CDCM User Manual – May 2012
Contents
1. Page 24 of 36 DRM Network model 173 This sheet derives unit costs form the 500 MW network model as outlined in table 2 Table 2 Network model DRM calculations 2101 Annuity rate This calculates the annuity rate to be used throughout the model 2102 Loss adjustment factors to transmission for each core level loss adjustment 2103 factors These two tables are used to reshape the loss adjustment factor table provided as input data 2104 Diversity calculations This cumulates the non cumulative diversity allowances entered as input data 2105 Network model total maximum demand at substation MW Network model 2108 contribution to system maximum load measured at network level exit MW Rerouteing matrix for DRM network levels GSP simultaneous maximum load assumed through each network level MW These tables estimate the simultaneous maximum load for each network level which the 500 MW model is designed to accommodate 2109 Network model annuity by simultaneous maximum load for each network level kW year This converts asset costs into unit annual costs kW year based on system simultaneous maximum load at each network level SM Service models 174 Table 3 outlines the calculations performed on service model data in the SM sheet Table 3 Service models SM calculations 2201 Asset customer from LV service models This calculates the average asset values by tariff from LV service models 2202 Asset M2. This calculates demand coefficients for demand users Load coefficient This combines the calculated demand coefficients with assumed load coefficients of 1 for generation Discount map This maps each tariff on the relevant LDNO discount percentage LDNO discounts and volumes adjusted for discount This calculates notional volumes adjusted for LDNO discounts which are used throughout the modelling of all the way charges Equivalent volume for each end user This aggregates the adjusted volume forecasts by end user type Multi Load characteristics for multiple unit rates 177 178 This sheet uses peaking probabilities and data on load patterns in order to calculate p kWh charges by time period The calculation uses distribution time bands These do not need to be the same as the charging time periods There are up to three distribution time bands this can be changed at model build time Page 26 of 36 Table 5 Load characteristics for multiple unit rates Multi calculations 2401 Adjust annual hours by distribution time band to match days in year This adjusts the number of annual hours by distribution time band provided on the Input sheet to ensure that it agrees with the number of days in the charging year 2402 Split of rate 1 3 units between distribution time bands 2406 These tables combine user input for TPR based tariffs with constant values for tariffs based on distribution time bands Values
3. User manual for CDCM Model 100 end May 2012 revision 3275 energynetworks association energynetworks org Contents OVEN An E T E AT OE E TO 3 Guidance on asset modelS ssssssnnnnensennnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnnn nnmnnn nnmnnn 7 General costing guidance for asset MOCEIS ccceeeeeeeseecnceeeeeeeeeeeeeceaaaeeeeeeeeesesenaaaeeeeeees 9 Network mod l een eei ED ER RE GREER E RAE ERRE A ERRE RA EAE A ERR 9 SeicSmodels 5 Hit susan A aaa a en ne met be a a n E 11 Input data tables gles neniarn PE Pre To TP aoaaa rte ene 15 1000 Company name charging year and model VErSiON cccceeeeeeeeeeeteeeeeeeeeeeeeeeetaaees 15 1010 Financial and general ASSUMPTIONS cece cette eeeeeeee eee eter ee eeecaaeeeeeeeeeeeeeeeaaees 15 1017 Diversity allowance between top and bottom of network level ccceeeeeeeeeeees 15 1018 Proportion of relevant load going through 132kV HV direct transformation 16 1019 Network model GSP demand MW ccceeeeeeeeeeeeeeceeeeeeeeeeesenaaeaeeeeeeeeeeeensaaaaes 16 1020 Gross asset cost by network level c cccceeeeeeeeeeeececeeeeeeeeeeesenaaeeeeeeeeeeeeenesaaaaes 16 1022 LV service model asset cost cc siccesicvesiedsc chicas Heveceedscch qet idee teedeaauire Hdewqehss ee qetiece 16 1023 HV service model asset cost a2 c22sen ee tne el ee eee aes 16 1025 Matrix of applicability of LV service models
4. CDCM target net revenue will be calculated in the model as a plus b plus c minus d To run the CDCM model for a mid year price change leave the number of days in the charging year in table 1010 unchanged and use the following procedure a Estimate net CDCM revenue forecast to accrue within the first half and within the second half of the year if current tariffs were continued Denote these forecasts R1 and R2 Unless volume forecasts have changed since tariffs were set R1 R2 will be equal to the net CDCM target revenue used to set tariffs b Produce an updated estimate of net CDCM revenue including K factor net of revenue outside the model etc for the whole year Denote this NTR c Populate the CDCM model with latest data for all inputs and with the following CDCM target revenue figure NTR R1 R2 R1 R2 The result of that calculation should be entered in the first column of table 1076 and all other columns in table 1076 should be set to zero for this purpose Page 22 of 36 1092 167 168 169 1201 170 Average kVAr by kVA by network level This table contains the average value of SQRT 1 PF 2 where PF stands for power factor or of the absolute value of the reactive power flow divided by the total kVA for network assets at different network levels These data need to be extracted from an analysis of similar data as peaking probabilities Data availability permitting the val
5. AGO Call ON saen E E EE EEE E aed eee aes 34 Revenue Revenue shortfall or SUPPIUS 2 0 0 0 2c cece ee eeeenee etter eee teeeeaeeee eee ee eetececaaeeeeeeeeeeteea 34 Scaler Revenue matching ccccecceceeeseeeceeeeeeeeeeeeeeeeaaeaeeeeeeeeteesncaaaaeeeeeeeeesssnsaaaeeeeeees 35 Adjust Tariff component adjustment and rounding ccccccceceeeeceeeeeeeeeeeeeeeeeeeeeeeeeeeseeeess 36 Page 2 of 36 Overview 1 This user manual accompanies the spreadsheet model that is used to implement the Common Distribution Charging Methodology CDCM for electricity distribution networks in Great Britain the CDCM Model The CDCM is contained within Schedule 16 of DCUSA and the current model version number is referred to in paragraph 3 of Schedule 16 This user manual is based on version 100 of the model which was published on 1 April 2010 The CDCM model may be updated following a DCUSA change proposal Users of the CDCM Model should check that they are using the most up to date version of the model by checking the current version of DCUSA at the DCUSA website http Avww dcusa co uk Public DCUSADocuments aspx s c Figure 1 reproduced from the CDCM statement shows the main steps in the methodology and model Figure 2 gives an overview of relationships between the main elements of the model Figure 1 Overview of main steps and data flows Network model costs Service model costs Load profile
6. i e the boundary point in the case of LDNO tariffs and calculates the additional loss adjustment element used in the Adjust sheet to adjust unit rates on these tariffs 2003 Loss adjustment factor to transmission for each DRM network level This table uses the mapping of DRM network levels to core networks to show the Loss adjustment factor to transmission that corresponds to each DRM network level 2904 Loss adjustment factor to transmission for each network level This table copies the loss adjustment factors provided as input data adding a figure of 1 for the GSP network level for completeness 2005 Network use factors This matrix shows which network levels would be chargeable to which tariffs if 132kV HV direct transformation was not used 2006 Proportion going through 132kV EHV EHV HV HV Rerouteing matrix for all 2010 network levels Network use factors including 132kV HV except for HV Sub These intermediate tables are used to calculate the extent to which costs for 132kV EHV EHV EHV HV and or 132HV HV are attributable to each tariff 2011 Network use factors including 132kV HV This matrix shows which network levels are chargeable to which tariffs taking account of 132kV HV 2012 Loss adjustment factors between end user meter reading and each network level scaled by network use This matrix combines network use factors and loss adjustment factors to enable the allocation of charges for each network level to each tariff
7. row relates to diversity between the GSP Group and individual grid supply points The figure in the 132kV row in England and Wales only relates to diversity between a grid supply point and the 132kV EHV bulk supply points under it It is labelled 132kV because it is the diversity between the top and the bottom of the 132kV network The figure in the EHV row relates to diversity between a 132kV EHV bulk supply point or grid supply point in Scotland and the EHV HV primary substations under it The figure in the HV row relates to diversity between a EHV HV primary substation and the HV LV substations under it These diversity allowances should be entered in a non cumulative basis The model cumulates them as necessary see the DRM sheet Insofar as the network topology and substation mix of the 500 MW model differs from the network topology and substation mix of the actual network diversity allowances relate to the 500 MW model Proportion of relevant load going through 132kV HV direct transformation The single cell in this table contains the percentage of the loads at HV LV Sub or LV load which is supplied through direct 132kV HV transformation Leaving this cell blank signifies that 132kV HV is not used in the 500 MW model Network model GSP demand MW The single cell in this table should be set to the figure of 500 corresponding to the 500 MW specified in the methodology statement Gross asset cost by ne
8. 25 DNOs can modify charges to customers at any time but Section 19 1 of DCUSA stipulates that DNOs should use reasonable endeavours to modify charges no more than twice a year and to use reasonable endeavours to vary charges from the effective date of 1 April or the 1 October The issue of charges follows a timetable which is set down in SLC 14 11 Under this licence condition DNOs are required to give 3 months notice for indicative charges and under section 19 1 of DCUSA 40 days notice for final charges The charges can only change between indicative and finals to the extent that the DNO identifies they contain assumptions when they issue indicatives that may change prior to the issue of the final charges The review and issue of the CDCM model will follow the timetable outlined above All of the inputs into the CDCM model will be reviewed once a year prior to the issue of charges for the 1 April For a mid year tariff change DNOs are able to review and modify any of the CDCM inputs However as a general guideline the table below shows which inputs would typically be modified as part of a mid year tariff review CDCM Input data table Reviewed for 1st April Tariff Reviewed for Mid Year Tariff Change Change 1000 Ni Company charging year data version 1010 N Financial and general assumptions 1017 Diversity allowance between top and bottom of network level 1018 Proportion of rel
9. CDCM target revenue used to set tariffs b Produce an updated estimate of net CDCM revenue including K factor net of revenue outside the model etc for the whole year Denote this NTR c Populate the CDCM model with latest data for all inputs and with the following CDCM target revenue figure NTR R1 R2 R1 R2 The result of that calculation should be entered in the first column of table 1076 and all other columns in table 1076 should be set to zero for this purpose Diversity allowance between top and bottom of network level Up to four figures are to be entered in this table They are in the rows labelled GSP 132kV EHV and HV The other cells in this table should be left blank or so to zero In Scotland the 132kV figure should also be left blank or set to zero Each figure is a diversity allowance expressed as a percentage It represents the extent to which aggregate maximum load across a set of substation sites exceeds the maximum of the total flow through these sites Page 15 of 36 99 100 101 102 103 104 105 1018 106 1019 107 1020 108 109 1022 110 1023 111 These diversity allowances are expressed as percentages relative to a value of zero to indicate no diversity The diversity allowance is the extent to which some aggregate maximum load exceeds the corresponding maximum of the aggregate load The figure in the GSP
10. December each year based on the CDCM model used to derive indicative charges If the CDCM model is amended between indicatives and finals the ARP will also be updated and published 40 days prior to when the charges take effect The ARP is only published once a year for charges that apply from 1 April DNOs are not obliged to produce an ARP if charges are amended at other times of the year The ARP is a Excel spreadsheet that contains the following a A 5 year forecast of the CDCM inputs which are used to derive tariffs The first year will be the actual values used by the DNO to derive indicative or final charges from the following April The subsequent years will be a forecast of the CDCM inputs by the DNO The ARP contains CDCM input sheets for each year that match the CDCM input sheet and can be directly copied into the CDCM model b Historical CDCM input data for a minimum period of three years c The ARP contains a macro that can be run to produce tariffs and typical bills for each of the 5 years This data is provided to assist customers suppliers and any other stakeholders in forecasting longer term Distribution Use of System Charges for HV and LV customers d Within the ARP the DNO provides a RPI forecast which will be linked to any of the CDCM inputs which the DNO believes are related to RPI This is to enable users of the annual review pack to update the RPI forecast and for it to automatically update the appropriate CDCM
11. Forecast simultaneous maximum load 179 This sheet uses demand forecasts and load characteristics to forecast system simultaneous maximum load at each network level Page 27 of 36 Table 6 Forecast simultaneous maximum load SMD calculations 2501 Contributions of users on one two three rate multi tariffs to system 2503 simultaneous maximum load by network level kW This performs a similar calculation as in table 2501 but taking account of information by rate or by distribution time band for tariffs where such information exists 2504 Estimated contributions of users on each tariff to system simultaneous maximum load by network level kW This combines load characteristic data volume forecast data and network use factors to determine the contribution of each tariff to system simultaneous maximum load disregarding any time band information 2505 Contributions of users on each tariff to system simultaneous maximum load by network level kW This combines tables 2501 to 2504 giving an estimated contribution to system simultaneous maximum load for each tariff that matches the basis single rate or multiple rates on which charges for that tariff are calculated 2506 Forecast system simultaneous maximum load kW from forecast units This aggregates the data in table 2505 so as to give forecasts of system simultaneous maximum load for each network level AMD Forecast aggregate maximum load 180 This sheet compiles inf
12. and indirect costs can be obtained from the 2007 2008 to 2009 2010 editions of the RRP as follows a Direct operating costs including some statutory depreciation on non operational assets are in table 2 2 cells L184 and M184 except for direct operating costs on faults which are in table 2 3 cells 138 and K38 Any statutory depreciation on non operational assets related to the faults activity entered in table 2 2 cell K166 is to be apportioned between faults operating and capital expenditure b Indirect operating costs including some statutory depreciation on non operational assets are in table 2 2 cell AD184 Depending on how the data has been reported some or all of table 2 2 cell J166 might need to be added to capture all statutory depreciation on non operational assets Historical information about network rates is in table 1 3 of the 2007 2008 to 2009 2010 editions of the RRP column AG Historical data should only be used for comparison purposes 1060 Customer contributions under current connection charging policy This table provides for each combination of user network level and asset network level the proportion of assets that are deemed to be covered by customer contributions under the current connection charging policy Page 19 of 36 142 143 144 145 146 147 148 149 Further information on the determination of these proportions is provided in the guidance section of this document In or
13. potentially shareable Small Non Domestic Two Rate 73 This service model relates to the building a new typical supply for a profile class 4 customer This will often be the same as for Small Non Domestic Unrestricted Small Non Domestic Off Peak related MPAN 74 The guidance given under Domestic Off Peak related MPAN applies to service models for this tariff LV Medium Non Domestic 75 This service model relates to the building of a new typical supply for a profile class 5 8 customer 76 As the customer will be non half hourly metered the capacity of the connection need not exceed 100 kW 77 Provision for current transformers used for metering purposes should be included in the service model No metering costs should be included these relate to the metering activity and not the distribution activity 78 Only cables on or very near the customer s land should be included in the service model Longer cables installed to connect to an existing mains are potentially shareable and therefore part of the network model LV Sub Medium Non Domestic 79 The typical customer for this tariff which must be under 100 kW as it is non half hourly metered is a legacy site in a remote area or a site which is no longer operating at the capacity for which it was designed 80 The guidance under LV Sub HH Metered applies to this service model LV HH Metered 81 This service model relates to the building of a new typical supply
14. rating substations supplying a 33kV interconnected ring would be considered able to supply an aggregate load of 156 MVA calculated as twice the emergency flow of 78 MVA At EHV including primary substations no additional capacity should be included in the hypothetical incremental network on account of geographical dispersion of loads a sufficient range of substation sizes should be included in the model to ensure that this is a reasonable assumption At HV and LV the estimated utilisation in the hypothetical incremental network should take account of geographical dispersion of loads and the use of standard size equipment A sample of maximum loads from substations on the network may be used to estimate utilisation as the aggregate maximum load divided by the aggregate of the smallest standard substation size that will accommodate each load in the sample In the absence of other information utilisation rates of assets in the network or assumed utilisation rates in recent extensions to the network may be used to inform the assumptions made Such evidence must not be used if doing so would conflict with the requirement not to include additional capacity to cater for future growth Circuit lengths in the hypothetical incremental network depend on the geographical distribution of loads and on the geographical distribution of substations Data on circuit lengths from the actual network may be used to inform these assumptions provided that app
15. should be entered as the cost of the five house rural scheme and the cost of the 20 house urban scheme and table 1025 should have in the domestic unrestricted row 2 10 5 against the rural scheme and 4 5 90 20 against the urban scheme Domestic Two Rate 67 68 The supply should reflect the way in which Domestic Two Rate customers are supplied in the relevant GSP Group This will usually be the same as for Domestic Unrestricted although in some areas it might include three phase supplies instead of single phase supplies The other guidance under Domestic Unrestricted applies to Domestic Two Rate Domestic Off Peak related MPAN 69 70 No service model data should be entered for the Domestic Off Peak related MPAN tariff if the same service cable would be used irrespective of whether there is a related MPAN or not lf in a particular GSP Group there is a strong association between having a three phase supply and having a related MPAN then it might be appropriate to treat the additional cost of a three phase supply over a single phase supply as a service model for the Domestic Off Peak related MPAN tariff Small Non Domestic Unrestricted 71 This service model relates to the building a new typical supply for a profile class 3 customer Page 12 of 36 72 Only cables on or very near the customer s land should be included in the service model Longer cables installed to connect to existing mains are
16. 34 of 36 Table 15 Revenue shortfall or surplus Revenue calculations 3401 3402 3403 Net revenues by tariff before matching year This combines the tariff information with volume forecast data For embedded network tariffs the unit rates used at this stage are not adjusted for losses between end user and boundary meter and the volume data used are therefore those that have been adjusted in the Loads sheet Allowed revenue year This puts together the input data on price control allowed revenue Net revenues outside the CDCM model are not netted off at this stage Revenue surplus or shortfall This calculates the desired revenue impact of the revenue matching adjustments to tariffs Net revenues outside the CDCM model are netted off at this stage Scaler Revenue matching 192 This sheet calculates adjustments to tariff components needed for revenue matching Table 16 Revenue matching Scaler calculations 3501 3502 3503 3504 3505 3509 3510 Factor to scale to 1 kW at transmission exit level applicability factor for 1 kW scaler This calculates the factor to be applied to the current transmission exit element of tariff components in order to estimate the impact of a 1 kW year fixed adder at the transmission exit level Scalable elements of tariff components This calculates the extent to which each tariff component for demand tariffs only would vary as a result of a 1 k
17. Loss adjustment factors to transmission This table contains the loss adjustment factors needed to adjust meter readings at each network level up to transmission A single loss adjustment factor is used for each network level even if the loss adjustment factors used in settlement vary by season or time of day or if different loss adjustment factors are set for customers at the same network level Loss adjustment factors should reflect as far as practicable average losses from all sources including commercial losses at the time of distribution system peak Embedded network LDNO discounts These percentages represent the proportion of all the way charges that should be applied to LDNO tariffs for each combination of the boundary network level and end user network level The values for this table should be sourced from the separate price control disaggregation model The disaggregation model will be updated on an annual basis as part of the annual review of CDCM inputs Load profile data for demand users coincidence factor load factor A load factor represents the average load of a user or user group relative to the maximum load level of that user or user group Load factors are numbers between 0 and 1 A coincidence factor represents the expectation value of the load of a user or user group at the time of system maximum load relative to the maximum load level of that user or user group Coincidence factors are numbers between 0 an
18. W year fixed adder Marginal revenue effect of scaler This calculates for each tariff the impact on revenue of a 1 kW year fixed adder Scaler value at which the minimum is breached root if there were no constraints starting point solve a simple linear programming problem general scaler rate This calculates the fixed adder necessary to match the revenue target taking account of the capping of tariff components to zero no negative tariff components allowed for demand Scaler This calculates the adjustment needed to each tariff component to absorb the revenue surplus or recover the revenue shortfall Page 35 of 36 Adjust Tariff component adjustment and rounding 193 194 This sheet rounds tariff elements to the nearest value with no more than three decimal places in the case of unit rates in p kWh and reactive power unit charges in p kVArh and no more than two decimal places in the case of other components These rounding calculations are only applied within the model to all the way charges LDNO tariffs are rounded in the final tariff table through the use of Excel formatting Table 17 Tariff component adjustment and rounding Adjust calculations 3601 3602 3603 3604 3605 3606 3607 Tariffs before rounding This adds up the tariff components before matching the matching element and the loss adjustment element Decimal places This constant table specifies the number of decimal place
19. Wh year from LV service models This calculates the average asset values from LV service models by annual MWh for unmetered tariffs 2203 Service model asset p kWh charge for tariffs for unmetered tariffs This calculates the unit rate uplift needed to recover an LV service model replacement annuity in the case of unmetered tariffs 2204 Asset customer from HV service models This calculates the average asset values by tariff from HV service models Page 25 of 36 Table 3 Service models SM calculations 2205 2206 Service model assets by tariff This collects data on service model asset values per customer for both HV and LV tariffs excluding unmetered tariffs Replacement annuities for service models This converts asset values per MPAN into replacement annuity charges p MPAN day All these values are zero if replacement costs for customer contributed assets are not included in the model Loads Load characteristics 175 176 This sheet collects and combines information about load characteristics of different categories of network users The main output is a load coefficient for each tariff which is set to 1 for generation tariffs and calculated as the ratio of the coincidence factor to the load factor for demand tariffs Table 4 Load characteristics Loads calculations 2301 2302 2303 2304 2304 Demand coefficient load at time of system maximum load divided by average load
20. are normalised to add up to 100 per cent 2407 All units MWh This calculates the total number of units for each tariff 2408 Calculation of implied load coefficients for two three rate users 2409 These tables calculate implied load coefficients from the distribution of units between time bands if there were no correlation between user and system peaking within each distribution time band This assumes that the time of system peak is always in the red time band 2410 Calculation of adjusted time band load coefficients This calculates the factor that needs to be applied to reconcile implied load coefficients from above with actual load coefficients from the Loads sheet 2411 Normalisation of peaking probabilities peaking probabilities by network 2412 level reshaped This table copies the peaking probability data provided by the user normalising the probabilities so that they add up to 100 per cent where they should and reshaping it to match the structure of the calculations on the Multi sheet 2413 Pseudo load coefficient by time band and network level This is what would be used instead of the coincidence factor to load factor ratio to calculate contributions of each network level to charges within each distribution time band 2414 Unit rate 1 3 pseudo load coefficient by network level 2416 This is what needs to be used instead of the coincidence factor to load factor ratio to calculate each unit rate SMD
21. communications equipment that would be generally required for an HV generation connection Page 11 of 36 Domestic Unrestricted 62 63 64 65 66 The supply is a single phase LV supply to a domestic customer The model is priced on the hypothetical basis that services are being built or re built for a whole street as a single planned project not an ad hoc replacement for one isolated user The cost of creating a joint between the LV mains and the LV service cable is included in the service model as are all costs associated with service cables and with any distribution boards No costs associated with the LV mains are included in the service model Because of the requirement to cost the service model on the basis of a single planned project the model will normally include several connections The number of connections in the model is reflected through table 1025 matrix of applicability The percentage figure in that table is the proportion of the cost of the service model that is attributable to each customer For example if the model is for a scheme to connect 20 houses then the percentage is 5 per cent Table 1025 also allows several service models to be averaged For example if 10 per cent of houses are in rural areas where the typical set up is a pole serving five houses and 90 per cent of houses are in urban areas where the typical set up is a length of mains serving 20 houses then the service model costs
22. d 1 The meter and profiling data for the most recent 3 year period for which these data are available in time for use in the calculation of charges must be used to calculate smoothed coincidence and load factors The smoothed inputs are the average of the annual figures calculated for each of the 3 years Page 17 of 36 124 125 126 127 128 129 1053 130 1055 131 The following raw data are required a Half hourly GSP Group take based on CDCA I029 or CDCA I030 data flows under the BSC depending on the licensee s analysis of whether embedded BM Units affect the time properly described as network peak on its network b Half hourly consumption for each half hourly demand customer class aggregated from the D0036 or D0275 data flows c Half hourly allocation of consumption for each combination of non half hourly demand customer class and unit rates e g for domestic unrestricted for the day rate of the domestic two rates tariff for the night rate of the domestic two rates tariff etc This is an aggregate of SPX data from the D0030 data flows d Half hourly GSP Group correction factor available from the ELEXON website GSP group take data are needed to determine distribution time bands and to determine the time of system peak for the calculation of coincidence factors The D0030 has one VMR dataset for each PC LLFC SSC TPR combination The data required for load data anlaysis are th
23. d coefficient for generation tariffs All values in this table are 1 in the current version of the model since load coefficients for generators are set to 1 Pay as you go components p kWh for reactive power absolute value This calculates p kWh yardsticks in absolute value without any deduction for capacity charges since the relevant tariffs are generation tariffs Pay as you go reactive p kVArh This uses the kVAr kVA factor for each network level to convert the p kWh yardstick from tale 3205 into a p kVArh charge element Aggreg Aggregation 190 The Aggreg sheet calculates tariff components by aggregating elements from the sheets described above Table 14 Aggregation Aggreg calculations 3301 3303 3304 3305 3306 3307 Unit rate 1 3 p kWh elements These tables collect unit rate elements from the Yard and Standing sheets Fixed charge p MPAN day elements This collects fixed charge elements from the SM Otex and NHH sheets Capacity charge p kVA day elements This collects capacity charge elements from the Standing sheet Reactive power charge p kVArh elements This collects reactive power unit charge elements from the Reactive sheet Summary of charges before revenue matching This aggregates the elements collected above Revenue Revenue shortfall or surplus 191 This sheet calculates the shortfall or surplus to be recovered or absorbed through revenue matching Page
24. der to determine the customer contribution percentages the following data need to be sourced for a representative selection of network investment schemes a For each network level of supply S and each network level of assets A the amount of capital expenditure on new assets excluding any asset replacement at network level A which are required for new connections for users supplied at network level S This customer specific investment is denoted CSlga b For each network level of supply S and each network level of assets A the amount of capital expenditure included with CSlsq which under the charging years connection charging policy would be chargeable as part of the connection charge to the relevant users This customer contribution is denoted CCsa c For each network level of assets A the amount of capital expenditure on new assets excluding any asset replacement at network level A which are required for general reinforcement and are not included in CSlsa for any customers This general reinforcement investment is denoted GRlba These data might be obtained by drilling down the information provided in tables LR1 and LR4 of the forecast business plan questionnaire provided to Ofgem in connection with price control reviews in that case the representative sample would comprise all schemes included in the part of the questionnaire used Data should be aggregated over several years to reduce the influence of fluctuations unl
25. e SPX data profiled consumption within that VMR dataset The following procedure is suggested for aggregating data into the relevant form a Map each supported PC LLFC SSC TPR combination to a tariff rate combination b Aggregate SPX data by tariff rate combination into a 366 50 matrix c If using a de linked or defaulting billing method then produce a separate aggregate of SPX data for unsupported SSCs into a 366 50 matrix for each DUoS tariff split that dataset into the different rates using the time bands specified in the charging statement and aggregate the result with the rest of the data from b above In the case of tariffs billed on a de linked basis the 366 50 matrix aggregated by tariff on the same way as the defaulted data from c above should be used instead of the calculations at a and b above In the case of unmetered supplies a single load factor and a single coincidence factor should be calculated to cover all unmetered supplies and these figures should be used for both the NHH UMS and LV UMS Pseudo HH Metered tariffs Volume forecasts for the charging year Volume forecasts should not include any volumes for which the charges are excluded service revenues for price control purposes e g capacities subject to standby availability charges Transmission exit charges year Transmission exit charges should be taken from a forecast by reference to relevant transmission tariff and price control informa
26. e construction activity should be included Land or easement purchase values should not be included The costs of applying for planning permission or taking part in a public inquiry should not be included Wayleave rental payments should not be included Legal and administrative costs incurred in establishing wayleaves should be included Unit costs for actual or planned asset replacement projects including any unit costs included in business plan submissions to Ofgem should be disregarded in pricing the network model if relying on them would conflict with the assumptions above Network model 35 36 37 38 39 The assets in each network level of the model should be sized to be sufficient to supply loads which are representative of the mix of demand for the licensee s area and which once aggregated and measured at the grid supply point level have a peak demand of 500 MW By exception to the rule above if a 132kV HV network level is used then the 132kV HV network level should be sized to meet loads which aggregated and measured at the grid supply point level would make a contribution to peak demand equal to 500 MW times the 132kV HV proportion In that case the 132kV EHV EHV and EHV HV network levels should be sized to loads which aggregated and measured at the grid supply point level would make a contribution to peak demand equal to 500 MW times one minus the 132kV HV proportion No generation should be assumed in
27. e input data sheet providing guidance on data definitions and possible data sources wherever possible Company name charging year and model version The text entered in table 1000 will be reproduced at the top of each sheet Financial and general assumptions This table contains the following assumptions a The rate of return to be used to calculate annuity factors This is the pre tax cost of capital set by the Authority as part of the then most recent review of the charge restriction conditions applying under the DNO Party s Distribution Licence b The annualisation period to be used to calculate annuity factors c The proportion of the full annuity that should be included in prices in respect of assets which are deemed to be covered by customer contributions d The power factor assumed in the network model e The number of days in the charging year The first four parameters are specified on the face of the methodology statement The CDCM model has been set up to run for a one year period To run the CDCM model for a mid year price change the number of days in the charging year should be left at 365 or 366 as appropriate and the following procedure used a Estimate net CDCM revenue forecast to accrue within the first half and within the second half of the year if current tariffs were continued Denote these forecasts R1 and R2 Unless volume forecasts have changed since tariffs were set R1 R2 will be equal to the net
28. eeeeeceeeeeeeeeeeeeeeeseeeseess 23 1201 Current tariff INfOrmMatlonsiecccsiticccsssaveccettcancnsssaanevussdencuvesncnetvardanchvcvecnbinetduactveanenenusaade 23 Calculation Sheets saas REE Er sient es eect 24 LAFs Loss adjustment factors and network use matrices ccccccccccecceeeeeeeeeeeeeeeeeeeess 24 DRM Network model acids an ER srine s srd nre ben re rele ror error orker 25 SM Service MAd E S suisse re ED en na eee he A EE Eo A ETS T A 25 Loads Edad Gharaciensies 4ctck cn csi entea data tacks oti ist atte ieee 26 Multi Load characteristics for multiple unit rates 2 cece teeter ee eeteeneeeeeeee rete 26 SMD Forecast simultaneous MAXIMUM load eee ee eeeeeee cette eee eeeeeeaeeeeeeeeeeeeeeesaaeeeeeeees 27 AMD Forecast aggregate maximum load seeren 28 Otex Other expenditure i scicicaeecssscckivetea Uenwesadaeceel secu cogs idakcees seceequnsdekdvelsnseepertdevaauaanabeqestede 29 Contrib Customer contributions 2 505053 ies escckdageds Recnsguechd coda renerne 31 NEM VIS ICIS ces case carcinrs mea cata tanks E ot aaaaiones can nek saeaaabeant cannes oh edadeans cannes 31 Standing Allocation to standing Charges ccccceessssceeeeeeeeeeeeeeseeeeeeeeeeeeeeseseaaaeeeeeees 32 NHH Standing charges as fixed Charges 0 ceeeeeeeeeeee eect eee eeeeeeeeee sees ee eeeeeceaaeeeeeeeeeeteea 32 Reactive Reactive power unit charges u ssseeeeeree reen 33 Aggreg
29. ements of capacity charges p kVA day that would apply if capacity charges were applicable Yardstick unit rate p kWh and unit rate 1 3 taking account of standing charges This applies the standing charge factors to unit rates calculated on the Yard sheet to take account of costs that are being recovered from fixed or capacity charges rather than unit rates NHH Standing charges as fixed charges 188 This sheet calculates the elements of fixed charges for non half hourly demand users that relate to network costs of the kind that would be charged through capacity charges for half hourly settled demand Page 32 of 36 Table 12 Standing charges as fixed charges NHH calculations 3101 3102 3103 3104 3105 3106 Average maximum kVA MPAN by end user class for user classes without an agreed import capacity This determines a factor to convert capacity related costs to fixed charges in the case of tariffs without capacity charges Capacity driven fixed charge elements from standing charges factors p MPAN day This calculates p MPAN day elements of fixed charges based on capacity Capacity used by LV users without an agreed capacity This estimates the capacity used by non half hourly settled demand users based on tariff specific load factors provided as input data and collects information on MPAN counts by tariff Aggregate data for LV users without agreed capacity for allocation of LV circuit costs Thi
30. en set on the Loads sheet as 1 for generation users and the ratio of the coincidence factor to the load factor for demand users Page 31 of 36 Table 10 Yardsticks Yard calculations 2901 2902 2903 2905 Unit costs at all levels kW year relative to system simultaneous maximum load This compiles all the kW year cost information where unit costs are based on system simultaneous maximum load Pay as you go yardstick unit rate by charging level p kWh This calculates the unit rate that would apply for each tariff on an unrestricted basis and if there were no standing charges Pay as you go unit rate 1 3 p kWh These tables calculates the unit rates that would apply for each tariff with more than one unit rate if there were no standing charges Standing Allocation to standing charges 187 This sheet applies allocates costs between consumption related charges and standing charges for demand tariffs which have either a kVA availability charge or a p MPAN day fixed charge that can used to cover assets at network levels close to the voltage of supply Table 11 Allocation to standing charges Standing calculations 3001 3002 3003 3006 Costs based on aggregate maximum load kW year This compiles kW year cost information where unit costs are based on aggregate maximum load at each network level i e taking account of asset diversity Capacity elements p kVA day This calculates el
31. eration NHH Intermittent Non Intermittent 88 89 These service models should reflect the additional cost of protection equipment for a typical generator in each category for example the difference in cost between a fuse and a circuit breaker There is almost certainly no service model for LV Generation NHH such small generating units would not be expected to require special protection NHH UMS LV UMS Pseudo HH Metered 90 91 For unmetered tariffs the service model cost is expressed as a cost for each estimated MWh of electricity distributed in a year To make that estimate the DNO Party defines one or more typical or average configurations of unmetered supplies and estimates for each configuration the service model cost and the number of units expected to be delivered through that hypothetical system in each year taking account of typical or average consumption rates and operating hours of items supplied under unmetered supply tariffs The percentages in the matrix of applicability are based on 1 MWh year For example if the scheme connects columns with in total 10 lamps of 70 W each burning for 8 hours a day on average then the total annual consumption of the scheme is 10 70W 8h 365 2 MWh and the figure in the relevant cell of table 1026 is 50 Page 14 of 36 Input data tables 92 1000 93 1010 94 95 96 1017 97 98 This section reviews each of the tables in th
32. ess there are good reasons to do otherwise the aggregate of actual data from 2005 2006 to 2008 2009 inclusive should be used If these data are not available a direct analysis of planned schemes and or a survey of recent investment schemes will be needed A general reinforcement uplift factor is defined for each network level of assets A by the following formula GRUFa 1 GRla sCSlsa where s denotes summation over all applicable network levels of supply S The contribution proportion corresponding to network level of supply S and network level of assets A is determined by the following formula CCPsa CCsa CSlsa GRUFa This formula provides the data for entry into table 1060 If data are not available separately for all network levels of supply e g if the available data do not distinguish between LV network and LV substation then calculations can be done by using a classification of customers into fewer categories 1061 and 1062 Average split of units between distribution time band 150 In each table each line relates to a different user type and tariff structure For each user type and tariff structure the figure entered against each of the time bands used Page 20 of 36 151 152 153 1068 154 155 1069 156 157 158 159 160 for network analysis is the proportion of the units recorded on the relevant TPR or within the relevant charging period that would fall with eac
33. ets proportion of assets annuities deemed to be covered by customer contributions This calculates the proportion of the annuity that is chargeable taking account of the fact that a lower replacement only annuity is required where assets are fully contributed Contribution proportion by tariff and network level proportion of assets annuities deemed to be covered by customer contributions This uses the table 2801 mapping to allocate the contribution proportions from table 2802 to each tariff Proportion of annual charge covered by contributions for all charging levels This extends the matrix with a set of zero figures for operating expenditure so that it covers all levels at which charges can be applied Yard Yardsticks 183 184 185 186 The yardstick calculations allocate network model costs kW simultaneous maximum load to p kWh yardsticks for each customer class without allowing for any capacity or fixed charges to cover the same costs A single yardstick unit rate is calculated for all tariffs taking no account of time of day patterns or of the lower level of diversity on local networks That calculation is done on the basis of all year averages and applying the single coincidence factor to system peak in respect of all network levels This sheet also calculates unit rates for multi rate tariffs The same set of formulae covers both demand and generation end users since the load coefficient has be
34. etwork must not include any spare capacity to cater for any further growth even if it would be normal practice of the company to plan for such growth when establishing new networks Because of this assumption the utilisation factors in the hypothetical incremental network may be higher than actual utilisation factors in the network Actual utilisation factors in the network should not be relied upon as the basis for assumptions in the model although they may be used as a cross check for the assumptions made The possibility of using emergency ratings in fault or outage situations should be taken into account in estimating the asset volumes and capacities required in the hypothetical incremental network For example a substation with two transformers rated 12 24 MVA i e 12 MVA with passive cooling and 24 MVA with active cooling is sufficient to meet a maximum load of 24 MVA since that level of load could be accommodated on a single transformer if the other was out of use n 1 situation Similarly a substation with two transformers rated 90 MVA who are each considered capable of accommodating an emergency flow of 117 MVA if necessary 30 per cent more than the continuous rating of 90 MVA is sufficient to meet 117 MVA In a situation where interconnection is used to provide security then a more detailed analysis of redundancy requirements should be used For example three 132kV 33kV_ single transformer 60 MVA with 30 per cent emergency
35. evant load going through 132kV HV direct transformation 1019 Network model GSP peak demand MW 1020 Gross asset cost by network level 1022 LV service model asset cost 1023 HV service model asset cost 1025 Matrix of applicability of LV service models to tariffs with fixed charges 1026 Matrix of applicability of LV service models to unmetered tariffs 1028 Matrix of applicability of HV service models to tariffs with fixed charges 1032 Loss adjustment factors to transmission 1037 Embedded network LDNO discounts 1041 Load profile data for demand users 1053 Volume forecasts for the charging year 1055 Transmission exit charges year 1059 L jeje Other expenditure 1060 Customer contributions under current connection charging policy 1061 Average split of rate 1 units by distribution time band 1062 Average split of rate 2 units by distribution time band 1068 Typical annual hours by distribution time band 1069 Peaking probabilities by network level 1076 Target revenue 1092 Average kVAr by kVA by network level 1201 Lje e jejejejejeje e J NH SJ SJ KS KH NH HK NH NM MS J NM SJ SJ eS Sm Current tariff information Page 7 of 36 Annual Review Pack 26 27 DNOs will issue the Annual Review Pack ARP on or before the 31
36. for half hourly metered customer typically over 100 kW 82 Provision for current transformers used for metering purposes should be included in the service model No metering costs should be included these relate to the metering activity and not the distribution activity 83 Only cables on or very near the customer s land should be included in the service model Longer cables installed to connect to an existing mains are potentially shareable and therefore part of the network model LV Sub HH Metered 84 This service model relates to the building of a new typical supply for a customer with a dedicated substation not including any HV LV transformation costs or any HV costs A charge for the average cost of HV LV transformation will be made through Page 13 of 36 85 86 87 the 500 MW model so that including the transformer in the service model would amount to double counting If the metering breaker is typically separate from the substation then the costs are for that breaker and the short cable between that breaker and the substation plus jointing It would not be surprising for the cost to be less than for LV HH Metered even though the capacity will be higher The above reflects the rule that a customer connected to a substation whether dedicated or shared through a LV cable owned by the DNO that goes beyond the boundary of the HV LV substation is a LV network customer not a LV substation customer LV Gen
37. h time band Each of these tables relates to a different TPR for linked tariffs or charging period for de linked tariffs Only tariffs which have at least the relevant number of unit rates and which use TPRs or charging periods that may differ from the distribution time bands are included in each table These data will need to be extracted from an analysis of load profiles or load data and on information about distribution time band switching times to be determined by the licensee The load data sources described under table 1041 can be used for this purpose However GSP Group Correction Factors should not be applied to data used to populate tables 1061 and 1062 Typical annual hours by distribution time band For each time band used for network cost analysis this table provides the number of hours that fall within that time band in a year If the figures entered are inconsistent with the number of days in the charging year then the model will rescale the annual hours by distribution time bands This is the only case in which user input data is sanitised this is so that leap years are correctly dealt with without needing to change the data in table 1068 Peaking probabilities by network level For network levels included in the network model the peaking probability is the proportion of assets at that level that have their time of maximum load during each distribution time band The three numbers entered in each row should add up
38. input e A commentary on the forecast and justification of the forecast for each CDCM input via individual comments f The timebands that will be used in each of the 5 years contained within the annual review The forecast CDCM input data will be provided by DNOs based on their own perception of how the CDCM input data may change over the 5 year period The format of the annual report will be common but the actual forecast will be DNO specific to allow DNOs flexibility to express their views and provide a realistic forecast Guidance on asset models 28 29 Two types of asset models are used a The network model also known as DRM or 500 MW model relates to shared or shareable assets in the network b The service models relate to assets dedicated to a single network user This section provides guidance on the development of these assets models Page 8 of 36 General costing guidance for asset models 30 31 32 33 34 The unit costs in the model should reflect what it would cost to purchase and install the assets included in the hypothetical incremental network including building and civil engineering works in unmade ground In the case of LV underground cables one third of excavation costs should be included in unit costs This factor comes from an assumption that these costs are shared with gas and water utilities No reinstatement costs should be included Overheads directly related to th
39. may vary when the model is changed or different options are selected Hyperlinks in the workbook 8 The tables in the model are listed in the overview sheet with hyperlinks to the data Links to the source data for each calculation are shown above each calculation table 9 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 10 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 11 Links do not work well if the model is displayed within a web browser To get the full functionality save the model as a file and open it in Microsoft Excel or compatible software Technologies and dependencies 12 The model is implemented as a stand alone Microsoft Excel workbook in Excel 1997 2003 file format No software other than Microsoft Excel 1997 or above or compatible software is needed to operate the model 13 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 14 The workbook is produced by a computer programme in the pr
40. nd fixed charges so as to adjust the operating expenditure allocation in line with the exact charging rule used 2608 Forecast simultaneous load replaced by standing charge kW This aggregates table 2607 by network level 2609 Calculated LV diversity allowance This estimates the figure equivalent to a diversity allowance that needs to be used between HV LV transformation and LV end users in order to set capacity or fixed charges for LV circuits which reflect the same underlying costs as those included in unit charges 2610 Network level mapping for diversity allowances diversity allowances 2612 including 132kV HV diversity allowances including calculated LV value This combines the calculated LV diversity allowance with input data for diversity allowances at other network levels 2613 Forecast simultaneous maximum load kW adjusted for standing charges This adjusts the system simultaneous maximum load estimate to the extent necessary to ensure that the operating expenditure recovered through capacity charges will match the amount allocated on the basis of system simultaneous maximum load The need for this adjustment arises from possible differences between the overall load factor implied by the diversity allowances and the tariff specific load factors provided as input data There is no adjustment in respect of the LV circuits level since the diversity allowance is set to a figure calculated using the tariff specific load factors pr
41. ogramming 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 15 The overview sheet Overview lists the data tables in the workbook Input sheet 16 The input data sheet Input contains all the input data for the model Tariff sheets 17 The tariff sheet Tariffs summarises the final tariffs Page 5 of 36 Additional output sheets 18 19 20 21 22 The summary sheet Summary gives a copy of the tariffs average revenue per unit and average revenue per user for each tariff and a summary of options and assumptions used in the model Tariff matrices are provided on the M ATW sheet Tariff matrices show the tariff components of the final tariffs and their decomposition into the various elements of cost and revenue in a form that can be easily read and printed The revenue matrix sheet M Rev shows the revenues raised in respect of each end user type and each element of cost or revenue in the model The comparison sheets CData and CTables attempt an indicative comparison between current and proposed all the way tariffs and between all the way and LDNO tariffs All these additional output sheets are for information only They can be removed or modified without effect on the rest of the calculations Page 6 of 36 Updating the CDCM model Frequency of Update 23 24
42. ormation on aggregate maximum loads derived from the volume forecast and makes some diversity related adjustments Table 7 Forecast aggregate maximum load AMD calculations 2601 Pre processing of data for standing charge factors standing charges factors 2602 adapted to use 132kV HV These factors show for each tariff and each network level the extent to which costs are to be recovered through fixed or availability charges rather than unit rates 2603 Capacity based contributions to chargeable aggregate maximum load by network level kW This collects information about contributions to aggregate maximum load for users with agreed import capacities 2604 Unit based contributions to chargeable aggregate maximum load kW This combines load characteristic data volume forecast data and network use factors to estimate the contribution of each tariff group to aggregate maximum load Page 28 of 36 Table 7 Forecast aggregate maximum load AMD calculations 2605 Contributions to aggregate maximum load by network level kW This combines data from table 2603 and 2604 2606 Forecast chargeable aggregate maximum load kW This aggregates table 2605 by network level 2607 Forecast simultaneous load subject to standing charge factors kW This applies the standing charge factors to system simultaneous maximum load estimates from the SMD sheet This is to identify the extent to which unit charges will be replaced with capacity a
43. ovided as input data Otex Other expenditure 181 This sheet allocates operating expenditure between network levels Table 8 Other expenditure Otex calculations 2701 Operating expenditure coded by network level year This collects information about transmission exit charges the only element of operating expenditure that is to be forecast by network level Page 29 of 36 Table 8 Other expenditure Otex calculations 2702 Network model assets scaled by load forecast This combines a forecast simultaneous maximum load at each network level with the network model costs in order to create a set of notional asset values for each network level 2703 Annual consumption by tariff for unmetered users MWh This collects information about forecast consumption of unmetered users in order to size the corresponding service models 2704 Service model asset data This calculates the asset values of service model assets based on the volume forecast number of MPANs and consumption on unmetered tariffs 2705 Data for allocation of operating expenditure This combines network model asset data and service model asset data 2706 Amount of expenditure to be allocated according to asset value This calculates the sum of other expenditure which includes direct costs network rates and a proportion of indirect costs 2707 Total operating expenditure by network level year This allocates the unallocated operating expendit
44. ropriate adjustments are made for any differences in the type of substations in the hypothetical incremental network compared to the actual network Circuit sizes must be taken to be the lowest relevant standard size that will deliver the required capacity Page 10 of 36 Service models 50 51 52 53 The assets included in service models are the assets that would be constructed under the licensee s current engineering practices to establish a connection with a customer excluding assets that are included in the 500 MW network model Shared shareable or potentially shareable assets should be included in the network model Only sole use assets that are not shareable or potentially shareable are therefore permitted in service models Different customers might require different service assets Averaging is required to produce generic figures for use in setting use of system tariffs The remainder of this section outlines the service model for each tariff HV Medium Non Domestic 54 This is a non half hourly metered customer i e less than 100 kW This will typically be a legacy site in a remote area a site which is no longer operating at the capacity for which it was designed or a generator s own demand 55 In order to avoid undue discrimination between generators on the basis of whether their station demand is half hourly settled or not this should use the same service models as for the HV HH Metered tariff HV HH Me
45. s Customer contributions Volume forecasts Price control Tariff components before matching allowed revenues Expenditure data All the way tariffs LDNO tariffs Page 3 of 36 Figure 2 Overview of the relationship between elements of the model Load profiles Network model Service models Volume forecasts N le 4 Opex allocation Yardsticks a Standing charges Reactive Revenue matching Tariffs Sheets 4 Sheets in the workbook have been given very short abbreviated names This is to make the best use of screen space given the way in which Microsoft Excel displays information A proper title appears at the top of each sheet 5 Figures 3 and 4 are maps of the calculation sheets in the model workbook Figure 3 Step 2 sheets in the workbook data flow from left to right Contrib Reactive Yard re DRM i Standing NHH re AMD OPex LAFs SM Loads Multi SMD Figure 4 Step 3 sheets in the workbook data flow from left to right Scaler Aggreg Revenue Adjust Tariffs Page 4 of 36 Tables 6 Each sheet is structured as a list of data tables to be read from top to bottom like a book 7 Each of these data tables has a four digit table number Numbers that start with 10 are manually assigned for input data tables and do not change from version to version Other table numbers are assigned when the model is built and
46. s aggregates table 3103 across all tariffs LV fixed charge elements from standing charges factors p MPAN day This calculates charges in respect of the proportion of LV circuit costs to be recovered on the basis of exit points rather than capacity Fixed charge elements from standing charges factors This combines capacity driven fixed charge elements from table 3102 with exit point driven fixed charge elements from table 3105 Reactive Reactive power unit charges 189 The Reactive sheet calculates charges for reactive power units Table 13 Reactive power unit charges Reactive calculations 3201 3202 3203 Standard components p kWh for reactive power absolute value This takes the absolute value of p kWh yardstick elements Standard reactive p kVArh This uses the kVAr kVA factor for each network level to convert the p kWh yardstick which excludes costs recovered through capacity charges into a p kVArh charge element Network use factors for generator reactive unit charges This table of network use factors reflects the fact that reactive units supplied from to generators affect the capacity required at the voltage of supply even though no active power credits are given in respect of this network level Page 33 of 36 Table 13 Reactive power unit charges Reactive calculations 3204 3205 3206 Absolute value of load coefficient kW peak average kW This takes the absolute value of the loa
47. s to be used in rounding Tariff rounding This calculates the minimum adjustment to each tariff component needed to make it comply with the rounding rules All the way tariffs This calculates all the tariffs after rounding Tariffs This calculates all tariffs after applying LDNO discounts Net revenues by tariff from rounding This calculates for each tariff the effect on forecast revenues of the rounding adjustment Revenue forecast summary This summarises the impact of the Scaler and Adjust sheet on total revenues Page 36 of 36
48. tered 56 The cost should cover the ring main unit including installation and jointing but none of the HV feeder cable or line costs all of the HV lines are treated as part of the HV network and not as service model assets 57 Different companies may use different grades of ring main units for their typical HV customers e g fuse based v circuit breakers so there may be large but legitimate differences in cost between companies HV Sub HH Metered 58 The cost should cover the installation and jointing of a suitable circuit breaker within the primary substation excluding any costs of expanding the primary substation building No EHV or transformation costs should be included 59 Only short lengths of cable within the substation can be included any HV line going outside the boundary of the substation is a potentially shareable asset and is treated as part of the HV network therefore not as a service model asset 60 The above reflects the rule that a customer connected to a primary substation through a HV cable owned by the DNO that goes beyond the boundary of the primary substation is a HV network customer not a HV substation customer HV Generation Intermittent HV Generation Non Intermittent 61 These service models should reflect the additional cost of protection equipment for a typical generator in each category for example the difference in cost between a fuse and a circuit breaker or the costs of additional tele
49. the network model s customer mix The hypothetical 500 MW network for each network level must be designed as an increment serving loads that have the same topography diversity and other characteristics as the actual loads on the existing network In particular customers locations and consumption patterns should be representative of reality in the licensee s area But the hypothetical network used to supply them must reflect current design practice and the assumptions about utilisation detailed below for a forward looking hypothetical incremental network the mix of assets in this hypothetical network need not be similar to that in the licensee s network The volume and capacity of assets included in the model at each network level should be based on the minimum cost way of delivering the minimum amount of redundancy required to comply with Engineering Recommendation P2 6 The design must be feasible asset quantities should be rounded up to accommodate at least the required capacity without using notional fractions of assets The licensee s own planning guidelines must be ignored insofar as they impose greater security redundancy or resilience requirements than Engineering Recommendation P2 6 Page 9 of 36 40 41 42 43 44 45 46 47 48 49 The design of the hypothetical incremental network must not rely on any spare capacity that might exist on current network assets The hypothetical incremental n
50. tion Page 18 of 36 132 1059 133 134 135 136 137 138 139 140 141 Historical figures for transmission exit charges are in table 2 6 of the RRP 2008 layout Historical data should only be used for comparison purposes Other expenditure This table contains data to determine the amount of other expenditure allocated according to asset values in the model The amount of expenditure to be allocated according to asset values in the model is a forecast for the charging year of the sum of a 100 per cent of direct operating costs including statutory depreciation on non operational assets related to direct activities b 60 per cent of indirect operating costs including statutory depreciation on non operational assets related to indirect activities c 100 per cent of network rates The cells in table 1059 contain this data including the indirect cost proportion set to 60 per cent by the methodology document No transmission exit charges should be included in the amount of expenditure to be allocated according to asset values in the model The concepts of direct and indirect costs are the same as in the RRP Forecasts of direct and indirect costs may be based on historical expenditure data combined with the licensee s estimate of trends in operating expenditure e g taking account of input price movements and productivity gains Historical values for relevant direct
51. tion level England and Wales only and the figures for EHV circuits should reflect data for the EHV HV transformation level The figures for HV and LV circuits and the HV LV transformation should reflect data for HV feeders or for the HV LV transformation level if available Otherwise data for the EHV HV level are used at these levels Target revenue This table provides the amount of revenue to be recovered from CDCM charges net of CDCM credits Table 1076 has four cells a Allowed revenue year This is intended to reflect a figure from price control calculations It includes revenue allowances and deductions under price control incentive schemes b Pass through charges year This is intended to reflect amounts specified as pass through items in the price control formulae but not already included in allowed revenue c Adjustment for previous year s under over recovery year This is intended to reflect the effect of the K factor in the price control formula A positive figure indicates an under recovery in the year The amount in that cell is added to target revenue for the charging year any applicable interest must be included in the figure entered in this cell d Revenue raised outside this model year This is intended to capture the revenue net of relevant credits forecast to be raised outside the CDCM model e g from EHV users insofar as they are not excluded revenue for price control purposes
52. to 100 per cent This data should be obtained from an analysis of substation meter data underpinning the week 24 data submission to National Grid Electricity Transmission NGET and data underpinning the long term development statement Where data permits the proportions should be weighted by peak load MVA To calculate the peaking probabilities at the GSP level data should typically be taken from the week 24 submission to NGET This table provides the time and date of substation peak and the peak load MVA at each substation Using this data the peaking probabilities at the GSP level for each time band can be calculated by summing the peak loads MVA s of each substation that occur in each time band and then dividing by the sum of the peak loads on each substation The proportion of the total MVA s that occurred in each time band represent the peaking probabilities At the primary substation level 132 kV and EHV the peak loads MVA s should be derived where possible from load forecast data underpinning the long term development statement The peaking probabilities for each time band can then be calculated following the same steps as at the GSP level i e based on the proportion of the total MVA s that occurred in each time band Page 21 of 36 161 162 1076 163 164 165 166 Unless data specific to circuits is available the figures for 132kV circuits should reflect data for the 132kV EHV transforma
53. to tariffs with fixed charges 17 1026 Matrix of applicability of LV service models to unmetered tariffs 17 1028 Matrix of applicability of HV service models to tariffs with fixed charges 17 1032 Loss adjustment factors to trAaNSMISSION ccccccccccecccceceeeeeeeeeeceeeeeeeeeeeeeeeeeeeeeeeess 17 1037 Embedded network LDNO discounts sssseeeeeeee renerne renerne 17 1041 Load profile data for demand users coincidence factor load factor 1 W W1 W1 1 1 17 1053 Volume forecasts for the Charging year cccceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeteeeeaaees 18 1055 Transmission exit charges yOar ccccccceeeeeeeeeeeeeeeceeeeeeeeeeesenaaeaeeeeeeeeeeeeesaaaaes 18 1059 Other expenditure saci cineca anea a a seen ed a eea 19 1060 Customer contributions under current connection charging policy 19 1061 and 1062 Average split of units between distribution time band ccccccceeeeees 20 1068 Typical annual hours by distribution time band ccccccccccccccceeeceeeeeeeeeeeeeeeeeeeeeeess 21 1069 Peaking probabilities by network level cccccccccccccccccecceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeess 21 1076 Target even us net cee necetasieee ocean Miva eet cate seo il ten veal as et nance aad aden notes 22 1092 Average kVAr by kVA by network leVel cccccccccccccccccecceeeeee
54. twork level The figure to be entered in each cell is the aggregate cost of the assets at that level in the 500 MW network model in See the asset models guidance above page 9 for more information LV service model asset cost This table gives asset costs for each LV service model HV service model asset cost This table gives gross asset replacement costs for each HV service model Page 16 of 36 1025 112 1026 113 1028 114 1032 115 116 117 1037 118 119 1041 120 121 122 123 Matrix of applicability of LV service models to tariffs with fixed charges This table gives for each tariff which might have LV sole use assets and includes a charge per MPAN the proportion of each service model that needs to be included to calculate the average value of sole use assets for one MPAN on this tariff Matrix of applicability of LV service models to unmetered tariffs This table gives for each LV unmetered tariff the proportion of each service model that needs to be included to calculate the average value of sole use assets for a load amounting to 1 MWh a year on this tariff Matrix of applicability of HV service models to tariffs with fixed charges This table gives for each tariff which might have HV sole use assets the proportion of each service model that needs to be included to calculate the average value of sole use assets for one MPAN on this tariff
55. ue of SQRT 1 PF 2 should be calculated at the time of each substation s peak and the averaging of these values should be weighed by reactive flow MVAr at the time of substation peak Where data are not available for a network level data nearest network level at which they are available are used as a proxy Current tariff information This table allows the entry of information about current tariffs for comparison purposes If the first column total revenue is populated with a positive value then the other data tariff components or p kWh averages are ignored Page 23 of 36 Calculation sheets LAFs Loss adjustment factors and network use matrices 171 This sheet combines data about line loss factor and network use in order to produce a matrix of line loss factors scaled by network use as outlined in table 2 172 The resulting matrix indicates the extent to which costs at each network level are to be charged to each type of network user Table 1 Loss adjustment factors and network use matrices LAFs calculations 2001 Loss adjustment factors to transmission This table maps each tariff to the network level corresponding to the relevant type of end user and extracts the corresponding loss adjustment factor to transmission 2002 Mapping of DRM network levels to core network levels This table maps each tariff to the network level corresponding to the relevant location for calculating flows subject to use of system charges
56. ure from table 1057 in the proportions given by the data for allocation of operating expenditure and combines these data with the operating expenditure coded by network level 2708 Operating expenditure percentage by network level This calculates the ratio of annual operating expenditure to asset gross replacement cost for each network level 2709 Unit operating expenditure based on simultaneous maximum load kW year This converts the total operating expenditure into a unit operating expenditure figure by dividing it by the forecast system simultaneous maximum load at each network level 2710 Operating expenditure for customer assets p MPAN day This allocates operating expenditure on service model assets to tariffs with fixed charges 2711 Operating expenditure for unmetered customer assets p kWh This allocates operating expenditure on service model assets to tariffs without fixed charges Page 30 of 36 Contrib Customer contributions 182 This sheet compiles matrices of customer contribution data for each tariff and network level combination Table 9 Customer contributions Contrib calculations 2801 2802 2803 2804 Network level of supply for customer contributions by tariff This matrix maps each tariff to the level of supply to which it belongs for the purpose of estimate the relevant customer contribution percentages Contribution proportion by network level of supply and network level of ass
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