise of the Code.

Defined Term

Acronym

Units

Definition/Explanatory Text

α

The number 0.45 as specified in Section T2.2.1(b).

The factor α is that proportion of transmission losses to be deducted in total from the BM Unit Metered Volume of BM Units in delivering Trading Units, for the purposes of allocating transmission losses.

For the purposes of the above, transmission losses are defined as the sum of BM Unit Metered Volume over all BM Units (with BM Units that import having a negative value of BM Unit Metered Volume)

QMFRziaj

MWh

An Active Energy value in accordance with Section P3.6.2(a).

In relation to any BM Unit i, for any Settlement Period j, QMFRziaj is a fixed volume of Active Energy to be allocated to the corresponding Energy Account a, of a Contract Trading Party other than the Lead Party from the Energy Account of the Lead Party to which the associated Metered Volume Reallocation Notification z, refers.

QMPRziaj

%

A percentage value in accordance with Section P3.6.2(b).

In relation to any BM Unit i, for any Settlement Period j, QMPRziaj is a percentage of the BM Unit Metered Volume to be allocated to the corresponding Energy Account a of a Contract Trading Party other than the Lead Party from the Energy Account of the Lead Party to which the associated Metered Volume Reallocation Notification z, refers.

ABSVD BM Unit Delivered Volume

AQVMDNLKji

MWh

Has the meaning given to it in Annex S-2 paragraph 7.1.1E.

Acceptance Data

Data (in accordance with Section Q5.3.1) to be submitted by the NETSO pursuant to Section Q6.2.1(e).

Acceptance Volume

qAkij(t)

MW

The quantity determined in accordance with Section T3.4.

The Acceptance Volume is a quantity of absolute MW for any spot time t obtained by interpolating between Point Acceptance Volumes, qAkit, derived from the Acceptance Volume Pairs submitted as part of Acceptance Data for BM Unit i,. and derived from Quarter Hour RR Activations using the Replacement Reserve Schedule Methodology Document.

Acceptance Volume Pair

A pair of data items expressed in accordance with Section Q5.3.1(a) and submitted as part of the Acceptance Data pursuant to Section Q6.2.1(e).

The Acceptance Volume Pair is a pair of MW levels each with an associated spot time which describe the absolute MW level at which a BM Unit should operate at those spot times as a result of Acceptance k.

accepted Bid

MWh

Has the meaning given to that term in Annex T-1.

Accepted Bid Volume

qABknij(t)

MW

The quantity established in accordance with Section T3.7.2.

The Accepted Bid Volume is the quantity of Bid n being the negative part of the Accepted Bid-Offer Volume accepted as a result of Bid-Offer Acceptance k from BM Unit i at spot times t within Settlement Period j.

Accepted Bid-Offer Volume

qABOknij(t)

MW

The quantity established in accordance with Section T3.6

The Accepted Bid-Offer Volume is the quantity of Bid or Offer from Bid-Offer Pair n accepted as a result of Bid-Offer Acceptance k, that is not flagged as relating to an RR Instruction, in Settlement Period j from BM Unit i, for any spot time t within Settlement Period j

accepted Offer

MWh

Has the meaning given to that term in Annex T-1.

Accepted Offer Volume

qAOknij(t)

MW

The quantity established in accordance with . T3.7.1.

The Accepted Offer Volume is the quantity of Offer n being the positive part of the Accepted Bid-Offer Volume accepted as a result of Bid-Offer Acceptance k from BM Unit i at spot times t within Settlement Period j.

Account Bilateral Contract Volume

QABCaj

MWh

The quantity determined in accordance with Section P4.1.1.

The Account Bilateral Contract Volume is the aggregate of all Energy Contract Volumes relating to Energy Account a in Settlement Period j disregarding those that have been rejected and those contained in Energy Contract Volume Notifications that were refused and represents the energy debited from account a and credited to the other accounts (except in the case of the NETSO) for the purpose of calculating Account Energy Imbalance Volume.

Account Credited Energy Volume

QACEaj

MWh

The quantity determined in accordance with Section T4.6.1.

The Account Credited Energy Volume is the aggregate of the BM Unit Metered Volumes allocated to Energy Account a in Settlement Period j.

Account Energy Imbalance Cashflow

CAEIaj

£

The amount determined in accordance with Section T4.7.1.

The Account Energy Imbalance Cashflow is the total cashflow resulting from the Energy Imbalance of Energy Account a in Settlement Period j such that a negative quantity represents a payment to the Trading Party holding Energy Account a and a positive quantity represents a payment by the Trading Party holding Energy Account a.

Account Energy Imbalance Volume

QAEIaj

MWh

The quantity determined in accordance with Section T4.6.3.

The Account Energy Imbalance Volume is the sum of the Account Credited Energy Volume, plus the Account Period Bid-Offer Volume less the Account Bilateral Contract Volume for Energy Account a, in Settlement Period j.

Account Period Balancing Services Volume

QABSaj

MWh

The quantity determined in accordance with Section T4.6.2.

The Account Period Balancing Services Volume is the sum of the net quantity of all accepted Bids and Offers, and the net energy associated with delivery of Applicable Balancing Services from all BM Units for which Energy Account a is the Lead Energy Account in Settlement Period j.

Activated Quantity

MW

In respect of a Position, the quantity of energy to be activated.

Activated Quantity forms part of the Replacement Reserve Activation Data, GB Need Met Data and Interconnector Schedule Data for each Position and is submitted by the NETSO pursuant to Section Q.

Actual Energy Indebtedness

AEIp

MWh

The amount determined as such in accordance with Section M1.2.5.

The Actual Energy Indebtedness is the net energy contribution determined to be allocated to a Trading Party for Settlement Periods as defined in Section M1.2.1.

Arbitrage Tagged

Arbitrage Tagged as provided in paragraph 7 of Part 1 of Annex T-1.

Balancing Demand Control Volume

QBDCcj

MWh

Has the meaning given to it in Section T3.15.3(b).

Balancing Energy Deviation Price

BEDPj

£/MWh

The price specified in Section T3.23, being an amount equal to zero.

Balancing Mechanism Window Period

In relation to a particular time, the Balancing Mechanism Window Period is the period from that time to the end of the Settlement Period for which Gate Closure has most recently occurred at that time.

The Balancing Mechanism Window Period has a duration of between one and one hour and thirty minutes .

Balancing Services Adjustment Action

m

An individual item in the Balancing Services Adjustment Data for which data is provided pursuant to Section Q6.3.2(b).

Balancing Services Adjustment Buy Action

m

A Balancing Services Adjustment Action for which the Balancing Services Adjustment Volume is positive.

Balancing Services Adjustment Buy Volume

QBSABmj

MWh

The Balancing Services Adjustment Volume in respect of a Balancing Services Adjustment Buy Action.

Balancing Services Adjustment Cost

£

The amount sent by the NETSO as 'Balancing Services Adjustment Cost' in respect of a Balancing Services Adjustment Action in accordance with Section Q6.3.

Balancing Services Adjustment Price

BSAPmj

£/MWh

The amount calculated by the SAA and the BMRA as 'Balancing Services Adjustment Price' in respect of a Balancing Services Adjustment Action in accordance with Section Q6.3.

Balancing Services Adjustment Sell Action

m

A Balancing Services Adjustment Action for which the Balancing Services Adjustment Volume is negative.

Balancing Services Adjustment Sell Volume

QBSASmj

MWh

The Balancing Services Adjustment Volume in respect of a Balancing Services Adjustment Sell Action.

Balancing Services Adjustment Volume

QBSAmj

MWh

The amount sent by the NETSO as 'Balancing Services Adjustment Volume' in respect of a Balancing Services Adjustment Action in accordance with Section Q6.3.

Bid

The quantity (as provided in Section Q4.1.3(a) or, where applicable, established in Section T3.4B.3) in a Bid-Offer Pair if considered as a possible decrease in Export or increase in Import of the relevant BM Unit at a given time.

Bid Non-Delivery Volume

QNDBnij

MWh

The quantity determined in accordance with Section T4.8.10.

The Bid Non-Delivery Volume is the quantity of non-delivery apportioned to Bid n from BM Unit i in Settlement Period j.

Bid Price

PBnij

£/MWh

The amount in £/MWh associated with a Bid and comprising part of a Bid-Offer Pair.

Bid-Offer Acceptance Number

k

A number used to identify a particular Acceptance.

Bid-Offer Acceptance Time

Tkit

Spot time

Has the meaning given to that term in Section Q5.1.11.

Bid-Offer Data

Data (comprising the items set out in Section Q4.1.3) to be submitted by the NETSO pursuant to Section Q6.2.1(d).

Bid-Offer Lower Range

BOLRnij(t)

MW

The range determined in accordance with Section T3.4A.3, T3.4A.4 or T3.5.2 (as the case may be).

The Bid-Offer Lower Range is that data calculated for spot times t in Settlement Period j and BM Unit i, for a Bid-Offer Pair with a negative Bid-Offer Pair Number n. It is used to determine the operating range (in absolute MW) below FPN in which a particular Bid-Offer Pair applies.

Bid-Offer Pair

Data which may be submitted in relation to a BM Unit for a Settlement Period, being data that comprises the items set out in Section Q4.1.3, or (where applicable) data created pursuant to Section T3.4B.1.

Bid-Offer Pair Number

n

A number used to identify a particular Bid-Offer Pair.

Values of n are negative for Bid-Offer Pairs that cover operating levels below FPN and positive for those that cover operating levels above FPN.

Bid-Offer Upper Range

BOURnij(t)

MW

The range determined in accordance with Section T3.4A.1, T3.4A.2 or T3.5.1 (as the case may be).

The Bid-Offer Upper Range is that data calculated for spot times t in Settlement Period j and BM Unit i, for a Bid-Offer Pair with a positive Bid-Offer Pair Number n. It is used to determine the operating range (in absolute MW) above FPN in which a particular Bid-Offer Pair applies.

Bid-Offer Volume

qBOnij(t)

MW

The quantity established in accordance with Section T3.3Section T3.3

The Bid-Offer Volume is the quantity of power increase or decrease available (relative to FPN) from Bid-Offer Pair n, in Settlement Period j for BM Unit i at spot time t. Initially the Bid-Offer Volume for a Bid-Offer Pair is constant across a particular Settlement Period.

BM Unit Allocated Demand Disconnection Volume

BMUADDVij

MWh

The quantity submitted in accordance with paragraph 9.6.2 of Annex S-2.

BM Unit Allocated Demand Volume

BMUADVij

MWh

The quantity submitted in accordance with paragraph 9.6.2 of Annex S-2.

BM Unit Applicable Balancing Services Volume Data or BM Unit ABSVD

QASij

MWh

In respect of a BM Unit and a Settlement Period, the Applicable Balancing Services Volume Data sent by the NETSO to the SAA pursuant to Section Q6.4.1.

BM Unit Chargeable Demand

CBMUDij

MWh

The amount determined in accordance with Section T8.

The BM Unit Chargeable Demand is the amount of Demand for a BM Unit which has been adjusted to remove electricity consumed by Generation or Storage Facility under the conditions of the Generation license, which should be subject to the Final Consumption Levy.

BM Unit Credit Assessment Export Capability

BMCAECi

MW

The quantity determined in accordance with Section M1.6.1(a).

BM Unit Credit Assessment Import Capability

BMCAICi

MW

The quantity determined in accordance with Section M1.6.1(b).

BM Unit Identification Number

i

A unique identifier for each BM Unit.

BM Unit Metered Volume

QMij

MWh

In respect of a Settlement Period:

(i) in relation to a BM Unit (other than an Interconnector BM Unit) comprising CVA Metering Systems, the Metered Volume (as determined in accordance with Section R);

(ii) in relation to an Interconnector BM Unit of an Interconnector User, the quantity determined in accordance with Section R7.4.2 (but without prejudice to Section T1.4.6);

(iii) in relation to an Interconnector BM Unit allocated to an Interconnector Error Administrator, the quantity determined in accordance with Section T4.1; and

(iv) in relation to a Supplier BM Unit, the quantity determined in accordance with Section T4.2.1 and

(v) in relation to a Secondary BM Unit, the quantity determined in accordance with Section T4.2A.1.

BM Unit MSID Pair Data

Has the meaning given to that term in Section S paragraph 10.1.3.

BM Unit Period Non-Delivery Charge

CNDij

£

The amount determined in accordance with Section T4.8.13.

The BM Unit Period Non-Delivery Charge is the total non-delivery charge associated with the non-deliver of Bids or Offers for BM Unit i in Settlement Period j.

Buy Price Price Adjustment

BPAj

£/MWh

The amount sent by the NETSO as the ‘Buy Price Price Adjustment’ in accordance with Section Q6.3.

CADL Flagged

CADL Flagged as provided in paragraph 3 of Part 1 of Annex T-1.

Classified Ranked Set

One of the Classified Ranked Sets as provided in paragraph 8 of Part 1 of Annex T-1.

Continuous Acceptance Duration

CADki

Minutes

Has the meaning given to that term in paragraph 12.3 of Annex T-1.

Continuous Acceptance Duration Limit

CADL

Minutes

The value established and from time to time revised and approved in accordance with Section T1.9.

Corrected Component

CORCiNj

MWh

The quantity submitted in accordance with paragraph 9.3.3 of Annex S-2.

Corrected MSID ABSVD Component

CORABSVDCi2Nj

Has the meaning given to it in Annex S-2 paragraph 9.3.5.

Credit Assessment Credited Energy Volume

CAQCEiaj

MWh

The amount determined in accordance with Section M1.2.3.

The Credit Assessment Credited Energy Volume is the contribution to a Trading Party’s Credit Assessment Energy Indebtedness from BM Unit i and Energy Account a in Settlement Period j.

Credit Assessment Energy Indebtedness

CEIpj

MWh

The amount determined as such in accordance with Section M1.2.2.

The Credit Assessment Energy Indebtedness is the net energy contribution determined to be allocated to a Trading Party for Settlement Periods as defined in Section M1.2.1.

Credit Cover

CCp

£

Is defined in Annex X-1

Credit Cover Error Compensation

CCECp

£

Has the meaning given to that term in Section M4.1.1.

The Credit Cover Error Compensation is the aggregate payment that may be made to a Trading Party in relation to a Credit Cover Error.

Credit Cover Error Erroneous Rejection Flag

FLAGpj

Has the value determined in accordance with Section M4.2.3.

The Credit Cover Error Erroneous Rejection Flag is a flag indicating whether Settlement Period j was determined erroneously to fall within a Credit Default Rejection Period for Trading Party p.

Credit Cover Error Imbalance Amount

ECBpj

£

The amount determined as such in accordance with Section M4.2.3.

The Credit Cover Error Imbalance Amount represents the Energy Imbalance related compensation that may be paid to a Trading Party in relation to Settlement Period j, as a consequence of a Credit Cover Error.

Credit Cover Error Interest Amount

ECApj

£

The amount determined as such in accordance with Section M4.2.2.

The Credit Cover Error Interest Amount represents the interest related compensation that may be paid to a Trading Party in relation to Settlement Period j, as a consequence of a Credit Cover Error.

Credit Cover Error Rejection Volume

REJaj

MWh

The quantity determined in accordance with Section M4.2.3.

The Credit Cover Error Rejection Volume represents an assessment of the change (whether positive or negative) in the quantity of energy that would have been allocated to Energy Account a, of Trading Party P, in Settlement Period j, had Energy Contract Volume Notifications and Data relating to Metered Volume Reallocation Notifications not been rejected in accordance with Sections P2.5.2, and P3.5.2, by virtue of Trading Party P being in Level 2 Credit Default.

Credit Cover Percentage

CCPpj

%

Has the meaning given to that term in Section M3.1.1.

Credited Energy Volume

QCEiaj

MWh

The quantity determined in accordance with Section T4.5.1.

Daily Party BM Unit Cashflow

CBMp

£

The amount determined in accordance with Section T3.12.2.

Daily Party Energy Imbalance Cashflow

CAEIp

£

The amount determined in accordance with Section T4.7.3.

Daily Party Information Imbalance Charge

CIIp

£

The amount determined in accordance with Section T4.3.8.

Daily Party Non-Delivery Charge

CNDp

£

The amount determined in accordance with Section T4.8.15

Daily Party Residual Settlement Cashflow

RCRCp

£

The amount determined in accordance with Section T4.10.4.

Daily Party RR Cashflow

CRRp

£

The amount determined in accordance with T3.25.2.

Daily Party RR Instruction Deviation Cashflow

CDRp

£

The amount determined in accordance with T3.25.3.

Daily System Operator Cashflow

CSO

£

The amount determined in accordance with Section T4.9.2.

DC Limits

MW and/or %

Is defined in Annex X-1.

De Minimis Acceptance Threshold

DMAT

MWh

The value established and from time to time revised and approved in accordance with Section T1.8.

De Minimis Tagged

De Minimis Tagged as provided in paragraph 6 of Part 1 of Annex T-1.

Deemed Standard Product Bid Volume

qDSPBJij(t)

MW

The quantity established in accordance with Section T3.19.2.

The Deemed Standard Product Bid Volume is the quantity of Bid being the negative part of the Deemed Standard Product Volume created as a result of a Quarter Hour RR Activation from BM Unit i at spot times t in Quarter Hour J.

Deemed Standard Product Offer Volume

qDSPOJij(t)

MW

The quantity established in accordance with Section T3.19.1.

The Deemed Standard Product Offer Volume is the quantity of Offer being the positive part of the Deemed Standard Product Volume created as a result of a Quarter Hour RR Activation from BM Unit i at spot times t in Quarter Hour J.

Deemed Standard Product Point Variables

qDSPJijt

MW

A MW level and associated time created in accordance with Section T3.1.5(c).

A Point Acceptance Volume, created from Quarter Hour RR Activation Data, is a level in absolute MW for spot time t and BM Unit i, used to imply the acceptance of one or more Replacement Reserve Bids.

Deemed Standard Product Shape

qDSPJij(t)

MW

The quantity established in accordance with Section T3.17.1.

The Deemed Standard Product Shape is a quantity of absolute MW for any spot time t obtained by interpolating between Deemed Standard Product Point Variables, qDSPJijt, derived from the Quarter Hour RR Activation Data submitted as part of the Quarter Hour Auction Result Data for an Replacement Reserve Auction Period

Deemed Standard Product Volume

qDSPVJij(t)

MW

The quantity established in accordance with Section T3.18.1.

The Deemed Standard Product Volume is the quantity of Bid or Offer accepted as a result of a Quarter Hour RR Activation from BM Unit i at spot times t in Quarter Hour J.

Default Funding Share

FSDpm

Has the meaning given to that term in Section D1.3.1(b).

Delivering Transmission Losses Adjustment.

TLMO+j

The factor determined as such in accordance with Section T2.3.1.

The factor used in the determination of the Transmission Loss Multiplier for BM Units in Delivering Trading Units in Settlement Period j

De-Rated Margin Forecast

MWh

The forecast submitted in accordance with Section Q6.1.25.

Emergency Acceptance

An Acceptance which falls within Section Q5.1.3(b).

Emergency Flagged Ranked Set

One of the Emergency Flagged Ranked Sets as provided in paragraph 5 of Part 1 of Annex T-1.

End Point Demand Control Level

MW

Has the meaning given to that term in Section T3.15(b).

Energy Contract Volume

ECQzabj

MWh

An Active Energy value in accordance with Section P2.6.1.

Energy Credit Cover

ECCp

MWh

Has the meaning given to that term in Section M2.4.1.

Energy Indebtedness

EIpj

MWh

Has the meaning given to that term in Section M1.2.1.

Erroneous Energy Indebtedness

EEIpj

MWh

The amount determined as such in accordance with Section M4.2.2.

The Erroneous Energy Indebtedness represents an assessment of that amount of Energy Credit Cover that a Trading Party would have had to establish in Settlement Period j, in order to avoid being in level 1 credit default based on the erroneous calculation of Energy Indebtedness.

Final Loss of Load Probability

LoLPj

In relation to a Settlement Period, the final probability to be provided by the NETSO in accordance with the Loss of Load Probability Calculation Statement and Section Q6.7.2 or Q6.8.4, as applicable.

Final Ranked Set

The Final Ranked Set as provided in paragraph 11.3 of Part 1 of Annex T-1.

First-Stage Flagged

First-Stage Flagged in accordance with paragraph 3, 4 or 5 of Part 1 of Annex T-1.

Flagged (and Unflagged)

Have the meanings given to those terms in paragraph 1.4 of Annex T-1.

Flow Direction

Indicates the direction of the flow of energy associated with a Position.

Flow Direction forms part of the Replacement Reserve Activation Data, GB Need Met Data and Interconnector Schedule Data for each Position and is submitted by the NETSO pursuant to Section Q.

Forecast Total Power Park Module Generation

MW

The forecast of total generation across all Power Park Modules metered by the NETSO in accordance with CC6.5.6 of the Grid Code.

FPN

FPNij(t)

MW

The quantity established in accordance with Section T3.2.1.

The final physical notification for BM Unit is the level of import or export (as the case may be) that the Party expects to import or export from BM Unit i, in Settlement Period j, in the absence of any Balancing Mechanism Acceptances from the NETSO.

The value of FPNij(t) is calculated for spot times t in Settlement Period by linear interpolation from the discrete values of Point FPN submitted.

Network Gas Supply Imbalance Adjustment Volume

QNGSIAij

MWh

Has the meaning given to that term in Section T3.9.2A.

Network Gas Supply Total Bid Payment

TNGSBi

£

Has the meaning given to that term in Section T3.12A.1.

GB Need Met Data

Data (comprising the items set out in Section Q5.6.3) to be submitted by the NETSO pursuant to Section Q6.2C.1(d).

GC Limits

MW and/or %

Is defined in Annex X-1.

General Funding Share

FSGpm

Has the meaning given to that term in Section D1.2.1(d).

In relation to month m, a Trading Party’s General Funding Share reflects its proportionate share of the aggregate of certain BSCCo Charges for that month.

Generating Plant Demand Margin

OCNMFD or OCNMFW

MW

Has the meaning given to that term in OC2 of the Grid Code.

Generic Line Loss Factor

A Line Loss Factor established for a class of Metering System as provided for in Section K1.7.2.

Gross Contract MWh

MWh

The value established in accordance with Annex D-3 paragraph 3.2.

The Gross Contract MWh is the gross aggregate of all Energy Contract Volumes and Metered Volume Fixed Reallocations relating to a Trading Party over a given month.

GSP Group Metered Volume

MWh

In relation to any GSP Group and any Settlement Period, a Metered Volume representing the algebraic sum of:

(i) the quantity of Active Energy flowing into a GSP Group at Grid Supply Points connected to that GSP Group and at Distribution Systems Connections Points connected to that GSP Group, and

(ii) the quantity of Active Energy flowing out of a GSP Group at Grid Supply Points connected to that GSP Group and at Distribution Systems Connections Points connected to that GSP Group

but disregarding Exports and Imports at Boundary Points in that GSP Group.

GSP Group Take

MWh

In relation to any GSP Group and any Settlement Period, shall be determined as follows:

GSPGT = GMV + I – E

where:

GSPGT means the GSP Group Take for that GSP Group and that Settlement Period;

GMV means the GSP Group Metered Volume for that GSP Group and that Settlement Period;

I means the magnitude of the quantities of Imports at CVA Boundary Points in that GSP Group (as at the Transmission Boundary) for that Settlement Period; and

E means the magnitude of the quantities of Exports at CVA Boundary Points in that GSP Group (as at the Transmission Boundary) for that Settlement Period.

High Reference Temperature

Degrees celsius

The daily average temperature for Great Britain which was exceeded on twelve (12) percent (%) of days during a thirty year historic period.

High Reference Transmission Energy

MWh

The daily aggregate Transmission Energy which was exceeded on twelve (12) percent (%) of days during a thirty year historic period.

Indicated Constraint Boundary Margin

MELNGC

MW

The import and export constraint limits for a BMRS Zone.

The import constraint limit being calculated as the boundary transfer limit minus the Demand Forecast plus the sum of Maximum Export Limits for exporting BM Units and the export constraint limit being calculated as the boundary transfer limit plus the Demand Forecast minus the sum of Maximum Export Limits for exporting BM Units

Indicated Demand

INDDEM

MW

The half-hour average MW expected demand in each Settlement Period calculated as the sum of all Physical Notifications for that Settlement Period prevailing at the time of the forecast and for BM Units for which the Physical Notifications are negative, i.e. will be importing energy.

Indicated Generation

INDGEN

MW

The half-hour average MW expected generation in each Settlement Period calculated as the sum of all Physical Notifications for that Settlement Period prevailing at the time of the forecast and for BM Units for which the Physical Notifications are positive, i.e. will be exporting energy.

Indicated Imbalance

IMBALNGC

MW

Has the meaning given to that term in the Grid Code.

Calculated as the difference between the sum of all Physical Notifications for exporting BM Units (i.e. the Indicated Generation) and the Transmission System Demand forecast

Indicated Margin

MW

Has the meaning given to that term in the Grid Code.

Calculated as the difference between the sum of all Maximum Export Limits for exporting BM Units and the Transmission System Demand forecast

Indicative Loss of Load Probability

In relation to a Settlement Period, the indicative probability to be provided by the NETSO in accordance with the Loss of Load Probability Calculation Statement and Sections Q6.8.2 and Q6.8.3.

Indicative Net Imbalance Volume

INIVj

MWh

The Indicative Net Imbalance Volume calculated in accordance with Section V2.6.5.

Indicative Period Accepted Bid Volume

IRRABknij

MWh

The quantity determined in accordance with Section V2.6.4

Indicative Period Accepted Offer Volume

IRRAOknij

MWh

The quantity determined in accordance with Section V2.6.4

Indicative Period Balancing Mechanism Bid Cashflow

ICBnij

£

The amount determined in accordance with Section V2.6.6.

Indicative Period Balancing Mechanism Offer Cashflow

ICOnij

£

The amount determined in accordance with Section V2.6.6.

Indicative Period BM Unit Total Accepted Bid Volume

IQABnij

MWh

The quantity determined in accordance with Section V2.6.4

Indicative Period BM Unit Total Accepted Offer Volume.

IQAOnij

MWh

The quantity determined in accordance with Section V2.6.4

Indicative Period RR BM Unit Cashflow

ICRRiJ

£

The quantity determined in accordance with Section V2.6.6A

Indicative Period RR Total Accepted Bid Volume

IRRABnij

MWh

The quantity determined in accordance with Section V2.6.4

Indicative Period RR Total Accepted Offer Volume

IRRAOnij

MWh

The quantity determined in accordance with Section V2.6.4

Indicative Quarter-Hour RR Cashflow

ICCRiJ

£

The quantity determined in accordance with Section V2.6.6A

Indicative System Buy Price

ISBPj

£/MWh

The Indicative System Buy Price calculated in accordance with Section V2.6.5.

Indicative System Sell Price

ISSPj

£/MWh

The Indicative System Sell Price calculated in accordance with Section V2.6.5.

Information Imbalance Charge

CIIij

£

The amount determined in accordance with Section T4.3.6.

The Information Imbalance Charge is the charge applicable to the associated Lead Party as a result of the difference in FPN data as modified by Acceptances and BM Unit Metered Volume from BM Unit i in Settlement Period j.

Information Imbalance Price

IIPj

£/MWh

The price specified in Section T4.3.5, being an amount equal to zero.

Initial Energy Credit Cover

IECCp

MWh

The amount determined as such in accordance with Section M4.2.2.

The Initial Energy Credit Cover is the amount of Credit Cover that a Trading Party p has in place at the start of a Credit Cover Error Period.

Initial National Demand Out-Turn

INDO

MW

The demand metered by the NETSO taking into account transmission losses but not including station transformer load, pumped storage demand or Interconnector demand. References to INDO in Section Q6.1.13 and in Table 1 of Section V Annex V-1 mean the half-hour average INDO for a Settlement Period. References to INDO in Section G3.1.4 mean the spot time INDO measured by the NETSO in accordance with that paragraph.

Initial Ranked Set

One of the Initial Ranked Sets of System Actions as provided in paragraph 2.1(c) of Part 1 of Annex T-1.

Initial Transmission System Demand Out-Turn

ITSDO

MW

The half-hour average MW demand metered by the NETSO taking into account transmission losses and including station transformers load, pumped storage demand and Interconnector demand.

Interconnector Metered Volume

IMVj

MWh

Is defined in Annex X-1.

The net aggregate volume of Active Energy, determined as at the Transmission System Boundary, which flowed from or to the relevant Interconnector in Settlement Period j.

Interconnector Schedule Data

Data (comprising the items set out in Section Q5.6.4) to be submitted by the NETSO pursuant to Section Q6.2C.1(d).

Line Loss Factor

Means a multiplier which, when applied to data from a CVA Metering System connected to a Boundary Point on a Distribution System, converts such data into an equivalent value at the Transmission System Boundary.

Line Loss Factor Class

LLFC

A set of SVA Metering Systems defined by a Licensed Distribution System Operator relating to any one or more of its Distribution System(s) that are assigned the same Line Loss Factor for the relevant Settlement Period.

Loss of Load Probability

In relation to a Settlement Period, the Final Loss of Load Probability or the Indicative Loss of Load Probability as the context so requires.

Low Reference Temperature

Degrees celsius

The daily average temperature for Great Britain which was exceeded on eighty eight (88) percent (%) of days during a thirty year historic period.

Low Reference Transmission Energy

MWh

The daily aggregate Transmission Energy which was exceeded on eighty eight (88) percent (%) of days during a thirty year historic period.

Main Funding Share

FSMpm

Has the meaning given to that term in Section D1.2.1(a).

The Main Funding Share represents a Trading Party’s proportionate share of the aggregate Credited Energy Volumes for month m.

Market Index Price

PXPsj

£/MWh

In relation to a Market Index Data Provider and a Settlement Period, the price data to be provided by that Market Index Data Provider in accordance with the Market Index Definition Statement or (where applicable) deemed in accordance with Section T4.3A.1.

Market Index Volume

QXPsj

MWh

In relation to a Market Index Data Provider and a Settlement Period, the volume data to be provided by that Market Index Data Provider in accordance with the Market Index Definition Statement or (where applicable) deemed in accordance with Section T4.3A.1.

Market Price

MPj

£/MWh

Has the meaning given to that term in Section T4.3A.2.

Maximum Delivery Period

Has the meaning given to that term in BC1 of the Grid Code.

Maximum Delivery Volume

Has the meaning given to that term in BC1 of the Grid Code.

Maximum Export Limit

Has the meaning given to that term in BC1 of the Grid Code.

Maximum Import Limit

Has the meaning given to that term in BC1 of the Grid Code.

Metered Credit Assessment Credited Energy Volume

MAQCEiaj

MWh

is defined in Section M1.2.4A.

The Metered Credit Assessment Credited Energy Volume is the contribution to a Trading Party’s Metered Energy Indebtedness from BM Unit i and Energy Account a in Settlement Period j.

Metered Energy Indebtedness

MEIpj

MWh

is defined in Section M1.2.4A.

The Metered Energy Indebtedness is the net energy contribution determined to be allocated to a Trading Party for Settlement Periods as defined in Section M1.2.4A.

Metered Volume Fixed Reallocation

QMFRiaj

MWh

A MWh value determined in accordance with Section P4.3.1.

In relation to any BM Unit i, for any Settlement Period j, Metered Volume Fixed Reallocation means, for Energy Account a of a Contract trading Party, the aggregate of all Metered Volume Reallocation Notification Fixed Data for Metered Volume Reallocation Notifications relating to such Energy Account.

Metered Volume Percentage Reallocation

QMPRiaj

%

A percentage value determined in accordance with Section P4.3.1.

In relation to any BM Unit i, for any Settlement Period j, Metered Volume Percentage Reallocation means, for Energy Account a of Contract Trading Party, the aggregate of all Metered Volume Reallocation Notification Percentage Data for Metered Volume Reallocation Notifications relating to such Party.

Minimum Non-Zero Time

Has the meaning given to that term in BC1 of the Grid Code.

Minimum Zero Time

Has the meaning given to that term in BC1 of the Grid Code.

Monthly Consumption-Charging Net SVA Costs

MCNSCm

£

Has the meaning given to that term in Section D4.1(d).

Monthly Default Costs

MDCm

£

Has the meaning given to that term in Section D4.1(e).

Monthly Net Main Costs

MNMCm

£

Has the meaning given to that term in Section D4.1(d).

Monthly payment

Ppm

£

Has the meaning given to that term in Annex D 4 1.1.

Monthly Production-Charging SVA Costs

MPSCm

£

Has the meaning given to that term in Section D4.1(d).

MSID Pair Data

The data comprising the data items pursuant to Section S10.1 and may be:

(i) BM Unit MSID Pair Data; or

(ii) Non BM Unit ABSVD MSID Pair Data

MSID Pair Delivered Volume

MPDV

MWh

The amount determined in accordance with Section Q6.4.10 or S11.1.1.

.MSID Pair Delivered Volume is such volumes of Active Energy notified to the SVAA by the NETSO for the purposes of calculating Non BM Unit ABSVD (SNBABSVDij); or by the Virtual Lead Party for the purposes of aggregating Secondary BM Unit Supplier Delivered Volume (VBMUSDViZj).

National Demand

Has the meaning given to the term National Demand as defined in the Grid Code.

Net Imbalance Volume

NIVj

MWh

Has the meaning given to that term in paragraph 14.1 of Annex T-1.

NIV Tagged

NIV Tagged as provided in paragraph 9 of Part 1 of Annex T-1.

Non BM Unit Applicable Balancing Services Volume Data or Non BM Unit ABSVD

The following data:

(i) Non BM Unit ABSVD MSID Pair Data ;

(ii) the associated MSID Pair Delivered Volume.

Non BM Unit ABSVD MSID Pair Data

Has the meaning given to that term in Section Q 6.4.8.

Non-BM STOR Instructed Volume

MWh

The volume of Short Term Operating Reserve instructed by the NETSO outside of the balancing mechanism in order to increase generation or reduce demand.

Non-BM STOR Instruction

A Short Term Operating Reserve instruction given by the NETSO outside of the balancing mechanism in order to increase generation or reduce demand.

Non-Delivered Bid Charge

CNDBnij

£

The amount determined in accordance with Section T4.8.12.

The Non-Delivered Bid Charge is a charge in Settlement Period j, that may relate to an accepted Bid n, that is determined not to have been delivered (either wholly or in part) from BM Unit i.

Non-Delivered Bid Price

NDPBnij

£/MWh

The amount determined in accordance Section T4.8.19, T4.8.20 and T4.8.21.

The amount in £/MWh associated with an Accepted Bid (being an Accepted Bid or a downward Quarter Hour RR Activation) that is allocated to Period BM Non-Delivered Bid Volume.

Non-Delivered Offer Charge

CNDOnij

£

The amount determined in accordance with Section T4.8.11.

The Non-Delivered Offer Charge is a charge in Settlement Period j, that may relate to an accepted Offer n, that is determined not to have been delivered (either wholly or in part) from BM Unit i.

Non-Delivered Offer Price

NDPOnij

£/MWh

The amount determined in accordance Section T4.8.16, T4.8.17 and T4.8.18.

The amount in £/MWh associated with an Accepted Offer (being an Accepted Offer or an upward Quarter Hour RR Activation) that is allocated to Period BM Non-Delivered Offer Volume.

Non-Delivery Order Number

u

The number allocated to an Offer or Bid in accordance with Section T4.8.4 or T4.8.8.

The Non-Delivery Order Number (u) is an index used to rank non-delivered Offers or Bids from a BM Unit in a particular Settlement Period in order to determine the order of allocation the Period BM Unit Non-Delivered Offer Volume, or the Period BM Unit Non-Delivered Bid Volume.

Non-Working Day Credit Assessment Load Factor

NWDCALFi

Is defined in Annex X-1.

The factor is used to establish the BM Unit Credit Assessment Export Capability and BM Unit Credit Assessment Import Capability for BM Unit i on a CALF Non-Working Day determined for the purposes of Credit Assessment Load Factor.

Normal Reference Temperature

Degrees celsius

The daily average temperature for Great Britain which was exceeded on fifty (50) percent (%) of days during a thirty year historic period.

Normal Reference Transmission Energy

MWh

The daily aggregate Transmission Energy which was exceeded on fifty (50) percent (%) of days during a thirty year historic period.

Notice to Deliver Bids

Has the meaning given to that term in BC1 of the Grid Code.

Notice to Deliver Offers

Has the meaning given to that term in BC1 of the Grid Code.

Notice to Deviate from Zero

Has the meaning given to that term in BC1 of the Grid Code.

Offer

The quantity (as provided in Section Q4.1.3(a) or, where applicable, established in Section T3.4B.3) in a Bid-Offer Pair if considered as a possible increase in Export or decrease in Import of the relevant BM Unit at a given time.

Offer Non-Delivery Volume

QNDOnij

MWh

The quantity determined in accordance with Section T4.8.6.

The Offer Non-Delivery Volume is the quantity of non-delivery apportioned to Offer n from BM Unit i in Settlement Period j.

Offer Price

POnij

£/MWh

The amount in £/MWh associated with an Offer and comprising part of a Bid-Offer Pair.

Offtaking Transmission Losses Adjustment

TLMO-j

The factor determined as such in accordance with Section T2.3.1.

The factor used in the determination of the Transmission Loss Multiplier for BM Units in Offtaking in Trading Units in Settlement Period j

Output Usable

MW

Has the meaning given to that term in the Grid Code.

Out-Turn Temperature

Degrees celsius

A single value deemed to be representative of the temperature for Great Britain as measured at midday.

PAR Tagged

PAR Tagged as provided in paragraph 11 of Part 1 of Annex T-1.

Party Daily Reallocation Proportion

Has the meaning given to that term in Section G1.3.

Party Submitted Expected Volumes

PSEV

MWh

The volume submitted by the Party which represents the Party’s forecast of expected volumes per Settlement Period for all MSID Pairs not selected for Baselining within a BMU providing Balancing Services

Period Accepted Bid Volume

QABknij

MWh

The quantity established in accordance with Section T3.8.2.

The Period Accepted Bid Volume is the volume of Bid n, accepted in respect of BM Unit i, in Settlement Period j, as a result of Acceptance k, where that Acceptance is not flagged as relating to an RR Schedule.

Period Accepted Offer Volume

QAOknij

MWh

The quantity established in accordance with Section T3.8.1.

The Period Accepted Offer Volume is the volume of Offer n, accepted in respect of BM Unit i, in Settlement Period j as a result of Acceptance k, where that Acceptance is not flagged as relating to an RR Schedule.

Period BM Unit Balancing Services Volume

QBSij

MWh

The quantity determined in accordance with Section T4.3.2.

The Period BM Unit Balancing Services Volume is the sum of the net quantity of accepted Bids and Offers and the net quantity of energy associated with delivery of Applicable Balancing Services from BM Unit i in Settlement Period j.

Period BM Unit Bid Cashflow

CBnij

£

The amount determined in accordance with Section T3.10.2.

The Period BM Unit Bid Cashflow is the total cashflow resulting from accepted volumes of Bid n from BM Unit i in Settlement Period j.

Period BM Unit Cashflow

CBMij

£

The amount determined in accordance with Section T3.11.1.

The Period BM Unit Cashflow is the total cashflow resulting from all accepted Bids and Offers from BM Unit i in Settlement Period j.

Period BM Unit Non Chargeable Demand

NCBMUDij

MWh

The amount determined in accordance with Annex S-2 3.11 which is used in Section T8.

The Period BM Unit Non Chargeable Demand is the amount of Demand for a BM Unit which has been consumed by Generation or Storage Facility under the conditions of the Generation license which should not be subject to the Final Consumption Levy.

Period BM Unit Demand Disconnection Volume

QDDij

MWh

The quantity established in accordance with Section R8.2.1.

The Period BM Unit Demand Disconnection Volume is the volume of energy for BM Unit i in Settlement Period j that was subject to Demand Disconnection.

Period BM Unit Non-Delivered Bid Volume

QNDBij

MWh

The quantity determined in accordance with Section T4.8.2.

The Period BM Unit Non-Delivered Bid Volume is the quantity of non-delivered Bids from BM Unit i in Settlement Period j.

Period BM Unit Non-Delivered Offer Volume

QNDOij

MWh

The quantity determined in accordance with Section T4.8.1.

The Period BM Unit Non-Delivered Offer Volume is the quantity of non-delivered Offers from BM Unit i in Settlement Period j.

Period BM Unit Offer Cashflow

COnij

£

The amount determined in accordance with Section T3.10.1.

The Period BM Unit Offer Cashflow is the total cashflow resulting from accepted volumes of Offer n from BM Unit i in Settlement Period j.

Period BM Unit Total Accepted Bid Volume

QABnij

MWh

The quantity established in accordance with Section T3.9.2.

The Period BM Unit Total Accepted Bid Volume is the quantity of Bid n, accepted in respect of BM Unit i, in Settlement Period j, as a result of all Acceptances that are not flagged as relating to an RR Schedule.

Period BM Unit Total Accepted Offer Volume

QAOnij

MWh

The quantity established in accordance with Section T3.9.1.

The Period BM Unit Total Accepted Offer Volume is the quantity of Offer n, accepted in respect of BM Unit i, in Settlement Period j, as a result of all Acceptances that are not flagged as relating to an RR Schedule.

Period Deemed Standard Product Bid Volume

DSPBJij

MWh

The quantity established in accordance with Section T3.20.2.

The Period Deemed Standard Product Bid Volume is the volume of Bid, accepted in respect of BM Unit i, in Settlement Period j as a result of an acceptance of a Replacement Reserve Bid in Quarter Hour J.

Period Deemed Standard Product Offer Volume

DSPOJij

MWh

The quantity established in accordance with Section T3.20.1.

The Period Deemed Standard Product Offer Volume is the volume of Offer, accepted in respect of BM Unit i, in Settlement Period j as a result of an acceptance of a Replacement Reserve Bid in Quarter Hour J.

Period Expected Metered Volume

QMEij

MWh

The quantity determined in accordance with Section T4.3.3.

The Period Expected Metered Volume is the quantity of energy that a particular BM Unit i, is expected to export or import in Settlement Period j, after taking account of any accepted offers or bids.

Period FPN

FPNij

MWh

The quantity determined in accordance with T4.3.1.

The Period FPN is the integrated MWh of energy implied by integrating the Final Physical Notification for BM Unit i over Settlement Period j.

Period Information Imbalance Volume

QIIij

MWh

The quantity determined in accordance with Section T4.3.4.

The Period Information Imbalance Volume is the difference between the BM Unit Metered Volume and the Period Expected Metered Volume for BM Unit i in Settlement Period j.

Period RR Accepted Bid Volume

RRABknij

MWh

The quantity established in accordance with Section T3.8.4.

The Period RR Accepted Bid Volume is the volume of Bid n, accepted in respect of BM Unit i, in Settlement Period j, as a result of Acceptance k, where that Acceptance is flagged as relating to an RR Schedule.

Period RR Accepted Offer Volume

RRAOknij

MWh

The quantity established in accordance with Section T3.8.3.

The Period RR Accepted Offer Volume is the volume of Offer n, accepted in respect of BM Unit i, in Settlement Period j as a result of Acceptance k, where that Acceptance is flagged as relating to an RR Schedule.

Period RR BM Unit Cashflow

CRRij

£

The amount determined in accordance with Section T3.11B.1.

The Period RR BM Unit Cashflow is the total cashflow resulting from all Quarter Hour RR Activations from BM Unit i in Settlement Period j.

Period RR Total Accepted Bid Volume

RRABnij

MWh

The quantity established in accordance with Section T3.9.4.

The Period RR Total Accepted Bid Volume is the quantity of Bid n, accepted in respect of BM Unit i, in Settlement Period j, as a result of all Acceptances that are flagged as relating to an RR Schedule.

Period RR Total Accepted Offer Volume

RRAOnij

MWh

The quantity established in accordance with Section T3.9.3.

The Period RR Total Accepted Offer Volume is the quantity of Offer n, accepted in respect of BM Unit i, in Settlement Period j, as a result of all Acceptances that are flagged as relating to an RR Schedule.

Period Secondary BM Unit Delivered Proportion

SPiji2

MWh

This quantity is determined in accordance with Section T4.3B.3.

Period Secondary BM Unit Delivered Volume

QSDij

or

QSDi2j

MWh

This quantity is determined in accordance with Section T4.3B.2.

This quantity is represented by the acronym QSDi2j in paragraph T4.3B.4 for the sole reason that the formula in this paragraph refers to both Primary BM Units and Secondary BM Units.

Period Secondary BM Unit Non-Delivered Volume

QSNDij

MWh

This quantity is determined in accordance with Section T4.3B.1.

Period Secondary BM Unit Supplier Delivered Volume

QSDiji2

MWh

This quantity is determined in accordance with Section T4.3B.4.

Period Supplier BM Unit Delivered Volume

QBSDij

MWh

This quantity is determined in accordance with Section T4.3B.5.

Point Acceptance Volume

qAkit

MW

A MW level and associated time created in accordance with Section T3.1.2(c)

A Point Acceptance Volume submitted as part of Acceptance Volume Pair, is a level in absolute MW for spot time t and BM Unit i, used to imply the acceptance of one or more Offers and/or Bids.

Point Bid-Offer Volume

fqBOnijt

MW

A MW level and associated time in accordance with Section T3.1.2(b).

The Point Bid-Offer Volume is one of two MW quantities each with the same or different associated spot time t, determined for each Bid-Offer Pair n, for BM Unit i in Settlement Period j.

Point FPN

fFPNijt

MW

A MW quantity and associated time in accordance with Section T3.1.2(a).

Point FPN data is a series of one or more MW spot values submitted for spot times t in Settlement Period j for BM Unit i. It is used to determine the values of Final Physical Notification.

Point Value Identification Number

f

A number used to differentiate two values of a point variable determined for the same spot time and established for Point FPN values in Section T3.1.2(a) and for Point Bid-Offer Volumes in Section T3.1.2(b).

Position

The identifier for a specific period of time submitted to the SAA pursuant to Section T3.1.5 with associated Replacement Reserve Activation Data, GB Need Met Data and Interconnector Schedule Data.

Each Position is an identifier determined by reference to a Replacement Reserve Auction Period Resolution Type. For a PT60 there will be one Position associated with the relevant Replacement Reserve Auction Period, for a PT30 there will be two Positions associated with the relevant Replacement Reserve Auction Period and for a PT15 there will be four Positions associated with the relevant Replacement Reserve Auction Period. The SAA will convert Replacement Reserve Activation Data, GB Need Met Data and Interconnector Schedule Data associated with each Position into Quarter Hour data pursuant to Section T3.1.5.

Price Average Reference Volume

PAR

MWh

The volume determined in accordance with Section T1.10.1

Quarter Hour

A period of fifteen minutes beginning on the hour or each quarter hour thereafter and in accordance with paragraph 4.3A of this Annex X-2.

Quarter Hour GB Need Met

For each Quarter Hour, data derived from GB Need Met Data pursuant to Section T3.1.5.

Quarter Hour Interconnector Schedule

For each Quarter Hour, data derived from Interconnector Schedule Data pursuant to Section T3.1.5.

Quarter Hour RR Activated Quantity

For each Quarter Hour, the MW level derived from Replacement Reserve Auction Result Data pursuant to Section T3.1.5.

Quarter Hour RR Activation

For each Quarter Hour, data derived from Replacement Reserve Activation Data pursuant to Section T3.1.5.

Quarter Hour RR Activation Data

Data (comprising the items set out in Section Q5.6.2) to be submitted by the NETSO pursuant to Section Q6.2C.1(d).

Quarter Hour RR Activation Price

£/MWh

The price associated with a RR Activation as defined in Section Q5.6.2(e).

Quarter Hour RR Activation Volume

RRAViJ

MWh

The quantity established in accordance with Section T3.9.5.

The RR Activation Level multiplied by the Quarter Hour duration in hours, for a given Quarter Hour RR Activation.

Quarter Hour RR Cashflow

CCRiJ

£

The amount determined in accordance with Section T3.11A.1.

The Quarter Hour RR Cashflow is the total cashflow resulting from a RR Activations from BM Unit i in Quarter Hour J.

Quarter Hour Volume GB Need Met

VGBJ

MWh

For each Quarter Hour, data derived from Quarter Hour Interconnector Schedule pursuant to Annex T1 paragraph 1.2.(b).vii or paragraph 1.2.(c).vii

Quarter Hour Volume Interconnector Schedule

VIJ

MWh

For each Quarter Hour, data derived from Quarter Hour Interconnector Schedule pursuant to Annex T1 paragraph 1.2.(b).viii or paragraph 1.2.(c).viii

Ranked Set

Has the meaning given to that term in paragraph 1.2 of Annex T-1.

Registered Capacity

MW

Has the meaning given to that term in the Grid Code.

Remaining Period BM Unit Non-Delivered Bid Volume

RQNDBuij

MWh

The quantity determined as such in accordance with Section T4.8.10

The Remaining Period BM Unit Non-Delivered Bid Volume is the amount of Non-Delivered Bid Volume remaining to be allocated to Bid u from BM Unit i in Settlement Period j.

Remaining Period BM Unit Non-Delivered Offer Volume

RQNDOuij

MWh

The quantity determined as such in accordance with Section T4.8.6.

The Remaining Period BM Unit Non-Delivered Offer Volume is the amount of Non-Delivered Offer Volume remaining to be allocated to Offer u from BM Unit i in Settlement Period j.

Replacement Buy Price

RBPj

£/MWh

The Replacement Buy Price determined in accordance with paragraph 15 of Part 2 of Annex T-1.

Replacement Price

RPj

£/MWh

Means either the Replacement Buy Price or the Replacement Sell Price as determined in accordance with paragraph 15 of Part 2 of Annex T-1, and Replacement Pricing shall have the same meaning.

Replacement Price Average Reference Volume

RPAR

Has the meaning given to that term in Section T1.11.1.

Replacement Reserve Activation Data

Data (comprising the items set out in Section Q5.6.2) to be submitted by the NETSO pursuant to Section Q6.2C.1(d).

Replacement Reserve Activation Price

RRAPJ

£/MWh

The price associated with a Position.

Replacement Reserve Activation Price forms part of the Replacement Reserve Activation Data, GB Need Met Data and Interconnector Schedule Data for each Position and is submitted by the NETSO pursuant to Section Q.

Replacement Reserve Activation Time

Spot time

Has the meaning given to that term in Section Q5.6.1.

Replacement Reserve Aggregated Unpriced System Buy Action

RRAUSBj

In respect of each Quarter Hour within a Replacement Reserve Auction Period, an aggregated unpriced System Buy Action derived from Replacement Reserve Auction Result Data.

Replacement Reserve Aggregated Unpriced System Sell Action

RRAUSSj

In respect of each Quarter Hour within a Replacement Reserve Auction Period, an aggregated unpriced System Sell Action derived from Replacement Reserve Auction Result Data.

Replacement Reserve Auction Period

A period of sixty minutes in relation to which Replacement Reserve Auction Result Data is associated pursuant to Section Q5.6 and which period corresponds to two complete Settlement Periods with the start of that Replacement Reserve Auction Period coinciding with the Settlement Period that begins on the hour.

Replacement Reserve Auction Period Resolution Type

Indicates the period of time within the Replacement Reserve Auction Period that the associated Replacement Reserve Activation Data, GB Need Met Data and Interconnector Schedule Data relate to.

A Replacement Reserve Auction Period Resolution Type may be categorised as PT60 which is comprised of a single period of sixty minutes, PT30 which is comprised of two periods of thirty minutes or PT15 which is comprised of four periods of fifteen minutes.

Replacement Reserve Auction Result Data

Data (comprising the items set out in Section Q5.6.1) to be submitted by the NETSO pursuant to Section Q6.2C.1(d).

Replacement Reserve Bid

Has the meaning given to the term TERRE Bid as defined in the Grid Code.

Replacement Reserve Bid Data

In relation to a Replacement Reserve Bid, the data comprising the items set out in the TERRE Data Validation and Consistency Rules (as defined under the Grid Code) to be submitted by the Lead Party of a BM Unit pursuant to Section Q4.3.3 and by the NETSO pursuant to Section Q6.2C.1(d).

Replacement Reserve Bid Price

£/MWh

The price associated with a Replacement Reserve Bid.

Replacement Reserve Instructed Bid Deviation Volume

IBDij

MWh

The quantity established in accordance with Section T3.22.2.

The Replacement Reserve Bid Deviation Volume is the volume of Bid, in respect of BM Unit i, in Settlement Period j as a result of all acceptances of a Replacement Reserve Bids in that Settlement Period compared to the volume of Bid determined to be the Total Period Deemed Standard Product Bid Volume for that Settlement Period.

Replacement Reserve Instructed Offer Deviation Volume

IODij

MWh

The quantity established in accordance with Section T3.22.1.

The Replacement Reserve Offer Deviation Volume is the volume of Offer, in respect of BM Unit i, in Settlement Period j as a result of all acceptances of a Replacement Reserve Offers in that Settlement Period compared to the volume of Offer determined to be the Total Period Deemed Standard Product Offer Volume for that Settlement Period.

Replacement Reserve Period Instructed Bid Deviation Cashflow

CDBij

£

The cashflow determined in accordance with T3.23.2.

Replacement Reserve Period Instructed Offer Deviation Cashflow

CDOij

£/MWh

The amount determined in accordance with T3.23.1.

Replacement Reserve Period Instruction Deviation Cashflow

CDRij

£

The cashflow determined in accordance with T3.24.1.

Replacement Sell Price

RSPj

£/MWh

The Replacement Sell Price determined in accordance with paragraph 15 of Part 2 of Annex T-1.

Replacement-Priced Ranked Set

The Replacement-priced Ranked Set as provided in paragraph 10.4 of Part 1 of Annex T-1.

Reserve Scarcity Price

RSVPj

£/MWh

In respect of a Settlement Period, the price determined in accordance with Section T3.13.

Residual Cashflow Reallocation Cashflow

RCRCaj

£

The cashflow determined in accordance with Section T4.10.3.

The Residual Cashflow Reallocation Cashflow is the cashflow to Energy Account a in Settlement Period j resulting from the reallocation the Total System Residual Cashflow.

Residual Cashflow Reallocation Proportion

RCRPaj

The proportion determined in accordance with Section T4.10.2.

The Residual Cashflow Reallocation Proportion is a fraction expressing the proportion of the Total System Residual Cashflow to be allocated to Energy Account a in Settlement Period j.

RR Schedule

A MW profile constructed by the SAA that provides a baseline for RR Activations with ramping considerations.

This MW profile is processed by Settlement in the same way as Bid-Offer Acceptance but not settled under Bid-Offer Prices.

Run-Down Rate(s)

Has the meaning given to that term in BC1 of the Grid Code.

Run-Up Rate(s)

Has the meaning given to that term in BC1 of the Grid Code.

Secondary BM Unit AMSID Pair Data

Has the meaning given to that term in Section S paragraph 10.1A

Secondary BM Unit Delivered Volume

QVBMDi2NKji

MWh

The quantity determined in accordance with 7.1.1D Annex S-2.

Secondary BM Unit Supplier Delivered Volume

VBMUSDVi2ji

MWh

The Secondary BM Unit half hourly Supplier Delivered Volumes determined by the SVAA pursuant to paragraph 9.6.1C of Annex S-2.

Second-Stage Flagged

Second-Stage Flagged in accordance with paragraph 8 of Part 1 of Annex T-1.

Sell Price Price Adjustment

SPAj

£/MWh

The amount sent by the NETSO as the ‘Sell Price Price Adjustment’ in accordance with Section Q6.3.

Settlement Expected Volumes

SEV

MWh

The quantity determined in accordance with 7.3.5 Annex S-2.

Settlement Period

j

A period of thirty minutes beginning on the hour or the half-hour and in accordance with paragraph 4.3 of this Annex X-2.

Settlement Period Duration

SPD

Hours

0.5 hours.

Site Specific Line Loss Factor

A Line Loss Factor established for a single Metering System as provided in Section K1.7.2.

Small Scale Third Party Generating Plant Limit

SSTPGPL

The quantity established in accordance with Section L1.5

The Small Scale Third Party Generating Plant Limit is the maximum generation capacity (measured at the Boundary Point) of the aggregate Small Scale Third Party Generating Plant connected to a Distribution System at a single Boundary Point.

SO-Flagged Ranked Set

One of the SO-Flagged Ranked Sets as provided in paragraph 4 of Part 1 of Annex T-1.

Stable Export Limit

Has the meaning given to that term in BC1 of the Grid Code.

Stable Import Limit

Has the meaning given to that term in BC1 of the Grid Code.

Start Point Demand Control Level

MW

Has the meaning given to that term in Section T3.15(a)(a).

STOR Action

An Accepted Offer derived from a STOR Flagged BOA taken by the NETSO during a STOR Availability Window in order to increase generation or reduce demand.

STOR Action Price

STAPtj

£/MWh

In relation to each STOR Action, the price determined in accordance with Section T3.14

STOR Instructed Volume

QSIVtj

MWh

The Period Accepted Offer Volume in respect of each STOR Action instructed by the NETSO in order to increase generation or reduce demand.

Submitted Bid-Offer Pair

A Bid-Offer Pair in respect of which the NETSO submits Bid-Offer Data pursuant to Section Q6.2.

Supplier BM Unit Non BM ABSVD

SNBABSVDij

MWh

The amount determined by the SVAA pursuant to Annex S-2 paragraph 9.6.1C.

Surplus

SPLD or SPLW

MW

Has the meaning given to that term in OC2 of the Grid Code

SVA (Production) Funding Share

FSPSpm

Has the meaning given to that term in Section D1.2.1(c).

In relation to a month m, the SVA (Production) Funding Share represents a Party’s proportionate share of aggregate Credited Energy Volumes for Production BM Units for that month.

System Action

w

Has the meaning given to that term in paragraph 1.2 of Annex T-1.

System Action Price

SAP wj

£/MWh

Has the meaning given to that term in paragraph 1.2 of Annex T-1.

System Buy Action

QSBwj

MWh

Has the meaning given to that term in paragraph 1.2 of Annex T-1.

System Buy Price

SBPj

£/MWh

The price determined in accordance with Section T4.4.2.

System Demand Control Volume

QSDCcj

MWh

Has the meaning given to it in Section T3.15.3(a).

System Operator Cashflow

CSOj

£

The amount determined in accordance with Section T4.9.1.

The System Operator Cashflow is the amount paid by or to the System Operator in Settlement Period j in relation to the settlement of the Balancing Services.

System Sell Action

QSSwj

MWh

Has the meaning given to that term in paragraph 1.2 of Annex T-1.

System Sell Price

SSPj

£/MWh

The price determined in accordance with Section T4.4.3.

System Warning

Has the meaning given to that term in BC1 of the Grid Code.

System Zone

Has the meaning given to that term in the Grid Code.

TLM-adjusted BM Unit Chargeable Demand

TCBMUDij

MWh

The amount determined in accordance with Section T8.1.3.

Total Instantaneous Out-Turn Generation

MW

The total instantaneous generation metered by the NETSO in accordance with CC6.5.6 of the Grid Code.

Total Metered Capacity

MW

The total value of the Registered Capacity of all Power Park Modules metered by the NETSO in accordance with CC6.5.6 of the Grid Code.

Total AMSID Pair Delivered Volume

TAPDVj

MWh

The amount determined in accordance with Annex S-2 3.11.3.

Total MSID Pair Delivered Volume

TMPDVj

MWh

The amount determined in accordance with Annex S-2 3.10.1B.

Total Output Usable

MW

Means the sum of Output Usables (as defined in the Grid Code) excluding (unless expressly stated otherwise in the Code) expected Interconnector transfer capacity.

Total Period Applicable Balancing Services Volume

TQASj

MWh

The amount determined in accordance with Section T4.6.5.

The Total Period Applicable Balancing Services Volume is the net quantity of energy associated with delivery of Applicable Balancing Services by all BM Units in Settlement Period j.

Total Period Deemed Standard Product Bid Volume

TDSPBij

MWh

The quantity established in accordance with Section T3.21.2.

The Total Period Deemed Standard Product Bid Volume is the volume of Bid, accepted in respect of BM Unit i, in Settlement Period j as a result of all acceptances of a Replacement Reserve Bid in that Settlement Period.

Total Period Deemed Standard Product Offer Volume

TDSPOij

MWh

The quantity established in accordance with Section T3.21.1.

The Total Period Deemed Standard Product Offer Volume is the volume of Offer, accepted in respect of BM Unit i, in Settlement Period j as a result of all acceptances of a Replacement Reserve Bid in that Settlement Period.

Total Period Out-Turn Generation

MW

In respect of a Settlement Period, the total generation for that Settlement Period as metered by the NETSO in accordance with CC6.5.6 of the Grid Code.

Total Specified BSC Charges

TSCpm

£

The sum of the Specified BSC Charges for Trading Party p relating to month m.

Total System Cashflow

TCBMj

£

The amount determined in accordance with Section T3.12.1.

The Total System Cashflow is the total payments and charges in respect of settlement of Balancing Services action for all BM Units, disregarding any Non-Delivered Offer Charges and Non-Delivered Bid Charges.

Total System Energy Imbalance Cashflow

TCEIj

£

The amount determined in accordance with Section T4.7.2.

The Total System Energy Imbalance Cashflow is the total cashflow resulting from the Settlement of Energy Imbalances, summed over all Energy Accounts in Settlement Period j.

Total System Energy Imbalance Volume

TQEIj

MWh

The quantity determined in accordance with Section T4.6.4.

Total System Energy Imbalance Volume is the sum over all Energy Accounts of the Account Energy Imbalance Volume..

Total System Information Imbalance Charge

TCIIj

£

The amount determined in accordance with Section T4.3.7.

The Total System Information Imbalance Charge is the total charge for information imbalances, summed over all BM Units in Settlement Period j.

Total System Non-Delivery Charge

TCNDj

£

The amount determined in accordance with Section T4.8.14.

The Total System Non-Delivery Charge is the BM Unit Period Non-Delivery Charge summed over all BM Units in Settlement Period j.

Total System Residual Cashflow

TRCj

£

The amount determined in accordance with Section T4.10.1.

The Total System Residual Cashflow is the surplus or deficit of funds remaining to be reallocated after the Settlement of Energy Imbalances, Information Imbalances, the Balancing Mechanism (including non-delivery) and the System Operator BM Charge.

Total System RR Cashflow

TCRRj

£

The amount determined in accordance with Section T3.25.1.

The Total System RR Cashflow is the summation of Quarter Hour RR Cashflow (CRRiJ) across all BM Units i and across both Quarter Hours J falling within a given Settlement Period j.

Trading Unit Delivery Mode

A flag identifying whether a Trading Unit was a delivering Trading Unit or an offtaking Trading Unit determined in accordance with Section T6.1.3.

Trading Unit Export Volume

QTUErj

MWh

The volume determined in accordance with Section T6.1.1.

Trading Unit Import Volume

QTUIrj

MWh

The volume determined in accordance with Section T6.1.2.

Transmission Energy

MWh

The integral with respect to time of National Demand.

Transmission Loss Factor

TLFij

The factor specified in Section T2.2.1(a).

The Transmission Loss Factor is that factor used to allocate transmission losses on a locational basis to BM Unit i in Settlement Period j.

Transmission Loss Factor Adjustment

TLFAS

The value determined in accordance with paragraph 9.1 of Annex T-2.

The Transmission Loss Factor Adjustment is the value calculated to ensure that, as far as possible, the Adjusted Seasonal Zonal TLF (ATLFZS) values have a zero net aggregate effect on Delivering Transmission Losses Adjustment (TLMO+j) values.

Transmission Loss Multiplier

TLMij

The multiplier calculated in accordance with Section T2.3.1(a) or (b).

The Transmission Loss Multiplier is the factor applied to BM Unit i in Settlement Period j in order to adjust for Transmission Losses.

Transmission System Demand

Has the meaning given to the term National Electricity Transmission System Demand as defined in the Grid Code.

Transmission System Frequency

Hertz

The Frequency of the Transmission System.

Unsubmitted Bid-Offer Pair

Has the meaning given to that term in Section T3.4B.2.

Utilisation Price

£/MWh

The amount sent by the NETSO as a utilisation payment in respect of a STOR Action which:

(i) in relation to a BM STOR Action shall be the Offer Price; and

(ii) in relation to a Non-BM STOR Action shall be the Balancing Services Adjustment Cost.

Value of Lost Load

VoLL

£/MWh

Has the meaning given to it in Section T1.12.1.

Working Day Credit Assessment Load Factor

WDCALFi

Is defined in Annex X-1.

The factor is used to establish the BM Unit Credit Assessment Export Capability and BM Unit Credit Assessment Import Capability for BM Unit i on a CALF Working Day determined for the purposes of Credit Assessment Load Factor.

Zonal Transmission System Demand

The forecast quantity of Transmission System Demand in a BMRS Zone.

Table X-3 –

Glossary of Acronyms Applying Except In Relation To Section S

This table provides a list of the acronyms defined in Table X-2, presented in alphabetical order of the acronym name.

Acronym

Units

Corresponding Defined Term or Expression

AEIp

MWh

Actual Energy Indebtedness

BEDPj

£/MWh

Balancing Energy Deviation Price

BMCAECi

MW

BM Unit Credit Assessment Export Capability

BMCAICi

MW

BM Unit Credit Assessment Import Capability

BMUADDVij

MWh

BM Unit Allocated Demand Disconnection Volume

BMUADVij

MWh

BM Unit Allocated Demand Volume

BOLRnij(t)

MW

Bid-Offer Lower Range

BOURnij(t)

MW

Bid-Offer Upper Range

BPAj

£/MWh

Buy Price Price Adjustment

BSAPmj

£/MWh

Balancing Services Adjustment Price

CADki

Minutes

Continuous Acceptance Duration

CADL

Minutes

Continuous Acceptance Duration Limit

CAEIaj

£

Account Energy Imbalance Cashflow

CAEIp

£

Daily Party Energy Imbalance Cashflow

CALFi

Credit Assessment Load Factor

CAP

£/MWh

Credit Assessment Price

CAQCEiaj

MWh

Credit Assessment Credited Energy Volume

CBMij

£

Period BM Unit Cashflow

CBMp

£

Daily Party BM Unit Cashflow

CBMUDij

MWh

BM Unit Chargeable Demand

CBnij

£

Period BM Unit Bid Cashflow

CCECp

£

Credit Cover Error Compensation

CCp

£

Credit Cover

CCPpj

%

Credit Cover Percentage

CCRiJ

Quarter Hour RR Cashflow

CDBij

£

Replacement Reserve Period Instructed Bid Deviation Cashflow

CDOij

£/MWh

Replacement Reserve Period Instructed Offer Deviation Cashflow

CDRij

£

Replacement Reserve Period Instruction Deviation Cashflow

CDRp

£

Daily Party RR Instruction Deviation Cashflow

CEIpj

MWh

Credit Assessment Energy Indebtedness

CGCAEIaj

£

Claim Group non-corrected Account Energy Imbalance Cashflow

CIIij

£

Information Imbalance Charge

CIIp

£

Daily Party Information Imbalance Charge

CNDBnij

£

Non-Delivered Bid Charge

CNDij

£

BM Unit Period Non-Delivery Charge

CNDOnij

£

Non-Delivered Offer Charge

CNDp

£

Daily Party Non-Delivery Charge

COnij

£

Period BM Unit Offer Cashflow

CORCiNj

MWh

Corrected Component

CORABSVDCi2Nj

Corrected MSID ABSVD Component

CRRij

£

Period RR BM Unit Cashflow

CRRp

£

Daily Party RR Cashflow

CSO

£

Daily System Operator BM Cashflow

CSOj

£

System Operator BM Cashflow

DMAT

MWh

De Minimis Acceptance Threshold

DSPBJij

MWh

Period Deemed Standard Product Bid Volume

DSPOJij

MWh

Period Deemed Standard Product Offer Volume

ECApj

£

Credit Cover Error Interest Amount

ECBpj

£

Credit Cover Error Imbalance Amount

ECCp

MWh

Energy Credit Cover

ECQzabj

MWh

Energy Contract Volume

EEIpj

MWh

Erroneous Energy Indebtedness

EIpj

MWh

Energy Indebtedness

f

Point Value Identification Number

fFPNijt

MW

Point FPN

FLAGpj

Credit Cover Error Erroneous Rejection Flag

FPNij

MWh

Period FPN

FPNij(t)

MW

FPN

fqBOnijt

MW

Point Bid-Offer Volume

FSGpm

General Funding Share

FSMpm

Main Funding Share

FSPSpm

SVA (Production) Funding Share

i

BM Unit Identification Number

IBDij

MWh

Replacement Reserve Instructed Bid Deviation Volume

ICBnij

£

Indicative Period Balancing Mechanism Bid Cashflow

ICOnij

£

Indicative Period Balancing Mechanism Offer Cashflow

IECCp

MWh

Initial Energy Credit Cover

IIPj

£/MWh

Information Imbalance Price

IMBALNGC

MW

Indicated Imbalance

IMVj

MWh

Interconnector Metered Volume

INDDEM

MW

Indicated Demand

INDGEN

MW

Indicated Generation

INDO

MW

Initial National Demand Out-Turn

INIVj

MWh

Indicative Net Imbalance Volume

IODij

MWh

Replacement Reserve Instructed Offer Deviation Volume

IQABnij

MWh

Indicative Period BM Unit Total Accepted Bid Volume

IQAOnij

MWh

Indicative Period BM Unit Total Accepted Offer Volume

ISBPj

£/MWh

Indicative System Buy Price

ISSPj

£/MWh

Indicative System Sell Price

ITSDO

MW

Initial Transmission System Demand Out-Turn

j

Settlement Period

k

Bid-Offer Acceptance Number

LLFC

Line Loss Factor Class

LoLPj

Final Loss of Load Probability

m

Balancing Services Adjustment Action

MAQCEiaj

MWh

Metered Credit Assessment Credited Energy Volume

MDCm

£

Monthly Default Costs

MEIpj

MWh

Metered Energy Indebtedness

MELNGC

MW

Indicated Constraint Boundary Margin

MNMCm

£

Monthly Net Main Costs

MPDV

MWh

MSID Pair Delivered Volume

MPj

Market Price

MPSCm

£

Monthly Production-Charging SVA Costs

n

Bid-Offer Pair Number

NCBMUDij

MWh

Period BM Unit Non Chargeable Demand

NDPBnij

£/MWh

Non-Delivered Bid Price

NDPOnij

£/MWh

Non-Delivered Offer Price

NIVj

MWh

Net Imbalance Volume

NTEBVAj

MWh

NIV Tagged EBVA

NTESVAj

MWh

NIV Tagged ESVA

NUEBVAj

MWh

NIV Untagged EBVA

NUESVAj

MWh

NIV Untagged ESVA

NWDCALFi

Non-Working Day Credit Assessment Load Factor

OCNMFD

MW

Generating Plant Demand Margin (daily value)

OCNMFW

MW

Generating Plant Demand Margin (weekly value)

PAR

MWh

Price Average Reference Volume

PBnij

£/MWh

Bid Price

POnij

£/MWh

Offer Price

PXPsj

£/MWh

Market Index Price

QABCaj

MWh

Account Bilateral Contract Volume

QABknij

MWh

Period Accepted Bid Volume

qABknij(t)

MW

Accepted Bid Volume

QABnij

MWh

Period BM Unit Total Accepted Bid Volume

qABOknij(t)

MW

Accepted Bid-Offer Volume

QABSaj

MWh

Account Period Balancing Services Volume

QACEaj

MWh

Account Credited Energy Volume

QAEIaj

MWh

Account Energy Imbalance Volume

qAkij(t)

MW

Acceptance Volume

qAkit

MW

Point Acceptance Volume

QAOknij

MWh

Period Accepted Offer Volume

qAOknij(t)

MW

Accepted Offer Volume

QAOnij

MWh

Period BM Unit Total Accepted Offer Volume

QASij

MWh

BM Unit Applicable Balancing Services Volume Data or BM Unit ABSVD

QBDCcj

MWh

Balancing Demand Control Volume

qBOnij(t)

MW

Bid-Offer Volume

QBSABmj

MWh

Balancing Services Adjustment Buy Volume

QBSAmj

MWh

Balancing Services Adjustment Volume

QBSASmj

MWh

Balancing Services Adjustment Sell Volume

QBSDij

MWh

Period Supplier BM Unit Delivered Volume

QBSij

MWh

Period BM Unit Balancing Services Volume

QCEiaj

MWh

Credited Energy Volume

QDDij

MWh

Period BM Unit Demand Disconnection Volume

qDSPBJij(t)

MW

Deemed Standard Product Bid Volume

qDSPJij(t)

MW

Deemed Standard Product Shape

qDSPJijt

MW

Deemed Standard Product Point Variables

qDSPOJij(t)

MW

Deemed Standard Product Offer Volume

qDSPVJij(t)

MW

Deemed Standard Product Volume

QNGSIAij

MWh

Network Gas Supply Imbalance Adjustment Volume

QIIij

MWh

Period Information Imbalance Volume

QMEij

MWh

Period Expected Metered Volume

QMFRiaj

MWh

Metered Volume Fixed Reallocation

QMFRziaj

MWh

Metered Volume Reallocation Fixed Data

QMij

MWh

BM Unit Metered Volume

QMPRiaj

%

Metered Volume Percentage Reallocation

QMPRziaj

%

Metered Volume Reallocation Percentage Data

QNDBij

MWh

Period BM Unit Non-Delivered Bid Volume

QNDBnij

MWh

Bid Non-Delivery Volume

QNDOij

MWh

Period BM Unit Non-Delivered Offer Volume

QNDOnij

MWh

Offer Non-Delivery Volume

QSBwj

System Buy Action

QSDCcj

MWh

System Demand Control Volume

QSDij or QSDi2j

MWh

Period Secondary BM Unit Delivered Volume

QSDiji2

MWh

Period Secondary BM Unit Supplier Delivered Volume

QSIVtj

MWh

STOR Instructed Volume

QSNDij

MWh

Period Secondary BM Unit Non-Delivered Volume

QSSwj

System Sell Action

QTUErj

MWh

Trading Unit Export Volume

QTUIrj

MWh

Trading Unit Import Volume

QVBMDi2NKij

MWh

Secondary BM Unit Delivered Volume

QXPsj

MWh

Market Index Volume

RBPj

£/MWh

Replacement Buy Price

RCRCaj

£

Residual Cashflow Reallocation Cashflow

RCRCp

£

Daily Party Residual Settlement Cashflow

RCRPaj

No Units

Residual Cashflow Reallocation Proportion

REJaj

MWh

Credit Cover Error Rejection Volume

RPAR

Replacement Price Average Reference Volume

RPj

£/MWh

Replacement Price

RQNDBuij

MWh

Remaining Period BM Unit Non-Delivered Bid Volume

RQNDOuij

MWh

Remaining Period BM Unit Non-Delivered Offer Volume

RRABknij

MWh

Period RR Accepted Bid Volume

RRABnij

MWh

Period RR Total Accepted Bid Volume

RRAOknij

MWh

Period RR Accepted Offer Volume

RRAOnij

MWh

Period RR Total Accepted Offer Volume

RRAPJ

£/MWh

Replacement Reserve Activation Price

RRAUSBj

Replacement Reserve Aggregated Unpriced System Buy Action

RRAUSSj

Replacement Reserve Aggregated Unpriced System Sell Action

RRAViJ

MWh

Quarter Hour RR Activated Volume

RSPj

£/MWh

Replacement Sell Price

RSVPj

£/MWh

Reserve Scarcity Price

SAPwj

System Action Price

SBPj

£/MWh

System Buy Price

SNBABSVDij

MWh

Supplier BM Unit Non BM ABSVD

SPAj

£/MWh

Sell Price Price Adjustment

SPBMEIaij

MWh

Settlement Period BM Unit Energy Indebtedness

SPD

h

Settlement Period Duration

SPiji2

MWh

Period Secondary BM Unit Delivered Proportion

SPLD

MW

Surplus (daily value)

SPLW

MW

Surplus (weekly value)

SSPj

£/MWh

System Sell Price

SSTPGPL

Small Scale Third Party Generating Plant Limit

STAPtj

£/MWh

STOR Action Price

TCBMj

£

Total System BM Cashflow

TCBMUDij

MWh

TLM-adjusted BM Unit Chargeable Demand

TCEIj

£

Total System Energy Imbalance Cashflow

TCIIj

£

Total System Information Imbalance Charge

TCNDj

£

Total System Non-Delivery Charge

TCRRj

£

Total System RR Cashflow

TDSPBij

MWh

Total Period Deemed Standard Product Bid Volume

TDSPOij

MWh

Total Period Deemed Standard Product Offer Volume

TNGSBi

£

Network Gas Supply Total Bid Payment

Tkit

Spot time

Bid-Offer Acceptance Time

TLFAS

Transmission Loss Factor Adjustment

TLFij

Transmission Loss Factor

TLMij

No Units

Transmission Loss Multiplier

TLMO+j

Delivering Transmission Losses Adjustment.

TLMO-j

Offtaking Transmission Losses Adjustment

TQASj

MWh

Total Period Applicable Balancing Services Volume

TQEIj

MWh

Total System Energy Imbalance Volume

TRCj

£

Total System Residual Cashflow

TSCpm

£

Total Specified BSC Charges

u

Non-Delivery Order Number

VBMUSDVi2ij

MWh

Secondary BM Unit Supplier Delivered Volume

VoLL

£/MWh

Value of Lost Load

w

System Action

WDCALFi

Working Day Credit Assessment Load Factor

Table X–4 –

Use of Subscripts and Superscripts Applying to Section S

The following subscripts used in the formulae and other algebraic expressions contained in the Code shall bear the following respective meanings for Section S of the Code:

a

refers to a Data Aggregator or, as the context may require in paragraph 3.5 of Annex S-2, to a Data Aggregator appointed by a Primary Supplier against a Primary SVA Metering System Number and a Data Aggregator appointed by an associated Secondary Supplier against a Secondary SVA Metering System Number;

a1

refers to a Data Aggregator appointed by a Primary Supplier against a Primary SVA Metering System Number K1;

a1.1

refers to a Data Aggregator appointed by a Primary Supplier against a Primary SVA Metering System Number K1.1;

an

refers to a Data Aggregator appointed by a Secondary Supplier against a Secondary SVA Metering System Number Kn;

an.1

refers to a Data Aggregator appointed by a Secondary Supplier against a Secondary SVA Metering System Number Kn.1;

(aa)

refers to an Analysis Class;

(ai)

refers to an Adjusted Interval;

j

refers to a Settlement Period;

i

refers to a BM Unit;

i2

refers to a Secondary BM Unit (where applicable);

(nn)

refers to an individual value of the Regression Coefficient (RC) or of the Matrix of Regression Coefficients (MRC), according to the context;

(vv)

refers to a Consumption Component Class (not for line losses) associated with Consumption Component Class N;

(vvn)

refers to a Consumption Component Class (not for line losses) associated with Consumption Component Class N for which the data aggregation type is ‘N’;

q

refers to a calendar quarter;

d(q)

refers to the number of days in a calendar quarter;

C

refers to a Standard Settlement Configuration;

G

refers to a Supplier Volume Reporting Group;

H

refers to a GSP Group;

J

refers to a Settlement Register;

K

Refers to a Metering System associated with an SVA Non-Final Demand Facility; and refers to an SVA Metering System Number and/or Asset Metering System associated with the provision of a Balancing Service;

K1

refers to a Primary SVA Metering System Number;

K1.1

refers to the "virtual" Primary SVA Metering System Number where Section K2.5.4(c)(ii) applies to the Primary Supplier;

Kn

refers to a Secondary SVA Metering System Number;

Kn.1

refers to the "virtual" Secondary SVA Metering System Number where Section K2.5.4(c)(ii) applies to the Secondary Supplier;

L

refers to a Line Loss Factor Class;

N

refers to a Consumption Component Class;

N(c)

refers to a non half hourly active import Consumption Component Class;

P

refers to a Profile Class;

Q

refers to a Profile;

R

refers to a valid combination of Time Pattern Regime and Standard Settlement Configuration;

T

refers to a Settlement Day;

X

refers to a Time Pattern Regime;

Y

refers to a calendar year;

Z

refers to a Supplier or, as the context may require in paragraph 3.5 of Annex S-2, to the Suppliers acting in the capacity of Primary Supplier and associated Secondary Supplier(s) in respect of a particular Shared SVA Metering System;

Z1

refers to a Supplier acting in the capacity of Primary Supplier in respect of a Shared SVA Metering System; and

Zn

refers to a Supplier acting in the capacity of Secondary Supplier in respect of a Shared SVA Metering System.

Table X–5 –

Use of Summations Applying to Section S

The following summations, used in the formulae and other algebraic expressions in Section S, shall bear the following respective meanings:

Σa

=

summed over all Data Aggregators (a);

Σ(ai)

=

summed over all Adjusted Intervals ((ai)) associated with the spot time in question for all Time Pattern Regimes associated with a particular Standard Settlement Configuration;

Σj

=

summed over all Settlement Periods;

ΣN

=

summed over all Consumption Component Classes (N) where, in such summation, values associated with Consumption Component Classes associated with Third Party Generating Plant comprised in SVA Metering Systems shall be subtracted and values associated with all other Consumption Component Classes shall be added, except in the case of ΣN(AA) and ΣN(EAC) for the purposes of Annex S-1 paragraph 2;

ΣN(n)

=

summed over all those Consumption Component Classes (N) for which the data aggregation type is ‘N’ and where, in such summation, values associated with Consumption Component Classes associated with Third Party Generating Plant comprised in SVA Metering Systems shall be subtracted and values associated with all other Consumption Component Classes shall be added;

ΣT

=

summed over all Settlement Days (T) in a particular Meter Advance Period;

ΣZ

=

summed over all Suppliers (Z);

ΣKJ

=

summed over all Settlement Registers (J) in a particular SVA Metering System (K);

ΣKNonDiff

=

summed over all Asset Metering Systems “K” allocated to a BM Unit in accordance with paragraph S10.1A.2(e)(i)

ΣKDiff

=

summed over all Asset Metering Systems “K” allocated to a BM Unit in accordance with paragraph S10.1A.2(e)(ii)

ΣNLK

=

summed over all SVA Metering Systems (K) within a particular Line Loss Factor Class (L) and Consumption Component Class (not for line losses) (N);

Σ(vv)LK

=

summed over all SVA Metering Systems (K) within a Line Loss Factor Class (L) and Consumption Component Class (for line losses) associated with a particular Consumption Component Class (not for line losses) ((vv));

Σ(vv)LK

=

summed over all Line Loss Factor Classes (L) and Metering Systems K within a Consumption Component Class (for losses) associated with a particular Consumption Component Class (not for losses) ((vv));

ΣNLPR

=

summed over all kWh readings within a Settlement Class (LPR) itself within a particular Consumption Component Class (N);

ΣN(n)LPR

=

summed over all kWh readings within a Settlement Class (LPR) itself within a particular Consumption Component Class (N) for which the data aggregation type is ‘N’;

Σ(vv)L

=

summed over all Line Loss Factor Classes (L) within a Consumption Component Class (for losses) associated with a particular Consumption Component Class (not for losses) ((vv));

Σ(vvn)L

=

summed over all Line Loss Factor Classes (L) within a Consumption Component Class (for losses) associated with a particular Consumption Component Class (not for line losses) for which the data aggregation type is ‘N’ ((vvn));

Σ(vv)PR

=

summed over all Profile Classes (P) and Time Pattern Regimes within Standard Settlement Configuration (R) within a Consumption Component Class (for losses) associated with a particular Consumption Component Class (not for losses) ((vv));

Σ(vvn)PR

=

summed over all Profile Classes (P) and Time Pattern Regimes within Standard Settlement Configuration (R) within a Consumption Component Class (for losses) associated with a particular Consumption Component Class (not for line losses) for which the data aggregation type is ‘N’ ((vvn));

ΣHZLPRK

=

summed over all non half hourly SVA Metering Systems (K) by Settlement Class (HLPR) for a particular Supplier (Z); and

ΣHZ

=

summed over all Suppliers (Z) active within a particular GSP Group (H).

ΣON

=

summed over all Settlement Periods in a Settlement Day for which the Modified Switched Load State Indicator (SQNEWCj) has been determined as equal to one by the Supplier Volume Allocation Agent;

ΣOFF

=

summed over all Settlement Periods in a Settlement Day for which the Modified Switched Load State Indicator (SQNEWCj) has been determined as equal to zero by the Supplier Volume Allocation Agent;

ΣN(AA)

=

summed over all Consumption Component Classes N that are associated with Annualised Advances;

ΣN(EAC)

=

summed over all Consumption Component Classes N that are associated with Estimated Annual Consumptions;

Σmd

=

summed over all Settlement Days in a month

ΣN(HHA)

=

summed over all Consumption Component Classes that are associated with actual values and with half hourly data aggregation in relation to Metering Systems which are 100kW Metering Systems save those which are associated with SVA Generation and SVA Generation line losses;

ΣN(HHE)

=

summed over all Consumption Component Classes that are associated with estimated values and with half hourly data aggregation in relation to Metering Systems which are 100kW Metering Systems save those which are associated with SVA Generation and SVA Generation line losses.

ΣHi

=

summed over all Supplier BM Units (i) associated with a particular GSP Group (H);

ΣHZi

=

summed over all Supplier BM Units (i) associated with a particular GSP Group (H) and Supplier (Z);

ΣHPRZL

=

summed over all Suppliers (Z) and Line Loss Factor Classes (L) for Standard Settlement Configuration and Time Pattern Regime combination (R) in Profile Class (P) within GSP Group (H);

ΣHPRT

=

summed over all Settlement Days (T) contained within the Calculation Period for which one or more values of TAAHZLPR was determined for Standard Settlement Configuration and Time Pattern Regime combination (R) in Profile Class (P) within GSP Group (H);

ΣHPCR

=

summed over all Standard Settlement Configuration and Time Pattern Regime combinations (R) valid for Standard Configuration (C) and Profile Class (P) within GSP Group (H);

ΣHPCTR

=

summed over all Standard Settlement Configuration and Time Pattern Regime combinations (R) valid for Standard Settlement Configuration (C) in Profile Class (P) within GSP Group (H) for Settlement Day (T);

ΣHPCZL

=

summed over all Suppliers (Z) and Line Loss Factor Classes (L) for any one valid combination of Standard Settlement Configuration and Time Pattern Regime for Standard Settlement Configuration (C) in Profile Class (P) within GSP Group (H);

ΣHPTC

=

summed over all Standard Settlement Configurations (C) for Profile Class (P) within GSP Group (H) for Settlement Day (T);

ΣHPT

=

summed over all Settlement Days (T) for Profile Class (P) within GSP Group (H).

ΣN(AI)

=

summed over all Consumption Component Classes N that are associated with active import.

ΣZqG

=

summed by Supplier (Z) over a calendar quarter (q) by Supplier Volume Reporting Group (G);

Table X–6 –

Definitions Applying To Section S

Unless otherwise expressly stated the expressions below bear the following meanings in Section S.

The definition of Non Half Hourly Supplier Deemed Take (NHHSDTHZj) also applies to Annex D-1. The definition of Measurement Class also applies to Section V and Section W.

Expression

Acronym

Units

Definition

K1HPC and K2HPC

Numbers

Baseload Profile Consumption during the ‘on’ and ‘off’ periods respectively of switched load Time Pattern Regimes for a valid Standard Settlement Configuration associated with switched load, determined pursuant to paragraph 6.6 of Annex S-2.

SIX_PM

Minutes

The time duration from the start of the Settlement Day to 1800 hours Greenwich Mean Time on that Settlement Day, determined pursuant to paragraph 6.5 of Annex S-2.

ABSVD BM Unit Delivered Volume

AQVMDNLKji

MWh

The quantity determined in accordance with paragraph 7.1.1E of Annex S-2.

Adjusted Interval

A period of time associated with a particular Time Pattern Regime based on a time period for which the associated Settlement Registers record Metered Data and determined pursuant to paragraph 6.4 of Annex S-2.

Adjusted Interval End Time

A time associated with a particular Time Pattern Regime and Standard Settlement Configuration determined pursuant to paragraph 6.4 of Annex S-2.

Adjusted Interval Start Time

A time associated with a particular Time Pattern Regime and Standard Settlement Configuration determined pursuant to paragraph 6.4 of Annex S-2.

Allocated BM Unit’s Demand Disconnection Volume

ABDDiaNLKj

kWh

The half hour Demand Disconnection volume of a Metering System determined pursuant to paragraph 3.8 of Annex S-2.

Allocated BM Unit’s Metering System Metered Consumption

ABMMMCiaNLKj

kWh

The half hour metered Consumption of a Metering System determined pursuant to paragraph 3.6 of Annex S-2.

Allocated Metering System Metered Consumption

AVMMCHZaNLKji

MWh

The quantity determined in accordance with paragraph 3.9.2 of Annex S-2.

The Allocated Metering System Metered Consumption is the Half Hourly metered volume per Settlement Period of SVA Metering Systems

Allocated Asset Metering System Metered Consumption

AAVMMCHNLKj

kWh

The quantity determined in accordance with paragraph 3.9.2A of Annex S-2.

The Allocated Asset Metering System Metered Consumption is the Half Hourly metered volume per Settlement Period of Asset Metering Systems

AMSID Declaration Boundary Point Export”

ADBPEDi

kWh

The quantity determined in accordance with paragraph 3.11.2 of Annex S-2.

The AMSID Declaration Boundary Point Export” is the total metered Line Loss Adjusted Export for an EMR AMSID Declaration.

AMSID Declaration Boundary Point Import”

ADBPIDj

kWh

The quantity determined in accordance with paragraph 3.11.2 of Annex S-2.

The AMSID Declaration Boundary Point Import” is the total metered Line Loss Adjusted Import for an EMR AMSID Declaration.

AMSID Declaration Generation Export”

ADGEDj

kWh

The quantity determined in accordance with paragraph 3.11.2 of Annex S-2.

The AMSID Declaration Generation Export” is the total metered Line Loss Adjusted Export from a Generator or Storage Facility for an EMR AMSID Declaration.

AMSID Declaration Generation Import”

ADGIDj

kWh

The quantity determined in accordance with paragraph 3.11.2 of Annex S-2.

The AMSID Declaration Generation Import” is the total metered Line Loss Adjusted Import to a Generator or Storage Facility for an EMR AMSID Declaration.

AMSID Declaration Non‑Chargeable Proportion”

ADNCPDj

kWh

The quantity determined in accordance with paragraph 3.11.2 of Annex S-2.

The AMSID Declaration Non‑Chargeable Proportion is a number between 0.0 and 1.0 inclusive representing the proportion of Boundary Point Imports to the Import MSIDs included in the Declaration that are deemed Non-Chargeable in that Settlement Period

Asset Metering System Metered Consumption

AMMC Kj

kWh

The half hourly metered Consumption for a SVA Metering System, determined pursuant to paragraph 3.5 of Annex S-2.

Asset Metering System Metered Consumption

VMMC HNLKj

MWhkWh

The Metering System Metered Consumption for an Asset Metering System, determined pursuant to paragraph 7.1.1C of Annex S-2.

Allocated Supplier’s Demand Disconnection Volume

ASDDHZaNLKj

kWh

The half hour Demand Disconnection volume of a SVA Metering System determined pursuant to paragraph 3.7 of Annex S-2.

Allocated Supplier’s Metering System Metered Consumption

ASMMCHZaNLKj

kWh

The half hour metered Consumption of a SVA Metering System determined pursuant to paragraph 3.5 of Annex S-2.

AMSID Pair Data

The data comprising the data items pursuant to Section S10.1A

AMSID Pair Delivered Volume

AMPDVj

MWh

AMSID Pair Delivered Volume is such volumes of Active Energy notified by the Virtual Lead Party in relation to an AMSID Pair and each Associated MSID Pair for the purposes of aggregating Secondary BM Unit Supplier Delivered Volume (VBMUSDViZj)

Alternative Average Fraction of Yearly Consumption

AAFYCHPC

A value set from time to time by the Panel for one or more multi‑register Standard Settlement Configurations, and used in place of the corresponding Average Fraction of Yearly Consumption value for the purpose of calculating profile coefficients pursuant to paragraph 5.1 of Annex S-2.

Analysis Class

A combination of Season Type and Day Type.

Annual Fraction of Yearly Consumption Adjustment

AFYCAHPC

The difference due to rounding between unity and the sum of the Unadjusted Average Fraction of Yearly Consumption Values for a Standard Settlement Configuration and Profile Class within a GSP Group, determined pursuant to paragraph 5.1 of Annex S-2.

Annualised Advance

AAKR

kWh

An estimation of the Meter Advance on a Settlement Register over a period of a year determined pursuant to paragraph 4.3 of Annex S-2.

Annualised Advance Adjustment Factor

AAAFKR

Number

A factor used in the determination of Estimated Annual Consumption and determined pursuant to paragraph 4.3 of Annex S-2.

Asset Meter Register Consumption

AMRCKJj

kWh

The half hourly metered Consumption for a Settlement Register within an Asset Metering System.

Average Fraction Of Yearly Consumption

AFYCHPR

An estimate of the fraction of the total Consumption of a multi-register Standard Settlement Configuration attributable to each Settlement Register of that Standard Settlement Configuration pursuant to paragraph 4.4 of Annex S-2.

Base Fraction

BFHPC

Number

The deemed proportion of Consumption for a Switched Load Metering System which is baseload determined pursuant to paragraph 6.6 of Annex S-2.

Baseload Profile

The half-hourly profile of all non-switched loads in the Profile Class population, including non-switched loads taken during the periods when the switched load registers are recording Consumption and referred to in paragraph 6.6 of Annex S-2.

Baseload Profile Coefficient

BAPHQj

Number

One of the Basic Period Profile Coefficients which correspond to the Baseload Profile associated with a Switched Load Metering System, determined pursuant to paragraph 6.6 of Annex S-2.

Basic Period Profile Coefficient

PHQj

Number

A number determined pursuant to paragraph 6.5 of Annex S-2 and representing the fraction of annual Consumption in a given Settlement Period for a particular profile.

BM Unit Allocated Demand Disconnection Volume

BMUADDVij

MWh

The disconnection volume per Settlement Period for a Supplier BM Unit determined pursuant to paragraph 9.6.1A of Annex S-2.

BM Unit Allocated Demand Volume

BMUADVij

MWh

The energy volume per Settlement Period for a Supplier BM Unit determined pursuant to paragraph 9.6.1 of Annex S-2.

BM Unit Disconnection Matrix

BMDMiaLPR

A matrix of data as determined pursuant to paragraph 8.2 of Annex S-2.

BM Unit Purchase Matrix

BMPMiaLPR

A matrix of data as determined pursuant to paragraph 8.1 of Annex S-2.

BM Unit’s Demand Disconnection Volume

BMDDiaNj

MWh

The half hourly Demand Disconnection volume, determined by a Half Hourly Data Aggregator pursuant to paragraph 3.8 of Annex S-2, or by the SVAA pursuant to paragraph 7.1 of Annex S-2.

BM Unit’s Demand Disconnection Volume (Losses)

BMDDLiaNj

MWh

The line losses determined by a Half Hourly Data Aggregator as resulting from the BM Unit’s Demand Disconnection Volume pursuant to paragraph 3.8 of Annex S-2, or by the SVAA pursuant to paragraph 7.2 of Annex S-2.

BM Unit’s Metered Consumption

BMMCiaNLj

MWh

The half hourly metered Consumption, determined by a Half Hourly Data Aggregator pursuant to paragraph 3.6 of Annex S-2, or by the SVAA pursuant to paragraph 7.1 of Annex S-2.

BM Unit’s Metered Consumption (Losses)

BMMCLiaNLj

MWh

The line losses determined by a Half Hourly Data Aggregator as resulting from the BM Unit’s Metered Consumption pursuant to paragraph 3.6 of Annex S-2, or by the SVAA pursuant to paragraph 7.2 of Annex S-2.

BM Unit’s Profiled Consumption

BMPCiLPRj

MWh

A Supplier BM Unit’s non half hourly Consumption profiled per Settlement Period for a particular Consumption Component Class, determined pursuant to paragraph 8.1 of Annex S-2.

BM Unit’s Profiled Disconnection

BMPDiLPRj

MWh

A Supplier BM Unit’s non half hourly Demand Disconnection volume profiled per Settlement Period for a particular Consumption Component Class, determined pursuant to paragraph 8.2 of Annex S-2.

Calculation Period

The period of consecutive Settlement Days (typically but not necessarily one year in duration) on whose Supplier Purchase Matrix data the calculation of Average Fractions of Yearly Consumption pursuant to paragraph 5.1 of Annex S-2 is based.

Certificate of Supply

For the purposes of Annex S-2 the Estimated Annual Consumption for a Non Qualifying Unmetered Supply as provided from time to time by Public Distribution Service Operator.

Clock Interval

A combination of seasons, dates, days and times defining the period over which Consumption is recorded by a Settlement Register the details of which are provided pursuant to paragraph 5.1.1 of Annex S-2.

Consumption

MWh

The amount of electricity produced by a SVA Generator or used by an SVA Customer.

Consumption Component Class

A classification of half hourly Consumption and/or electricity produced or used by an Asset which comprises one element from each of the following categories as shown in Table X-8:

  • metered or unmetered;

  • consumption or SVA generation;

  • SVA Metering System with or without Metering System specific line losses (but a SVA Metering System without Metering System specific line losses can only be combined with unmetered Consumption);

  • Consumption without line losses or line losses;

  • based on actual or estimated half hourly; or

  • based on Annualised Advance or Estimated Annual Consumption.

Consumption Data

That part of the Supplier Purchase Matrix containing the values of Total Annualised Advance, Total Metered Estimated Annual Consumption and Total Unmetered Consumption.

Co-ordinated Universal Time

UTC

Number

Bears the same meaning as in the document Standard Frequency and Time Signal Emission, International Telecommunication Union - RTF.460(ISBN92-61-05311-4) (colloquially referred to as Rugby Time).

Corrected Component

CORCiNj

MWh

The Consumption for a Supplier BM Unit's Consumption Component Class after the application of the GSP Group Correction Factor, determined pursuant paragraph 9.3 of Annex S-2.

Corrected Component by Profile Class

CORCiN(c)Pj

MWh

The consumption for a Supplier BM Unit's Profile Class after the application of the GSP Group Correction Factor and Line Loss Factor, determined pursuant paragraph 9A.1.3 of Annex S-2.

Corrected Disconnection Component

CORDCiNj

MWh

The Demand Disconnection volume for a Supplier BM Unit's Consumption Component Class after the application of the GSP Group Correction Factor, determined pursuant to paragraph 9.3 of Annex S-2.

Corrected MSID ABSVD Component

CORABSVDCi2Nj

MWh

The quantity determined in accordance with paragraph 9.3.5 of Annex S-2.

Customer Consent Flag

A flag in the SVA Metering System Register indicating that, in relation to a Supplier, an SVA Customer or SVA Generator has consented to their Metering System Delivered Volumes being provided to that Supplier in accordance with paragraphs 7.1.8 and 7.2.8 of Annex S-2.

Daily Profile Coefficient

DPCHPRT

Number

A value which, when applied to an Estimated Annual Consumption or Annualised Advance value, supplies an estimate of Consumption for a Settlement Day and which is equal to the sum of the corresponding Period Profile Class Coefficients for that Settlement Day.

Day Type

A code describing whether a particular Settlement Day is a weekday, a Saturday, a Sunday, or a particular Bank Holiday.

Deemed Meter Advance

DMAKR

kWh

An estimated Meter Advance calculated by the relevant Non-Half Hourly Data Collector pursuant to paragraph 4.3 of Annex S-2 and BSCP504.

Deemed Meter Advance Period

A period bearing the same relationship to a Deemed Meter Advance as a Meter Advance Period bears to a Meter Advance.

Default Estimated Annual Consumption For Metered Metering Systems

DEMHZLPR

kWh

The Estimated Annual Consumption value determined by a Non-Half Hourly Data Aggregator pursuant to paragraph 4.4 of Annex S-2.

Default Estimated Annual Consumption For Unmetered Metering Systems

DEUHZLPR

kWh

The value of Estimated Annual Consumption determined for an Unmetered Supply pursuant to paragraph 4.4 of Annex S-2.

Demand Disconnection Daily Profile Coefficient

DDDPCHPKRT

Number

A value which, when applied to an Estimated Annual Consumption or Annualised Advance value, supplies an estimate of Demand Disconnection volume for a Settlement Day and which is equal to the sum of the corresponding Period Profile Class Coefficients for that Settlement Day multiplied by the proportion of each Settlement Period in that Settlement Day for which a given Metering System was subject to Demand Disconnection.

Effective From Settlement Date

The date of the Settlement Day on which an Annualised Advance or an Estimated Annual Consumption becomes effective.

Effective To Settlement Date

The date of the last Settlement Day on which an Annualised Advance is effective.

Estimated Annual Consumption

EACKR

kWh

For each Settlement Register, an estimate of Consumption over a year.

Estimated Regional Average Demand Per Customer

YHQj

kW

An estimate of customer Consumption by profile and GSP Group in respect of each Settlement Period, determined pursuant to paragraph 6.5 of Annex S-2.

Export Consumption Component Class

a Consumption Component Class as shown in Table X-8 as having a measurement quantity ID of Active Export

Fraction Of Yearly Consumption

FYCKR

The fraction of annual Consumption allocated to a Meter Advance Period pursuant to paragraph 4.3 of Annex S-2.

Grid Supply Point Group Measured Temperature

THT

F

A temperature taken at locations and times from time to time agreed by the Panel and provided by the Temperature Provider pursuant to paragraph 5.2.2 of Annex S-2.

Group Average Annual Consumption

GAACHQ

MWh

The average annual Consumption for each GSP Group for each profile as supplied by the Profile Administrator pursuant to paragraph 5.1.4 of Annex S-2.

GSP Group Correction Factor

CFHj

The factor by which the relevant components of GSP Group Consumption are adjusted and which is determined pursuant to paragraph 9.2 of Annex S-2.

GSP Group Correction Scaling Weight

WTN

Number

The weighting for each Consumption Component Class used in GSP Group correction and which is supplied pursuant to paragraph 5.1.5 of Annex S-2.

GSP Group Half Hourly Consumption

GCHNj

MWh

The GSP Group half hourly Consumption by Consumption Component Class determined pursuant to paragraph 9.1 of Annex S-2.

GSP Group Profile Class Average Estimated Annual Consumption

GGPCAEACHPC

kWh

The average Estimated Annual Consumption in respect of a GSP Group, Profile Class and Standard Settlement Configuration determined pursuant to paragraph 5.1 of Annex S-2.

GSP Group Profile Class Default Estimated Annual Consumption

GGPCDEACHP

kWh

The average Estimated Annual Consumption provided in respect of a GSP Group and Profile Class pursuant to paragraph 5.1.3 of Annex S-2.

GSP Group Take

GSPGTHj

MWh

In relation to a GSP Group and a Settlement Period, the number submitted to the SVAA by the CDCA pursuant to Section R5.7.1(b).

Half Hourly Consumption (Losses)

CLOSSiNj

MWh

The half hourly Consumption for a Consumption Component Class which is defined as line losses, determined pursuant to paragraph 7.2 or 8.1 of Annex S-2.

Half Hourly Consumption (Losses) by Profile Class

CLOSSiN(c)Pj

MWh

The half hourly consumption for a Profile Class within a non half hourly active import Consumption Component Class which is defined as being for line losses, determined pursuant to paragraph 9A.1.2 of Annex S-2.

Half Hourly Consumption (Non Losses)

CiNj

MWh

The half hourly Consumption for a Consumption Component Class which is defined as not being line losses, determined pursuant to paragraph 7.1 or 8.1 of Annex S-2.

Half Hourly Consumption (Non Losses) by Profile Class

CiN(c)Pj

MWh

The half hourly consumption for a Profile Class within a non half hourly active import Consumption Component Class which is defined as not being for line losses, determined pursuant to paragraph 9A.1.1 of Annex S-2.

Half Hourly Demand Disconnection Volume

HDDKj

kWh

The quantity established in accordance with S-2 3.7.2.

The Half Hourly Demand Disconnection Volume (HDDKj) is calculated in reference to, for the Demand Control Impact Settlement Period ZaKj: the estimate of the metered data (E); the Supplier’s Metering System Metered Consumption (SMMC); and the estimated Non-BM STOR Instruction Volume anticipated to have been delivered (NBSVD).

Half Hourly Disconnection (Losses)

DLOSSiNj

MWh

The half hourly Demand Disconnection volume for a Consumption Component Class which is defined as line losses, determined pursuant to paragraph 7.2 or 8.2 of Annex S-2.

Half Hourly Disconnection (Non Losses)

DiNj

MWh

The half hourly Demand Disconnection volume for a Consumption Component Class which is defined as not being line losses, determined pursuant to paragraph 7.1 or 8.2 of Annex S-2.

Half Hourly Non-Final Demand Consumption (Losses)

SCLOSSiNj

MWh

In respect of an SVA Non-Final Demand Facility, the half hourly Consumption for a Consumption Component Class which is defined as line losses, determined pursuant to paragraph 13.5.2 of Annex S-2.

Half Hourly Non-Final Demand Consumption (Non Losses)

SCiNj

MWh

In respect of an SVA Non-Final Demand Facility, the half hourly Consumption for a Consumption Component Class which is defined as not being line losses, determined pursuant to paragraph 13.5.1 of Annex S-2.

Historical Daily Profile Coefficient

DPCHPRT

Number

A particular Daily Profile Coefficient in respect of a Settlement Day which Settlement Day occurs prior to the 1998 Operational Date and which is determined employing a method authorised by the Executive Committee.

Import Consumption Component Class

A Consumption Component Class as shown in Table X-8 as having a measurement quantity ID of Active Import

Initial Total Annualised Advance

ITAAHZLPR

KWh

The total of all the Annualised Advances for a Supplier in kWh and in respect of a Profile Class, Line Loss Factor Class, Time Pattern Regime and GSP Group, determined pursuant to paragraph 4.4 of Annex S-2.

Initial Total Annualised Advance (Disconnected)

ITAADHZLPR

kWh

The total of all the Annualised Advances for a Supplier in kWh subject to Demand Disconnection and in respect of a Profile Class, Line Loss Factor Class, Time Pattern Regime and GSP Group, determined pursuant to paragraph 4.5 of Annex S-2.

Line Loss Factor

LLFLj

A multiplier which, when applied to the value of a SVA Metering System’s Consumption, converts such value into its estimated value at the Grid Supply Point, that is including distribution losses.

Line Loss Factor Class

A set of SVA Metering Systems defined by a Distribution System Operator and relating to any one or more of its Distribution System(s) and that are assigned the same Line Loss Factor for the relevant Settlement Period.

Longest Off Period

A period used in determining profile coefficients for Switched Load Metering Systems and determined pursuant to paragraph 6.6 of Annex S-2.

Longest On Period

A period used in determining profile coefficients for Switched Load Metering Systems and determined pursuant to paragraph 6.6 of Annex S-2.

Low Fraction

LOWFHPC

Number

The deemed annual Consumption associated with the switched load Settlement Registers expressed as a fraction of total annual Consumption for a Switched Load Metering System, determined pursuant to paragraph 6.6 of Annex S-2.

Low Fraction Consumption

HHPC

Number

The ratio of electricity Consumption deemed as baseload Consumption during the ‘on’ periods of switched load Time Pattern Regimes to that during the ‘off’ periods of switched load Time Pattern Regimes, determined pursuant to paragraph 6.6 of Annex S-2.

Low Register Profile Coefficient

LRPCHPCj

Number

The deemed fraction of annual Consumption for a Switched Load Metering System in a Settlement Period recorded on those meter registers which are 'on' during times when there is switched load Consumption at such Metering System, determined pursuant to paragraph 6.6 of Annex S-2.

Matrix Of Regression Coefficients

MRCQ(aa)(nn)j

Various

The matrix of regression coefficients from time to time supplied by the Profile Administrator pursuant to paragraph 5.1.4 of Annex S-2.

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 with current transformer (equivalent to Measurement Class “E”)

Half Hourly Metering Equipment at below 100kW Premises with current transformer or whole current, and at Domestic Premises (equivalent to Measurement Class “F”)

Half Hourly Metering Equipment at below 100kW Premises with whole current and not at Domestic Premises (equivalent to Measurement Class “G”).

Measurement Quantity

An indicator to show whether Metered Data in respect of a Metering System is export or import active energy.

Meter Advance

MADVKR

kWh

The difference recorded for a Settlement Register between one reading, or as the case may be, deemed reading of this register and the next reading or, as the case may be, deemed reading of this register (that is over the Meter Advance Period) used in the determination of Annualised Advance pursuant to paragraph 4.3 of Annex S-2. In the case where such next reading is deemed, the Meter Advance may also be known more particularly as a Deemed Meter Advance in which case it shall have an associated Deemed Meter Advance Period.

Meter Advance Period

MAP

The period of complete Settlement Days between successive meter readings for a Settlement Register, which shall be the period from and including the Settlement Day on which a meter reading is taken up to and including the Settlement Day prior to the Settlement Day on which the next meter reading is taken.

Metered Data

Data concerning the quantities of Active Energy exported or imported measured, collected, recorded and otherwise determined pursuant to the Code.

Metering System Delivered Volumes

QVMDKj

MWh

The quantity determined in accordance with paragraph 3.10.4A of Annex S-2.

Metering System Metered Consumption

VMMCHZaNKji

MWh

The quantity determined in accordance with paragraph 7.1.1B of Annex S-2.

Metering System Non-Chargeable Consumption”

NCMCiNLKj

KWh

The quantity determined in accordance with paragraph 3.11.1 of Annex S-2.

Metering System Non-Chargeable Losses” for an EMR MSID Declaration

NCMLiNLKj

KWh

The quantity determined in accordance with paragraph 3.11.1 of Annex S-2.

Metering System Period Disconnection Duration

MKj

Hours

The duration in hours in a given Settlement Period for which a given Metering System was subject to Demand Disconnection.

Modified Switched Load State Indicator

SQNEWCj

Indicator (1 or 0)

A Switched Load State Indicator modified pursuant to paragraph 6.6 of Annex S-2.

MonT, WedT, ThuT and FriT

Indicators (1 or 0)

A set of indicators whose values are determined pursuant to paragraph 6.5 of Annex S-2.

MSID ABSVD (Non Losses)

MSABSVDNKji

MWh

The amount determined in accordance with Annex S-2 paragraph 7.1.6

MSID ABSVD (Losses)

MSABSVDLNKji

The data determined by the SVAA in accordance with Annex S-2 paragraph 7.2.6.

MSID Pair Delivered Volume

MPDVj

MWh

MSID Pair Delivered Volume is such volumes of Active Energy notified to the SVAA by the NETSO for the purposes of calculating Non BM Unit ABSVD (SNBABSVDij); or by the Virtual Lead Party for the purposes of aggregating Secondary BM Unit Supplier Delivered Volume (VBMUSDViZj)

MSID Standing Data

The data procured by the SVAA where it has confirmed the allocation of an MSID Pair to a Secondary BM Unit and shall include those data items described in Section S11.2.3.

Non-Final Demand Metering System Metered Consumption

SVMMCHZaNLKji

MWh

The quantity determined in accordance with paragraph 7.1.1D of Annex S-2.

Non-Final Demand Corrected Component

SCORCiNj

MWh

The quantity submitted in accordance with paragraph 13.5.3 of Annex S-2.

Net Differencing Delivered Volume

NDDVj

MWh

has the meaning given to it in Annex S-2 3.11.5

Net Differencing Volume

VNDKj

MWh

has the meaning given to it in AnnexS-2 7.1.1C

Non Half Hourly Supplier Deemed Take

NHHSDTHZj

MWh

That part of the corrected Supplier Deemed Take associated with those Consumption Component Classes for which the data aggregation type is ‘N’, determined pursuant to paragraph 9.5 of Annex S-2.

Non-BM STOR Instruction Volume

NBSVDZaKj

MWh

The estimated volume of demand side Non-BM STOR delivered as determined and notified by the NETSO pursuant to Section S9.2.1.

”Non-Chargeable Consumption (Losses)”

NCCLOSSiNj

MWh

The quantity determined in accordance with paragraph 3.11.3 of Annex S-2.

”Non-Chargeable Consumption (Non Losses)”

NCCiNj

MWh

The quantity determined in accordance with paragraph 3.11.3 of Annex S-2.

”Non-Chargeable Corrected Component”

NCCORCiNj

MWh

The quantity determined in accordance with paragraph 3.11.3 of Annex S-2.

Noon Effective Temperature

NETH

F

A temperature determined pursuant to paragraph 6.5 of Annex S-2.

Normal Fraction

NFHPC

Number

The deemed annual Consumption associated with the non-switched load Settlement Registers expressed as a fraction of total annual Consumption for a Switched Load Metering System determined pursuant to paragraph 6.6 of Annex S-2.

Normal Register Profile Coefficient

NRPCHPCj

Number

The deemed fraction of annual Consumption for a Switched Load Metering System in a Settlement Period recorded on those meter registers which are 'on' during times when there is no switched load Consumption at such Metering System, determined pursuant to paragraph 6.6 of Annex S-2.

Number of Metering Systems Contributing to the Standard Settlement Configuration Estimated Daily Consumption

NMSSCEDCHPCT

Number

The number of non half hourly metering systems for which SPM data was used in determining the Standard Settlement Configuration Estimated Daily Consumption pursuant to paragraph 5.1 of Annex S-2.

Number Of Non Half Hourly Metered Metering Systems Requiring A Default Estimated Annual Consumption

NMMDEHZLPR

Number

The number of non half hourly Settlement Registers within metered SVA Metering Systems without either an Annualised Advance or an Estimated Annual Consumption and which therefore require a Default Estimated Annual Consumption to be determined, the value of which is maintained pursuant to Annex S-2.

Number Of Non Half Hourly Metered Metering Systems Requiring A Default Estimated Annual Consumption (Disconnected)

NMMDEDHZLPR

Number

The number of non half hourly Settlement Registers within metered SVA Metering Systems without either an Annualised Advance or an Estimated Annual Consumption and which therefore require a Default Estimated Annual Consumption to be determined which were subject to Demand Disconnection, the value of which is maintained pursuant to Annex S-2.

Number Of Non Half Hourly Metering Systems Contributing To The Total Annualised Advance

NMAHZLPR

Number

The number of non half hourly Settlement Registers within SVA Metering Systems contributing to the calculation of Total Annualised Advance, the value of which is maintained pursuant to paragraph 4.4 of Annex S-2.

Number Of Non Half Hourly Metering Systems Contributing To The Total Estimated Annual Consumption

NMMEHZLPR

Number

The number of non half hourly Settlement Registers within metered SVA Metering Systems contributing to the calculation of Total Estimated Annual Consumption, the value of which is maintained pursuant to paragraph 4.4 of Annex S-2.

Number Of Non Half Hourly Metering Systems Contributing To The Total Annualised Advance (Disconnected)

NMADHZLPR

Number

The number of non half hourly Settlement Registers within SVA Metering Systems contributing to the calculation of Total Annualised Advance which were subject to Demand Disconnection, the value of which is maintained pursuant to paragraph 4.5 of Annex S-2.

Number Of Non Half Hourly Metering Systems Contributing To The Total Estimated Annual Consumption (Disconnected)

NMMEDHZLPR

Number

The number of non half hourly Settlement Registers within metered SVA Metering Systems contributing to the calculation of Total Estimated Annual Consumption which were subject to Demand Disconnection, the value of which is maintained pursuant to paragraph 4.5 of Annex S-2.

Number Of Non Half Hourly Unmetered Metering Systems Contributing To The Total Estimated Annual Consumption

NMUEHZLPR

Number

The number of non half hourly Settlement Registers within Unmetered Supplies contributing to Total Estimated Annual Consumption, the value of which is maintained pursuant to paragraph 4.4 of Annex S-2.

Number Of Non Half Hourly Unmetered Metering Systems Contributing To The Total Estimated Annual Consumption (Disconnected)

NMUEDHZLPR

Number

The number of non half hourly Settlement Registers within Unmetered Supplies contributing to Total Estimated Annual Consumption which were subject to Demand Disconnection, the value of which is maintained pursuant to paragraph 4.5 of Annex S-2.

Number Of Non Half Hourly Unmetered Metering Systems Requiring A Default Estimated Annual Consumption

NMUDEHZLPR

Number

The number of non half hourly Settlement Registers within Unmetered Metering System without an Estimated Annual Consumption and which therefore require a Default Estimated Annual Consumption to be determined, the value of which is maintained pursuant to paragraph 4.4 of Annex S-2.

Number Of Non Half Hourly Unmetered Metering Systems Requiring A Default Estimated Annual Consumption (Disconnected)

NMUDEDHZLPR

Number

The number of non half hourly Settlement Registers within Unmetered Metering System without an Estimated Annual Consumption and which therefore require a Default Estimated Annual Consumption to be determined which were subject to Demand Disconnection, the value of which is maintained pursuant to paragraph 4.5 of Annex S-2.

Period BM Unit Gross Non-Final Demand

SDBMUimj

The quantity established in accordance with paragraph 13.5.4 of Annex S-2.

Period BM Unit Non Chargeable Demand

NCBMUDij

MWh

The amount determined in accordance with Annex S-2 3.11.

The Period BM Unit Non Chargeable Demand is the amount of Demand for a BM Unit which has been consumed by Generation or Storage Facility under the conditions of the Generation license which should not be subject to the Final Consumption Levy.

Period Profile Class Coefficient

PPCCHPRj

Number

The profile coefficient for a Time Pattern Regime associated with a valid combination of Profile Class and Standard Settlement Configuration determined pursuant to paragraph 6.7 of Annex S-2.

Period Time Pattern State Indicator

QRj

Indicator (1 or 0)

An indicator showing for a particular combination of Time Pattern Regime and Standard Settlement Configuration whether the associated Settlement Registers are recording Metered Data, determined pursuant to paragraph 6.4 of Annex S-2.

Previous Estimated Annual Consumption

PEACKR

kWh

The value of Estimated Annual Consumption determined pursuant to paragraph 4.3 of Annex S-2.

Primary Supplier's Metering System Metered Consumption

PSMMCZ1a1K1j or (where applicable) PSMMCZ1a1.1K1.1j

kWh

The half hourly metered Consumption for a Primary SVA Metering System Number determined pursuant to paragraph 3.5 of Annex S-2.

Profile

A pattern of Consumption specified over a Settlement Day, or part thereof, on a Settlement Period basis.

Profile Class

A classification of profiles which represents an exclusive category of customers whose Consumption can be reasonably approximated to a common profile for Settlement purposes.

Profile Class Estimated Daily Consumption

PCEDCHPT

kWh

The average Estimated Daily Consumption in respect of a GSP Group, Profile Class, Standard Settlement Configuration and Settlement Day determined pursuant to paragraph 5.1 of Annex S-2.

Quarterly Metering Systems by Supplier

NMZqG

Number

The total number of Metering Systems attributed to a Supplier, averaged over a calendar quarter by Supplier Volume Reporting Group, determined pursuant to paragraph 9A.1.5 of Annex S-2.

Quarterly Supplier Energy Volume

CORCZqG

MWh

The total energy volume attributed to a Supplier, summed over a calendar quarter by Supplier Volume Reporting Group, determined pursuant to paragraph 9A.1.4 of Annex S-2.

Regression Coefficients

RCHQ(nn)j

Various

A set of regression coefficients determined pursuant to paragraph 6.5 of Annex S-2.

Replica Settlement Day

In relation to a Settlement Day, a Settlement Day having the same attributes as that Settlement Day including any Clock Change.

Rounded-Down Duration

RDDR(ai)

minutes

The duration of a period employed in the rounding of Time Pattern Regime data and determined pursuant to paragraph 6.4 of Annex S-2.

Rounded-Down Spot Time

A spot time associated with a combination of Time Pattern Regimes and Standard Settlement Configuration employed in the rounding of Time Pattern Regime data and determined pursuant to paragraph 6.4 of Annex S-2.

Rounded-Up Duration

RUDR(ai)

minutes

The duration of a period employed in the rounding of Time Pattern Regime data and determined pursuant to paragraph 6.4 of Annex S-2.

Rounded-Up Spot Time

A spot time associated with a combination of Time Pattern Regimes and Standard Settlement Configuration employed in the rounding of Time Pattern Regime data and determined pursuant to paragraph 6.4 of Annex S-2.

Secondary BM Unit Delivered Volume

QVBMDi2NLKji

MWh

The quantity determined in accordance with 7.1.1D Annex S-2.

Secondary BM Unit Demand Volume

VBMUDVi2j

MWh

The quantity is determined in accordance with 9.6.1B Annex S-2.

The energy volume per Settlement Period for a Secondary BM Unit.

Secondary BM Unit Metered Consumption

VBMMCi2aNLKji

MWh

The Secondary BM Unit half hourly metered Consumption, determined by the SVAA pursuant to paragraph 7.1.1C of Annex S-2.

Secondary BM Unit Supplier Delivered Volume

VBMUSDVi2ji

MWh

The Secondary BM Unit half hourly Supplier Delivered Volumes determined by the SVAA pursuant to paragraph 9.6.1C of Annex S-2.

Secondary Corrected Component

VCORCi2Nj

MWh

The quantity determined in accordance with paragraph 9.3.3 of Annex S-2.

The Consumption for a SVA Metering System allocated to a Secondary BM Unit after the application of the GSP Group Correction.

Secondary Corrected Delivered Component

VCORDCi2NKji

MWh

The quantity determined in accordance with paragraph 9.3.4 of Annex S-2

The Delivered Volumes for a SVA Metering System allocated to a Secondary BM Unit after the application of the GSP Group Correction.

Secondary Half Hourly Consumption (Losses)

VLOSSi2Nj

MWh

The quantity determined in accordance with paragraph 7.2.4 of Annex S-2.

The half hourly Consumption for a SVA Metering System allocated to a Secondary BM Unit which is defined as line losses.

Secondary Half Hourly Consumption (Non Losses)

Vi2Nj

MWh

The quantity determined in accordance with paragraph 7.1.4 of Annex S-2.

The half hourly Consumption for a SVA Metering System allocated to a Secondary BM Unit which is defined as not being line losses.

Secondary Half Hourly Delivered (Losses)

VDLOSSi2NKji

MWh

The quantity determined in accordance with paragraph 7.2.5 of Annex S-2.

The half hourly Delivered Volumes for a SVA Metering System allocated to a Secondary BM Unit which is defined as not being line losses.

Secondary Half Hourly Delivered (Non Losses)

VDi2NKji

MWh

The quantity determined in accordance with paragraph 7.1.5 of Annex S-2.

The half hourly Delivered Volumes for a SVA Metering System allocated to a Secondary BM Unit which is defined as line losses.

Secondary Supplier's Metering System Metered Consumption

SSMMCZnanKnj or (where applicable) SSMMCZnan.1Kn.1j

kWh

The half hourly metered Consumption for a Secondary SVA Metering System Number determined pursuant to paragraph 3.5 of Annex S-2.

Settlement Class

For a Supplier a unique combination of Profile Class, Line Loss Factor Class, Time Pattern Regime and Standard Settlement Configuration within a GSP Group provided pursuant to paragraph 5.1.6 of Annex S-2.

Settlement Period

j

A period of thirty minutes beginning on the hour or the half hour and in accordance with paragraph 4.3.

Settlement Period Duration

SPD

Hours

0.5 hours.

Settlement Register

A logical register of a Metering System corresponding to one or more physical active import or active export registers (e.g. totalising meters) and, in the case of SVA Metering Systems not subject to half hourly metering, relating to a single valid combination of Time Pattern Regime and Standard Settlement Configuration.

Shared Suppliers' Metering System Metered Consumption

SHMMCZaKj

kWh

The half hourly metered Consumption for a SVA Metering System which measures Active Energy that is allocated between a Primary Supplier and the associated Secondary Supplier(s) and which half hourly consumption is determined pursuant to paragraph 3.5 of Annex S-2.

Smoothing Parameter

SPAR

Number

A parameter set by the Panel from time to time is used in the determination of the Annualised Advance Adjustment Factor pursuant to paragraph 4.3 of Annex S-2.

Specimen Settlement Day

In relation to any Settlement Day, a Settlement Day having the same attributes as that Settlement Day other than a Clock Change.

Standard Settlement Configuration

A standard Metering System configuration recognised by the Supplier Volume Allocation Agent System.

Standard Settlement Configuration Estimated Daily Consumption

SSCEDHPCT`

kWh

The average Estimated Daily Consumption in respect of a GSP Group, Profile Class, Standard Settlement Configuration and Settlement Day determined pursuant to paragraph 5.1 of Annex S-2.

Sunset Time

SUNT

Minutes

The time duration from the start of the Settlement Day to the time of sunset determined pursuant to paragraph 6.5 of Annex S-2 with reference to the Time of Sunset Data.

Sunset Variable

S

Minutes

The number of minutes after 1800 hours GMT that the sun is deemed to set, determined pursuant to paragraph 6.5 of Annex S-2.

Supplier BM Unit Non BM ABSVD

SNBABSVDij

MWh

The amount determined in accordance with Annex S-2 paragraph 9.6.1D.

Supplier Cap Take

SCTHZj

MWh

The deemed take (active import) at GSP Group level for a SVA Supplier during a Settlement Period pursuant to paragraph 9.7 of Annex S-2.

Supplier Deemed Take

SDTHZj

MWh

The deemed take at GSP Group level for a SVA Supplier during a Settlement Period determine pursuant to paragraph 9.4 of Annex S-2.

Supplier Disconnection Matrix

SDMHZaLPR

A matrix of data as determined pursuant to paragraph 4.5 of Annex S-2.

Supplier Purchase Matrix

SPMHZaLPR

A matrix of data as determined pursuant to paragraph 4.4 of Annex S-2.

Supplier’s Demand Disconnection Volume

SDDHZaNj

MWh

The half hourly Demand Disconnection volume, determined by a Half Hourly Data Aggregator pursuant to paragraph 3.7 of Annex S-2.

Supplier’s Demand Disconnection Volume (Losses)

SDDLHZaNj

MWh

The line losses determined by a Half Hourly Data Aggregator as resulting from the Supplier’s Demand Disconnection Volume pursuant to paragraph 3.7 of Annex S-2.

Supplier’s Meter Register Consumption

SMRCaKJj

kWh

The half hourly metered Consumption for a Settlement Register within a SVA Metering System.

Supplier’s Metered Consumption

SMCHZaNLj

MWh

The half hourly metered Consumption, determined by a Half Hourly Data Aggregator pursuant to paragraph 3.5 of Annex S-2.

Supplier’s Metered Consumption (Losses)

SMCLHZaNLj

MWh

The line losses determined by a Half Hourly Data Aggregator as resulting from the Supplier’s Metered Consumption pursuant to paragraph 3.5 of Annex S-2.

Supplier’s Metering System Metered Consumption

SMMC ZaKj

kWh

The half hourly metered Consumption for a SVA Metering System, determined pursuant to paragraph 3.5 of Annex S-2.

Switched Fraction

SWFHPC

Number

The deemed proportion of Consumption for a Switched Load Metering System which is switched load determined pursuant to paragraph 6.6 of Annex S-2.

Switched Load Metering System

A Metering System which has a Profile Class classified as Economy 7 and/or such other classification as may be agreed from time to time by the Panel.

Switched Load Profile Coefficient

SLPHPCj

Number

A number determined pursuant to paragraph 6.6 of Annex S-2 and representing the fraction of annual Consumption in a given Settlement Period for a particular switched load profile.

Switched Load State Indicator

SQCj

Indicator (1 or 0)

An indicator showing if any Time Pattern Regime associated with a switched load within a Standard Settlement Configuration is recording Metered Data in a given Settlement Period, determined pursuant to paragraph 6.6 of Annex S-2.

Teleswitch Contact

One of the logical contacts within each teleswitched meter.

Teleswitch Contact Interval Data

In respect of a Teleswitch Group, the state of a particular Teleswitch Contact within all Metering Systems within such Teleswitch Group at the start of a UTC Day and, for each following change of state of such contact, the new state of such contact and the time in Co-ordinated Universal Time of such change of state.

Teleswitch Contact Rule

The relationship between a Teleswitch Contact and a Teleswitch Register Rule which is notified by a Supplier pursuant to paragraph 5.1.1 of Annex S-2.

Teleswitch Group

A group of Metering Systems which are controlled by the same teleswitch messages which messages are under the control of a particular person.

Teleswitch Interval

A period during which the Settlement Registers associated with a Teleswitch Time Pattern Regime are recording metered consumption and which is determined pursuant to paragraph 6.2 of Annex S-2.

Teleswitch Regime Indicator

Indicator

An indicator indicating whether a Settlement Register is associated with a Time Pattern Regime provided pursuant to paragraph 5.1.5 of Annex S-2.

Teleswitch Register Rule

A rule defining when the Settlement Registers associated with a Teleswitch Time Pattern Regime are recording metered consumption which is notified by a Supplier pursuant to paragraph 5.1.1 of Annex S-2.

Teleswitch Time Pattern Regime

A Time Pattern Regime associated with a teleswitched Standard Settlement Configuration in a particular Teleswitch Group.

Threshold Parameter

TP

Number

A parameter set by the Panel from time to time and used in the determination of the Default Estimated Annual Consumption pursuant to paragraph 4.4 of Annex S-2.

Time of Sunset

Time

A set of data supplied to the Supplier Volume Allocation Agent pursuant to paragraph 5.1.6 of Annex S-2.

Time Pattern Regime

A pattern of switching behaviour through time that determines when a Settlement Register is or is not recording Metered Data provided pursuant to paragraph 5.1.5 of Annex S-2.

Time Pattern Regime Estimated Annual Consumption

TPREACHPR

kWh

The average Estimated Annual Consumption in respect of a GSP Group, Profile Class, Standard Settlement Configuration and Time Pattern Regime determined pursuant to paragraph 5.1 of Annex S-2.

Time Pattern Regime Estimated Daily Consumption

TPREDCHPRT

kWh

The average Estimated Daily Consumption in respect of a GSP Group, Profile Class, Standard Settlement Configuration, Time Pattern Regime and Settlement Day determined pursuant to paragraph 5.1 of Annex S-2.

Timeswitch Regime Indicator

Indicator

An indicator indicating whether a Settlement Register is associated with a Time Pattern Regime provided pursuant to paragraph 5.1.5 of Annex S-2.

Total Annualised Advance

TAAHZLPR

MWh

The total of all the Annualised Advances for a Supplier in MWh and in respect of a Profile Class, Line Loss Factor Class, Time Pattern Regime and GSP Group determined pursuant to paragraph 4.4 of Annex S-2.

Total Annualised Advance (Disconnected)

TAADHZLPR

MWh

The total of all the Annualised Advances for a Supplier in MWh and in respect of a Profile Class, Line Loss Factor Class, Time Pattern Regime and GSP Group which were subject to Demand Disconnection, determined pursuant to paragraph 4.5 of Annex S-2.

Total Estimated Annual Consumption For Non Half Hourly Metered Metering Systems

MEHZLPR

KWh

The sum of Estimated Annual Consumption for non half hourly metered SVA Metering Systems calculated pursuant to paragraph 4.4 of Annex S-2.

Total Estimated Annual Consumption For Non Half Hourly Metered Metering Systems (Disconnected)

MEDHZLPR

kWh

The sum of Estimated Annual Consumption for non half hourly metered SVA Metering Systems which were subject to Demand Disconnection, determined pursuant to paragraph 4.5 of Annex S-2.

Total Metered Estimated Annual Consumption

TMEACHZLPR

MWh

The total metered annual Consumption for a SVA Supplier and in respect of a Profile Class, Line Loss Factor Class, Time Pattern Regime and GSP Group, determined pursuant to paragraph 4.4 of Annex S-2.

Total Metered Estimated Annual Consumption (Disconnected)

TMEACDHZLPR

MWh

The total metered annual Consumption for a SVA Supplier subject to Demand Disconnection and in respect of a Profile Class, Line Loss Factor Class, Time Pattern Regime and GSP Group, determined pursuant to paragraph 4.5 of Annex S-2.

Total Metering System Delivered Volume

TQVMDKj

MWh

The quantity determined in accordance with paragraph 3.10.2 of Annex S-2.

Total Number Of Metered Non Half Hourly Metering Systems Contributing To Total Metered Estimated Annual Consumption

TMEACCHZLPR

Number

The number of metered non half hourly Settlement Registers within SVA Metering Systems contributing to the calculation of Total Metered Estimated Annual Consumption the value of which is maintained pursuant to paragraph 4.4 of Annex S-2.

Total Number Of Metered Non Half Hourly Metering Systems Contributing To Total Metered Estimated Annual Consumption (Disconnected)

TMEACCDHZLPR

Number

The number of metered non half hourly Settlement Registers within SVA Metering Systems contributing to the calculation of Total Metered Estimated Annual Consumption which were subject to Demand Disconnection, the value of which is maintained pursuant to paragraph 4.5 of Annex S-2.

Total Number Of Non Half Hourly Unmetered Metering Systems Contributing To Total Unmetered Consumption

TMUECHZLPR

Number

The number of non half hourly Settlement Registers within Unmetered Supplies contributing to the calculation of Total Unmetered Consumption the value of which is maintained pursuant to paragraph 4.4 of Annex S-2.

Total Number Of Non Half Hourly Unmetered Metering Systems Contributing To Total Unmetered Consumption (Disconnected)

TMUECDHZLPR

Number

The number of non half hourly Settlement Registers within Unmetered Supplies contributing to the calculation of Total Unmetered Consumption which were subject to Demand Disconnection, the value of which is maintained pursuant to paragraph 4.5 of Annex S-2.

Total Unmetered Consumption

TUEHZLPR

MWh

The total unmetered annual Consumption for a SVA Supplier and in respect of a Profile Class, Line Loss Factor Class, Time Pattern Regime and GSP Group, determined pursuant to paragraph 4.4 of Annex S-2.

Total Unmetered Consumption (Disconnected)

TUEDHZLPR

MWh

The total unmetered annual Consumption for a SVA Supplier subject to Demand Disconnection and in respect of a Profile Class, Line Loss Factor Class, Time Pattern Regime and GSP Group, determined pursuant to paragraph 4.5 of Annex S-2.

Unadjusted Annual Fraction of Consumption

UAFYCHPR

An estimate of the fraction of the total average consumption of a multi-register Standard Settlement Configuration attributable to each Time Pattern Regime of that Standard Settlement Configuration, prior to adjustment for rounding errors, determined pursuant to paragraph 5.1 of Annex S-2.

Unadjusted Interval

A period of time beginning at an Unadjusted Interval Start Time and ending at its associated Unadjusted Interval End Time, determined pursuant to paragraph 6.4 of Annex S-2.

Unadjusted Interval End Time

UIETX(ai)

A time associated with a particular Time Pattern Regime determined pursuant to paragraph 6.4 of Annex S-2.

Unadjusted Interval Start Time

UISTX(ai)

A time associated with a particular Time Pattern Regime determined pursuant to paragraph 6.4 of Annex S-2.

Unrounded Duration

UDX(ai)

Minutes

The time duration of an Unadjusted Interval determined pursuant to paragraph 6.4 of Annex S-2.

Value Of Estimated Annual Consumption For Non Half Hourly Unmetered Metering Systems

UEHZLPR

KWh

The value of Estimated Annual Consumption for non half hourly Settlement Registers within Unmetered Supplies, the value of which is maintained pursuant to paragraph 4.4 of Annex S-2.

Value Of Estimated Annual Consumption For Non Half Hourly Unmetered Metering Systems (Disconnected)

UEDHZLPR

kWh

The value of Estimated Annual Consumption for non half hourly Settlement Registers within Unmetered Supplies which were subject to Demand Disconnection, the value of which is maintained pursuant to paragraph 4.5 of Annex S-2.

Table X–7 –

List of Acronyms Applicable to Section S

This table provides a list of the acronyms defined in Table X-6, presented in alphabetical order of the acronym name.

Acronym

Corresponding Defined Term or Expression

AAAFKR

Annualised Advance Adjustment Factor

AAFYCHPC

Alternative Average Fraction of Yearly Consumption

AAKR

Annualised Advance

ABDDiaNLKj

Allocated BM Unit’s Demand Disconnection Volume

ABMMMC iaNLKj

Allocated BM Unit's Metering System Metered Consumption

ADBPEDi

AMSID Declaration Boundary Point Export”

ADBPIDj

AMSID Declaration Boundary Point Import”

ADGEDj

AMSID Declaration Generation Export”

ADGIDj

AMSID Declaration Generation Import”

ADNCPDj

AMSID Declaration Non‑Chargeable Proportion”

AFYCAHPC

Annual Fraction of Yearly Consumption Adjustment

AFYCHPR

Average Fraction Of Yearly Consumption

AMPDVj

AMSID Pair Delivered Volume

AQVMDNLKji

ABSVD BM Unit Delivered Volume

ASDDHZaNLKj

Allocated Supplier’s Demand Disconnection Volume

ASMMCHZaNLKj

Allocated Supplier’s Metering System Metered Consumption

AVMMCHZaNLKji

Allocated Metering System Metered Consumption

BAPHQj

Baseload Profile Coefficient

BFHPC

Base Fraction

BEVji

Baselined Expected Volumes

BMDDiaNj

BM Unit’s Demand Disconnection Volume

BMDDLiaNj

BM Unit’s Demand Disconnection Volume (Losses)

BMDMiaLPR

BM Unit Disconnection Matrix

BMMC iaNLj

BM Unit's Metered Consumption

BMMCL iaNLj

BM Unit's Metered Consumption (Losses)

BMPC iLPRj

BM Unit's Profiled Consumption

BMPDiLPRj

BM Unit’s Profiled Disconnection

BMPM iaLPR

BM Unit Purchase Matrix

BMUADDVij

BM Unit Allocated Demand Disconnection Volume

BMUADVij

BM Unit Allocated Demand Volume

CFHj

GSP Group Correction Factor

CiN(c)Pj

Half Hourly Consumption (Non Losses) by Profile Class

CiNj

Half Hourly Consumption (Non Losses)

CLOSSiN(c)Pj

Half Hourly Consumption (Losses) by Profile Class

CLOSSiNj

Half Hourly Consumption (Losses)

CORCiN(c)Pj

Corrected Component by Profile Class

CORCiNj

Corrected Component

CORCZqG

Quarterly Supplier Energy Volume

CORDCiNj

Corrected Disconnection Component

DDDPCHPKRT

Demand Disconnection Daily Profile Coefficient

DEMHZLPR

Default Estimated Annual Consumption For Metered Metering Systems

DEUHZLPR

Default Estimated Annual Consumption For Unmetered Metering Systems

DiNj

Half Hourly Disconnection (Non Losses)

DLOSSiNj

Half Hourly Disconnection (Losses)

DMAKR

Deemed Meter Advance

DPCHPRT

Daily Profile Coefficient

DPCHPRT

Historical Daily Profile Coefficient

EACKR

Estimated Annual Consumption

FYCKR

Fraction Of Yearly Consumption

GAACHQ

Group Average Annual Consumption

GCHNj

GSP Group Half Hourly Consumption

GGPCAEACHPC

GSP Group Profile Class Average Estimated Annual Consumption

GGPCDEACHP

GSP Group Profile Class Default Estimated Annual Consumption

HDDKj

Half Hourly Demand Disconnection Volume

HHPC

Low Fraction Consumption

ITAADHZLPR

Initial Total Annualised Advance (Disconnected)

K1HPC

K2HPC

LLFLj

Line Loss Factor

LOWFHPC

Low Fraction

LRPCHPCj

Low Register Profile Coefficient

MADVKR

Meter Advance

MAP

Meter Advance Period

MEDHZLPR

Total Estimated Annual Consumption For Non Half Hourly Metered Metering Systems (Disconnected)

MKj

Metering System Period Disconnection Duration

MPDVj

MSID Pair Delivered Volume

MRCQ(aa)(nn)j

Matrix Of Regression Coefficients

MSABSVDLHZLKj

MSID ABSVD (Losses)

MSABSVDNKji

MSID ABSVD (Non Losses)

MBVKiLj

MSID Baseline Value

MBLKiLj

MSID Baseline Losses

NBSVDZaKj

Non-BM STOR Instruction Volume

NDDVj

Net Differencing Delivered Volume

NETH

Noon Effective Temperature

NCBMUDij

Period BM Unit Non Chargeable Demand

NCCiNj

Non-Chargeable Consumption (Non Losses)

NCCLOSSiNj

Non-Chargeable Consumption (Losses)

NCCORCiNj

Non-Chargeable Corrected Component

NCMCiNLKj

Metering System Non-Chargeable Consumption

NCMLiNLKj

Metering System Non-Chargeable Losses” for an EMR MSID Declaration

NFHPC

Normal Fraction

NHHSDTHZj

Non Half Hourly Supplier Deemed Take

NMADHZLPR

Number Of Non Half Hourly Metering Systems Contributing To The Total Annualised Advance (Disconnected)

NMAHZLPR

Number Of Non Half Hourly Metering Systems Contributing To The Total Annualised Advance

NMMDEDHZLPR

Number Of Non Half Hourly Metered Metering Systems Requiring A Default Estimated Annual Consumption (Disconnected)

NMMDEHZLPR

Number Of Non Half Hourly Metered Metering Systems Requiring A Default Estimated Annual Consumption

NMMEDHZLPR

Number Of Non Half Hourly Metering Systems Contributing To The Total Estimated Annual Consumption (Disconnected)

NMMEHZLPR

Number Of Non Half Hourly Metering Systems Contributing To The Total Estimated Annual Consumption

NMSSCEDCHPCT

Number of Metering Systems Contributing to the Standard Settlement Configuration Estimated Daily Consumption

NMUDEDHZLPR

Number Of Non Half Hourly Unmetered Metering Systems Requiring A Default Estimated Annual Consumption (Disconnected)

NMUDEHZLPR

Number Of Non Half Hourly Unmetered Metering Systems Requiring A Default Estimated Annual Consumption

NMUEDHZLPR

Number Of Non Half Hourly Unmetered Metering Systems Contributing To The Total Estimated Annual Consumption (Disconnected)

NMUEHZLPR

Number Of Non Half Hourly Unmetered Metering Systems Contributing To The Total Estimated Annual Consumption

NMZqG

Quarterly Metering Systems by Supplier

NRPCHPCj

Normal Register Profile Coefficient

ORABSVDCi2Nj

Corrected MSID ABSVD Component

PCEDCHPT

Profile Class Estimated Daily Consumption

PEACKR

Previous Estimated Annual Consumption

PHQj

Basic Period Profile Coefficient

PPCCHPRj

Period Profile Class Coefficient

PSEVji

Party Submitted Expected Volume

PSMMCZ1a1.1K1.1j

Primary Supplier's Metering System Metered Consumption for Secondary SVA Metering System Number K1.1

PSMMCZ1a1K1j

Primary Supplier's Metering System Metered Consumption for Secondary SVA Metering System Number K1

QRj

Period Time Pattern State Indicator

QVBMDi2NLKji

Secondary BM Unit Delivered Volume

QVMDKj

Metering System Delivered Volume

RCHQ(nn)j

Regression Coefficients

RDDR(ai)

Rounded-Down Duration

RUDR(ai)

Rounded-Up Duration

S

Sunset Variable

SCiNj

Half Hourly Non-Final Demand Consumption (Non Losses)

SCLOSSiNj

Half Hourly Non-Final Demand Consumption (Losses)

SCORCiNj

Non-Final Demand Corrected Component

SDDHZaNj

Supplier’s Demand Disconnection Volume

SDDLHZaNj

Supplier’s Demand Disconnection Volume (Losses)

SDMHZaLPR

Supplier Disconnection Matrix

SDTHZj

Supplier Deemed Take

SEVji

Settlement Expected Volume

SHSMMCZaKj

Shared Suppliers' Metering System Metered Consumption

SIX_PM

SLPHPCj

Switched Load Profile Coefficient

SMCHZaNLj

Supplier's Metered Consumption

SMCLHZaNLj

Supplier’s Metered Consumption (Losses)

SMMC ZaKj

Supplier’s Metering System Metered Consumption

SMRCaKJj

Supplier’s Meter Register Consumption

SNBABSVDij

Supplier BM Unit Non BM ABSVD

SPAR

Smoothing Parameter

SPD

Settlement Period Duration

SPMHZaLPR

Supplier Purchase Matrix

SQCj

Switched Load State Indicator

SSCEDHPCT

Standard Settlement Configuration Estimated Daily Consumption

SSMMCZnan.1Kn.1j

Secondary Supplier's Metering System Metered Consumption for Secondary SVA Metering System Number Kn.1

SSMMCZnanKnj

Secondary Supplier's Metering System Metered Consumption for Secondary SVA Metering System Number Kn

SUNT

Sunset Time

SVMMCHZaNLKji

Non-Final Demand Metering System Metered Consumption

SWFHPC

Switched Fraction

TAADHZLPR

Total Annualised Advance (Disconnected)

TAPDVj

Total AMSID Pair Delivered Volume

THT

Grid Supply Point Group Measured Temperature

TMEACCDHZLPR

Total Number Of Metered Non Half Hourly Metering Systems Contributing To Total Metered Estimated Annual Consumption (Disconnected)

TMEACDHZLPR

Total Metered Estimated Annual Consumption (Disconnected)

TMPDVj

Total MSID Pair Delivered Volume

TMUECDHZLPR

Total Number Of Non Half Hourly Unmetered Metering Systems Contributing To Total Unmetered Consumption (Disconnected)

TQVMDKj

Total Metering System Delivered Volume

TPREACHPR

Time Pattern Regime Estimated Annual Consumption

TPREDCHPRT

Time Pattern Regime Estimated Daily Consumption

TUEDHZLPR

Total Unmetered Consumption (Disconnected)

UAFYCHPR

Unadjusted Annual Fraction of Consumption

UEDHZLPR

Value Of Estimated Annual Consumption For Non Half Hourly Unmetered Metering Systems (Disconnected)

VBMMCi2aNLKji

Secondary BM Unit Metered Consumption

VBMUDVi2j

Secondary BM Unit Demand Volume

VBMUSDVi2ji

Secondary BM Unit Supplier Delivered Volume

VCORCi2Nj

Secondary Corrected Component

VCORDCi2NKji

Secondary Corrected Delivered Component

VDi2NKji

Secondary Half Hourly Delivered (Non Losses)

VDLOSSi2NKji

Secondary Half Hourly Delivered (Non Losses)

Vi2Nj

Secondary Half Hourly Consumption (Non Losses)

VLOSSi2Nj

Secondary Half Hourly Delivered (Losses)

VMMCHZaNLKji

Metering System Metered Consumption

WTN

GSP Group Correction Scaling Weight

yHQj

Estimated Regional Average Demand Per Customer

Table X-8

List of Valid Consumption Component Classes

The following table shows a list of valid Consumption Component Classes. The Panel may amend such list of valid Consumption Component Classes from time to time.

Consumption Component Class Id

Measurement Quantity ID

Data Aggregation Type

Metered / Unmetered Indicator

Consumption Component Indicator

Actual / Estimated Indicator

AA / EAC Indicator

Consumption Level Indicator

Measurement Class

1

AI

H

M

C

A

B

C

2

AI

H

U

C

A

-

D

3

AI

H

M

M

A

B

C

4

AI

H

M

L

A

B

C

5

AI

H

U

L

A

-

D

6

AE

H

M

C

A

-

C

7

AE

H

M

M

A

-

C

8

AE

H

M

L

A

-

C

9

AI

H

M

C

E

B

C

10

AI

H

U

C

E

-

D

11

AI

H

M

M

E

B

C

12

AI

H

M

L

E

B

C

13

AI

H

U

L

E

-

D

14

AE

H

M

C

E

-

C

15

AE

H

M

M

E

-

C

16

AE

H

M

L

E

-

C

17

AI

N

M

C

E

-

A

18

AI

N

M

C

A

-

A

19

AI

N

U

C

E

-

B

20

AI

N

M

L

E

-

A

21

AI

N

M

L

A

-

A

22

AI

N

U

L

E

-

B

23

AI

H

M

C

A

A

E

25

AI

H

M

M

A

A

E

26

AI

H

M

L

A

A

E

28

AI

H

M

C

E

A

E

30

AI

H

M

M

E

A

E

31

AI

H

M

L

E

A

E

32

AE

N

M

C

E

-

A

33

AE

N

M

C

A

-

A

34

AE

N

M

L

E

-

A

35

AE

N

M

L

A

-

A

36

AE

H

M

C

A

-

E

37

AE

H

M

M

A

-

E

38

AE

H

M

L

A

-

E

39

AE

H

M

C

E

-

E

40

AE

H

M

M

E

-

E

41

AE

H

M

L

E

-

E

42

AI

H

M

C

A

A

F

43

AI

H

M

M

A

A

F

44

AI

H

M

L

A

A

F

45

AI

H

M

C

E

A

F

46

AI

H

M

M

E

A

F

47

AI

H

M

L

E

A

F

48

AE

H

M

C

A

-

F

49

AE

H

M

M

A

-

F

50

AE

H

M

L

A

-

F

51

AE

H

M

C

E

-

F

52

AE

H

M

M

E

-

F

53

AE

H

M

L

E

-

F

54

AI

H

M

C

A

A

G

55

AI

H

M

M

A

A

G

56

AI

H

M

L

A

A

G

57

AI

H

M

C

E

A

G

58

AI

H

M

M

E

A

G

59

AI

H

M

L

E

A

G

60

AE

H

M

C

A

-

G

61

AE

H

M

M

A

-

G

62

AE

H

M

L

A

-

G

63

AE

H

M

C

E

-

G

64

AE

H

M

M

E

-

G

65

AE

H

M

L

E

-

G

The attributes of such Consumption Component Classes are for the time being and from time to time valid:

(i) measurement quantity ID, which shall have values:

AI active import (consumption); or

AE active export (generation);

(ii) data aggregation type, which shall have values:

H half hourly; or

N non-half hourly;

(iii) metered/ unmetered indicator shall have values:

M metered; or

U unmetered;

(iv) consumption component indicator shall have values:

C basic consumption (or generation);

M metering system specific line losses; or

L metering system non-specific line losses;

(v) actual/ estimated indicator shall have values:

A actual;

E estimated; or

Null;

(vi) AA/EAC indicator shall have values:

A Annualised Advance;

E Estimated Annual Consumption; or

Null; and

(vii) Consumption Level Indicators shall have the following values:

A Metering Systems which are not 100kW Metering Systems (equivalent to Measurement Class "E", "F" and "G");

B Metering Systems which are 100kW Metering Systems (equivalent to Measurement Class "C"); or

Null Not applicable, shown as a hyphen (-), including export, NHH and unmetered MSIDs.

viii) Measurement Class as defined in Table X-6.

Table X–9

List of Supplier Volume Reporting Groups and associated relationships used for the purposes of the Supplier Quarterly Volume Report determined according to paragraph 9A of Annex S-2:

Supplier Volume Reporting Group

Consumption Component Classes

Profile Classes (where used and/or applicable)

1

17, 18, 20, 21

1, 2

2

17, 18, 20, 21

3, 4

3

17, 18, 20, 21

5, 6, 7, 8

4

19, 22

Not used

5

32, 33, 34, 35

Not used

6

1, 3, 4, 9, 11, 12, 23, 25, 26, 28, 30, 31, 42, 43, 44, 45, 46, 47, 54, 55, 56, 57, 58, 59

Not applicable

7

2, 5, 10, 13

Not applicable

8

6, 7, 8, 14, 15, 16, 36, 37, 38, 39, 40, 41, 48, 49, 50, 51, 52, 53, 60, 61, 62, 63, 64, 65

Not applicable

For the Supplier Quarterly Volume Report as set out in paragraph 4.2.10 of Section V, the Supplier Volume Reporting Groups with the numbers in the far left column of the table above shall be given the following descriptive labels in the actual report:

1. "Non half hourly metered import, Profile Classes 1 and 2";

2. "Non half hourly metered import, Profile Classes 3 and 4";

3. "Non half hourly metered import, Profile Classes 5, 6, 7 and 8";

4. "Non half hourly unmetered import";

5. "Non half hourly metered export";

6. "Half hourly metered import";

7. "Half hourly unmetered import"; and

8. "Half hourly metered export".