User Manual for the EDCM charging model (Jan 2013)
Contents
1. 913 LRIC models only contains table 913 only LRIC location data d Sheet 935 contains table 935 only volume data and tariff mappings Page 2 Input data sheets and tables 15 This section reviews each of the input data sheets providing guidance on data definitions and possible data sources wherever possible 911 FCP power flow modelling data 16 Sheet 911 is only included in FCP models Table 911 the only table in the sheet contains outputs from the FCP power flow modelling and reinforcement costing analysis 17 A description of each column in table 911 is provided below Location name ID 18 This is a unique identifier for the location any combination of letters and numbers is permissible provided that it is unique in Microsoft Excel s view The location might be either a network group or a pseudo hybrid network group in the case of a network group with two or more parent or grandparent groups 19 It is important to ensure that that this identifier is unique Level 20 Data in this column are not used Parent location if any 21 This column contains the location name ID of the higher level network group serving the location This is to be left blank if the location is at the top of the hierarchy Charge 1 kVA year 22 This is the network group charge in kVA year for demand load Under the FCP methodology this number is always zero or positive If this number is positive it will be a c2. Rall gt b o0 Y yow X Yf 9 0100 0001 I ft It aw 9 Q 2 Q perp Ge LU 1110 Page 10 Network use factor 77 78 Super r 79 80 81 These columns contain the network use factors applicable to each network level Blank cells will be treated as zeros In the case of a generation dominated mixed site default values for network use factors must be entered for each network level These default values are equal to the minimum network use factors in table 1134 Please do not leave these as 1 or blank ed kW import divided by kVA capacity This column contains a forecast for each customer that should be calculated using historical consumption and maximum import capacity for that customer Historical refers to the last full regulatory year for which data are available If peak time Al denotes active power import for each half hour in the super red time band in kWh and average kVA is the average of the maximum import capacity over the last regulatory year for which data are available then the formula for this item is Sum peak time Al super red hours average kVA If the customer is new or its circumstances have changed since the last regulatory year for which data are available an estimate of the current value should be entered Super red kVAr import divided by kVA capacity 82 83 84 85 86 87 88 This column contains data for FCP only and is not used for LRIC This co
3. a A tariff and this can be an import only tariff an export only tariff or a import and export tariff Tariffs where all three of the import capacity exempt export capacity and non exempt export capacity are either zero blank or VOID are not permitted in table 935 unless these are part of completely blank rows b A portfolio tariff element for any tariff on any LDNO network nested network or offshore network which is subject to a site specific locational element of a portfolio tariff 56 A description of each column in table 935 is provided below Name 57 This is a full name identifier for the tariff This is for labelling purposes and does not affect any calculations Maximum import capacity kVA 58 This column should contain the forecast average maximum import capacity over the charging year If you do not want to calculate a any import charges for a particular tariff or include in the calculation of import charges for other customers data relating to a particular tariff please enter the text string VOID in this column Any other entry including blank or zero will result in import charges being calculated and displayed for this tariff Exempt export capacity kVA 59 This column should contain the export capacity in kVA of the customer associated with the tariff that is exempt from use of system charges Non exempt pre 2005 export capacity kVA 60 This column should contain the export capacity in kVA the
4. methodology to meet Condition 3 of the EDCM approval Table 2 Network use factor caps Network levels Caps 132 kV 2 246 132kV EHV 1 558 EHV 3 290 EHV HV 2 380 132kV HV 2 768 1134 Minimum network use factor 139 This table contains the collars for the network use factors at different network levels These collars are common across all DNO areas 140 The collars for each network level calculated using the current EDCM methodology are set out in table 3 below These collars may change following changes to the methodology to meet Condition 3 of the EDCM approval Table 3 Network use factor collars Network levels Collars 132 kV 0 273 132kV EHV 0 677 EHV 0 332 EHV HV 0 631 132kV HV 0 697 1135 Loss adjustment factor to transmission for each network level from CDCM table 2004 141 These figures can be taken from table 2004 of the CDCM model 1181 LDNO discounts 142 This table should be populated with discount percentages from the extended Method M model version M12 Page 16 1182 CDCM end user tariffs 143 144 This table should be populated with CDCM end user tariffs from table 3701 of the CDCM model 100 Note that HV sub HH metered HV generation intermittent and HV generation non intermittent tariffs are not to be copied into this table 1183 LDNO volume data 145 146 4601 147 148 This should be populated with volume forecas
5. a demand only tariff please enter the text string VOID in this column Any other entry including blank or zero will result in export charges being calculated and displayed for this tariff Sole use asset MEAV 67 68 This is the modern equivalent asset value of the sole use assets attributed to the customer associated with the tariff Where a site has both import and export MPANSs the full value of sole use assets are to be entered LRIC location in LRIC models and FCP network group in FCP models 69 70 This is the identifier location name ID of the lead location for this tariff in table 913 in LRIC models and table 911 in FCP models In the case of LRIC models if the location is part of a chain of linked locations the location name ID of the first location in the chain must be entered here Customer category for demand scaling 71 72 An identifier that can take fifteen values based on which parts of the EHV network the customer is deemed to use Five levels are defined for the network s assets a Level 1 comprises 132 kV circuits b Level 2 comprises substations with a primary voltage of 132 kV and a secondary voltage of 22 kV or more c Level 3 comprises circuits of 22 kV or more but less than 132 kV d Level 4 comprises substations with a primary voltage of 22 kV or more but less than 132 kV and a secondary voltage of less than 22 kV Page 7 e Level 5 comprises
6. substations with a primary voltage of 132 kV and a secondary voltage of less than 22 kV 73 In some cases it might be appropriate to treat 66 kV equipment as being equivalent to 132 kV equipment and allocate customers to categories accordingly 74 EDCM customers are split into 15 categories based on the parts of the EHV network they are deemed to use This is based on the point of common coupling defined as the point at which the sole use assets meet the rest of the distribution network The point of common coupling might be at a different voltage than the customer s supply and might also be at a different voltage than the voltage of connection when the customer was connected Table 1 Categorisation of EDCM customers Category Definition Category 0000 Category 1000 Category 1100 Category 0100 Category 1110 Category 0110 Category 0010 Category 0001 Point of common coupling at the GSP whether the GSP is shared or not In England or Wales only point of common coupling at a voltage of 132 kV unless the customer qualifies for category 0000 Point of common coupling at 22 kV or more on the secondary side of a substation where the primary side is attached to a 132 kV circuit Point of common coupling at 22 kV or more but less than 132 kV on the secondary side of a substation where the primary side is attached at 132 kV to a co located GSP with no use of any 132 kV circuits Point of common coupling
7. 1 kVA year 44 45 This is the local kVA year charge at the location under maximum demand conditions This number may be positive or negative If this is positive it is a charge to demand at that location or a credit to non intermittent generation at that location Remote charge 1 kVA year 46 This is the remote kVA year charge at the location under maximum demand conditions 47 This number may be positive or negative If this is positive it is a charge to demand at that location or a credit to non intermittent generation at that location Not used 48 Data in this column are not used Not used 49 Data in this column are not used Maximum demand run kW 50 This is the total relevant active power in kW in the maximum demand scenario This number is positive for a generation flows and negative for demand flows Maximum demand run kVAr 51 This is the total relevant reactive power in kVAr in the maximum demand scenario This number has the same sign as kW in the maximum demand run if the current calculated for demand lags its voltage Not used Previously Minimum demand run kW 52 Data in this column are not used Not used Previously Minimum demand run kVAr 53 Data in this column are not used 935 Tariff input data 54 This table provides input information about each EDCM tariff Page 5 55 There needs to be one line in table 935 for each of the following
8. 13 is only included in LRIC models Table 913 the only table in the sheet contains outputs from the LRIC power flow modelling and reinforcement costing analysis 37 A description of each column in table 913 is provided below Location name ID 38 A unique identifier for the location any combination of letters and numbers is permissible provided that it is unique in Microsoft Excel s view 39 It is important to ensure that that this identifier is unique Demand or Generation 40 This should contain the word Demand or Generation indicating how the load at the relevant location was modelled Linked location if any 41 This should be blank unless this location is one of several feeders serving the same EDCM customer Page 4 42 43 lf an EDCM customer is served by several locations feeders then a chain linked list of these locations must be established through the linked location field The chain linked list should be uni directional and not circular For example take a chain linked list with three linked locations A B and C One of these locations should be selected as the first link in the chain If the first location is A then one of either Location B or location C let s say B should be entered as the linked location for location A The third location in this case C should be as the linked location for location B Location C should not have a linked location entered against it Local charge
9. 506 of the CDCM model 1131 Assets in CDCM model from CDCM table 2705 132 This is the MEAV of assets at each network level to be used to allocate allowed revenue for demand scaling 133 These figures can be taken from table 2705 of the CDCM model The data in table 1120 of the CDCM model should not be entered in this table as they relate to a hypothetical 500 MW of load at each network level not to the actual CDCM loads they also exclude service model assets which are included in table 2705 1132 Override notional asset rate for 132kV HV kW 134 This cell should be left blank or VALUE if the cell corresponding the 132kV HV network level in the previous table 1131 has a value entered 135 Otherwise this table should contain the kW notional asset rate that should be used in the model for the 132kV HV network level DNOs should enter an appropriate estimate in view of the rates for the 132kV EHV and EHV HV network levels in table 4102 in the FCP and LRIC versions 136 If table 1131 and 1132 both contain values for the 132kV HV network level the number in table 1132 would be used 1133 Maximum network use factor 137 This table contains the caps for the network use factors at different network levels These caps are common across all DNO areas Page 15 138 The caps for each network level calculated using the current EDCM methodology are set out in table 2 below These caps may change following changes to the
10. Manual for the EDCM2 model Combined demand and generation input data 15 January 2013 Model version r5247 FCP and r5248 LRIC OVETVIEW aceon Pr SO eo ee 1 Input data sheets and tables ccccccssseeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeseneeeeeeeeeeeeeeesesseeeeneeeeeeeeenenees 3 911 FCP power flow modelling data sss sese 3 913 LRIC power flow modelling data sss sss 4 935 Tariff inputdata isre a e A aAa eis ed teen taeeteduenteoltanediad 5 1100 Company name charging year and version sse eee eee eee eee 13 1105 Diversity allowance between level exit and GSP Group from CDCM table 2611 13 1113 elz eae CTT 12 1122 Forecast system simultaneous maximum load kW from CDCM users from DIG Malle 2 0G S nee ea Z Set TRA taeda Mas dead eae ease Meares 15 1131 Assets in CDCM model from CDCM table 2705 0 0 sss 15 1132 Override notional asset rate for 132KV HV L KW ee 15 1133 Maximum network use factor eee 15 1134 Minimum network use faCtOl ccccceeeeeeeeeeeeeeeeeeeeeeeeeeeeeseeeeeeeeseeeeeseeeeeeeeeeeeees 16 1135 Loss adjustment factor to transmission for each network level from CDCM table 2004 aa TTT 16 MEAKA EBIN Oo TAOL A e A PREE EEEE EAE T AA EE T AN ET 16 1182 CDCM Grid user tariff Sissid eenei ad aean ede aed adie 17 1183 LDNO volume data 17 4601 Horizontal Information 17 Overview 1 This is a user manual for the input data tables of the combined model implementing the EHV distribut
11. TNAa is the total adjusted site specific assets kVA for that demand user defined earlier NR rate is the network rates charge rate in per cent See methodology statement for how this is calculated DOC rate is the direct operating costs charge rate in per cent See methodology statement for how this is calculated Second for each EDCM user calculate the revenue year associated with import super red tariffs on the basis of super red tariffs set at the level prior to the adjustment that is made if the EDCM import capacity charge p kVA day is negative This is calculated as Super red demand charge pre adjustment year FCP LRIC super red rate in p kWh Super red hours Hours in super red for which not a customer Peak time kW divided by kVA capacity Maximum import capacity kVA 100 where FCP super red rate in p kWh is the super red rate prior to rounding and the adjustment made in the case that the EDCM import capacity charge p kVA day is calculated to be negative prior to it being set t o zero the adjustment to the super red rate is described above See methodology statement for how the other terms are calculated Third for each EDCM user calculate two blocks of revenue first the sum of revenue associated with the import capacity fixed adder charge the indirect costs capacity charge the FCP LRIC local capacity charge and the transmission exit capacity charge second the revenue associat
12. at a voltage of 22 kV or more but less than 132 kV not at a substation fed from a substation whose primary side is attached to a 132 kV distribution circuit Point of common coupling at a voltage of 22 kV or more but less than 132 kV not at a substation fed from a substation whose primary side is attached at 132 kV to a co located GSP with no use of any 132 kV circuits Point of common coupling at a voltage of 22 kV or more but less than 132 kV fed from a GSP with no intermediate transformation Point of common coupling at a voltage of less than 22 kV on the secondary side of a substation where the primary side is attached at 132 kV to a co located GSP with no circuit Page 8 75 76 Category 0002 Category 1001 Category 0011 Category 0111 Category 0101 Category 1101 Category 1111 Point of common coupling at a voltage of less than 22 kV on the secondary side of a substation where the primary side is attached at 22 kV or more but less than 132 kV to a co located GSP with no circuit Point of common coupling at a voltage of less than 22 kV on the secondary side of a substation whose primary side is attached to a 132 kV distribution circuit Point of common coupling at a voltage of less than 22 kV on the secondary side of a substation whose primary side is at a voltage of 22 kV or more but less than 132 kV fed from a GSP with no intermediate transformation Point of common coupling at a voltage of le
13. ation to demand that is charged to this tariff 90 This column should be set to 0 5 if the tariff relates to an end user connected to an LDNO s network and 1 otherwise Capacity subject to DSM GSM contraints kVA 91 This is that element of the customers maximum import capacity that would be subject to constraints under a demand side management DSM 92 For example if the customer has a maximum import capacity of 50 MVA and an agreement exists so that the customer may be constrained to 20 MVA the column should set to 30 MVA 93 This is zero if no DSM agreements would be in place in the charging year Super red units exported kWh 94 This column contains the forecast active power generation over the super red time band Capacity eligible for GSP generation credits kW 95 This column contains the forecast export capacity kW that would be eligible for transmission connection exit credits to generaton 96 This should be zero unless the customer has an agreement with the DNO the terms of which require the generator for the purposes of P2 6 compliance to export power during supergrid transformer SGT outage conditions Proportion eligible for charge 1 credits 97 98 This column should be set to 1 for non intermittent generation and 0 for intermittent generation 99 In the case of a site with a single meter and intermittent and non intermittent generation on site this should be set to 1 100 For the p
14. customer associated with the tariff that a is subject to use of system charges and b had connected before 1 April 2005 61 If you do not want to calculate a full set of export charges for a particular tariff for example a demand only tariff please enter the text string VOID in this column Any other entry including blank or zero will result in export charges being calculated and displayed for this tariff Non exempt 2005 2010 export capacity kVA 62 This column should contain the export capacity in kVA the customer associated with the tariff that a is subject to use of system charges and b had connected on or after 1 April 2005 but before 1 April 2010 Page 6 63 If you do not want to calculate a full set of export charges for a particular tariff for example a demand only tariff please enter the text string VOID in this column Any other entry including blank or zero will result in export charges being calculated and displayed for this tariff Non exempt post 2010 export capacity kVA 64 65 66 This column should contain the export capacity in kVA the customer associated with the tariff that a is subject to use of system charges and b had connected on or after 1 April 2010 This column should include any capacity that is forecast to connect during the charging year If you do not want to calculate a full set of export charges for a particular tariff for example
15. d the two years immediately preceding the charging year using a modified version of the formula in paragraph 11 6 of the Electricity Distribution Licence CRC11 1 Special Conditions of the Electricity Distribution Licence 31 March 2010 Available from http Awww ofgem gov uk Networks ElecDist PriceCntrls DPCR5 Documents1 CRCs 20master 20merged pdf Page 14 126 To calculate the adjusted GP the term GPX is replaced by the term GPS in the formula in paragraph 11 6 Both GPX and GPS are defined in paragraph 11 7 of the same document GL term from the DG incentive revenue calculation year 127 This should contain the GL term used to calculate the DNO s DG incentive revenue 128 GLis the incentive revenue in the charging year in respect of DG connected between 2005 and 2010 calculated for the charging year as in paragraph 11 10 of the Special Conditions of the Electricity Distribution Licence CRC11 Total CDCM generation capacity 2005 2010 kVA 129 This is the sum of the export capacities of all non exempt CDCM generators in the DNO area that connected on or after 1 April 2005 but before 1 April 2010 Total CDCM generation capacity Post 2010 kVA 130 This is the sum of the export capacities of all non exempt CDCM generators in the DNO area that connected on or after 1 April 2010 1122 Forecast system simultaneous maximum load kW from CDCM users from CDCM table 2506 131 These figures can be taken from table 2
16. ed with the import capacity direct operating cost charge the network rates charge and the asset based scalar charge Page 19 156 157 158 Charge from Block 1 year Single fixed adder in p kVA day Indirect costs charge in p kVA day FCP p kVA day capacity charge Transmission exit charge p kVA day Maximum import capacity kVA DC Days for which not a customer 100 Charge from Block 2 year Asset based residual revenue charges in p kVA day DOC rates charge in p kVA day Network rates charge in p kVA day Maximum import capacity kVA DC Days for which not a customer 100 where Terms are as defined earlier Fourth for each EDCM user define a term denoted by Ratio which takes the value of 1 except where the sum of Charge from Block 1 year Charge from Block 2 year and Super red demand charge pre adjustment year is negative In that case the value of Ratio is calculated as Ratio Charge from Block 1 year Super red demand charge pre adjustment year Charge from Block 2 year Fifth use the computed Ratio to calculate adjusted values for the asset based direct operating costs and network rates charges Adjusted asset based residual revenue charges in p kVA day Asset based residual revenue charges in p kVA day Ratio Adjusted network rates charge in p kVA day Network rates charge in p kVA da
17. harge to demand users connected to that network group and a credit to non intermittent generation users connected to that network group Not used Previously Charge 2 kVA year 23 Data in this column are not used Maximum demand run load kW 24 This is the total relevant active power consumption in kW in the maximum demand scenario 25 This number is always zero or negative Maximum demand run load kVAr 26 This is the total relevant reactive power consumption in kVAr in the maximum demand scenario 27 This number is negative if the current calculated for demand lags its voltage Page 3 Maximum demand run generation kW 28 This is the total relevant active power generation in kW in the maximum demand scenario 29 This number is zero or always positive Maximum demand run generation kVAr 30 This is the total relevant reactive power generation in kVAr in the maximum demand scenario 31 This number is positive if the current calculated for demand lags its voltage Not used Previously Minimum demand run load kW 32 Data in this column are not used Not used Previously Minimum demand run load kVAr 33 Data in this column are not used Not used Previously Minimum demand run generation kW 34 Data in this column are not used Not used Previously Minimum demand run generation kVAr 35 Data in this column are not used 913 LRIC power flow modelling data 36 Sheet 9
18. ion charging methodology EDCM for import tariffs and export tariffs connected to electricity distribution networks in Great Britain 2 This version is consistent with the model versions r5247 FCP and r5248 LRIC Sheets 3 Sheets in the workbook have been given short abbreviated names This is to make the best use of screen space given the way in which Microsoft Excel displays information Tables 4 Each sheet is structured as a list of data tables to be read from top to bottom like a book 5 Each data table has a three or four digit table number Numbers that start with 9 or 11 are assigned for input data tables are their numbers do not change from version Page 1 to version of the model Other table numbers are assigned tables that carry out intermediate calculations or present the resulting tariffs Hyperlinks in the workbook 6 The Forward and Back buttons on Microsoft Excel s Web toolbar can be useful when navigating around the workbook using these hyperlinks For example to go back to where you were before clicking a hyperlink use the Back button To show the Web toolbar in Microsoft Excel 2000 2004 select Web from Toolbars from the View menu details may vary depending on the Excel version The Web toolbar has been removed from Microsoft Excel 2007 but the Back and Forward buttons can be added to the Quick Access Toolbar instead Links do not work well if the model is displayed within a web browser T
19. kdowns use charging rates before rounding Three of these eight components can be calculated directly from terms derived earlier Sole use asset charge year Demand fixed charge p day unrounded DC Days for which not a customer 100 Transmission exit charge year Transmission exit charge p kVA day 100 UDC Days for which not a customer Maximum import capacity kVA Demand scaling fixed adder year Single fixed adder in p kVA day 100 UDC Days for which not a customer Maximum import capacity kVA where DC is the number of days in the charging year an input data Demand fixed charge p day is not rounded Transmission exit charge p kVA day is the transmission exit charge applied to demand tariffs defined earlier Page 18 152 153 154 155 Single fixed adder in p kVA day is the charge associated with the fixed adder defined earlier Other terms are as defined earlier The remaining five components are calculated following a series of preliminary computations First calculate an import capacity based charge associated with direct operating costs and one associated with network rates that is expressed in p kVA day for each EDCM demand user These charges are calculated as Network rates charge in p kVA day 100 DC TNAa NR rate DOC rates charge in p kVA day 100 DC TNAa DOC rate where DC is the number of days in the charging year
20. lumn contains a forecast for each customer that should be calculated using historical net reactive power import reactive import minus reactive export and agreed import capacity for that customer Historical refers to the last full regulatory year for which data are available If peak time RI RE denotes net reactive power import for each half hour in the super red time band in kVArh and average kVA is the average of the agreed import capacity over the last regulatory year for which data are available then the formula for this item is Sum peak time RI RE Super red hours average kVA In the case of sites with both import and export only reactive flows in half hours with active power import are taken into account If the DNO considers that the reactive consumption data relates to export rather than import e g the average kVAr figure exceeds half of the import capacity then the import capacity in the denominator should be replaced by the export capacity of the same customer In the case of import tariffs associated with a site which operates subject to grid code requirements for generation this ratio should be set to zero If the customer is new or its circumstances have changed since the last regulatory year for which data are available an estimate of the current value should be entered Page 11 Proportion exposed to indirect cost allocation 89 Data in this column determines the proportion of the indirect cost alloc
21. o get the full functionality save the model as a file and open it in Microsoft Excel or compatible software Technologies and dependencies 9 10 11 The model is implemented as a stand alone Microsoft Excel workbook in Excel 2007 file format No software other than Microsoft Excel 2007 or above or compatible software is needed to operate the model The model relies on standard spreadsheet formulae It does not use any macros Visual Basic for Application pivot tables solver goal seek or array formulae The workbook is produced by a computer programme in the programming language Perl 5 This programme can be run on a personal computer or as a web service and can generate versions of the models with different tariffs or allocation rules Overview sheet 12 The overview sheet Overview lists the data tables in the workbook Input sheets 13 14 In the EDCM model there are two types of input data tables a Some input tables are long database style tables These have a number between 900 and 999 and are on a worksheet of their own to facilitate copy paste operations b Some input tables are like CDCM input data tables They are given a number between 1100 and 1199 and appear on sheet 11 The input data sheets have numerical names a Sheet 11 contains all the input data tables with a number starting 11 b Sheet 911 FCP models only contains table 911 only FCP location data c Sheet
22. r year Import charge in previous charging year year Change demand year Annual demand charge year Import charge in previous charging year year Change demand Annual demand charge year Import charge in previous charging year year 1 Page 17 149 150 151 Total for generation year Capacity charge for generation year Fixed charge for generation year Super red credit year Export charge in previous charging year year Export charge in previous charging year year Change generation year Net annual generation charge credit year Export charge in previous charging year year Change generation Net annual generation charge credit year Export charge in previous charging year year 1 The Total for demand year can be allocated into the following set of components before rounding a Fixed charge for demand unrounded year Transmission exit charge year Direct cost allocation year Indirect cost allocation year Network rates allocation year FCP LRIC charge year Demand scaling fixed adder year Demand scaling asset based year The text below describes how each of these eight components are calculated In all cases they draw on terms calculated as described in the methodology statement It is important to note that these brea
23. r short identifier This is for labelling purposes and does not affect any calculations LLFC export 108 This is the line loss factor class for the export tariff or any other short identifier This is for labelling purposes and does not affect any calculations 1100 Company name charging year and version 109 The input data entered in the three boxes in table 1000 will be reproduced at the top of each sheet in the workbook 1105 Diversity allowance between level exit and GSP Group from CDCM table 2611 110 These allowances should relate to the diversity all the way from the lower voltage end of each network level and the DNO s GSP Group licence area 111 The relevant figures are calculated within the CDCM model In model 100 they can be found in table 2611 1113 General inputs 112 This table contains miscellaneous parameters that are used in the calculation of charges Days in year 113 This cell should contain the number of days in the charging year This number is used to calculate daily charging rates Page 13 O amp M charging rate based on FBPQ data kW year 114 Under the proposed methodology this parameter is to be set at 0 20 Annual hours in super red 115 This is the total number of hours in the DNO s super red time band The amount of money that the DNO wants to raise from use of system charges less transmission exit year year 116 This is the amount of money that the DNO
24. ss than 22 kV on the secondary side of a substation whose primary side is at a voltage of 22 kV or more but less than 132 kV fed through a distribution circuit from a substation whose primary side is attached at 132 kV to a co located GSP with no circuit Point of common coupling at a voltage of less than 22 kV on the secondary side of a substation whose primary side is at a voltage of 22 kV or more but less than 132 kV fed from the secondary side of a co located substation whose primary side is attached at 132 kV to a co located GSP with no circuit Point of common coupling at a voltage of less than 22 kV on the secondary side of a substation whose primary side is at a voltage of 22 kV or more but less than 132 kV fed from the secondary side of a co located substation whose primary side is attached to a 132 kV distribution circuit Point of common coupling at a voltage of less than 22 kV on the secondary side of a substation whose primary side is at a voltage of 22 kV or more but less than 132 kV fed through a distribution circuit from a substation whose primary side is attached to a 132 kV distribution circuit All references to GSP in the table above relate to interconnections with the main interconnected onshore transmission network The figure overleaf provides examples of customers who might be placed in each of the categories described above Page 9 Customer Categories 400 or 275kV GSP A G AN Ld
25. ts if available This should be left as VALUE if no data is available This table is only used to calculate forecast LDNO revenues It is not used for the calculation of tariffs Horizontal information This table is for information only and is not used for the calculation of tariffs Annual charges associated with the components of the demand and generation tariffs and measures of usage are calculated as Capacity charge for demand year Import capacity charge p kVA day DC Days for which not a customer Maximum import capacity kVA 100 Super red charge for demand year Super red unit charge p kWh Super red hours Hours in super red for which not a customer Peak time kW divided by kVA capacity Maximum import capacity kVA 100 Fixed charge for demand year Demand fixed charge p day DC Days for which not a customer 100 Net capacity charge or credit for generation year Net export capacity charge p kVA day DC Days for which not a customer non exempt export capacity 100 Fixed charge for generation year Generation fixed charge p day DC Days for which not a customer 100 Super red credit year Generation credit p kWh Super red units exported kWh 100 Total for demand year Super red charge for demand year Fixed charge for demand year Capacity charge for demand year Import charge in previous charging yea
26. urposes of the EDCM intermittent generators are those that have been assigned an F factor of 0 in the power flow analysis following the method described in paragraphs 32 36 page 553 of Schedule 17 FCP and 43 32 page 677 of Schedule 18 LRIC of the DCUSA All other generators are deemed to be non intermittent Days for which not a customer 101 This column should be zero for customers who are expected to remain connected for the whole charging year Page 12 102 For customers who are expected to be connected for part of the year this column should contain the number of days in the charging that the customer is not connected Hours in super red for which not a customer 103 This column should be zero for customers who are expected to remain connected for all the hours in the DNO s super red time band 104 For customers who are expected to be connected for part of the year this column should contain the number of hours in the super red time band that the customer is not connected Import charge in previous charging year year 105 This column contains the total import use of system charge that would have been paid by the customer over the charging year Export charge in previous charging year year 106 This column contains the total export use of system charge that would have been paid by the customer over the charging year LLFC import 107 This is the line loss factor class for the import tariff or any othe
27. wants to raise from use of system charges less transmission exit year for the charging year 117 This is to be calculated by adding up the numbers in the first three columns of table 1076 of the CDCM model 100 and then subtracting the transmission exit charge table 1055 of the CDCM model 100 Transmission exit charges year 118 This is the total forecast annual expenditure on transmission connection point charges This number can be taken from table 1055 of the CDCM model 100 Direct cost year 119 This is the total direct operating costs across the network relating to inspection and maintenance including tree cutting and direct operating costs on faults 120 This number can be obtained from table 1059 of the CDCM model 100 Indirect cost year 121 This is the total indirect costs across the network This number can be obtained from table 1059 of the CDCM model 100 Network rates year 122 This is the total business rates network rates payable by the DNO in the charging year This number can be obtained from table 1059 of the CDCM model 100 Average adjusted GP year 123 This should contain the average adjusted GP year calculated as set out in the proposed EDCM for DG 124 The average adjusted GP is the average of the values of adjusted GP for the charging year and each of the two years immediately preceding the charging year 125 The adusted GP is calculated for the charging year an
28. y Ratio Adjusted DOC rates charge in p kVA day DOC rates charge in p kVA day Ratio where Terms are as defined earlier Sixth using the set of terms just derived calculate the remaining five components as Direct cost allocation year Adjusted DOC rates charge in p kVA day DC Days for which not a customer Maximum import capacity kVA 100 Network rates allocation year Adjusted network rates charge in p kVA day UDC Days for which not a customer Maximum import capacity kVA 100 Indirect cost allocation year Indirect costs charge in p kVA day DC Days for which not a customer Maximum import capacity kVA 100 Demand scaling asset based year Adjusted asset based residual revenue charges in p kVA day DC Days for which not a customer Maximum import capacity kVA 100 FCP LRIC charge year FCP LRIC p kVA day capacity charge DC Days for which not a customer Maximum import capacity kVA 100 Super red demand charge pre adjustment year Page 20 159 Check is the difference between Total for demand year and the sum of the eight components listed This is an estimate of the effect of rounding on forecast charges Check year Total for demand year Direct cost allocation year Network rates allocation year FCP charge year Indirect cost allocation
29. year Sole use asset charge year Transmission exit charge year Demand scaling fixed adder year 4602 Total for all tariffs 160 This table reports the following a Total for demand across all tariffs year is the sum across all EDCM tariffs in the model of the numbers reported in the column titled Total for demand year in table 4601 b Total for generation across all tariffs year is the sum across all EDCM tariffs in the model of the numbers reported in the column titled Total for generation year in table 4601 c Total for all tariffs year is the sum of the numbers reported in the first two columns of this table 4701 Total EDCM revenue year 161 This table reports the sum of the following a the value reported in the column titled Total for all tariffs year in table 4602 and b the value reported in table 6004 Total net revenue from discounted LDNO tariffs year Page 21
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