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{"sheet":"3.1 Revenue","index":0,"n_rows":35,"n_cols":12,"rows_kept":35,"cut":false,"hidden":false,"merged":[[1,1,1,3]]}
[]
[null,"SA Power Networks",null,null,"Basis of Preparation"]
[null,1,1.1000000000000001,2,3,"4.0a","4.0b",null,5,6,7,8]
[null,"CA RIN Table Ref / EB RIN Variable Code","RIN Row/ Column/ Cell or All (entire tab)","Financial /\nNon-Financial","Data Source","Actual / Estimated\nStandard Control Services","Actual / Estimated\nAlternative Control Services",null,"Justification\n(if estimated)","Methodology \n(actual and estimated)","Assumptions\n(actual and estimated)","SAPN Additional Comments\n(if any)"]
[null,"State the table reference (CA) or Variable Code (EB)","\nState the applicable row, column, cell, or entire tab","\nSelect whether the referenced information is financial or non-financial","\nExplanation of the data source for the referenced information","\nSelect whether the information from data source is either actual or estimated?","\nSelect whether the information from data source is either actual or estimated?",null,"\nExplanation of why an estimate is required and why actual data does not exist\n\nFor financial information, explanation of why financial information is not in accordance to the financial reporting framework and any changes, impacts and deviations to accounting policies (for any regulatory years).","\nExplanation of the method applied to provide the requested data. This should include an explanation of how the data was derived from other sources (if applicable) where this was undertaken and explain any allocation the approach applied.","\nExplanation/list of any assumptions made for data source, justification and methodology applied or made.","\nState any additional comments, notes or explanations."]
[null,"3.1.1 - REVENUE GROUPING BY CHARGEABLE QUANTITY",null,null,null,"SCS","ACS"]
[null,"DREV0101","Revenue from Fixed Customer Charges ","Financial","Sales Model (Internal) ","Actual",null,null,"Data is based on an as-billed basis. \nActual data is extracted from the Sales Model, and includes revenue from all supply charges for Residential, LV Business Single and LV Business Two Rates."]
[null,"DREV0102","Revenue from Energy Delivery charges where time of use is not a determinant","Financial","Sales Model (Internal) ","Actual",null,null,"Data is based on an as-billed basis.\nActual data is extracted from the Sales Model, and includes revenue from Residential tariffs (excl Controlled Load and residential demand), LV Business Single Rates, LV kVA agreed/actual demand, HV kVA Demand and Majors where non-time of use tariffs have been allocated."]
[null,"DREV0103","Revenue from On–Peak Energy Delivery charges ","Financial","Sales Model (Internal) \nAnnual Pricing Proposal - Appendix G","Actual",null,null,"Data is based on an as-billed basis. \nActual data is extracted from the Sales Model for total Energy Delivery Charges, and includes revenue from LV/HV Business Two and LV Business Transition tariffs. \n","The split between peak and off-peak energy deliveries is based on the quantities split approved in the annual pricing proposal."]
[null,"DREV0104","Revenue from Shoulder period Energy Delivery Charges","Financial","Nil",null,null,null,"SAPN does not have any 'shoulder' charges."]
[null,"DREV0105","Revenue from Off–Peak Energy Delivery charges ","Financial","Sales Model (Internal) \nAnnual Pricing Proposal - Appendix G","Actual",null,null,"Data is based on an as-billed basis. \nActual data is extracted from the Sales Model for total Energy Delivery Charges, and includes revenue from LV/HV Business Two and LV Business Transition tariffs."," The split between peak and off-peak energy deliveries is based on the quantities split approved in the annual pricing proposal."]
[null,"DREV0106","Revenue from controlled load customer charges","Financial","Sales Model (Internal) ","Actual",null,null,"Data is based on an as-billed basis.\nActual data is extracted from the Sales Model, and includes revenue from Controlled Load Rates (primarily Residential)."]
[null,"DREV0107","Revenue from unmetered supplies","Financial","Sales Model (Internal) ","Actual",null,null,"Actual data is extracted from the Sales Model.\nIncludes revenue from 12 and 24 hour Unmetered rates (incl Public Lighting NUOS)"]
[null,"DREV0108","Revenue from Contracted Maximum Demand charges","Financial","Sales Model (Internal) ","Actual",null,null,"Data is based on an as-billed basis. \nActual data is extracted from the Sales Model, and includes revenue for LV/HV kVA Demand and Major Customer Tariffs. (Fixed Charges)"]
[null,"DREV0109","Revenue from Measured Maximum Demand charges","Financial","Sales Model (Internal) ","Actual",null,null,"Data is based on an as-billed basis.\nActual data is extracted from the Sales Model, and includes revenue for Residential Demand, LV/HA Actual Demand (Incl. LV Transition). (Fixed Charges)"]
[null,"DREV0110","Revenue from metering charges","Financial","Annual RIN",null,"Actual",null,"Data is based on an as-billed basis.\nSCS: N/A\nACS: Actual data is extracted from the Sales Model."]
[null,"DREV0111","Revenue from connection charges","N/A","Nil",null,null,null,"Connection charges revenue is Negotiated Services Revenue for SAPN"]
[null,"DREV0112","Revenue from public lighting charges","N/A","Nil",null,null,null,"Public Lighting revenue is Negotiated Services Revenue for SAPN"]
[null,"DREV0113","Revenue from other Sources","Financial","Sales Model (Internal) ","Actual",null,null,"Includes Revenue adjustments relating to billing timing; over/under revenue recoveries. As well as an adjustment for revenue associated with negotiated backup tariffs (Negotiated Services Revenue for SAPN).  "]
[null,"DREV01","Total revenue by chargeable quantity","Financial","Regulatory Accounts","Actual","Actual","Actual","As reported to AER."]
[null,"3.1.2 - REVENUE GROUPING BY CUSTOMER TYPE OR CLASS",null,null,null,"SCS","ACS"]
[null,"DREV0201","Revenue from residential Customers ","Financial","Sales Model (internal)","Actual","Actual",null,"Data is based on a tariff-applied basis.\nActual data is extracted from Sales Model (internal) for SCS and ACS, and includes revenue from  Supply, Controlled Load, Peak and Non-Peak charges.\n","SCS: The Annual Pricing Proposal is used to determine the proportion of controlled load that should be allocated to residential customers.\nACS: Straight from Sales Model"]
[null,"DREV0202","Revenue from Non residential customers not on demand tariffs ","Financial","Sales Model (internal)","Actual","Actual",null,"Data is based on a tariff-applied basis. \nActual data is extracted from Sales Model (internal) for SCS and ACS, and includes revenue from Business 1 & 2 Rates, Supply, Peak and Non-Peak charges.\n","SCS: The Annual Pricing Proposal is used to determine the proportion of controlled load that should be allocated to non-residential customers.\nACS: Straight from Sales Model."]
[null,"DREV0203","Revenue from Non-residential low voltage demand tariff customers ","Financial","Sales Model (internal)","Actual",null,null,"Data is based on a tariff-applied basis.\nSCS: Actual data is extracted from the Sales Model, and includes revenue from all LV Demand Rates (kVA, kW)) including Supply, Contracted Demand, Peak and Non-Peak charges.\nACS: Nil\n"]
[null,"DREV0204","Revenue from Non-residential high voltage demand tariff customers ","Financial","Sales Model (internal)","Actual",null,null,"Data is based on a tariff-applied basis.\nSCS: Actual data is extracted from the Sales Model, and includes revenue from all HV Demand Rates (kVA, kW & Sub)) including Supply, Contracted Demand, Peak and Non-Peak charges.\nACS: Nil"]
[null,"DREV0205","Revenue from unmetered supplies","Financial","Sales Model (internal)","Actual",null,null,"SCS: Actual data is extracted from the Sales Model (same number as DREV0107).\nIncludes revenue from 12 and 24 hour Unmetered rates (incl Public Lighting NUOS)\nACS: Nil"]
[null,"DREV0206","Revenue from Other Customers","Financial","Sales Model (Internal) ","Actual",null,null,"Includes Revenue adjustments relating to billing timing; over/under revenue recoveries and interest. As well as an adjustment for revenue associated with negotiated backup tariffs (Negotiated Services Revenue for SAPN).  "]
[null,"DREV02","Total revenue by customer class","Financial","Regulatory Accounts","Actual","Actual",null,"As reported to the AER."]
[null,"3.1.3 - REVENUE (penalties) ALLOWED (deducted) THROUGH INCENTIVE SCHEMES",null,null,null,"SCS","ACS"]
[null,"DREV0301","EBSS","Financial","EDPD 2010-2015 AER Reset","Actual",null,null,"Actual data extracted from the 2015-2020 EDPD Decision from the AER, escalated to current year reporting dollars.\nIncludes incentives/penalties recovered from customers within the tariffs for the applicable years as opposed to when earned/incurred from an accounting perspective."]
[null,"DREV0302","STPIS","Financial","AER communication\nAnnual Pricing Proposal","Actual",null,null,"Incentives/penalties percentage of revenue recovered from customers within the tariffs for the applicable year as advised by the AER. 2014/15 STIPIS recovered in the 2016/17 Regulatory Year."]
[null,"DREV0303","F-Factor ","Financial","N/A",null,null,null,"SAPN does not have an F-factor"]
[null,"DREV0304","S-Factor True up","Financial","N/A",null,null,null,"SAPN does not have a S-Factor True up"]
[null,"DREV0305","Other","Financial","Nil",null,null,null,"Nil"]
[null,"DREV03","Total revenue of incentive schemes","Financial","Sum of DREV0301-DREV0303","Actual"]

{"sheet":"3.2 Opex","index":1,"n_rows":32,"n_cols":12,"rows_kept":32,"cut":false,"hidden":false,"merged":[[1,1,1,3],[1,4,1,11]]}
[]
[null,"SA Power Networks",null,null,"Basis of Preparation"]
[null,1,1.1000000000000001,2,3,"4.0a","4.0b",null,5,6,7,8]
[null,"CAT RIN Table Ref / EBT RIN Variable Code","RIN Row/ Column/ Cell or All (entire tab)","Financial /\nNon-Financial","Data Source","Actual / Estimated\nStandard Control Services","Actual / Estimated\nAlternative Control Services",null,"Justification\n(if estimated)","Methodology \n(actual and estimated)","Assumptions\n(actual and estimated)","SAPN Additional Comments\n(if any)"]
[null,"State the table reference (CA) or Variable Code (EB)","\nState the applicable row, column, cell, or entire tab","\nSelect whether the referenced information is financial or non-financial","\nExplanation of the data source for the referenced information","\nSelect whether the information from data source is either actual or estimated?","\nSelect whether the information from data source is either actual or estimated?",null,"\nExplanation of why an estimate is required and why actual data does not exist\n\nFor financial information, explanation of why financial information is not in accordance to the financial reporting framework and any changes, impacts and deviations to accounting policies (for any regulatory years).","\nExplanation of the method applied to provide the requested data. This should include an explanation of how the data was derived from other sources (if applicable) where this was undertaken and explain any allocation the approach applied.","\nExplanation/list of any assumptions made for data source, justification and methodology applied or made.","\nState any additional comments, notes or explanations."]
[null,"3.2.1 - OPEX CATEGORIES",null,null,null,"SCS","ACS"]
[null,"DOPEX0101","Distribution licence fee","Financial","SAP GL Account","Actual","Actual",null,null,"Costs for the Distribution licence fee are captured against a specific GL account in SAP.","Directly attributed to Standard Control Services as per current Cost Allocation Method.","Reported value is as per Table 8.4.1 of SA Power Networks' 2018-19 Annual RIN response."]
[null,"DOPEX0102","Network operating costs","Financial","SAP Functional Area / Activities report","Actual","Actual",null,null,"SA Power Networks has a comprehensive Functional Area structure within SAP containing capital and operating activities relating to specific lines of work which are identifiable by ID codes.  This enabled the reporting of expenditure associated with Network operating cost activities.  The reported cost includes an allocated writeback of SAPN over-recoveries in the 2018/19 regulatory year.  The writeback allocation was based on a pro rata split of relevant network business overheads attributed to all direct network capital and operating functions for the year.","Directly attributed to Standard Control Services as per current Cost Allocation Method.","Refer SAPN Additional Comments provided for DOPEX0101."]
[null,"DOPEX0103","Inspections","Financial","SAP Functional Area / Activities report","Actual","Actual",null,null,"SA Power Networks has a comprehensive Functional Area structure within SAP containing capital and operating activities relating to specific lines of work which are identifiable by ID codes.  This enabled the reporting of expenditure associated with Inspection activities.  The reported cost includes an allocated writeback of SAPN over-recoveries in the 2018/19 regulatory year.  The writeback allocation was based on a pro rata split of relevant network business overheads attributed to all direct network capital and operating functions for the year.","Directly attributed to Standard Control Services as per current Cost Allocation Method.","Refer SAPN Additional Comments provided for DOPEX0101."]
[null,"DOPEX0104","Maintenance & repair","Financial","SAP Functional Area / Activities report","Actual","Actual",null,null,"SA Power Networks has a comprehensive Functional Area structure within SAP containing capital and operating activities relating to specific lines of work which are identifiable by ID codes.  This enabled the reporting of expenditure associated with Maintenance and repair activities.  The reported cost includes an allocated writeback of SAPN over-recoveries in the 2018/19 regulatory year.  The writeback allocation was based on a pro rata split of relevant network business overheads attributed to all direct network capital and operating functions for the year.","Directly attributed to Standard Control Services or Alternative Control Services dependent upon current asset classifications and in accordance with the current Cost Allocation Method.  Costs reported under Alternative Control Services relate to Meter maintenance, with costs for this function captured against specific activities in SAP.","Reported values are as per Table 8.4.1 of SA Power Networks' 2018-19 Annual RIN response."]
[null,"DOPEX0105","Substation property maintenance","Financial","SAP cost centre reports / SA Power Networks' cost allocation method","Actual","Actual",null,null,"SA Power Networks has a comprehensive cost centre accounting structure within SAP to capture the costs of each individual organisational department that cannot be directly attributed to specific activities or lines of work.  This enabled the reporting of total costs associated with the businesses' Real Estate and Property Services groups.","A portion of total Real Estate and Property Services costs are directly attributed to Substation property maintenance in accordance with SA Power Networks' cost allocation method.","Refer SAPN Additional Comments provided for DOPEX0101."]
[null,"DOPEX0106","Vegetation management","Financial","SAP Functional Area / Activities report","Actual","Actual",null,null,"SA Power Networks has a comprehensive Functional Area structure within SAP containing capital and operating activities relating to specific lines of work which are identifiable by ID codes.  This enabled the reporting of expenditure associated with Vegetation management activities.  The reported cost includes an allocated writeback of SAPN over-recoveries in the 2018/19 regulatory year.  The writeback allocation was based on a pro rata split of relevant network business overheads attributed to all direct network capital and operating functions for the year.","Directly attributed to Standard Control Services as per current Cost Allocation Method.","Refer SAPN Additional Comments provided for DOPEX0101."]
[null,"DOPEX0107","Emergency response","Financial","SAP Functional Area / Activities report","Actual","Actual",null,null,"SA Power Networks has a comprehensive Functional Area structure within SAP containing capital and operating activities relating to specific lines of work which are identifiable by ID codes.  This enabled the reporting of expenditure associated with Emergency response activities.  The reported cost includes an allocated writeback of SAPN over-recoveries in the 2018/19 regulatory year.  The writeback allocation was based on a pro rata split of relevant network business overheads attributed to all direct network capital and operating functions for the year.","Directly attributed to Standard Control Services as per current Cost Allocation Method.","Refer SAPN Additional Comments provided for DOPEX0101."]
[null,"DOPEX0108","Guaranteed service level payments","Financial","SAP GL Account","Actual","Actual",null,null,"GSL costs are captured against a specific GL account in SAP.","Directly attributed to Standard Control Services as per current Cost Allocation Method.","Refer SAPN Additional Comments provided for DOPEX0101."]
[null,"DOPEX0109","Network insurance","Financial","SA Power Networks Insurance Policy Schedule for 2018-19","Actual","Actual",null,null,"Total costs associated with SA Power Networks' insurance policies are contained within a specific Cost Centre in SAP.  The reported value represents the total value of policies which are considered to relate directly to the Distribution Network as per an itemised policy listing provided by the Risk and Insurance group.","Directly attributed to Standard Control Services as per current Cost Allocation Method.","Refer SAPN Additional Comments provided for DOPEX0101."]
[null,"DOPEX0110","Call centre","Financial","SAP Order report","Actual","Actual",null,null,"Costs for the operation of the network Call Centre are captured against a specific internal Order in SAP.","Directly attributed to Standard Control Services as per current Cost Allocation Method.","Refer SAPN Additional Comments provided for DOPEX0101."]
[null,"DOPEX0111","Customer billing (previously full retail contestability)","Financial","SAP cost centre reports / SA Power Networks' cost allocation method","Actual","Actual",null,null,"SA Power Networks has a comprehensive cost centre accounting structure within SAP to capture the costs of each individual organisational department that cannot be directly attributed to specific activities or lines of work.  This enabled the reporting of total costs associated with the businesses' Revenue management and IT customer billing groups.","The total costs of the Revenue management and IT customer billing groups are reported against Customer billing with the exception of costs relating to Meter reading (refer row 18 below).  Costs associated with Metering customer billing functions are directly attributed to alternative control services, with the remaining costs reported as standard control services.","Refer SAPN Additional Comments provided for DOPEX0104."]
[null,"DOPEX0112","Meter reading","Financial","SAP Order reports","Actual","Actual",null,null,"Costs relating to Meter reading services are captured against various specific internal Orders in SAP.","The direct attribution of Meter reading costs as either Alternative Control Services or Negotiated services is dependent upon current asset service classifications and in accordance with the current Cost Allocation Method.  Cost are captured against various internal Orders, with each Order related to a different Meter reading function that has a specific regulatory service type attached to it.","Reported values are as per Table 8.4.1 of SA Power Networks' 2018-19 Annual RIN response."]
[null,"DOPEX0113","Other customer services","Financial","SAP cost centre reports / SA Power Networks' cost allocation method","Actual","Actual",null,null,"SA Power Networks has a comprehensive cost centre accounting structure within SAP to capture the costs of each individual organisational department that cannot be directly attributed to specific activities or lines of work.  This enabled the reporting of total costs associated with the businesses' Customer Relations department.  ","Customer Relations departmental costs are allocated between Standard Control Services, Alternative Control Services, Negotiated Distribution Services and Unregulated Distribution Services in accordance with SA Power Networks' cost allocation method.  ","Reported values for Standard Control Services and Alternative Control Services are as per Table 8.4.1 of SA Power Networks' 2018-19 Annual RIN response."]
[null,"DOPEX0114","Corporate costs and other operating","Financial","Various SAP reports","Actual","Actual",null,null,"Represents the total balance of operating and maintenance expenditure not reported against the other categories in Table 3.2.1.  Costs primarily relate to SA Power Networks' corporate groups.","Corporate costs are allocated between Standard Control Services, Alternative Control Services, Negotiated Distribution Services, Unregulated Distribution Services and Non-Distribution Services as detailed in SA Power Networks' cost allocation method. ","Reported values for Standard Control Services and Alternative Control Services are as per Table 8.4.1 of SA Power Networks' 2018-19 Annual RIN response."]
[null,"DOPEX01","Total opex","Financial","DOPEX0101-DOPEX0114 above","Actual","Actual",null,null,"Represents total Standard Control Services and Alternative Control Services opex reported against Variables DOPEX0101 to DOPEX0114 in Table 3.2.1.","N/A","Reported values for Standard Control Services and Alternative Control Services are as per Table 8.4.1 of SA Power Networks' 2018-19 Annual RIN response."]
[]
[null,"3.2.2 - OPEX CONSISTENCY",null,null,null,"SCS","ACS"]
[null,"DOPEX0201","Opex for network services","Financial","DOPEX01 and DOPEX0203","Actual","Actual",null,null,"Total Standard Control Services opex reported against DOPEX01 in Table 3.2.1 excluding Standard Control Services opex reported against DOPEX0203 Opex for Connection Services in Table 3.2.2.","Assumes that all direct and allocated indirect Standard Control Services costs reported in Table 3.2.1 necessarily support the delivery of Network Services, other than those classified as Connection Services.","N/A"]
[null,"DOPEX0202","Opex for metering","Financial","DOPEX01 and DOPEX0203","Actual","Actual",null,null,"Total Alternative Control Services opex reported against DOPEX01 in Table 3.2.1 excluding Alternative Control Services opex reported against DOPEX0203 Opex for Connection Services in Table 3.2.2.","Assumes that all direct and allocated indirect Alternative Control Services costs reported in Table 3.2.1 necessarily support the delivery of Metering Services, other than those classified as Connection Services.","N/A"]
[null,"DOPEX0203","Opex for connection services","Financial","SAP cost centre reports / SA Power Networks' cost allocation method","Actual","Actual",null,null,"Represents a component of the reported Other Customer Services cost reported against Variable DOPEX0113 in Table 3.2.1.  The costs are identifiable against a specific cost centre that holds transactions associated with SA Power Networks' Connection Services group.","Costs associated with the dedicated Connection Services group were extracted from SAP and allocated across service segments in accordance with the current Cost Allocation Method.","N/A"]
[null,"DOPEX0204","Opex for public lighting","Financial","N/A","Actual","Actual",null,null,"SA Power Networks' Public Lighting works are classified under Negotiated Services, hence a nil value is reported for both Standard and Alternative Control Services.","N/A","N/A"]
[null,"DOPEX0205","Opex for amounts payable for easement levy or similar direct charges on DNSP","Financial","N/A","Actual","Actual",null,null,"SA Power Networks are not subject to any easement levy or similar direct charges.","N/A","N/A"]
[null,"DOPEX0206","Opex for transmission connection point planning","Financial","N/A","Actual","Actual",null,null,"SA Power Networks capitalises all costs associated with transmission connection points.  ","N/A","N/A"]
[]
[null,"3.2.4 - OPEX FOR HIGH VOLTAGE CUSTOMERS",null,null,null,"SCS","ACS"]
[null,"DOPEX0401","Opex for high voltage customers","Financial","There is no reasonable data source for this information.  Hence, it has been necessary for SA Power Networks to calculate a best estimate of costs as described in the Methodology column.","Estimated","N/A",null,"For commercial reasons, SA Power Networks is unable to obtain actual cost information from it's high voltage customers, hence an estimate of end user costs is necessary.","SA Power Networks were required to estimate the additional Opex that would have been incurred had it been responsible for operating and maintaining the electricity Distribution Transformers that are owned by its high voltage customers.  This was achieved by undertaking the following processes: (1) Using costs reported in Table 3.2.1 as the basis, SA Power Networks identified the relevant Standard Control Services opex categories that were considered to represent the type of costs its high voltage customers might incur in maintaining their Distribution Transformer assets, these categories were: Network operating costs; Maintenance & repair; and Network insurance; (2) In order to approximate the amount of this opex relating to Distribution Transformers, the total of the relevant Standard Control Services opex categories for the year were then multiplied by a percentage amount, representing the percentage of SA Power Networks' closing RAB values for Standard Control Services at 30 June 2019 attributable to Distribution Transformers; and (3) In order to determine the share  of these calculated values relating to high voltage customers for the 2018-19 regulatory year, the values were multiplied by the ratio of high voltage customer observed peak demand MVA (reported against Variable Code DPA0502 in Table 3.5.2.1 of the RIN) as a portion of SA Power Networks' total network observed peak demand MVA (reported against Variable Code DOPSD0201 in Table 3.4.3.3 of the RIN).  ","N/A","N/A"]

{"sheet":"3.2.3 Provisions","index":2,"n_rows":165,"n_cols":12,"rows_kept":165,"cut":false,"hidden":false,"merged":[[1,1,1,3],[1,4,1,11]]}
[]
[null,"SA Power Networks",null,null,"Basis of Preparation"]
[null,1,1.1000000000000001,2,3,4,null,null,5,6,7,8]
[null,"CAT RIN Table Ref / EBT RIN Variable Code","RIN Row/ Column/ Cell or All (entire tab)","COMPONENT","Data Source","Actual / Estimated",null,null,"Justification\n(if estimated)","Methodology \n(actual and estimated)","Assumptions\n(actual and estimated)","SAPN Additional Comments\n(if any)"]
[null,"State the table reference (CA) or Variable Code (EB)","\nState the applicable row, column, cell, or entire tab","\nSelect whether the referenced information is Capex/Opex or Total","\nExplanation of the data source for the referenced information","\nSelect whether the information from data source is either actual or estimated?",null,null,"\nExplanation of why an estimate is required and why actual data does not exist\n\nFor financial information, explanation of why financial information is not in accordance to the financial reporting framework and any changes, impacts and deviations to accounting policies (for any regulatory years).","\nExplanation of the method applied to provide the requested data. This should include an explanation of how the data was derived from other sources (if applicable) where this was undertaken and explain any allocation the approach applied.","\nExplanation/list of any assumptions made for data source, justification and methodology applied or made.","\nState any additional comments, notes or explanations."]
[null,"3.2.3 - PROVISIONS"]
[null,"DOPEX03A","Annual Leave"]
[null,"DOPEX0301A","Opening balance (the carrying amount at the beginning of the period)","Total","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual",null,null,"N/A","Standard Control Services balance reported against Variable DOPEX0314A in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A"]
[null,"DOPEX0302A","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Account / DOPEX0305A / DOPEX0311A","Estimated",null,null,"SA Power Networks considers the total movement in additional provisions and the total movement in the Annual Leave provision relating to Opex and Capex to be actual values.  However there is no practical way to assign an actual split between Opex and Capex for the movement in the additional provisions line.","The movement in the closing balance of the Annual Leave provision reported against DOPEX0314A and the opening balance reported against DOPEX0301A was split between Opex and Capex via the following process: (1) A SAP GL report was run for 2018/19 Annual Leave expense, broken down by business area; (2) The portion of Annual Leave expense attributable to the operational business areas was split between Opex and Capex based on the ratio of labour hours booked to Standard Control Services capital functions to Standard Control Services operating functions in 2018/19; (3) The remaining portion of Annual Leave expense attributable to the corporate and customer relations business areas was allocated to Opex only; (4) The outcomes from steps 2 and 3 were applied to derive the share of the total movement in the provision related to Opex and Capex.  DOPEX0302A represents a derived balancing value, being the Standard Control Services component of the Annual Leave expense related to Opex +/- any offsetting movements in the provision as a result of values reported against DOPEX0305A and DOPEX0311A.  ","The balances and movements in the Provision for Annual Leave are allocated across service segments in accordance with SA Power Networks' current Cost Allocation Method."]
[null,"DOPEX0303A","Additional provisions made in the period, including increases to existing provisions","Capex","SAP GL Account / DOPEX0306A","Estimated",null,null,"Refer Justification provided for DOPEX0302A.","Refer Methodology provided for DOPEX0302A.  DOPEX0303A represents a derived balancing value, being the Standard Control Services component of the Annual Leave expense related to Capex +/- any offsetting movements in the provision as a result of values reported against DOPEX0306A.  ","Refer Assumptions provided for DOPEX0302A."]
[null,"DOPEX0304A","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","Movements in SA Power Networks' Annual Leave provision are attributed to Opex and Capex only.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A"]
[null,"DOPEX0305A","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301A-DOPEX0314A","Estimated",null,null,"SA Power Networks considers the total movement in amounts used and the total movement in the Annual Leave provision relating to Opex and Capex to be actual values.  However there is no practical way to assign an actual split between Opex and Capex for the movement in the amounts used line.","Refer Methodology provided for DOPEX0302A.  DOPEX0305A represents the Standard Control Services component of payments made from the Annual Leave provision related to Opex.","Refer Assumptions for DOPEX0302A."]
[null,"DOPEX0306A","Amounts used (that is, incurred and charged against the provision) during the period","Capex","DOPEX0301A-DOPEX0314A","Estimated",null,null,"Refer Justification provided for DOPEX0305A.","Refer Methodology provided for DOPEX0302A.  DOPEX0306A represents the Standard Control Services component of payments made from the Annual Leave provision related to Capex.","Refer Assumptions for DOPEX0302A."]
[null,"DOPEX0307A","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304A","N/A"]
[null,"DOPEX0308A","Unused amounts reversed during the period","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  Any unused amounts provided for annual leave are paid out to employees upon departure from the business.","N/A"]
[null,"DOPEX0309A","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308A","N/A"]
[null,"DOPEX0310A","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308A","N/A"]
[null,"DOPEX0311A","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","SAP GL Account ","Actual",null,null,"N/A","Standard Control Services component of movements in the provision as a result of changes arising from the passage of time and the effect of any change in the discount rate.  These movements are fully captured against a specific operating expenditure GL account in SAP. ","Refer Assumptions for DOPEX0302A."]
[null,"DOPEX0312A","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311A.  Hence a nil value is reported against Capex.","N/A"]
[null,"DOPEX0313A","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304A","N/A"]
[null,"DOPEX0314A","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Accounts","Actual",null,null,"N/A","The Standard Control Services component of the specific GL accounts that represent the total Provision for Annual Leave.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302A."]
[]
[null,"DOPEX03B","Long Service Leave"]
[null,"DOPEX0301B","Opening balance (the carrying amount at the beginning of the period)","Total","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual",null,null,"N/A","Standard Control Services balance reported against Variable DOPEX0314B in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A"]
[null,"DOPEX0302B","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Account / DOPEX0305B / DOPEX0308B / DOPEX0311B","Estimated",null,null,"SA Power Networks considers the total movement in additional provisions and the total movement in the Long Service Leave provision relating to Opex and Capex to be actual values.  However there is no practical way to assign an actual split between Opex and Capex for the movement in the additional provisions line.","The movement in the closing balance of the Long Service Leave provision reported against DOPEX0314B and the opening balance reported against DOPEX0301B was split between Opex and Capex via the following process: (1) A SAP GL report was run for 2018/19 Long Service Leave expense, broken down by business area; (2) The portion of Long Service Leave expense attributable to the operational business areas was split between Opex and Capex based on the ratio of labour hours booked to Standard Control Services capital functions to Standard Control Services operating functions in 2018/19; (3) The remaining portion of Long Service Leave expense attributable to the corporate and customer relations business areas was allocated to Opex only; (4) The outcomes from steps 2 and 3 were applied to derive the share of the total movement in the provision related to Opex and Capex.  DOPEX0302B represents a derived balancing value, being the Standard Control Services component of the Long Service Leave expense related to Opex +/- any offsetting movements in the provision as a result of values reported against DOPEX0305B, DOPEX0308B and DOPEX0311B.  ","The balances and movements in the Provision for Long Service Leave are allocated across service segments in accordance with SA Power Networks' current Cost Allocation Method."]
[null,"DOPEX0303B","Additional provisions made in the period, including increases to existing provisions","Capex","SAP GL Account / DOPEX0306B / DOPEX0309B","Estimated",null,null,"Refer Justification provided for DOPEX0302B.","Refer Methodology provided for DOPEX0302B.  DOPEX0303B represents a derived balancing value, being the Standard Control Services component of the Long Service Leave expense related to Capex +/- any offsetting movements in the provision as a result of values reported against DOPEX0306B and DOPEX0309B.  ","Refer Assumptions provided for DOPEX0302B."]
[null,"DOPEX0304B","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","Movements in SA Power Networks' Long Service Leave provision are attributed to Opex and Capex only.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A"]
[null,"DOPEX0305B","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301B-DOPEX0314B","Estimated",null,null,"SA Power Networks considers the total movement in amounts used and the total movement in the Long Service Leave provision relating to Opex and Capex to be actual values.  However there is no practical way to assign an actual split between Opex and Capex for the movement in the amounts used line.","Refer Methodology provided for DOPEX0302B.  DOPEX0305B represents the Standard Control Services component of payments made from the Long Service Leave provision related to Opex.","Refer Assumptions for DOPEX0302B."]
[null,"DOPEX0306B","Amounts used (that is, incurred and charged against the provision) during the period","Capex","DOPEX0301B-DOPEX0314B","Estimated",null,null,"Refer Justification provided for DOPEX0305B.","Refer Methodology provided for DOPEX0302B.  DOPEX0306B represents the Standard Control Services component of payments made from the Long Service Leave provision related to Capex.","Refer Assumptions for DOPEX0302B."]
[null,"DOPEX0307B","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304B","N/A"]
[null,"DOPEX0308B","Unused amounts reversed during the period","Opex","SAP GL Accounts","Estimated",null,null,"SA Power Networks considers the total movement in unused amounts reversed and the total movement in the Long Service Leave provision relating to Opex and Capex to be actual values.  However there is no practical way to assign an actual split between Opex and Capex for the movement in unused amounts reversed.","Refer Methodology provided for DOPEX0302B.  DOPEX0308B represents the Standard Control Services Opex component of the sum of any net monthly decrements to the total provision by way of journal.","Refer Assumptions for DOPEX0302B.","Note the total unused amount reflects the gross accrual for each individual employee and accordingly does not consider the adjustments required by AASB119 for probability, wage increases and on-costs.  These AASB119 adjustments are reflected in the annual assessment of SA Power Networks' long service leave liability, as calculated by an independent Actuary, and are included in the amounts reported against Variable Code DOPEX0311B."]
[null,"DOPEX0309B","Unused amounts reversed during the period","Capex","SAP GL Accounts","Estimated",null,null,"Refer Justification provided for DOPEX0308B.","Refer Methodology provided for DOPEX0302B.  DOPEX0309B represents the Standard Control Services Capex component of the sum of any net monthly decrements to the total provision by way of journal.","Refer Assumptions for DOPEX0302B.","Refer Comments for DOPEX0308B"]
[null,"DOPEX0310B","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304B","N/A"]
[null,"DOPEX0311B","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","SAP GL Accounts","Actual",null,null,"N/A","Standard Control Services component of movements in the provision as a result of changes arising from the passage of time and the effect of any change in the discount rate.  These movements are fully captured against specific operating expenditure GL accounts in SAP. ","Refer Assumptions for DOPEX0302B."]
[null,"DOPEX0312B","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311B.  Hence a nil value is reported against Capex.","N/A"]
[null,"DOPEX0313B","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304B","N/A"]
[null,"DOPEX0314B","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Accounts","Actual",null,null,"N/A","The Standard Control Services component of the specific GL accounts that represent the total Provision for Long Service Leave.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302B."]
[]
[null,"DOPEX03C","Workers' Compensation"]
[null,"DOPEX0301C","Opening balance (the carrying amount at the beginning of the period)","Total","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual",null,null,"N/A","Standard Control Services balance reported against Variable DOPEX0314C in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A"]
[null,"DOPEX0302C","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Accounts","Actual",null,null,"N/A","Movements in the Provision for Workers' Compensation are captured against specific GL accounts in SAP.  The reported value represents the sum of any net monthly increments to the total provision by way of journal +/- any other movements in the provision not captured within the other categories.","The balances and movements in the Provision for Workers' Compensation are allocated across service segments in accordance with SA Power Networks' current Cost Allocation Method."]
[null,"DOPEX0303C","Additional provisions made in the period, including increases to existing provisions","Capex","N/A","Actual",null,null,"N/A","SA Power Networks' Workers' Compensation provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Capex components of the provision.","N/A"]
[null,"DOPEX0304C","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","SA Power Networks' Workers' Compensation provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A"]
[null,"DOPEX0305C","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301C-DOPEX0314C","Actual",null,null,"N/A","Balancing item, reflecting payments from the provision.","Refer Assumptions for DOPEX0302C."]
[null,"DOPEX0306C","Amounts used (that is, incurred and charged against the provision) during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0303C","N/A"]
[null,"DOPEX0307C","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304C","N/A"]
[null,"DOPEX0308C","Unused amounts reversed during the period","Opex","SAP GL Accounts","Actual",null,null,"N/A","Movements in the Provision for Workers' Compensation are captured against specific GL accounts in SAP.  The reported value represents the sum of any net monthly decrements to the total provision by way of journal.","Refer Assumptions for DOPEX0302C."]
[null,"DOPEX0309C","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0303C","N/A"]
[null,"DOPEX0310C","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304C","N/A"]
[null,"DOPEX0311C","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  Workers' Compensation claims are regularly assessed, normally resulting in either re-estimations or settlements within a defined period.  Accordingly there is generally no measurable impacts on the provision associated with either changes in the discount rate or the passage of time.","N/A"]
[null,"DOPEX0312C","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311C","N/A"]
[null,"DOPEX0313C","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311C","N/A"]
[null,"DOPEX0314C","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Accounts","Actual",null,null,"N/A","The Standard Control Services component of the specific GL accounts that represent the total Provision for Workers' Compensation.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302C."]
[]
[null,"DOPEX03D","Self Insurance"]
[null,"DOPEX0301D","Opening balance (the carrying amount at the beginning of the period)","Total","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual",null,null,"N/A","Standard Control Services balance reported against Variable DOPEX0314D in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A"]
[null,"DOPEX0302D","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Accounts","Actual",null,null,"N/A","Movements in the Provision for Self Insurance are captured against specific GL accounts in SAP.  The reported value represents the sum of any net monthly increments to the total provision by way of journal.","The balances and movements in the Provision for Self Insurance are directly attributed to Standard Control Services in accordance with SA Power Networks' current Cost Allocation Method."]
[null,"DOPEX0303D","Additional provisions made in the period, including increases to existing provisions","Capex","N/A","Actual",null,null,"N/A","SA Power Networks' Self Insurance provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Capex components of the provision.","N/A"]
[null,"DOPEX0304D","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","SA Power Networks' Self Insurance provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A"]
[null,"DOPEX0305D","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301D-DOPEX0314D","Actual",null,null,"N/A","Balancing item, reflecting payments from the provision.","Refer Assumptions for DOPEX0302D."]
[null,"DOPEX0306D","Amounts used (that is, incurred and charged against the provision) during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0303D","N/A"]
[null,"DOPEX0307D","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304D","N/A"]
[null,"DOPEX0308D","Unused amounts reversed during the period","Opex","SAP GL Accounts","Actual",null,null,"N/A","Movements in the Provision for Self Insurance are captured against specific GL accounts in SAP.  The reported value represents the sum of any net monthly decrements to the total provision by way of journal.","Refer Assumptions for DOPEX0302D."]
[null,"DOPEX0309D","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0303D","N/A"]
[null,"DOPEX0310D","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304D","N/A"]
[null,"DOPEX0311D","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  The amount of the Self Insurance provision is assessed and adjusted by SA Power Networks on a monthly basis via the P&L expense account.  SA Power Networks has not made any adjustments to the provision for either changes to the discount rate or the passage of time.","N/A"]
[null,"DOPEX0312D","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311D","N/A"]
[null,"DOPEX0313D","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311D","N/A"]
[null,"DOPEX0314D","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Accounts","Actual",null,null,"N/A","The closing balance of the specific GL accounts that represent the total Provision for Self Insurance.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302D."]
[]
[null,"DOPEX03E","Income Protection Scheme"]
[null,"DOPEX0301E","Opening balance (the carrying amount at the beginning of the period)","Total","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual",null,null,"N/A","Standard Control Services balance reported against Variable DOPEX0314E in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A"]
[null,"DOPEX0302E","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Accounts","Actual",null,null,"N/A","Movements in the Provision for Income Protection are captured against specific GL accounts in SAP.  The reported value represents the sum of any net monthly increments to the total provision by way of journal +/- any other movements in the provision not captured within the other categories.","The balances and movements in the Provision for Income Protection are allocated across service segments in accordance with SA Power Networks' current Cost Allocation Method."]
[null,"DOPEX0303E","Additional provisions made in the period, including increases to existing provisions","Capex","N/A","Actual",null,null,"N/A","SA Power Networks' Income Protection provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Capex components of the provision.","N/A"]
[null,"DOPEX0304E","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","SA Power Networks' Income Protection provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A"]
[null,"DOPEX0305E","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301E-DOPEX0314E","Actual",null,null,"N/A","Balancing item, reflecting payments from the provision.","Refer Assumptions for DOPEX0302E."]
[null,"DOPEX0306E","Amounts used (that is, incurred and charged against the provision) during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0303E","N/A"]
[null,"DOPEX0307E","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304E","N/A"]
[null,"DOPEX0308E","Unused amounts reversed during the period","Opex","SAP GL Accounts","Actual",null,null,"N/A","Movements in the Provision for Income Protection are captured against specific GL accounts in SAP.  The reported value represents the sum of any net monthly decrements to the total provision by way of journal.","Refer Assumptions for DOPEX0302E."]
[null,"DOPEX0309E","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0303E","N/A"]
[null,"DOPEX0310E","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304E","N/A"]
[null,"DOPEX0311E","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  The amount of the Income Protection provision is assessed and adjusted by SA Power Networks on a monthly basis via the P&L expense account.  SA Power Networks has not made any adjustments to the provision for either changes to the discount rate or the passage of time.","N/A"]
[null,"DOPEX0312E","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311E","N/A"]
[null,"DOPEX0313E","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311E","N/A"]
[null,"DOPEX0314E","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Accounts","Actual",null,null,"N/A","The Standard Control Services component of the specific GL accounts that represent the total Provision for Income Protection.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302E."]
[]
[null,"DOPEX03F","Environmental"]
[null,"DOPEX0301F","Opening balance (the carrying amount at the beginning of the period)","Total","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual",null,null,"N/A","Standard Control Services balance reported against Variable DOPEX0314F in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A"]
[null,"DOPEX0302F","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Accounts","Actual",null,null,"N/A","Movements in the Environmental Provision are captured against specific GL accounts in SAP.  The reported value represents the sum of any net monthly increments to the total provision by way of journal.","The balances and movements in the Environmental Provision are directly attributed to Standard Control Services in accordance with SA Power Networks' current Cost Allocation Method."]
[null,"DOPEX0303F","Additional provisions made in the period, including increases to existing provisions","Capex","N/A","Actual",null,null,"N/A","SA Power Networks' Environmental provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Capex components of the provision.","N/A"]
[null,"DOPEX0304F","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","SA Power Networks' Environmental provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A"]
[null,"DOPEX0305F","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301F-DOPEX0314F","Actual",null,null,"N/A","Balancing item, reflecting payments from the provision.","Refer Assumptions for DOPEX0302F."]
[null,"DOPEX0306F","Amounts used (that is, incurred and charged against the provision) during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0303F","N/A"]
[null,"DOPEX0307F","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304F","N/A"]
[null,"DOPEX0308F","Unused amounts reversed during the period","Opex","SAP GL Accounts","Actual",null,null,"N/A","Movements in the Environmental Provision are captured against specific GL accounts in SAP.  Represents the sum of any net monthly decrements to the total provision by way of journal.  As there were no net monthly decrements to the total provision in 2018/19, a nil value has been reported.","Refer Assumptions for DOPEX0302F."]
[null,"DOPEX0309F","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308F","N/A"]
[null,"DOPEX0310F","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308F","N/A"]
[null,"DOPEX0311F","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  The total amount of the Environmental provision is assessed by SA Power Networks on a monthly basis, and adjusted periodically via the P&L expense account as required.  SA Power Networks has not made any adjustments to the provision for either changes to the discount rate or the passage of time.","N/A"]
[null,"DOPEX0312F","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311F","N/A"]
[null,"DOPEX0313F","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311F","N/A"]
[null,"DOPEX0314F","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Accounts","Actual",null,null,"N/A","The Standard Control Services component of the specific GL accounts that represent the total Environmental Provision.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302F."]
[]
[null,"DOPEX03G","Employee Bonuses"]
[null,"DOPEX0301G","Opening balance (the carrying amount at the beginning of the period)","Total","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual",null,null,"N/A","Standard Control Services balance reported against Variable DOPEX0314G in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A"]
[null,"DOPEX0302G","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Account / DOPEX0308G","Actual",null,null,"N/A","Employee Bonuses expense is captured against a specific GL account in SAP.  Represents a derived value, being the Standard Control Services component of the Employee Bonuses expense +/- any offsetting movements in the provision as a result of values reported against DOPEX0308G.","The balances and movements in the Employee Bonuses Provision are allocated across service segments in accordance with SA Power Networks' current Cost Allocation Method."]
[null,"DOPEX0303G","Additional provisions made in the period, including increases to existing provisions","Capex","N/A","Actual",null,null,"N/A","SA Power Networks' Employee Bonuses provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Capex components of the provision.","N/A"]
[null,"DOPEX0304G","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","SA Power Networks' Employee Bonuses provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A"]
[null,"DOPEX0305G","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301G-DOPEX0314G","Actual",null,null,"N/A","Balancing item, reflecting payments from the provision.","Refer Assumptions for DOPEX0302G."]
[null,"DOPEX0306G","Amounts used (that is, incurred and charged against the provision) during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0303G","N/A"]
[null,"DOPEX0307G","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0304G","N/A"]
[null,"DOPEX0308G","Unused amounts reversed during the period","Opex","SAP GL Account","Actual",null,null,"N/A","Movements in the Employee Bonuses Provision are captured against a specific GL account in SAP.  The reported value represents the sum of any net monthly decrements to the total provision by way of journal.  As there were no net monthly decrements to the total provision in 2018/19, a nil value has been reported.","Refer Assumptions for DOPEX0302G."]
[null,"DOPEX0309G","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308G","N/A"]
[null,"DOPEX0310G","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308G","N/A"]
[null,"DOPEX0311G","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  The amount of the Employee Bonuses provision is assessed and adjusted by SA Power Networks on a monthly basis via the P&L expense account.  SA Power Networks has not made any adjustments to the provision for either changes to the discount rate or the passage of time.","N/A"]
[null,"DOPEX0312G","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311G","N/A"]
[null,"DOPEX0313G","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311G","N/A"]
[null,"DOPEX0314G","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Account","Actual",null,null,"N/A","The Standard Control Services component of the specific GL account that represents the total Employee Bonuses Provision.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302G."]
[]
[null,"DOPEX03H","Guaranteed Service Level (GSL) Payments"]
[null,"DOPEX0301H","Opening balance (the carrying amount at the beginning of the period)","Total","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","N/A","In 2016-17, a GSL payments provision was included in the closing balance reported against DOPEX0314D Self Insurance.  This is the first year in which GSL payments has been reported as a separate provision.","N/A","Standard Control Services balance reported against Variable DOPEX0314H in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A"]
[null,"DOPEX0302H","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Account","Actual","N/A",null,"N/A","Movements in the GSL payments provision are captured against a specific GL account in SAP.  This value represents the sum of any net monthly increments to the total provision by way of journal.  As there were no net monthly increments to the total provision in 2018/19, a nil value has been reported.","The balances and movements in the GSL payments provision are directly attributed to Standard Control Services in accordance with SA Power Networks' current Cost Allocation Method."]
[null,"DOPEX0303H","Additional provisions made in the period, including increases to existing provisions","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0302H","N/A"]
[null,"DOPEX0304H","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0302H","N/A"]
[null,"DOPEX0305H","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301H-DOPEX0314H","Actual",null,null,"N/A","Balancing item, reflecting payments from the provision.  As there were no payments made from the provision in 2018/19, a nil value has been reported.","Refer Assumptions for DOPEX0302H."]
[null,"DOPEX0306H","Amounts used (that is, incurred and charged against the provision) during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0305H","N/A"]
[null,"DOPEX0307H","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0305H","N/A"]
[null,"DOPEX0308H","Unused amounts reversed during the period","Opex","SAP GL Account","Actual",null,null,"N/A","Movements in the GSL payments provision are captured against a specific GL account in SAP.  The reported value represents the sum of any net monthly decrements to the total provision by way of journal.","Refer Assumptions for DOPEX0302H."]
[null,"DOPEX0309H","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","SA Power Networks' GSL payments provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Capex components of the provision.","N/A"]
[null,"DOPEX0310H","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","SA Power Networks' GSL payments provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A"]
[null,"DOPEX0311H","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  Eligible GSL payments are regularly assessed and are settled within a defined period as legislated by the GSL Scheme.  Accordingly there is generally no measurable impacts on the provision associated with either changes in the discount rate or the passage of time.","N/A"]
[null,"DOPEX0312H","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311H","N/A"]
[null,"DOPEX0313H","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311H","N/A"]
[null,"DOPEX0314H","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Account","Actual",null,null,"N/A","SA Power Networks' GSL payments provision has a nil balance at 30 June 2019.  ","N/A"]
[]
[null,"DOPEX03I","Restructuring"]
[null,"DOPEX0301I","Opening balance (the carrying amount at the beginning of the period)","Total","N/A","Actual",null,null,"N/A","2018/19 is the first year in which SA Power Networks has taken up a Restructuring provision.","N/A","N/A"]
[null,"DOPEX0302I","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Account","Actual",null,null,"N/A","Movements in the Restructuring provision are captured against a specific GL account in SAP.  This value represents the sum of any net monthly increments to the total provision by way of journal.  ","The balances and movements in the Restructuring Provision are allocated across service segments in accordance with SA Power Networks' current Cost Allocation Method.","N/A"]
[null,"DOPEX0303I","Additional provisions made in the period, including increases to existing provisions","Capex","N/A","Actual",null,null,"N/A","SA Power Networks' Restructuring provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Capex components of the provision.","N/A","N/A"]
[null,"DOPEX0304I","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","SA Power Networks' Restructuring provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A","N/A"]
[null,"DOPEX0305I","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301I-DOPEX0314I","Actual",null,null,"N/A","Balancing item, reflecting payments from the provision.  As there were no payments made from the provision in 2018/19, a nil value has been reported.","Refer Assumptions for DOPEX0302I.","N/A"]
[null,"DOPEX0306I","Amounts used (that is, incurred and charged against the provision) during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0305I","N/A","N/A"]
[null,"DOPEX0307I","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0305I","N/A","N/A"]
[null,"DOPEX0308I","Unused amounts reversed during the period","Opex","SAP GL Account","Actual",null,null,"N/A","Movements in the Restructuring provision are captured against a specific GL account in SAP.  The reported value represents the sum of any net monthly decrements to the total provision by way of journal.  As there were no net monthly decrements to the total provision in 2018/19, a nil value has been reported.","Refer Assumptions for DOPEX0302I.","N/A"]
[null,"DOPEX0309I","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308I","N/A","N/A"]
[null,"DOPEX0310I","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308I","N/A","N/A"]
[null,"DOPEX0311I","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  The amount of the Restructuring provision is assessed and adjusted by SA Power Networks on a monthly basis via the P&L expense account.  SA Power Networks has not made any adjustments to the provision for either changes to the discount rate or the passage of time.","N/A","N/A"]
[null,"DOPEX0312I","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311I","N/A","N/A"]
[null,"DOPEX0313I","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311I","N/A","N/A"]
[null,"DOPEX0314I","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Account","Actual",null,null,"N/A","The Standard Control Services component of the specific GL account that represents the total Restructuring Provision.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302I.","N/A"]
[]
[null,"DOPEX03J","Superannuation"]
[null,"DOPEX0301J","Opening balance (the carrying amount at the beginning of the period)","Total","N/A","Actual",null,null,"N/A","2018/19 is the first year in which SA Power Networks has taken up a Superannuation provision.","N/A","N/A"]
[null,"DOPEX0302J","Additional provisions made in the period, including increases to existing provisions","Opex","SAP GL Account","Actual",null,null,"N/A","Movements in the Superannuation provision are captured against a specific GL account in SAP.  This value represents the sum of any net monthly increments to the total provision by way of journal.  ","The balances and movements in the Superannuation Provision are allocated across service segments in accordance with SA Power Networks' current Cost Allocation Method.","N/A"]
[null,"DOPEX0303J","Additional provisions made in the period, including increases to existing provisions","Capex","N/A","Actual",null,null,"N/A","SA Power Networks' Superannuation provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Capex components of the provision.","N/A","N/A"]
[null,"DOPEX0304J","Additional provisions made in the period, including increases to existing provisions","Other","N/A","Actual",null,null,"N/A","SA Power Networks' Superannuation provision is accounted for wholly against the operating accounts.  Therefore, there are nil balances and movements reported against the Other components of the provision.","N/A","N/A"]
[null,"DOPEX0305J","Amounts used (that is, incurred and charged against the provision) during the period","Opex","DOPEX0301J-DOPEX0314J","Actual",null,null,"N/A","Balancing item, reflecting payments from the provision.  As there were no payments made from the provision in 2018/19, a nil value has been reported.","Refer Assumptions for DOPEX0302J.","N/A"]
[null,"DOPEX0306J","Amounts used (that is, incurred and charged against the provision) during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0305J","N/A","N/A"]
[null,"DOPEX0307J","Amounts used (that is, incurred and charged against the provision) during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0305J","N/A","N/A"]
[null,"DOPEX0308J","Unused amounts reversed during the period","Opex","SAP GL Account","Actual",null,null,"N/A","Movements in the Superannuation provision are captured against a specific GL account in SAP.  The reported value represents the sum of any net monthly decrements to the total provision by way of journal.  As there were no net monthly decrements to the total provision in 2018/19, a nil value has been reported.","Refer Assumptions for DOPEX0302J.","N/A"]
[null,"DOPEX0309J","Unused amounts reversed during the period","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308J","N/A","N/A"]
[null,"DOPEX0310J","Unused amounts reversed during the period","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0308J","N/A","N/A"]
[null,"DOPEX0311J","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Opex","N/A","Actual",null,null,"N/A","Not applicable to SA Power Networks.  The amount of the Superannuation provision is assessed and adjusted by SA Power Networks on a monthly basis via the P&L expense account.  SA Power Networks has not made any adjustments to the provision for either changes to the discount rate or the passage of time.","N/A","N/A"]
[null,"DOPEX0312J","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Capex","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311J","N/A","N/A"]
[null,"DOPEX0313J","The increase during  the period in the discounted amount arising from the passage of time and the effect of any change in the discount rate","Other","N/A","Actual",null,null,"N/A","Refer Methodology for DOPEX0311J","N/A","N/A"]
[null,"DOPEX0314J","Closing balance (the carrying amount at the end of the period)","Total","SAP GL Account","Actual",null,null,"N/A","The Standard Control Services component of the specific GL account that represents the total Superannuation Provision.  This forms part of the total Provisions liability reported in SA Power Networks' financial accounts at 30 June 2019.","Refer Assumptions for DOPEX0302J.","N/A"]

{"sheet":"3.3 Assets (RAB)","index":3,"n_rows":127,"n_cols":12,"rows_kept":127,"cut":false,"hidden":false,"merged":[[1,1,1,3],[1,4,1,11]]}
[]
[null,"SA Power Networks",null,null,"Basis of Preparation"]
[null,1,1.1000000000000001,2,3,"4.0a","4.0b","4.0c",5,6,7,8]
[null,"CAT RIN Table Ref / EBT RIN Variable Code","RIN Row/ Column/ Cell or All (entire tab)","Financial /\nNon-Financial","Data Source","Actual / Estimated\nNetwork Services","Actual / Estimated\nStandard Control Services","Actual / Estimated\nAlternative Control Services","Justification\n(if estimated)","Methodology \n(actual and estimated)","Assumptions\n(actual and estimated)","SAPN Additional Comments\n(if any)"]
[null,"State the table reference (CA) or Variable Code (EB)","\nState the applicable row, column, cell, or entire tab","\nSelect whether the referenced information is financial or non-financial","\nExplanation of the data source for the referenced information","\nSelect whether the information from data source is either actual or estimated?","\nSelect whether the information from data source is either actual or estimated?","\nSelect whether the information from data source is either actual or estimated?","\nExplanation of why an estimate is required and why actual data does not exist\n\nFor financial information, explanation of why financial information is not in accordance to the financial reporting framework and any changes, impacts and deviations to accounting policies (for any regulatory years).","\nExplanation of the method applied to provide the requested data. This should include an explanation of how the data was derived from other sources (if applicable) where this was undertaken and explain any allocation the approach applied.","\nExplanation/list of any assumptions made for data source, justification and methodology applied or made.","\nState any additional comments, notes or explanations."]
[null,"3.3.1 - REGULATORY ASSET BASE VALUES",null,null,null,"Network Services","SCS","ACS"]
[null,"DRAB0101","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0107 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0102","Inflation addition","Financial","AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016); and\nAustralian Bureau of Statistics - Consumer Price Index, Australia ","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","N/A","N/A"]
[null,"DRAB0103","Straight line depreciation","Financial","AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016); and\nAustralian Bureau of Statistics - Consumer Price Index, Australia ","Actual","Actual","Actual","N/A","SA Power Networks' forecast 2018/19 straight-line depreciation in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Network Services depreciation was derived by taking the Network Services opening RAB value divided by the Standard Control Services opening RAB value multiplied by the Standard Control Services straight line depreciation charge for each applicable asset category.  ","N/A"]
[null,"DRAB0105","Actual additions (recognised in RAB)","Financial","Actual capital additions and contributions as reported in SA Power Networks' Annual RIN Response for 2018-19; the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016); and Australian Bureau of Statistics - Consumer Price Index, Australia.","Actual","Actual","Actual","N/A","Represents the net of actual capital additions and contributions as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 total RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the total RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Network Services, additions exclude values associated with Connection Services assets. ","N/A"]
[null,"DRAB0106","Disposals","Financial","Actual Disposals as reported in SA Power Networks' 2018-19 Annual RIN Response.","Actual","Actual","Actual","N/A","Disposal values represent gross proceeds from the sale of assets.","N/A","N/A"]
[null,"DRAB0107","Closing value ","Financial","DRAB0101-DRAB0106; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0101 to DRAB0106.","Reported values align to 30 June 2019 nominal balances as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks, including the previous period adjustment for the difference between actual and forecast net capex, but excluding the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"3.3.2 - ASSET VALUE ROLL FORWARD",null,null,null,"Network Services","SCS","ACS"]
[null,"For overhead network assets less than 33kV:"]
[null,"DRAB0201","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0207 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0202","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values for the Distribution lines, LVS and Contributions asset classes at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a pro rata assignment of inflation additions from the data source to the Distribution Lines (Overhead) and Low Voltage Services (Overhead) asset classes based on opening balances.  ","N/A"]
[null,"DRAB0203","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","SA Power Networks' forecast 2018/19 straight-line depreciation for the Distribution lines, LVS and Contributions asset classes in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Values represent a pro rata assignment of forecast depreciation from the data source to the Distribution Lines (Overhead) and Low Voltage Services (Overhead) asset classes based on opening balances.  Network Services depreciation was derived by taking the Network Services opening RAB value divided by the Standard Control Services opening RAB value multiplied by the Standard Control Services straight line depreciation charge for each applicable asset category.  ","N/A"]
[null,"DRAB0205","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Represents the net of actual capital additions and contributions for the Distribution lines, LVS and Contributions asset classes as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Represents the net of Capital Additions, Capital Contributions and Rate of return (nominal WACC) additions to the Distribution Lines (Overhead) and Low Voltage Services (Overhead) asset classes.  For Network Services, additions exclude values associated with Connection Services assets. ","N/A"]
[null,"DRAB0206","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Distribution Lines (Overhead) and Low Voltage Services (Overhead) asset classes.  For Network Services, additions exclude values associated with Connection Services assets. ","N/A"]
[null,"DRAB0207","Closing value","Financial","DRAB0201-DRAB0206; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0201 to DRAB0206.","Reported values represent a pro rata allocation of 30 June 2019 balances for the Distribution lines, LVS and Contributions asset classes as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks, including the previous period adjustment for the difference between actual and forecast net capex, but excluding the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"For underground network assets less than 33kV:"]
[null,"DRAB0301","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0307 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0302","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0202.","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a pro rata assignment of inflation additions from the data source to the Distribution Lines (Underground) and Low Voltage Services (Underground) asset classes based on opening balances.  ","N/A"]
[null,"DRAB0303","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0203.","Values represent a pro rata assignment of forecast depreciation from the data source to the Distribution Lines (Underground) and Low Voltage Services (Underground) asset classes based on opening balances.  Network Services depreciation was derived by taking the Network Services opening RAB value divided by the Standard Control Services opening RAB value multiplied by the Standard Control Services straight line depreciation charge for each applicable asset category.  ","N/A"]
[null,"DRAB0305","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0205.","Represents the net of Capital Additions, Capital Contributions and Rate of return (nominal WACC) additions to the Distribution Lines (Underground) and Low Voltage Services (Underground) asset classes.  For Network Services, additions exclude values associated with Connection Services assets. ","N/A"]
[null,"DRAB0306","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Distribution Lines (Underground) and Low Voltage Services (Underground) asset classes.  For Network Services, additions exclude values associated with Connection Services assets. ","N/A"]
[null,"DRAB0307","Closing value","Financial","DRAB0301-DRAB0306; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0301 to DRAB0306.","Refer Assumptions provided for DRAB0207.","N/A"]
[]
[null,"For distribution substations and transformers:"]
[null,"DRAB0401","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0407 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0402","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values for the Substations and Distribution transformers asset classes at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a pro rata assignment of inflation additions from the data source to the Distribution Substations asset class based on opening balances and a full assignment of inflation additions from the data source to the Distribution Transformers asset class.","N/A"]
[null,"DRAB0403","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","SA Power Networks' forecast 2018/19 straight-line depreciation for the Substations and Distribution transformers asset classes in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Values represent a pro rata assignment of forecast depreciation from the data source to the Distribution Substations asset class based on opening balances and a full assignment of forecast depreciation from the data source to the Distribution Transformers asset class.  ","N/A"]
[null,"DRAB0405","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Represents actual capital additions for the Substations and Distribution transformers asset classes as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Represents the total of Capital Additions and Rate of return (nominal WACC) additions to the Distribution Substations and Distribution Transformers asset classes.  ","N/A"]
[null,"DRAB0406","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Distribution Substations and Distribution Transformers asset classes.  ","N/A"]
[null,"DRAB0407","Closing value ","Financial","DRAB0401-DRAB0406; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0401 to DRAB0406.","Reported values represent a pro rata allocation of the 30 June 2019 nominal balance for the Substations asset class and a full allocation of the 30 June 2019 nominal balance for the Distribution transformers asset class as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks.  Reported values include the previous period adjustment for the difference between actual and forecast net capex, but exclude the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"For overhead network assets 33kV and above:"]
[null,"DRAB0501","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0507 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0502","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values for the Sub-transmission lines asset class at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a pro rata assignment of inflation additions from the data source to the Sub-transmission Lines (overhead) asset class based on opening balances.","N/A"]
[null,"DRAB0503","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","SA Power Networks' forecast 2018/19 straight-line depreciation for the Sub-transmission Lines asset class in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Values represent a pro rata assignment of forecast depreciation from the data source to the Sub-transmission Lines (Overhead) asset classes based on opening balances.","N/A"]
[null,"DRAB0505","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Represents actual capital additions for the Sub-transmission Lines asset class as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Represents the total of Capital Additions and Rate of return (nominal WACC) additions to the Sub-transmission Lines (Overhead) asset classes.","N/A"]
[null,"DRAB0506","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Sub-transmission Lines (Overhead) asset classes.  ","N/A"]
[null,"DRAB0507","Closing value","Financial","DRAB0501-DRAB0506; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0501 to DRAB0506.","Reported values represent a pro rata allocation of the 30 June 2019 nominal balance for the Sub-transmission Lines asset class as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks.  Reported values include the previous period adjustment for the difference between actual and forecast net capex, but exclude the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"For underground network assets 33kV and above:"]
[null,"DRAB0601","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0607 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0602","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0502.","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a pro rata assignment of inflation additions from the data source to the Sub-transmission Lines (underground) asset class based on opening balances.","N/A"]
[null,"DRAB0603","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0503.","Values represent a pro rata assignment of forecast depreciation from the data source to the Sub-transmission Lines (Underground) asset classes based on opening balances.","N/A"]
[null,"DRAB0605","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0505.","Represents the total of Capital Additions and Rate of return (nominal WACC) additions to the Sub-transmission Lines (Underground) asset classes.","N/A"]
[null,"DRAB0606","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Sub-transmission Lines (Underground) asset classes.  ","N/A"]
[null,"DRAB0607","Closing value","Financial","DRAB0601-DRAB0606; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0601 to DRAB0606.","Refer Assumptions provided for DRAB0507.","N/A"]
[]
[null,"For zone substations and transformers:"]
[null,"DRAB0701","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0707 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0702","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values for the Substations and Substation Land asset classes at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a pro rata assignment of inflation additions from the data source to the Zone Substations and Transformers asset class based on opening balances and a full assignment of inflation additions to the Substation Land asset class.","N/A"]
[null,"DRAB0703","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","SA Power Networks' forecast 2018/19 straight-line depreciation for the Substations asset class in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Values represent a pro rata assignment of forecast depreciation from the data source to the Zone Substations and Transformers asset classes based on opening balances.","N/A"]
[null,"DRAB0705","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Represents actual capital additions for the Substations and Substation Land asset classes as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Represents the total of Capital Additions and Rate of return (nominal WACC) additions to the Zone Substations and Transformers asset classes, together with the Substation Land asset class.","N/A"]
[null,"DRAB0706","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Zone Substations and Transformers asset classes, together with the Substation Land asset class.  ","N/A"]
[null,"DRAB0707","Closing value ","Financial","DRAB0701-DRAB0706; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0701 to DRAB0706.","Reported values represent a pro rata allocation of the 30 June 2019 nominal balance for the Substations asset class and a full allocation of the 30 June 2019 nominal balance for the Substation Land asset class as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks.  Reported values include the previous period adjustment for the difference between actual and forecast net capex, but exclude the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"For easements:"]
[null,"DRAB0801","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0807 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0802","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values for the Easements asset class at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a full assignment of inflation additions from the data source to the Easements asset class.","N/A"]
[null,"DRAB0805","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Represents actual capital additions for the Easements asset class as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Represents the total of Capital Additions and Rate of return (nominal WACC) additions to the Easements asset class.","N/A"]
[null,"DRAB0806","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Easements asset class.  ","N/A"]
[null,"DRAB0807","Closing value","Financial","DRAB0801-DRAB0806; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0801 to DRAB0806.","Reported values represent a full allocation of the 30 June 2019 nominal balance for the Easements asset class as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks.  Reported values include the previous period adjustment for the difference between actual and forecast net capex, but exclude the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"For meters:"]
[null,"DRAB0901","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX0907 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB0902","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values for the Meters asset class at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a full assignment of inflation additions from the data source to the Meters asset classes.","N/A"]
[null,"DRAB0903","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","SA Power Networks' forecast 2018/19 straight-line depreciation for the Meters asset class in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Values represent a full assignment of forecast depreciation from the data source to the Meters asset classes based on opening balances.","N/A"]
[null,"DRAB0905","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Represents actual capital additions for the Meters asset class as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Represents the total of Capital Additions and Rate of return (nominal WACC) additions to the Meters asset class.","N/A"]
[null,"DRAB0906","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Meters asset classes.  ","N/A"]
[null,"DRAB0907","Closing value","Financial","DRAB0901-DRAB0906; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB0901 to DRAB0906.","Reported values represent a full allocation of the 30 June 2019 nominal balance for the Meters asset class as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks.  Reported values include the previous period adjustment for the difference between actual and forecast net capex, but exclude the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"For \"other\" asset items with long lives:"]
[null,"DRAB1001","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX1007 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB1002","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values for the Communications, Land, Buildings, Vehicles - 15 years, Vehicles - 10 years, Plant & Tools/Office Furniture and Equity Raising Costs asset classes at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a full assignment of inflation additions from the data source to the Communications, Land, Buildings, Vehicles - 15 years, Vehicles - 10 years, Plant & Tools/Office Furniture and Equity Raising Costs asset classes based on opening balances.","N/A"]
[null,"DRAB1003","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","SA Power Networks' forecast 2018/19 straight-line depreciation for the Communications, Buildings, Vehicles - 15 years, Vehicles - 10 years, Plant & Tools/Office Furniture and Equity Raising Costs asset classes in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Values represent a full assignment of forecast depreciation from the data source to the Communications, Buildings, Vehicles - 15 years, Vehicles - 10 years, Plant & Tools/Office Furniture and Equity Raising Costs asset classes based on opening balances.","N/A"]
[null,"DRAB1005","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Represents actual capital additions for the Communications, Land, Buildings, Vehicles - 15 years, Vehicles - 10 years, Plant & Tools/Office Furniture and Equity Raising Costs asset classes as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Represents the total of Capital Additions and Rate of return (nominal WACC) additions to the Communications, Land, Buildings, Vehicles - 15 years, Vehicles - 10 years, Plant & Tools/Office Furniture and Equity Raising Costs asset classes.  ","N/A"]
[null,"DRAB1006","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Communications, Land, Buildings, Vehicles - 15 years, Vehicles - 10 years, Plant & Tools/Office Furniture and Equity Raising Costs asset classes.  ","N/A"]
[null,"DRAB1007","Closing value","Financial","DRAB1001-DRAB1006; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB1001 to DRAB1006.","Reported values represent a full allocation of the 30 June 2019 nominal balances for the Communications, Land, Buildings, Vehicles - 15 years, Vehicles - 10 years, Plant & Tools/Office Furniture and Equity Raising Costs asset classes as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks.  Reported values include the previous period adjustment for the difference between actual and forecast net capex, but exclude the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"For \"other\" asset items with short lives:"]
[null,"DRAB1101","Opening value","Financial","SA Power Networks' 2017-18 Benchmarking RIN Response","Actual","Actual","Actual","N/A","Balances reported against Variable DOPEX1107 in SA Power Networks' 2017-18 Benchmarking RIN response.","N/A","N/A"]
[null,"DRAB1102","Inflation addition","Financial","Refer Data Source provided for DRAB0102.","Actual","Actual","Actual","N/A","SA Power Networks' opening RAB values for the Light Vehicles, IT and Meter Reading Handheld Devices asset classes at 30 June 2018 in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) multiplied by the December 2018 on December 2017 movement in the ABS's \"Weighted average of eight capital cities index\".   ","Each SA Power Networks' asset class can be directly mapped to a Roll Forward Model asset category as well as a Benchmarking RIN asset category.  Values represent a full assignment of inflation additions from the data source to the Light Vehicles, IT and Meter Reading Handheld Devices asset classes based on opening balances.","N/A"]
[null,"DRAB1103","Straight line depreciation","Financial","Refer Data Source provided for DRAB0103.","Actual","Actual","Actual","N/A","SA Power Networks' forecast 2018/19 straight-line depreciation for the Light Vehicles, IT and Meter Reading Handheld Devices asset classes in nominal dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Values represent a full assignment of forecast depreciation from the data source to the Light Vehicles, IT and Meter Reading Handheld Devices asset classes based on opening balances.","N/A"]
[null,"DRAB1105","Actual additions (recognised in RAB)","Financial","Refer Data Source provided for DRAB0105.","Actual","Actual","Actual","N/A","Represents actual capital additions for the Light Vehicles, IT and Meter Reading Handheld Devices asset classes as reported in SA Power Networks' Annual RIN Response for 2018-19 plus rate of return (nominal WACC) additions to RAB as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks adjusted to nominal using the actual CPI increase from December 2017 to December 2018.  Reported values include adjustments to align the 30 June 2018 RAB balances reported in SA Power Networks' 2017-18 Benchmarking RIN response with the RAB values at 30 June 2018 in real dollars as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Represents the total of Capital Additions and Rate of return (nominal WACC) additions to the Light Vehicles, IT and Meter Reading Handheld Devices asset classes.","N/A"]
[null,"DRAB1106","Disposals","Financial","Refer Data Source provided for DRAB0106.","Actual","Actual","Actual","N/A","Refer Methodology provided for DRAB0106.","Represents disposals from the Light Vehicles, IT and Meter Reading Handheld Devices asset classes.","N/A"]
[null,"DRAB1107","Closing value ","Financial","DRAB1101-DRAB1106; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Actual","Actual","Actual","N/A","Represents the net sum of values reported against Variable Codes DRAB1101 to DRAB1106.","Reported values represent a full allocation of the 30 June 2019 nominal balances for the Light Vehicles, IT and Meter Reading Handheld Devices asset classes as per the AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks.  Reported values include the previous period adjustment for the difference between actual and forecast net capex, but exclude the previous period adjustment for the return on difference for net capex.  SA Power Networks will reflect the cumulative impact of the return on difference for net capex adjustment in its 2019/20 RAB roll forward.","N/A"]
[]
[null,"3.3.3 - TOTAL DISAGGREGATED RAB ASSET VALUES",null,null,null,"Network Services","SCS","ACS"]
[null,"DRAB1201","Overhead distribution assets (wires and poles)","Financial","Refer Data Sources provided for DRAB0201 to DRAB0207.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB0201) and the closing value at 30 June 2019 (as per DRAB0207).","N/A","N/A"]
[null,"DRAB1202","Underground distribution assets (cables, ducts etc)","Financial","Refer Data Sources provided for DRAB0301 to DRAB0307.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB0301) and the closing value at 30 June 2019 (as per DRAB0307).","N/A","N/A"]
[null,"DRAB1203","Distribution substations including transformers","Financial","Refer Data Sources provided for DRAB0401 to DRAB0407.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB0401) and the closing value at 30 June 2019 (as per DRAB0407).","N/A","N/A"]
[null,"DRAB1204","Overhead assets 33kV and above (wires and towers / poles etc)","Financial","Refer Data Sources provided for DRAB0501 to DRAB0507.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB0501) and the closing value at 30 June 2019 (as per DRAB0507).","N/A","N/A"]
[null,"DRAB1205","Underground assets 33kV and above (cables, ducts etc)","Financial","Refer Data Sources provided for DRAB0601 to DRAB0607.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB0601) and the closing value at 30 June 2019 (as per DRAB0607).","N/A","N/A"]
[null,"DRAB1206","Zone substations","Financial","Refer Data Sources provided for DRAB0701 to DRAB0707.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB0701) and the closing value at 30 June 2019 (as per DRAB0707).","N/A","N/A"]
[null,"DRAB1207","Easements ","Financial","Refer Data Sources provided for DRAB0801 to DRAB0807.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB0801) and the closing value at 30 June 2019 (as per DRAB0807).","N/A","N/A"]
[null,"DRAB1208","Meters","Financial","Refer Data Sources provided for DRAB0901 to DRAB0907.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB0901) and the closing value at 30 June 2019 (as per DRAB0907).","N/A","N/A"]
[null,"DRAB1209","\"Other\" assets with long lives","Financial","Refer Data Sources provided for DRAB1001 to DRAB1007.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB1001) and the closing value at 30 June 2019 (as per DRAB1007).","N/A","N/A"]
[null,"DRAB1210","\"Other\" assets with short lives","Financial","Refer Data Sources provided for DRAB1101 to DRAB1107.","Actual","Actual","Actual","N/A","As stipulated in the AER's Instructions and Definitions document, values in this table should represent the average of the opening and closing values for each asset class:  in this case the opening value at 1 July 2018 (as per DRAB1101) and the closing value at 30 June 2019 (as per DRAB1107).","N/A","N/A"]
[null,"DRAB13","Value of Capital Contributions or Contributed Assets (included in the above)","Financial","SA Power Networks' 2018-19 Annual RIN Response","Actual","Actual","Actual","N/A","Represents Capital Contributions as reported in SA Power Networks' 2018-19 Annual RIN Response.","N/A","N/A"]
[]
[null,"3.3.4 - ASSET LIVES",null,null,null,"Network Services","SCS","ACS"]
[null,"ESTIMATED SERVICE LIFE OF NEW ASSETS"]
[null,"DRAB1401","Overhead network assets less than 33kV (wires and poles)","Financial","SA Power Networks' 2018-19 Benchmarking RIN Response; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Estimated","Estimated","Actual","Given that assets do not have a literal defined life span, estimated services lives (where > 0) provided, must by their nature be estimates rather than actuals.  ","Weighted average standard lives were determined using closing balances from Table 3.3.2 of SA Power Networks' 2018-19 Benchmarking RIN Response; and Standard Life values taken from the AER's Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks (refer RFM Input sheets).","Determined as the weighted average of estimated service lives for the SA Power Networks' depreciable asset classes comprising this asset category based on 30 June 2019 closing balances.  Wherever the asset category did not apply to one or more of Network Services, Standard Control Services and Alternative Control Services, a nil value was reported in the \"Actual\" RAB worksheet.","N/A"]
[null,"DRAB1402","Underground network assets less than 33kV (cables)","Financial","Refer Data Source provided for DRAB1401.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1401.","Refer Methodology provided for DRAB1401.","Refer Assumptions provided for DRAB1401.","N/A"]
[null,"DRAB1403","Distribution substations including transformers","Financial","Refer Data Source provided for DRAB1401.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1401.","Refer Methodology provided for DRAB1401.","Refer Assumptions provided for DRAB1401.","N/A"]
[null,"DRAB1404","Overhead network assets 33kV and above (wires and towers / poles etc) ","Financial","Refer Data Source provided for DRAB1401.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1401.","Refer Methodology provided for DRAB1401.","Refer Assumptions provided for DRAB1401.","N/A"]
[null,"DRAB1405","Underground network assets 33kV and above(cables, ducts etc)","Financial","Refer Data Source provided for DRAB1401.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1401.","Refer Methodology provided for DRAB1401.","Refer Assumptions provided for DRAB1401.","N/A"]
[null,"DRAB1406","Zone substations and transformers","Financial","Refer Data Source provided for DRAB1401.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1401.","Refer Methodology provided for DRAB1401.","Refer Assumptions provided for DRAB1401.","N/A"]
[null,"DRAB1407","Meters","Financial","Refer Data Source provided for DRAB1401.","Actual","Actual","Estimated","Refer Justification provided for DRAB1401.","Refer Methodology provided for DRAB1401.","Refer Assumptions provided for DRAB1401.","N/A"]
[null,"DRAB1408","\"Other\" assets with long lives","Financial","Refer Data Source provided for DRAB1401.","Estimated","Estimated","Estimated","Refer Justification provided for DRAB1401.","Refer Methodology provided for DRAB1401.","Refer Assumptions provided for DRAB1401.","N/A"]
[null,"DRAB1409","\"Other\" assets with short lives","Financial","Refer Data Source provided for DRAB1401.","Estimated","Estimated","Estimated","Refer Justification provided for DRAB1401.","Refer Methodology provided for DRAB1401.","Refer Assumptions provided for DRAB1401.","N/A"]
[null,"ESTIMATED RESIDUAL SERVICE LIFE"]
[null,"DRAB1501","Overhead network assets less than 33kV (wires and poles)","Financial","SA Power Networks' 2018-19 Benchmarking RIN Response; and AER Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016).","Estimated","Estimated","Actual","Given that assets do not have a literal defined life span, estimated residual lives (where > 0) provided, must by their nature be estimates rather than actuals.  ","Weighted average residual service lives were determined using closing balances from Table 3.3.2 of SA Power Networks' 2018-19 Benchmarking RIN Response; and Forecast 2019/20 straight line depreciation values taken from the AER's Electricity Distribution Network Service Provider Roll Forward Model Version 2 (December 2016) for SA Power Networks (refer RFM Input sheets).","Determined as the weighted average of estimated residual lives for the SA Power Networks' depreciable asset classes comprising this asset category based on 30 June 2019 closing balances.  Wherever the asset category did not apply to one or more of Network Services, Standard Control Services and Alternative Control Services, a nil value was reported in the \"Actual\" RAB worksheet.","N/A"]
[null,"DRAB1502","Underground network assets less than 33kV (cables)","Financial","Refer Data Source provided for DRAB1501.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1501.","Refer Methodology provided for DRAB1501.","Refer Assumptions provided for DRAB1501.","N/A"]
[null,"DRAB1503","Distribution substations including transformers","Financial","Refer Data Source provided for DRAB1501.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1501.","Refer Methodology provided for DRAB1501.","Refer Assumptions provided for DRAB1501.","N/A"]
[null,"DRAB1504","Overhead network assets 33kV and above (wires and towers / poles etc) ","Financial","Refer Data Source provided for DRAB1501.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1501.","Refer Methodology provided for DRAB1501.","Refer Assumptions provided for DRAB1501.","N/A"]
[null,"DRAB1505","Underground network assets 33kV and above (cables, ducts etc)","Financial","Refer Data Source provided for DRAB1501.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1501.","Refer Methodology provided for DRAB1501.","Refer Assumptions provided for DRAB1501.","N/A"]
[null,"DRAB1506","Zone substations and transformers","Financial","Refer Data Source provided for DRAB1501.","Estimated","Estimated","Actual","Refer Justification provided for DRAB1501.","Refer Methodology provided for DRAB1501.","Refer Assumptions provided for DRAB1501.","N/A"]
[null,"DRAB1507","Meters","Financial","Refer Data Source provided for DRAB1501.","Actual","Actual","Estimated","Refer Justification provided for DRAB1501.","Refer Methodology provided for DRAB1501.","Refer Assumptions provided for DRAB1501.","N/A"]
[null,"DRAB1508","\"Other\" assets with long lives","Financial","Refer Data Source provided for DRAB1501.","Estimated","Estimated","Estimated","Refer Justification provided for DRAB1501.","Refer Methodology provided for DRAB1501 for Network Services and Standard Control Services.  In the case of Alternative Control Services, the Methodology described in DRAB1501 produced a residual service life value greater than the service life of new assets.  Consequently, SA Power Networks substituted the reported value with one based on our calculation of residual service lives for \"Other\" assets with long lives in table 3.3.4 of the 2020-25 Reset RIN.","Refer Assumptions provided for DRAB1501.","N/A"]
[null,"DRAB1509","\"Other\" assets with short lives","Financial","Refer Data Source provided for DRAB1501.","Estimated","Estimated","Estimated","Refer Justification provided for DRAB1501.","Refer Methodology provided for DRAB1501.","Refer Assumptions provided for DRAB1501.","N/A"]

{"sheet":"3.4 Operational Data","index":4,"n_rows":99,"n_cols":12,"rows_kept":99,"cut":false,"hidden":false,"merged":[[1,1,1,3],[1,4,1,11],[44,4,47,4],[44,9,48,9]]}
[]
[null,"SA Power Networks",null,null,"Basis of Preparation"]
[null,1,1.1000000000000001,2,3,4,null,null,5,6,7,8]
[null,"CAT RIN Table Ref / EBT RIN Variable Code","RIN Row/ Column/ Cell or All (entire tab)","Financial /\nNon-Financial","Data Source","Actual / Estimated",null,null,"Justification\n(if estimated)","Methodology \n(actual and estimated)","Assumptions\n(actual and estimated)","SAPN Additional Comments\n(if any)"]
[null,"State the table reference (CA) or Variable Code (EB)","\nState the applicable row, column, cell, or entire tab","\nSelect whether the referenced information is financial or non-financial","\nExplanation of the data source for the referenced information","\nSelect whether the information from data source is either actual or estimated?",null,null,"\nExplanation of why an estimate is required and why actual data does not exist\n\nFor financial information, explanation of why financial information is not in accordance to the financial reporting framework and any changes, impacts and deviations to accounting policies (for any regulatory years).","\nExplanation of the method applied to provide the requested data. This should include an explanation of how the data was derived from other sources (if applicable) where this was undertaken and explain any allocation the approach applied.","\nExplanation/list of any assumptions made for data source, justification and methodology applied or made.","\nState any additional comments, notes or explanations."]
[null," 3.4.1 - ENERGY DELIVERY"]
[null,"DOPED01","Total energy delivered","Non-Financial","Straight from Sales Model","Actual ",null,null,null,"Data is assigned on a tariff-applied basis.\nActual data extracted from Sales Model."]
[null," 3.4.1.1 - Energy grouping - delivery by chargeable quantity"]
[null,"DOPED0201","Energy Delivery where time of use is not a determinant","Non-Financial","Straight from Sales Model","Actual ",null,null,null,"Data is assigned on a tariff-applied basis.\nActual data extracted from Sales Model. \nIncludes Residential (excl Controlled load) & Business Single tariff volumes\n* Includes Energy where TOU is not a determinant but a demand-based cost reflective time is used."]
[null,"DOPED0202","Energy Delivery at On-peak times","Non-Financial","Sales Model (Internal) \nAnnual Pricing Proposal - Appendix G","Actual ",null,null,null,"Data is assigned on a tariff-applied basis.\nActual data is extracted from the Sales Model for all energy received, and includes revenue from LV/HV Business Two and LV Business Transition tariffs. The split between peak and off-peak energy deliveries is based on the quantities split approved in the annual pricing proposal.\n","The split between peak and off-peak energy deliveries is based on the quantities split approved in the annual pricing proposal."]
[null,"DOPED0203","Energy Delivery at Shoulder times ","Non-Financial","Nil","N/A",null,null,null,"SAPN does not have any shoulder period charges"]
[null,"DOPED0204","Energy Delivery at Off-peak times","Non-Financial","Sales Model (Internal) \nAnnual Pricing Proposal - Appendix G","Actual ",null,null,null,"Data is assigned on a tariff-applied basis.\nActual data is extracted from the Sales Model for all energy received, and includes revenue from LV/HV Business Two and LV Business Transition tariffs. ","The split between peak and off-peak energy deliveries is based on the quantities split approved in the annual pricing proposal."]
[null,"DOPED0205","Controlled load energy deliveries","Non-Financial","Straight from Sales Model","Actual ",null,null,null,"Data is assigned on a tariff-applied basis.\nActual data is extracted from the Sales Model.\nIncludes Controlled Load volumes (primarily Residential)"]
[null,"DOPED0206","Energy Delivery to unmetered supplies","Non-Financial","Straight from Sales Model","Actual ",null,null,null,"Data is assigned on a tariff-applied basis.\nActual data is extracted from the Sales Model.\nIncludes 12 & 24 Hour Unmetered volumes"]
[null," 3.4.1.2 - Energy - received from TNSP and other DNSPs by time of receipt"]
[null,"DOPED0301","Energy into DNSP network at On-peak times","Non-Financial","Sales Model (internal)\nPurchases and Customer Segment Data (internal)","Actual",null,null,null,"Total energy from ElectraNet is agreed with ElectraNet each 6 months as part of our financial accounts audit (by Deloitte).\nBased on work day/time of day.\nActual data is extracted from the Sales Model for all energy received. \nThe split between peak and off-peak energy received is based on quantities in the Purchases and Customer Segment Data file.","ON PEAK TIMES: weekdays (Monday to Friday) between 8.00am and 9.30pm.\nOFF-PEAK TIMES: weekends (Saturday and Sunday) and public holidays all day, and Monday to Friday between 10pm and 7.30am \n"]
[null,"DOPED0302","Energy into DNSP network at Shoulder times ","Non-Financial","SAPN does not have any shoulder period charges",null,null,null,null,"Nil"]
[null,"DOPED0303","Energy into DNSP network at Off-peak times","Non-Financial","Sales Model (internal)\nPurchases and Customer Segment Data (internal)","Actual",null,null,null,"Total energy from ElectraNet is agreed with ElectraNet each 6 months as part of our financial accounts audit (by Deloitte).\nBased on work day/time of day.\nActual data is extracted from the Sales Model for all energy received. \nThe split between peak and off-peak energy received is based on quantities in the Purchases and Customer Segment Data file.","ON PEAK TIMES: weekdays (Monday to Friday) between 8.00am and 9.30pm.\nOFF-PEAK TIMES: weekends (Saturday and Sunday) and public holidays all day, and Monday to Friday between 10pm and 7.30am \n"]
[null,"DOPED0304","Energy received from TNSP and other DNSPs not included in the above categories","Non-Financial","SAPN has no other energy received",null,null,null,null,"Nil"]
[null," 3.4.1.3 - Energy - received into DNSP system from embedded generation by time of receipt"]
[null,"DOPED0401","Energy into DNSP network at On-peak times from non-residential embedded generation","Non-Financial","Sales Model (internal)\nPurchases and Customer Segment Data (internal)","Actual",null,null,null,"Summation of individual generators export.\nActual data is extracted from the Sales Model for all energy received. \nThe split between peak and off-peak energy received is based on quantities in the Purchases and Customer Segment Data file.","ON PEAK TIMES: weekdays (Monday to Friday) between 8.00am and 9.30pm.\nOFF-PEAK TIMES: weekends (Saturday and Sunday) and public holidays all day, and Monday to Friday between 10pm and 7.30am \n"]
[null,"DOPED0402","Energy into DNSP network at Shoulder times from non-residential embedded generation","Non-Financial","SAPN does not have any shoulder periods",null,null,null,null,"Nil"]
[null,"DOPED0403","Energy into DNSP network at Off-peak times from non-residential embedded generation","Non-Financial","Sales Model (internal)\nPurchases and Customer Segment Data (internal)","Actual",null,null,null,"Summation of individual generators export.\nActual data is extracted from the Sales Model for all energy received. \nThe split between peak and off-peak energy received is based on quantities in the Purchases and Customer Segment Data file.","ON PEAK TIMES: weekdays (Monday to Friday) between 8.00am and 9.30pm.\nOFF-PEAK TIMES: weekends (Saturday and Sunday) and public holidays all day, and Monday to Friday between 10pm and 7.30am \n"]
[null,"DOPED0404","Energy received from embedded generation not included in above categories from non-residential embedded generation","Non-Financial","SAPN has no other energy received",null,null,null,null,"Nil"]
[null,"DOPED0405","Energy into DNSP network at On-peak times from residential embedded generation","Non-Financial","Sales Model (internal)\nPurchases and Customer Segment Data (internal)","Actual",null,null,null,"Based on approved PV capacity installed with daily output profiles determined by panel efficiency and sample data, for both the gross output of PV and (non TOU) for residential in-house.  The nett of these two numbers reflects the actual nett PV exported via meters as per pricing proposal data.\nActual data is extracted from the Sales Model for all energy received. The split between peak and off-peak energy received is based on quantities in the Purchases and Customer Segment Data file.","ON PEAK TIMES: weekdays (Monday to Friday) between 8.00am and 9.30pm.\nOFF-PEAK TIMES: weekends (Saturday and Sunday) and public holidays all day, and Monday to Friday between 10pm and 7.30am \n"]
[null,"DOPED0406","Energy into DNSP network at Shoulder times from residential embedded generation","Non-Financial","SAPN does not have any shoulder periods",null,null,null,null,"Nil"]
[null,"DOPED0407","Energy into DNSP network at Off-peak times from residential embedded generation","Non-Financial","Sales Model (internal)\nPurchases and Customer Segment Data (internal)","Actual",null,null,null,"Based on approved PV capacity installed with daily output profiles determined by panel efficiency and sample data, for both the gross output of PV and (non TOU) for residential in-house.  The nett of these two numbers reflects the actual nett PV exported via meters as per pricing proposal data.\nActual data is extracted from the Sales Model for all energy received. The split between peak and off-peak energy received is based on quantities in the Purchases and Customer Segment Data file.","ON PEAK TIMES: weekdays (Monday to Friday) between 8.00am and 9.30pm.\nOFF-PEAK TIMES: weekends (Saturday and Sunday) and public holidays all day, and Monday to Friday between 10pm and 7.30am \n"]
[null,"DOPED0408","Energy received from embedded generation not included in above categories from residential embedded generation","Non-Financial","SAPN has no other energy received","Actual",null,null,null,"Nil"]
[null," 3.4.1.4 - Energy grouping  - customer type or class"]
[null,"DOPED0501","Residential customers energy deliveries","Non-Financial","Sales model","Actual",null,null,null,"Data is based on a tariff-applied basis\nActual data is extracted from Sales Model (internal), for all residential customers including contracted demand, peak and non-peak volumes.\nThe proportion of controlled load energy deliveries that should be allocated to residential customers, is applied as per the split allocated in the Annual Pricing Proposal."]
[null,"DOPED0502","Non-residential customers not on demand tariffs energy deliveries","Non-Financial","Sales model","Actual",null,null,null,"Data is based on a tariff-applied basis\nActual data is extracted from Sales Model (internal), for all LV/HV Business Single and Two rates customers peak and non-peak volumes.\nThe proportion of controlled load energy deliveries that should be allocated to residential customers, is applied as per the split allocated in the Annual Pricing Proposal."]
[null,"DOPED0503","Non-residential low voltage demand tariff customers energy deliveries","Non-Financial","Sales model","Actual",null,null,null,"Data is based on a tariff-applied basis\nActual data is extracted from Sales Model (internal).\nIncludes all LV Demand Rates (kVA & kW) including contracted demand, peak and non-peak volumes"]
[null,"DOPED0504","Non-residential high voltage demand tariff customers energy deliveries","Non-Financial","Sales model","Actual",null,null,null,"Data is based on a tariff-applied basis\nActual data is extracted from Sales Model (internal).\nIncludes all HV Demand Rates (kVA & kW) including contracted demand, peak and non-peak volumes"]
[null,"DOPED0505","Other Customer Class Energy Deliveries","Non-Financial","Sales model","Actual",null,null,null,"Data is based on a tariff-applied basis\nActual data is extracted from Sales Model (internal).\nIncludes all 12 & 24 hour unmetered volumes"]
[null," 3.4.2 - CUSTOMER NUMBERS"]
[null," 3.4.2.1 - Distribution customer numbers by customer type or class"]
[null,"DOPCN0101","Residential customer numbers","Non-Financial","CIS/OV Monthly NMI Statistics June","Actual",null,null,null,"Actual data is extracted from the CIS/OV NMI Status and Tariff snapshot report, filtered to Fuse In/out (energised and de-energised) customers. \nA pro-rata adjustment is then applied to customer number by type to align with the averaging of total customers already applied to the values reported for customers by location (3.4.2.2). \nNote: this adjustment excludes unmetered customers as they are not reported in customers by location (3.4.2.2) ","Data is based on a tariff-applied basis and includes all Residential tariffs."]
[null,"DOPCN0102","Non residential customers not on demand tariff customer numbers","Non-Financial","CIS/OV Monthly NMI Statistics June","Actual",null,null,null,"Actual data is extracted from the CIS/OV NMI Status and Tariff snapshot report, filtered to Fuse In/out (energised and de-energised) customers. \nA pro-rata adjustment is then applied to customer number by type to align with the averaging of total customers already applied to the values reported for customers by location (3.4.2.2). \nNote: this adjustment excludes unmetered customers as they are not reported in customers by location (3.4.2.2) ","Data is based on a tariff-applied basis and includes all LV non-demand customer tariffs."]
[null,"DOPCN0103","Low voltage demand tariff customer numbers","Non-Financial","CIS/OV Monthly NMI Statistics June","Actual",null,null,null,"Actual data is extracted from the CIS/OV NMI Status and Tariff snapshot report, filtered to Fuse In/out (energised and de-energised) customers. \nA pro-rata adjustment is then applied to customer number by type to align with the averaging of total customers already applied to the values reported for customers by location (3.4.2.2). \nNote: this adjustment excludes unmetered customers as they are not reported in customers by location (3.4.2.2) ","Data is based on a tariff-applied basis and includes all LV Demand Customer tariffs."]
[null,"DOPCN0104","High voltage demand tariff customer numbers","Non-Financial","CIS/OV Monthly NMI Statistics June","Actual",null,null,null,"Actual data is extracted from the CIS/OV NMI Status and Tariff snapshot report, filtered to Fuse In/out (energised and de-energised) customers. \nA pro-rata adjustment is then applied to customer number by type to align with the averaging of total customers already applied to the values reported for customers by location (3.4.2.2). \nNote: this adjustment excludes unmetered customers as they are not reported in customers by location (3.4.2.2) ","Data is based on a tariff-applied basis and includes all HV Business and Major Customers tariffs."]
[null,"DOPCN0105","Unmetered Customer Numbers","Non-Financial","CIS/OV Monthly NMI Statistics June","Actual",null,null,null,"Actual data is extracted from the CIS/OV NMI Status and Tariff snapshot report, filtered to Fuse In/out (energised and de-energised) customers. \nA pro-rata adjustment is then applied to customer number by type to align with the averaging of total customers already applied to the values reported for customers by location (3.4.2.2). \nNote: this adjustment excludes unmetered customers as they are not reported in customers by location (3.4.2.2) ","Data is based on a tariff-applied basis and includes all 12 & 24 hour unmetered volumes."]
[null,"DOPCN0106","Other Customer Numbers","Non-Financial","CIS/OV Monthly NMI Statistics June","Actual"]
[null,"DOPCN01","Total customer numbers","Non-Financial","Total Customers - Aligns with 3.4.2.2"]
[null," 3.4.2.2 - Distribution customer numbers by location on the network"]
[null,"DOPCN0201","Customers on CBD network","Non-Financial","CIS/OV, GIS, OMS, SCADA (where available) and load recorders for feeder demand readings.","Actual",null,null,null,"Calculations are in accordance with our QMS procedures:\no Obtain all feeder lengths as at 30 June\no Obtain the maximum demand for the period ending 30 June\no If the feeder name begins with CBD and the transformer is situated within the CBD boundary defined by the Distribution Code and the feeder plans, assign the feeder to the SCONRRR category ‘CBD’\no Based on the feeder length and maximum demand, determine the load per km for all other feeders.  Use the actual maximum demand over the reporting period where available, otherwise, use the forecast peak\no If the demand per km > 0.3 MVA and the feeder is not a ‘CBD’ feeder, assign the feeder to the SCONRRR category ‘Urban’.  If the feeder is located in a metropolitan or regional metropolitan area, also assign to 'Urban' (as agreed with the local Regulator, ESCOSA)\no If the demand per km ≤ 0.3 MVA but the feeder is situated in the general metropolitan area or a regional metropolitan area as defined in the Distribution Code, generally assign the feeder to the SCONRRR category ‘Urban’\no If the feeder is not ‘CBD’ or ‘Urban’ and the feeder route length is ≤ 200km, assign the feeder to the SCONRRR category ‘Rural Short’\no If the feeder is not ‘CBD’ or ‘Urban’ and the feeder route length is > 200km, assign the feeder to the SCONRRR category ‘Rural Long’\no NMI’s are linked to transformers, which are linked to feeders (via CIS/OV, GIS and OMS), which are then mapped to the feeder categories as calculated above and then summated to obtain the customers per feeder category"]
[null,"DOPCN0202","Customers on Urban network","Non-Financial",null,"Actual"]
[null,"DOPCN0203","Customers on Short rural network","Non-Financial",null,"Actual"]
[null,"DOPCN0204","Customers on Long rural network","Non-Financial",null,"Actual"]
[null,"DOPCN02","Total customer numbers","Non-Financial",null,"Actual"]
[null," 3.4.3 - SYSTEM DEMAND"]
[null," 3.4.3.1 - Annual system maximum demand characteristics at the zone substation level – MW measure"]
[null,"DOPSD0101","Non-coincident Summated Raw System Annual Maximum Demand","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"All data relating to PoE values, by virtue of the fact that the data provided has been calculated, must therefore be considered as estimated.","The following steps were undertaken to derive the non-coincident and coincident actual, 10 and 50 PoE, MW and MVA demand values at the zone substation level:\n\tFor each zone substation, the actual non-coincident readings and non-coincident, 10 and 50 PoE MW values were summated to arrive at the values submitted within fields DOPSD0101, DOPSD0102 and DOPSD0103 respectively.  This summation excluded those substations categorised within variable DPA0602 in Table 6.2.2 as “Stage 2” transformations to avoid double counting of loads at both a Stage 1 and Stage 2 level as well as those loads supplied by unregulated and customer owned zone substation transformer assets.\n\tSimilarly, the coincident, zone substation actual, 10 and 50 PoE MW values were summated to arrive at the values submitted within fields, DOPSD0104, DOPSD0105 and DOPSD0106 respectively.\n\tAll non-coincident and coincident MVAr values measured and at the 10 and 50 PoE level were separately summated.  Again, this summation excluded those substations categorised within DPA0602 of Table 6.2.2 as “Stage 2” transformations to avoid double counting of loads at both a Stage 1 and Stage 2 level.\n\tThe resultant MW and MVAr totals were then converted to the non-coincident and coincident MVA value using the formula;\nMVA=√(〖MW〗^2+ 〖MVAr〗^2 )\n\tThe calculated non-coincident and coincident actual MVA values and at 10 and 50 PoE were then entered within DOPSD0201, DOPSD0202, DOPSD0203, DOPSD0204, DOPSD0205 and DOPSD0206 respectively.","The following assumptions were made in preparing the data provided:\n1.\t“Coincident” refers to the time the associated upstream sub-transmission connection point peaked (ie SA Power Networks load only and therefore excludes the influence of and ElectraNet direct connected customers).\n2.\tFor non-continuously metered zone substations, weather corrected forecasts were produced assuming peak actual values.  SA Power Networks forecasting tool then produced 10 and 50 PoE corrected values.\n3.\tFor non-continuously metered zone substations, the time of day peak has been assumed to be when the upstream connection point peaks (ie: coincident and non-coincident peaks are at the same time).\n4.\tWhere actual demand data is only available in Amps, the MW and MVA values have been determined assuming nominal voltage and the PF of the upstream sub-transmission connection point substation.\n5.\tThe 10 and 50 PoE values used are based on the output of SA Power Networks’ forecasting system which performs a linear regression of the measured values against 30 years of historic temperature readings.\n6.\tAll values used correspond to those provided within section 5.4 of the latest financial year’s Category Analysis RIN.","1.\tCalculation of the zone substation’s total non-coincident and coincident MVA should not simply be as a result of a summation of the constituent zone substation’s MVA values at any given time as these are vector quantities rather than scalar values and therefore should be determined by adding their rectangular components (ie MW and MVAr) and then converting these sums to MVA.\nFor example, consider two loads constituted by 3 MW + j 4 MVAr and 4 MW + j 3 MVAr respectively.  Individually, both have a total load of 5 MVA.  If simply added, we would obtain a total MVA value of 10 MVA, however, if added vectorially, these two loads summate to 9.89 MVA (ie MVA= √((3+4)2+ (4+3)2=9.89)).  Whilst not a major difference in this example, over multiple summations of greater value, this can result in a significant variation from the true value.\n2.\tIt should also be noted that particularly in country areas, SA Power Networks’ 33kV sub-transmission lines contain direct connected 33/0.4V distribution transformers and 33/19kV SWER Isolating transformers.  As such, not all load seen at the transmission connection points passes through a zone substation before reaching the customer.  Similarly, SA Power Networks have some major customers who are connected directly at the transmission connection point’s 33kV bus, take supply at 66kV or are supplied through unregulated zone substation transformers, further increasing the difference between the load seen by the transmission connection point and the regulated zone substation assets at times of peak system demand.\n3.\tGiven SA Power Networks do have some stage 1 and stage 2 transformations within its network, in order to avoid double counting these loads, those “stage 2” zone substation’s loads have been excluded from the totals entered within the RIN.  For example, consider a 66/33kV substation with a measured load of 14 MW during the Financial Year.  If the 33kV line emanating from this substation then supplies 33/11kV substations with loads of 8MW, 4MW and 2MW, inclusion of these loads within the totals would suggest the existence of 28MW of load rather than the 14MW which actually exists.\n4.\tWhen comparing the coincident zone substation MVA values to the corresponding coincident connection point MVA summation values, it should be noted that the MVAr load seen by the connection points is less than that seen by the zone substations due to the impact of capacitor banks installed at the sub-transmission (ie 33 and 66kV) level.  At present, SA Power Networks has 15 MVAr of capacitors installed at 33kV and 1,082 MVAr installed at 66kV level which are switched in and out of service via supervisory control at the direction of ElectraNet’s System Control."]
[null,"DOPSD0102","Non–coincident Summated Weather Adjusted System Annual Maximum Demand 10% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0101","Refer assumptions for DOPSD0101"]
[null,"DOPSD0103","Non–coincident Summated Weather Adjusted System Annual Maximum Demand 50% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0101","Refer assumptions for DOPSD0101"]
[null,"DOPSD0104","Coincident Raw System Annual Maximum Demand","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0101","Refer assumptions for DOPSD0101"]
[null,"DOPSD0105","Coincident Weather Adjusted System Annual Maximum Demand 10% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0101","Refer assumptions for DOPSD0101"]
[null,"DOPSD0106","Coincident Weather Adjusted System Annual Maximum Demand 50% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0101","Refer assumptions for DOPSD0101"]
[null," 3.4.3.2 - Annual system maximum demand characteristics at the transmission connection point  – MW measure"]
[null,"DOPSD0107","Non-coincident Summated Raw System Annual Maximum Demand","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"All data relating to PoE values, by virtue of the fact that the data provided has been calculated, must therefore be considered as estimated.","The following steps were undertaken to derive the non-coincident and coincident actual, 10 and 50 PoE, MW and MVA demand values at the connection point level:\n\tThe non-coincident actual and 10 and 50 PoE MW values for connection point substations in the Financial Year were summated to arrive at the values submitted within field DOPSD107, DOPSD108 and DOPSD0109 respectively.\n\tSimilarly, the coincident, connection point actual, 10 and 50 PoE MW values for each were summated to arrive at the values submitted within field DOPSD0110, DOPSD0111 and DOPSD0112 respectively.\n\tAll corresponding non-coincident and coincident MVAr forecast values for a given year were separately summated.\n\tThe resultant MW and MVAr totals were then converted to the non-coincident and coincident MVA value using the formula;\nMVA=√(〖MW〗^2+ 〖MVAr〗^2 )\n\tThe calculated non-coincident and coincident MVA values were then entered within DOPSD0207, DOPSD0208, DOPSD0209, DOPSD0210, DOPSD0211 and DOPSD0212 respectively.","The following assumptions were made in preparing the data provided:\n1.\t“Coincident” refers to the time of system peak (ie SA Power Networks load only and therefore excludes the influence of and ElectraNet direct connected customers) determined by summating all of the sub-transmission connection point substation’s load profiles.\n2.\tThe 10 and 50 PoE values used are based on the output of SA Power Networks’ forecasting system which performs a linear regression of the measured values against the last 30 years of historic temperature readings.\n3.\tAll values used correspond to those provided within section 5.4 of the latest financial year’s Category Analysis RIN.","1.\tCalculation of the connection point substation’s total non-coincident and coincident MVA should not simply be as a result of a summation of the constituent connection point substation’s MVA values at any given time as these are vector quantities rather than scalar values and therefore should be determined by adding their rectangular components (ie MW and MVAr) and then converting these sums to MVA.\nFor example, consider two loads constituted by 3 MW + j 4 MVAr and 4 MW + j 3 MVAr respectively.  Individually, both have a total load of 5 MVA.  If simply added, we would obtain a total MVA value of 10 MVA, however, if added vectorially, these two loads summate to 9.89 MVA (ie MVA= √((3+4)2+ (4+3)2=9.89)).  Whilst not a major difference in this example, over multiple summations of greater value, this can result in a significant variation from the true value."]
[null,"DOPSD0108","Non–coincident Summated Weather Adjusted System Annual Maximum Demand 10% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0107","Refer assumptions for DOPSD0107"]
[null,"DOPSD0109","Non–coincident Summated Weather Adjusted System Annual Maximum Demand 50% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0107","Refer assumptions for DOPSD0107"]
[null,"DOPSD0110","Coincident Raw System Annual Maximum Demand","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"SA Power Networks operates a meshed 66kV sub-transmission network within metropolitan Adelaide. At the time of segregation of the South Australian transmission and distribution networks, not all metropolitan 66kV buses were allocated to SA Power Networks. Several of these buses contain direct connection of generation sources and TNSP owned 66kV lines. Therefore, for these regions it is not simply a matter of summating the output of the TNSP’s connection point transformers to determine the load supplied by the TNSP to SA Power Networks. In order to determine the load in some regions, SA Power Networks has created pre-defined summations within its SCADA system (SubsLoad) to calculate the total demand delivered by the TNSP in each area. These values have been used within the values contained within the RIN.","Refer methodology for DOPSD0107. This number includes all embedded generation at the time of the coincident peak.","Refer assumptions for DOPSD0107"]
[null,"DOPSD0111","Coincident Weather Adjusted System Annual Maximum Demand 10% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0107","Refer assumptions for DOPSD0107"]
[null,"DOPSD0112","Coincident Weather Adjusted System Annual Maximum Demand 50% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0107","Refer assumptions for DOPSD0107"]
[null," 3.4.3.3 - Annual system maximum demand characteristics at the zone substation level – MVA measure"]
[null,"DOPSD0201","Non–coincident Summated Raw System Annual Maximum Demand","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"All data relating to PoE values, by virtue of the fact that the data provided has been calculated, must therefore be considered as estimated.","The following steps were undertaken to derive the non-coincident and coincident actual, 10 and 50 PoE, MW and MVA demand values at the zone substation level:\n\tFor each zone substation, the actual non-coincident readings and non-coincident, 10 and 50 PoE MW values were summated to arrive at the values submitted within fields DOPSD0101, DOPSD0102 and DOPSD0103 respectively.  This summation excluded those substations categorised within variable DPA0602 in Table 6.2.2 as “Stage 2” transformations to avoid double counting of loads at both a Stage 1 and Stage 2 level as well as those loads supplied by unregulated and customer owned zone substation transformer assets.\n\tSimilarly, the coincident, zone substation actual, 10 and 50 PoE MW values were summated to arrive at the values submitted within fields, DOPSD0104, DOPSD0105 and DOPSD0106 respectively.\n\tAll non-coincident and coincident MVAr values measured and at the 10 and 50 PoE level were separately summated.  Again, this summation excluded those substations categorised within DPA0602 of Table 6.2.2 as “Stage 2” transformations to avoid double counting of loads at both a Stage 1 and Stage 2 level.\n\tThe resultant MW and MVAr totals were then converted to the non-coincident and coincident MVA value using the formula;\nMVA=√(〖MW〗^2+ 〖MVAr〗^2 )\n\tThe calculated non-coincident and coincident actual MVA values and at 10 and 50 PoE were then entered within DOPSD0201, DOPSD0202, DOPSD0203, DOPSD0204, DOPSD0205 and DOPSD0206 respectively.","The following assumptions were made in preparing the data provided:\n1.\t“Coincident” refers to the time the associated upstream sub-transmission connection point peaked (ie SA Power Networks load only and therefore excludes the influence of and ElectraNet direct connected customers).\n2.\tFor non-continuously metered zone substations, weather corrected forecasts were produced assuming peak actual values.  SA Power Networks forecasting tool then produced 10 and 50 PoE corrected values.\n3.\tFor non-continuously metered zone substations, the time of day peak has been assumed to be when the upstream connection point peaks (ie: coincident and non-coincident peaks are at the same time).\n4.\tWhere actual demand data is only available in Amps, the MW and MVA values have been determined assuming nominal voltage and the PF of the upstream sub-transmission connection point substation.\n5.\tThe 10 and 50 PoE values used are based on the output of SA Power Networks’ forecasting system which performs a linear regression of the measured values against 30 years of historic temperature readings.\n6.\tAll values used correspond to those provided within section 5.4 of the latest financial year’s Category Analysis RIN.","1.\tCalculation of the zone substation’s total non-coincident and coincident MVA should not simply be as a result of a summation of the constituent zone substation’s MVA values at any given time as these are vector quantities rather than scalar values and therefore should be determined by adding their rectangular components (ie MW and MVAr) and then converting these sums to MVA.\nFor example, consider two loads constituted by 3 MW + j 4 MVAr and 4 MW + j 3 MVAr respectively.  Individually, both have a total load of 5 MVA.  If simply added, we would obtain a total MVA value of 10 MVA, however, if added vectorially, these two loads summate to 9.89 MVA (ie MVA= √((3+4)2+ (4+3)2=9.89)).  Whilst not a major difference in this example, over multiple summations of greater value, this can result in a significant variation from the true value.\n2.\tIt should also be noted that particularly in country areas, SA Power Networks’ 33kV sub-transmission lines contain direct connected 33/0.4V distribution transformers and 33/19kV SWER Isolating transformers.  As such, not all load seen at the transmission connection points passes through a zone substation before reaching the customer.  Similarly, SA Power Networks have some major customers who are connected directly at the transmission connection point’s 33kV bus, take supply at 66kV or are supplied through unregulated zone substation transformers, further increasing the difference between the load seen by the transmission connection point and the regulated zone substation assets at times of peak system demand.\n3.\tGiven SA Power Networks do have some stage 1 and stage 2 transformations within its network, in order to avoid double counting these loads, those “stage 2” zone substation’s loads have been excluded from the totals entered within the RIN.  For example, consider a 66/33kV substation with a measured load of 14 MW during the Financial Year.  If the 33kV line emanating from this substation then supplies 33/11kV substations with loads of 8MW, 4MW and 2MW, inclusion of these loads within the totals would suggest the existence of 28MW of load rather than the 14MW which actually exists.\n4.\tWhen comparing the coincident zone substation MVA values to the corresponding coincident connection point MVA summation values, it should be noted that the MVAr load seen by the connection points is less than that seen by the zone substations due to the impact of capacitor banks installed at the sub-transmission (ie 33 and 66kV) level.  At present, SA Power Networks has 15 MVAr of capacitors installed at 33kV and 1,082 MVAr installed at 66kV level which are switched in and out of service via supervisory control at the direction of ElectraNet’s System Control."]
[null,"DOPSD0202","Non–coincident Summated Weather Adjusted System Annual Maximum Demand 10% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0201","Refer assumptions for DOPSD0201"]
[null,"DOPSD0203","Non–coincident Summated Weather Adjusted System Annual Maximum Demand 50% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0201","Refer assumptions for DOPSD0201"]
[null,"DOPSD0204","Coincident Raw System Annual Maximum Demand","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0201","Refer assumptions for DOPSD0201"]
[null,"DOPSD0205","Coincident Weather Adjusted System Annual Maximum Demand 10% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0201","Refer assumptions for DOPSD0201"]
[null,"DOPSD0206","Coincident Weather Adjusted System Annual Maximum Demand 50% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0201","Refer assumptions for DOPSD0201"]
[null," 3.4.3.4 - Annual system maximum demand characteristics at the transmission connection point – MVA measure"]
[null,"DOPSD0207","Non–coincident Summated Raw System Annual Maximum Demand","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"All data relating to PoE values, by virtue of the fact that the data provided has been calculated, must therefore be considered as estimated.","The following steps were undertaken to derive the non-coincident and coincident actual, 10 and 50 PoE, MW and MVA demand values at the connection point level:\n\tThe non-coincident actual and 10 and 50 PoE MW values for connection point substations in the Financial Year were summated to arrive at the values submitted within field DOPSD107, DOPSD108 and DOPSD0109 respectively.\n\tSimilarly, the coincident, connection point actual, 10 and 50 PoE MW values for each were summated to arrive at the values submitted within field DOPSD0110, DOPSD0111 and DOPSD0112 respectively.\n\tAll corresponding non-coincident and coincident MVAr forecast values for a given year were separately summated.\n\tThe resultant MW and MVAr totals were then converted to the non-coincident and coincident MVA value using the formula;\nMVA=√(〖MW〗^2+ 〖MVAr〗^2 )\n\tThe calculated non-coincident and coincident MVA values were then entered within DOPSD0207, DOPSD0208, DOPSD0209, DOPSD0210, DOPSD0211 and DOPSD0212 respectively.","The following assumptions were made in preparing the data provided:\n1.\t“Coincident” refers to the time of system peak (ie SA Power Networks load only and therefore excludes the influence of and ElectraNet direct connected customers) determined by summating all of the sub-transmission connection point substation’s load profiles.\n2.\tThe 10 and 50 PoE values used are based on the output of SA Power Networks’ forecasting system which performs a linear regression of the measured values against the last 30 years of historic temperature readings.\n3.\tAll values used correspond to those provided within section 5.4 of the latest financial year’s Category Analysis RIN.","1.\tCalculation of the connection point substation’s total non-coincident and coincident MVA should not simply be as a result of a summation of the constituent connection point substation’s MVA values at any given time as these are vector quantities rather than scalar values and therefore should be determined by adding their rectangular components (ie MW and MVAr) and then converting these sums to MVA.\nFor example, consider two loads constituted by 3 MW + j 4 MVAr and 4 MW + j 3 MVAr respectively.  Individually, both have a total load of 5 MVA.  If simply added, we would obtain a total MVA value of 10 MVA, however, if added vectorially, these two loads summate to 9.89 MVA (ie MVA= √((3+4)2+ (4+3)2=9.89)).  Whilst not a major difference in this example, over multiple summations of greater value, this can result in a significant variation from the true value."]
[null,"DOPSD0208","Non–coincident Summated Weather Adjusted System Annual Maximum Demand 10% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0207","Refer assumptions for DOPSD0207"]
[null,"DOPSD0209","Non–coincident Summated Weather Adjusted System Annual Maximum Demand 50% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0207","Refer assumptions for DOPSD0207"]
[null,"DOPSD0210","Coincident Raw System Annual Maximum Demand","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"SA Power Networks operates a meshed 66kV sub-transmission network within metropolitan Adelaide. At the time of segregation of the South Australian transmission and distribution networks, not all metropolitan 66kV buses were allocated to SA Power Networks. Several of these buses contain direct connection of generation sources and TNSP owned 66kV lines. Therefore, for these regions it is not simply a matter of summating the output of the TNSP’s connection point transformers to determine the load supplied by the TNSP to SA Power Networks. In order to determine the load in some regions, SA Power Networks has created pre-defined summations within its SCADA system (SubsLoad) to calculate the total demand delivered by the TNSP in each area. These values have been used within the values contained within the RIN.","Refer methodology for DOPSD0207","Refer assumptions for DOPSD0207"]
[null,"DOPSD0211","Coincident Weather Adjusted System Annual Maximum Demand 10% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0207","Refer assumptions for DOPSD0207"]
[null,"DOPSD0212","Coincident Weather Adjusted System Annual Maximum Demand 50% POE","Non-Financial","Load forecast model, SCADA","Estimate",null,null,"PoE values are calculated not actually measured","Refer methodology for DOPSD0207","Refer assumptions for DOPSD0207"]
[null," 3.4.3.5 - Power factor conversion between MVA and MW"]
[null,"DOPSD0301","Average overall network power factor conversion between MVA and MW","Non-Financial","SCADA","Estimate",null,null,"Not all zone substations are SCADA enabled and therefore actual values do not exist and needed to be estimated.\n\nGiven that SA Power Networks does not individually SCADA monitor its distribution transformers, it has been assumed that the value for these parameters will be equivalent to that of the combined 11 and 7.6kV networks from which the vast majority of SA Power Networks’ distribution transformers are supplied, with the MVAr values corrected for the removal of any 11 or 7.6kV capacitor banks.\n\nSimilarly, SA Power Networks does not individually SCADA monitor its SWER systems, it has been assumed that the value for these parameters will be equivalent to the “corrected” values of the 33kV networks from which the vast majority of SA Power Networks’ SWER systems are supplied with the MVAr values corrected for the removal of any 33kV capacitor banks.","The following methodology was used to calculate the PF values at the respective levels of the network:\nDOPSD0301 - Average overall network power factor\n1.\tGiven this is intended to represent the average PF of the entire network, the non-coincident, actual connection point values in DOPSD0107 have been divided by those contained in DOPSD0207 to arrive at the values entered within DOPSD0301 of the RIN.","The following assumptions have been made in preparing the data submitted:\nDOPSD0301 - Average overall network power factor\n4.\tThe non coincident actual, MW and MVA values at the connection point level have been used as these represent the average PF seen by the TNSP’s network at the time of each connection point’s peak.  The PF submitted includes the effect of any capacitor banks which may or may not have been on at the time the demand readings were recorded.","All customers supplied at 6.6kV and 3.3kV are supplied from dedicated zone substation transformers with all secondary cable / overhead connection assets being owned by the customer (eg cables).  As such, SA Power Networks does not operate any 6.6 or 3.3kV feeders, hence the reason these voltages are not contained within Tables 3.5.1.1, 3.5.1.2, 3.5.1.3 or 3.5.1.4."]
[null,"DOPSD0302","Average power factor conversion for  low voltage distribution lines","Non-Financial","SCADA","Estimate",null,null,"Refer explanation given in DOPSD0301","The following methodology was used to calculate the PF values at the respective levels of the network:\n\nDOPSD0302 - Average power factor conversion for low voltage\n1.\tGiven this value is intended to represent the average PF of the entire LV network and the majority of SA Power Networks’ distribution transformers are supplied by the 11 and 7.6kV networks, the non-coincident actual MW and MVAr values for all 11 and 7.6kV zone substations have been summated according to each substation’s secondary voltage (eg 11and 7.6kV) to provide a summated value of the MW and MVAr supplied by the 11kV and 7.6kV networks.\n2.\tThe final MVAr value was then adjusted to remove the effect of any 11kV or 7.6kV capacitor banks in each year as these reduce the MVArs measured at the 11 and 7.6kV terminals of the zone substation’s transformers.\n3.\tThe summated MW and “adjusted” MVAr values at 11 and 7.6kV were then converted to MVA using Pythagoras’ Theorem.  The MW sum was then divided by the result of the MVA calculation to arrive at the average LV PF value per annum entered within DOPSD0302 of the RIN.","DOPSD0302 - Average power factor conversion for low voltage\n1.\tGiven the lack of metering at LV level, all distribution transformers have been assumed to be connected to the 11 & 7.6kV networks.  Whilst there are distribution transformers directly connected to the 33kV and SWER networks (largely supplied from the 33kV sub-transmission network), it is not anticipated that these customer’s PF values will vary greatly (if at all) from the vast majority of those customers supplied by the LV networks primarily supplied by both the 11 and 7.6kV networks."]
[null,"DOPSD0303","Average power factor conversion for 3.3 kV lines","Non-Financial","SCADA","Estimate",null,null,"Refer explanation given in DOPSD0301","DOPSD0303 - Average power factor conversion for 3.3kV\n1.\tSA Power Networks separately summated the MW and MVAr values for all zone substations with a secondary voltage of 3.3kV.  These summated values were then converted to MVA using Pythagoras’ Theorem with the summated MW value being divided by the calculated MVA value.  The result was then entered within DOPSD0303 of the RIN.","\nAll customers supplied at 6.6kV and 3.3kV are supplied from dedicated zone substation transformers with all secondary cable / overhead connection assets being owned by the customer (eg cables).  As such, SA Power Networks does not operate any 6.6 or 3.3kV feeders, hence the reason these voltages are not contained within Tables 3.5.1.1, 3.5.1.2, 3.5.1.3 or 3.5.1.4."]
[null,"DOPSD0304","Average power factor conversion for 6.6 kV lines","Non-Financial","SCADA","Estimate",null,null,"Refer explanation given in DOPSD0301","DOPSD0304 - Average power factor conversion for 6.6kV\n1.\tSA Power Networks separately summated the MW and MVAr values for all zone substations with a secondary voltage of 6.6kV.  These summated values were then converted to MVA using Pythagoras’ Theorem with the summated MW value being divided by the calculated MVA value.  The result was then entered within DOPSD0304 of the RIN.","All customers supplied at 6.6kV and 3.3kV are supplied from dedicated zone substation transformers with all secondary cable / overhead connection assets being owned by the customer (eg cables).  As such, SA Power Networks does not operate any 6.6 or 3.3kV feeders, hence the reason these voltages are not contained within Tables 3.5.1.1, 3.5.1.2, 3.5.1.3 or 3.5.1.4."]
[null,"DOPSD0305","Average power factor conversion for 7.6 kV lines","Non-Financial","SCADA","Estimate",null,null,"Refer explanation given in DOPSD0301","DOPSD0305 - Average power factor conversion for 7.6kV\n1.\tSA Power Networks summated the MW and MVAr values for all zone substations with a secondary voltage of 7.6kV.  These summated values were then converted to MVA using Pythagoras’ Theorem with the summated MW value being divided by the calculated MVA value.  The result was then entered within DOPSD0305 of the RIN.","DOPSD0305 and DOPSD0306 - Average power factor conversion for 7.6 kV and 11kV\n1.\tCalculated values at 11 and 7.6kV do not represent customer’s PF levels as they are compensated for by SA Power Networks owned capacitor banks installed across the network.  They therefore represent PF values as effectively seen by the upstream network and substation’s transformers."]
[null,"DOPSD0306","Average power factor conversion for 11 kV lines","Non-Financial","SCADA","Estimate",null,null,"Refer explanation given in DOPSD0301","DOPSD0306 - Average power factor conversion for 11kV\n1.\tSA Power Networks summated the MW and MVAr values for all zone substations with a secondary voltage of 11kV.  These summated values were then converted to MVA using Pythagoras’ Theorem with the summated MW value being divided by the calculated MVA value.  The result was then entered within DOPSD0306 of the RIN.","DOPSD0305 and DOPSD0306 - Average power factor conversion for 7.6 kV and 11kV\n1.\tCalculated values at 11 and 7.6kV do not represent customer’s PF levels as they are compensated for by SA Power Networks owned capacitor banks installed across the network.  They therefore represent PF values as effectively seen by the upstream network and substation’s transformers."]
[null,"DOPSD0307","Average power factor conversion for SWER lines","Non-Financial","SCADA","Estimate",null,null,"Refer explanation given in DOPSD0301","DOPSD0307 - Average power factor conversion for SWER\n1\tThis section is intended to represent the average PF of the SWER network, the MW and MVAr values used to generate the values contained in DOPSD0102 and DOPSD0202 have been added according to each substation’s secondary voltage (ie 33kV) to provide a summated value of the MW and MVAr supplied by the 33kV network.\n2\tThe final MVAr value has then been adjusted to remove the effect of any 33kV capacitor banks as these reduce the MVArs seen at the 33kV terminals of the zone substation transformers.\n3\tThe summated MW and adjusted MVAr values at 33kV have then been converted to MVA using Pythagoras’ Theorem.  The MW sum was then divided by the result of this MVA calculation to arrive at the average SWER PF value entered within DOPSD0307 of the RIN.","DOPSD0307 - Average power factor conversion for SWER\n1.\tGiven the lack of metering at SWER level, all SWER systems have been assumed to be connected to the 33kV network.  Whilst there are a few SWER systems supplied from 11kV feeders (ie 11/19kV), it is not anticipated that the customer’s connected to these systems will have different PF values (if at all) to those supplied primarily by the 33kV network."]
[null,"DOPSD0308","Average power factor conversion for 22 kV lines","Non-Financial","Nil","Estimate",null,null,"SAPN does not have any 22kV","Nil","Nil"]
[null,"DOPSD0309","Average power factor conversion for 33 kV lines","Non-Financial","SCADA","Estimate",null,null,"Refer explanation given in DOPSD0301","DOPSD0309 - Average power factor conversion for 33kV\n1\tIn order to determine the PF of the 33kV network, SA Power Networks separately summated the MW and MVAr values for all zone substations and connection points with a secondary voltage of 33kV.\n2\tThese summated values were then converted to MVA using Pythagoras’ Theorem.\n3\tThe summated MW value was then divided by the calculated MVA value.  The result was then entered into DOPSD0309 of the RIN.","DOPSD0309 & DOPSD0311- Average power factor conversion for 33 kV and 66kV\n1.\tCalculated values do not represent customer’s PF levels as they are compensated for by SA Power Networks’ and ElectraNet’s capacitor banks installed across the network.  They therefore represent PF values as effectively seen by the upstream transmission network and substation’s transformers."]
[null,"DOPSD0310","Average power factor conversion for 44 kV lines","Non-Financial","Nil","Estimate",null,null,"SAPN does not have any 44kV","Nil","Nil"]
[null,"DOPSD0311","Average power factor conversion for 66 kV lines","Non-Financial","SCADA","Estimate",null,null,"Refer explanation given in DOPSD0301","DOPSD0311 - Average power factor conversion for 66kV\n1\tIn order to determine the PF of the 66kV network, SA Power Networks separately summated the MW and MVAr values for all zone substations and connection points with a secondary voltage of 66kV.\n2\tThese summated values were then converted to MVA using Pythagoras’ Theorem.\n3\tThe summated MW value was then divided by the calculated MVA value.  The result was then entered into DOPSD0311 of the RIN.","DOPSD0309 & DOPSD0311- Average power factor conversion for 33 kV and 66kV\n1.\tCalculated values do not represent customer’s PF levels as they are compensated for by SA Power Networks’ and ElectraNet’s capacitor banks installed across the network.  They therefore represent PF values as effectively seen by the upstream transmission network and substation’s transformers."]
[null,"DOPSD0312","Average power factor conversion for 110 kV lines","Non-Financial","Nil","Estimate",null,null,"SAPN does not have any 110kV","Nil","Nil"]
[null,"DOPSD0313","Average power factor conversion for 132 kV lines","Non-Financial","Nil","Estimate",null,null,"SAPN does not have any 132kV","Nil","Nil"]
[null,"DOPSD0314","Average power factor conversion for 220 kV lines","Non-Financial","Nil","Estimate",null,null,"SAPN does not have any 220kV","Nil","Nil"]
[null," 3.4.3.6 - Demand supplied (for customers charged on this basis) – MW measure"]
[null,"DOPSD0401","Summated Chargeable Contracted Maximum Demand","Non-Financial","Nil","Actual",null,null,null,"Nil"]
[null,"DOPSD0402","Summated Chargeable Measured Maximum Demand ","Non-Financial","Annual sales and demand by customer report (ASDC - Year)","Actual",null,null,null,"Actual data is extracted from the ASDC report by period.\nData is summarised into tariff groups and aggregated demand billed for the period.","This value represents the maximum actual demand billed to residential customers on a demand tariff. Reported value is based on the aggregated residential demand tariff quantities billed for the reporting period."]
[null," 3.4.3.7 - Demand supplied (for customers charged on this basis) – MVA measure"]
[null,"DOPSD0403","Summated Chargeable Contracted Maximum Demand","Non-Financial","Annual sales and demand by customer report (ASDC - Year)","Actual",null,null,null,"Actual data is extracted from the ASDC report by period.\nData is summarised into tariff groups and aggregated demand billed for the period.","This value represents the maximum agreed/actual demand billed to non-residential customers on a demand tariff. Reported value is based on the aggregated non-residential demand tariff quantities billed for the reporting period."]
[null,"DOPSD0404","Summated Chargeable Measured Maximum Demand ","Non-Financial","Annual sales and demand by customer report (ASDC - Year)","Actual",null,null,null,"Actual data is extracted from the ASDC report by period.\nData is summarised into tariff groups and aggregated demand billed for the period.","This value represents the maximum actual demand billed to non-residential customers on a demand tariff. Reported value is based on the aggregated non-residential demand tariff quantities billed for the reporting period."]

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[null,"SA Power Networks",null,null,"Basis of Preparation"]
[null,1,1.1000000000000001,2,3,4,null,null,5,6,7,8]
[null,"CAT RIN Table Ref / EBT RIN Variable Code","RIN Row/ Column/ Cell or All (entire tab)","Financial /\nNon-Financial","Data Source","Actual / Estimated",null,null,"Justification\n(if estimated)","Methodology \n(actual and estimated)","Assumptions\n(actual and estimated)","SAPN Additional Comments\n(if any)"]
[null,"State the table reference (CA) or Variable Code (EB)","\nState the applicable row, column, cell, or entire tab","\nSelect whether the referenced information is financial or non-financial","\nExplanation of the data source for the referenced information","\nSelect whether the information from data source is either actual or estimated?",null,null,"\nExplanation of why an estimate is required and why actual data does not exist\n\nFor financial information, explanation of why financial information is not in accordance to the financial reporting framework and any changes, impacts and deviations to accounting policies (for any regulatory years).","\nExplanation of the method applied to provide the requested data. This should include an explanation of how the data was derived from other sources (if applicable) where this was undertaken and explain any allocation the approach applied.","\nExplanation/list of any assumptions made for data source, justification and methodology applied or made.","\nState any additional comments, notes or explanations."]
[null,"3.5.1 - NETWORK CAPACITIES"]
[null,"3.5.1.1 - Overhead network length of circuit at each voltage"]
[null,"DPA0101","Overhead low voltage distribution","Non-financial","Geographic Information System (GIS)","Actual",null,null,null,"Snapshot has been taken of GIS circuit length data by voltage.\nSAPN does not have any 6.6kV, 22kV, 44kV 110kV or 220kV lines and the 132kV circuit length in GIS is all unregulated assets - so not reported.\n\nSome parts of 33kV feeders may operate as SWER lines giving rise to differences between modelled GIS voltages and the designated feeder voltages (in uncommon single-phase cases). Designated feeder voltages are applied in this report.\n\nUpgrading of feeders from 7.6kV to 11kV is a staged process which can result in some transitional variations in the balance of line-lengths reported between these two voltages due to differences between normal / designated feeder voltages and point-in-time GIS modelled voltages. Such  variations are expected to cease when all of our 7.6kV network has been upgraded. Normal / designated feeder voltages are applied in this report.\n\nLV excludes service lines <10m in length)\nGIS extract is in tabs:\n . HVOH\n . LVOH(Serv>10m)\n\nHVOH is filtered by voltages and lengths per voltage summated."]
[null,"DPA0102","Overhead 2.2 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0103","Overhead 6.6kV"]
[null,"DPA0104","Overhead 7.6 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0105","Overhead 11 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0106","Overhead SWER","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0107","Overhead 22 kV"]
[null,"DPA0108","Overhead 33 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0109","Overhead 44 kV"]
[null,"DPA0110","Overhead 66 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0111","Overhead 110kV"]
[null,"DPA0112","Overhead 132 kV"]
[null,"DPA0113","Overhead 220kV"]
[null,"DPA0114","Other "]
[null,"DPA01","Total overhead circuit km"]
[null,"3.5.1.2 - Underground network circuit length at each voltage"]
[null,"DPA0201","Underground low voltage distribution","Non-financial","Geographic Information System (GIS)","Actual",null,null,null,"Snapshot has been taken of GIS circuit length data by voltage.\nSAPN does not have any 6.6kV, 22kV, 110kV or 132 cables.\n\nUpgrading of feeders from 7.6kV to 11kV is a staged process which can result in some transitional variations in the balance of line-lengths reported between these two voltages due to differences between normal / designated feeder voltages and point-in-time GIS modelled voltages. Such  variations are expected to cease when all of our 7.6kV network has been upgraded. Normal / designated feeder voltages are applied in this report.\n\nLV excludes service lines <10m in length)\nGIS extract is in tabs:\n. HVUG\n. LVUG(Serv>10m)\n\nHVUG is filtered by voltages and lengths per voltage summated."]
[null,"DPA0202","Underground 5 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0203","Underground 6.6 kV"]
[null,"DPA0204","Underground 7.6 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0205","Underground 11 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0206","Underground SWER","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0207","Underground 22 kV"]
[null,"DPA0208","Underground 33 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0209","Underground 66 kV","Non-financial","Geographic Information System (GIS)","Actual"]
[null,"DPA0210","Underground 110 kV"]
[null,"DPA0211","Underground 132 kV"]
[null,"DPA0212","Other "]
[null,"DPA02","Total underground circuit km"]
[null,"3.5.1.3 - Estimated overhead network weighted average MVA capacity by voltage class"]
[null,"DPA0301","Overhead low voltage distribution","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset information is available within SA Power Networks’ record systems, therefore where only partial data exists, this has been excluded from consideration at a given voltage","The following steps were undertaken to compile the data submitted:\nFor 33kV and 66kV (ie DPA0307 and 309 respectively),\n1.\tThe 66kV and 33kV line spreadsheets held, maintained and used by Network Planning Department for planning purposes were updated to reflect any augmentation of the 66kV and 33kV sub-transmission networks completed during the course of financial year.  Those augmentations of the 33kV and 66kV sub-transmission network (both new lines, upgrades and asset relocations) in progress, but not completed were not considered as per the instructions in the RIN Notice.\n2.\tWhere a line contains multiple types of conductor or at varying design temperatures, the line’s overall rating is based on that section of conductor which has the lowest rating.  For each line, the length of the overhead section(s) was multiplied by the rating of the overall line to arrive at a MVA.km value for that line’s overhead conductors.\n3.\tThese MVA.km values were then summated (according to operating voltage) as was the total length of overhead conductor at each voltage.\n4.\tThe weighted average MVA per km value was then determined by dividing the MVA.km value determined in step 2 by the total route length of the relevant voltage’s overhead circuits determined in step 3.\nFor 7.6kV and 11kV (ie DPA0303 and 304 respectively),\n1.\tAn extract from SA Power Networks’ GIS system was obtained.\n2.\tThe MVA capacity of each conductor for which sufficient details were available was determined and multiplied by the length of the conductor segment.  These resulting MVA.km values were then summated according to their nominal voltage.\n3.\tSimilarly, the route length of each conductor used in the MVA.km calculation was summated to arrive at the respective voltage’s total conductor length in km.\n4.\tThe total MVA.km value was then divided by the total route length for each voltage to arrive at the final MVA per km value.\nFor SWER and LV (ie DPA0301 and 305 respectively), as stated within the assumptions section:\n1.\tthe capacity of SA Power Networks’ SWER systems has been limited to a maximum of 0.2 MVA per km for the reasons stated in Section 5.4.\n2.\tFor the low voltage network, an extract from SA Power Networks’ GIS system was obtained.\n3.\tThe MVA capacity of each conductor for which sufficient details were available was determined and multiplied by the length of the conductor segment.  These resulting MVA.km values were then summated according to their nominal voltage.\n4.\tSimilarly, the route length of each conductor used in the MVA.km calculation was summated to arrive at the respective voltage’s total length in km.\n5.\tThe total MVA.km value was then divided by the total route length for each voltage to arrive at the final MVA per km value.","In compiling the data contained within this table, the following assumptions were made:\n1.\tThis analysis was based on a system snapshot taken from SA Power Networks’ GIS.  This analysis considered all overhead conductors for which adequate records existed to enable determination of a conductor rating irrespective of whether the conductor formed part of the feeder backbone or a spur.\n2.\tFor all 66kV and 33kV lines containing multiple conductor sizes or design temperatures, the conductor with the lowest rating was used to determine the MVA.km value for that line.\n3.\tFor all 11kV, 7.6kV and LV conductors, a design temperature of 75oC was assumed to determine the conductor rating.  For 66kV and 33kV conductors, the actual design temperature where known was used.\n4.\tIrrespective of the capacity of the overhead conductors used to construct SA Power Networks’ SWER networks, their capacity is limited to the largest SWER Isolating TF to prevent both overloading of the TF and also to ensure adequate protection co-ordination with upstream protection devices.\n5.\tAll MVA capacity values are based on the asset’s “normal” rating according to SA Power Networks’ QMS Procedure 638.","The following variable codes within Table 3.5.1.3 were not submitted either due to these voltages not being operated by SA Power Networks or where provided by SA Power Networks at these voltages, they directly supply HV customers from the ZSS and therefore SA Power Networks does not operate any overhead assets at this voltage:\n1.\tDPA0302 – 6.6kV (no overhead assets owned by SA Power Networks);\n2.\tDPA0306 – 22kV (not operated by SA Power Networks);\n3.\tDPA0308 – 44kV (not operated by SA Power Networks);\n4.\tDPA0310 – 110kV (not operated by SA Power Networks);\n5.\tDPA0311 – 132kV (not operated by SA Power Networks as a regulated asset);\n6.\tDPA0312 – 220kV (not operated by SA Power Networks);\n7.\tDPA0313 – Other (no overhead assets owned by SA Power Networks).\nThere are no significant changes in the values reported for the Financial Year from those reported in the previous financial year.\nVariation in the capacity of the 7.6kV network is due to the conversion of a number of substations and their associated feeders from operation at 7.6kV to 11kV within the metropolitan area.  The majority of remaining 7.6kV systems are located in the rural areas and therefore have smaller capacity conductors resulting in an overall drop in capacity on a weighted average, per km basis"]
[null,"DPA0302","Overhead 6.6 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 6.6kV","Nil","Nil"]
[null,"DPA0303","Overhead 7.6 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0301","Refer assumptions under DPA0301"]
[null,"DPA0304","Overhead 11 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0301","Refer assumptions under DPA0301"]
[null,"DPA0305","Overhead SWER","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0301","Refer assumptions under DPA0301"]
[null,"DPA0306","Overhead 22 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 22kV","Nil","Nil"]
[null,"DPA0307","Overhead 33 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0301","Refer assumptions under DPA0301"]
[null,"DPA0308","Overhead 44 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 44kV","Nil","Nil"]
[null,"DPA0309","Overhead 66 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0301","Refer assumptions under DPA0301"]
[null,"DPA0310","Overhead 110 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 110kV","Nil","Nil"]
[null,"DPA0311","Overhead 132 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,null,"Refer methodology under DPA0301","Refer assumptions under DPA0301"]
[null,"DPA0312","Overhead 220 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 220kV","Nil","Nil"]
[null,"DPA0313","Other ","Non-financial"]
[null,"3.5.1.4 - Estimated underground network weighted average MVA capacity by voltage class"]
[null,"DPA0401","Underground low voltage distribution","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset information is available within SA Power Networks’ record systems, therefore where only partial data exists, this has been excluded from consideration at a given voltage","The following steps were undertaken to compile the data submitted:\nFor 33kV and 66kV (ie DPA0409 and 410 respectively),\n1.\tThe 66kV and 33kV line spreadsheets held, maintained and used by the Network Planning Department for planning purposes were updated to reflect any augmentation of the 66kV and 33kV sub-transmission networks completed during the course of the financial year.  Those augmentations of the 33kV and 66kV sub-transmission network (both new lines and upgrades) in progress, but not completed were not considered as per the instructions in the RIN Notice.\n2.\tFor each line segment, the length of the underground section(s) was multiplied by the lowest rating of those cable sections within the overall line to arrive at a MVA.km value for that line.\n3.\tThese MVA.km values were then summated (according to operating voltage) as was the total length of overhead conductor at each voltage.\n4.\tThe weighted average MVA per km value was then determined by dividing the MVA.km value by the total route length of the relevant voltage’s underground circuits.\nFor 7.6kV and 11kV (ie DPA0304 and 305 respectively),\n1.\tAn extract from SA Power Networks’ GIS system was obtained.\n2.\tThe MVA capacity of each cable for which sufficient details were available was determined and multiplied by the length of the cable segment.  These resulting MVA.km values were then summated according to their nominal voltage.\n3.\tSimilarly, the route length of each cable used in the MVA.km calculation was summated to arrive at the respective voltage’s total cable length in km.\n4.\tThe total MVA.km value was then divided by the total route length for each voltage to arrive at the final MVA per km value.\nFor SWER and LV (ie DPA0406 and 401 respectively), as stated within the assumptions section:\n1.\tthe capacity of SA Power Networks’ SWER systems has been limited to 0.2 MVA per km.\n2.\tFor the low voltage network, an extract from SA Power Networks’ GIS system was obtained.\n3.\tThe MVA capacity of each cable for which sufficient details were available was determined and multiplied by the length of the cable segment.  These resulting MVA.km values were then summated according to their nominal voltage.\n4.\tSimilarly, the route length of each cable used in the MVA.km calculation was summated to arrive at the respective voltage’s total cable length in km.\n5.\tThe total MVA.km value was then divided by the total route length for each voltage to arrive at the final MVA per km value.","In compiling the data contained within this table, the following assumptions were made:\n1.\tThis analysis was based on a system snapshot taken from SA Power Networks’ GIS system.  This analysis considered all overhead conductors for which adequate records existed to enable determination of a conductor rating irrespective of whether the conductor formed part of the feeder backbone or a spur.\n2.\tFor all 66kV and 33kV lines containing multiple cable sizes or installation configurations, the cable with the lowest rating was used to determine the MVA.km value for that line.\n3.\tFor all 11kV, 7.6kV and LV cables, ratings have been determined assuming a standard installation configuration.  For 66kV and 33kV cables, the actual configuration where known was used.\n4.\tIrrespective of the capacity of the underground cables used to construct SA Power Networks’ SWER networks, their capacity is limited to the largest SWER Isolating TF to prevent both overloading of the TF and also to ensure adequate protection co-ordination with upstream protection devices.\n1.\tAll MVA capacity values are based on the asset’s “normal” rating according to SA Power Networks’ QMS Procedure 638.","The following variable codes within Table 3.5.1.4 were not submitted either due to these voltages not being operated by SA Power Networks or where operated by SA Power Networks at these voltages, they directly supply HV customers from the ZSS and therefore SA Power Networks does not operate any underground assets at this voltage:\t\n1.\tDPA0402 – 5kV (not operated by SA Power Networks);\n2.\tDPA0403 – 6.6kV (no underground assets owned by SA Power Networks);\n3.\tDPA0407 – 12.7kV (not operated by SA Power Networks);\n4.\tDPA0408 – 22kV (not operated by SA Power Networks);\n5.\tDPA0411 – 110kV (not operated by SA Power Networks);\n6.\tDPA0412 – 132kV (not operated by SA Power Networks);\n7.\tDPA0413 – Other (no underground assets owned by SA Power Networks)."]
[null,"DPA0402","Underground 5 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 5kV","Nil","Nil"]
[null,"DPA0403","Underground 6.6 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 6.6kV","Nil","Nil"]
[null,"DPA0404","Underground 7.6 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0401","Refer assumptions under DPA0401"]
[null,"DPA0405","Underground 11 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0401","Refer assumptions under DPA0401"]
[null,"DPA0406","Underground SWER","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0401","Refer assumptions under DPA0401"]
[null,"DPA0407","Underground 12.7 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 12.7kV","Nil","Nil"]
[null,"DPA0408","Underground 22 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 22kV","Nil","Nil"]
[null,"DPA0409","Underground 33 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0401","Refer assumptions under DPA0401"]
[null,"DPA0410","Underground 66 kV","Non-financial","Geographic Information System (GIS), Network Planning sub-transmission line records, QMS Procedure 638","Estimate",null,null,"Not all asset infomration available within SAPN records. ","Refer methodology under DPA0401","Refer assumptions under DPA0401"]
[null,"DPA0411","Underground 110 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 110kV","Nil","Nil"]
[null,"DPA0412","Underground 132 kV","Non-financial","Nil",null,null,null,"SAPN does not have any 132kV","Nil","Nil"]
[null,"DPA0413","Other","Non-financial"]
[null,"3.5.2 - TRANSFORMER CAPACITIES"]
[null,"3.5.2.1 - Distribution transformer total installed capacity"]
[null,"DPA0501","Distribution transformer capacity owned by utility","Non-financial","Distribution and sub-transmission transformer MVA from SAP and internal records and\nSA Power Networks internal stock records","Estimated",null,null,"Unknown MVA can be best estimated based on known MVA.","Transformer data is extracted from SAP and uploaded into an Access Database with a number of data updates made to produce the standard transformer MVA report (updates include Voltage transformations, Transformer Type conversions, Voltage Ratio conversions, Transformer Size conversions and GIS tran_type conversions to ensure the data is correctly reported). Once all data updates are complete, a summary Transformer MVA report is produced, providing the count of transformers by type. DPA0501 provides the sum of all transformers with Secondary voltage of \"LV\" and \"3.3kV\" inflated by the total cold spare capacity reported at DPA0503.\n"]
[null,"DPA0502","Distribution transformer capacity owned by High Voltage Customers","Non-financial","Sales Model (internal)","Actual",null,null,null,"Data is based on HV demand tariff kW and kVA quantities billed relating to HV Demand, Zone substation, Subtransmission.  \nData is extracted from an annual sales and demand by customer report for the period, specifically the peak demand day for the year. Aggregating either the maximum agreed demand or maximum actual demand (whichever is higher) required on this day for all HV tariff customers.","Customers would require transformers at their property to at least equal to the agreed HV demand or actual demand required on the raw network coincident maximum demand day during the year."]
[null,"DPA0503","Cold spare capacity included in DPA0501","Non-financial","SA Power Networks internal stock records","Actual",null,null,null," Actual data is based on actual stockholding in warehouses as at 30th June each year, the type, capacity and number of transformers were entered into a spreadsheet and then the capacity of the transformer was multiplied by the number of transformers held in stock.  All of the capacity figures were summed to calculate the total spare capacity.\n\n",null,"SA Power Networks only collects this data for stock reconciliation at the end of the financial year and hence the data is a snapshot of transformer capacity in hand at 30th of June each year, as a result this data is accurate for this day each year it does not reflect an average for the year.  For transformers the peak stock holding is typically around the 1st of November as summer emergency spare numbers are required to be in place by this date, after summer is over the spares are consumed without replacement until re-ordering occurs for the following November.  There are no other stock holding records for other times of the years. "]
[null,"3.5.2.2 - Zone substation transformer capacity"]
[null,"DPA0601","Total installed capacity for first step transformation where there are two steps to reach distribution voltage","Non-financial","SAP","Actual",null,null,null,"1.\tStarting with the installed TF nameplate capacities submitted within the previous Economic Benchmarking (EB) RIN, those capacity driven augmentations involving the upgrading or addition of further TFs at existing zone substation sites, or the installation of TFs at new zone substation sites, were added to the baseline TF installed capacity portfolio based on the installed TF capacity held within SAP and registered on the SSDs as stated within the assumptions section above.\n2.\tAn audit of SA Power Networks’ TF stores was undertaken to verify those TFs registered in SAP as held in stock.  These were segmented for internal use into “system spares” and “project”.\n3.\tEach TF according to its ZSS, was assigned a \"classification code\" (S1, S2, P or C) to indicate whether they were \"Stage 1\", \"Stage2\", \"Primary\" or \"Cold Standby\" TFs respectively, based on their position and function within the network.  Those TF units held in stores were classified as cold standby units.\n4.\tA summation of the capacity of those TFs within each classification in each forecast year was then performed using the “SUMIF” function within MS Excel, to arrive at the forecast summated TF capacity according to the classifications specified within the RIN.","1.\tThe figures provided are based on those TF nameplate capacities recorded in SAP and manually cross checked against those values specified on SA Power Networks’ SSDs.\n2.\tIn order to maintain consistency and comparability with previous Economic Benchmarking RIN submissions, all TF capacities (at each voltage reporting level), are based on the highest in service nameplate rating for the given TF according to its operating voltage (ie dual ratio transformers will have differing ratings depending on the secondary voltage they are set to operate at).  In the case of cold standby units, if the TF has forced cooling, the nameplate rating reported is the ONAF rather than ONAN nameplate rating.\nNameplate ratings have historically been provided rather than normal ratings as those normal ratings applied by SA Power Networks are subject to change based on their location.  This is due to changes in rating parameters (eg consideration of impact of PV on demand profile curve, localised temperature curves) or to reflect unbalanced sharing of transformers.  For consistency therefore, the highest nameplate value according to the TF’s operating voltage has been used where fans exist and according to operating voltage.\n3.\tAll TFs owned by SA Power Networks but which are deemed “unregulated assets” have been excluded from the reported values.\n4.\tThose TFs reported as being \"cold standby\" include TFs which are:\ni)\tinstalled, but de-energised (ie traditional cold standby);\nii)\tinstalled and energised, but not on load (ie hot standby);\niii)\tmobile units for use by SA Power Networks under contingent conditions or during ZSS augmentation;\niv)\tnot installed and held as system spares; and\nv)\tnot installed, but held in stores awaiting future installation (either as part of a planned network upgrade or new customer installation).","A total increase of 21.8MVA capacity has occurred in the Stage 1 Transformer category over the last 12 months is largely due to an increase in the capacity of cold standby units. \n\nA total reduction of 4.75MVA capacity has occurred in the Stage 2 Transformers category over the last 12 months is due to the conversion of a customer’s installation from supply at 33kV to 11kV.  A total of two transformers with primary voltages at 33kV were replaced with units with a primary voltage of 11kV at the Queen Elizabeth Hospital. \n\nCold Standby category has increased by almost 37MVA over the past year from 520MVA to 557MVA.  This has primarily occurred through an increase in the number of zone sub transformers being placed into standby operation for a variety of reasons"]
[null,"DPA0602","Total installed capacity for second step transformation where there are two steps to reach distribution voltage","Non-financial","SAP","Actual",null,null,null,"Refer methodology under DPA0601","Refer assumptions under DPA0601"]
[null,"DPA0603","Total zone substation transformer capacity where there is only a single step transformation to reach distribution voltage","Non-financial","SAP","Actual",null,null,null,"Refer methodology under DPA0601","Refer assumptions under DPA0601"]
[null,"DPA0604","Total zone substation transformer  capacity ","Non-financial","SAP","Actual",null,null,null,"Refer methodology under DPA0601","Refer assumptions under DPA0601"]
[null,"DPA0605","Cold spare capacity of zone substation transformers included in DPA0604","Non-financial","SAP","Actual",null,null,null,"Refer methodology under DPA0601","Refer assumptions under DPA0601"]
[null,"3.5.2.3 - Distribution - other transformer capacity"]
[null,null,"Distribution other - transformer capacity owned by utility ","Non-financial","Sales Model (internal)\n","Actual",null,null,null,"Data is based on HV demand tariff kW and kVA quantities billed relating to HV Demand, Zone substation, Subtransmission.  \nData is extracted from the preliminary YTD summary (based on information available at a point in time, reconciliation and true-up to be performed later in the year for inclusion in the Annual Pricing Proposal (APP)). ","Customers would require transformers at their property to at least equal to the agreed HV demand."]
[null,"3.5.3 - PUBLIC LIGHTING"]
[null,"DPA0701","Public lighting luminaires","Non-financial","SAP","Actual\n",null,null,null,"Luminaires are taken from the SAP lighting summary at end June. For clarity, the luminaire total excludes 'Long Pipe Bracket' tarriffs (SAP counts these as luminaire assets however they are a special support structure to a luminaire, not luminaires).",null,"The number of Public Lights may not match the number of poles/columns. This is because there may be more than one Luminaire per pole/column and some columns have double outreach arms which may have more than one luminaire attached."]
[null,"DPA0702","Public lighting poles","Non-financial","SAP","Actual",null,null,null,"This is the actual data from SAP of the count for dedicated public lighting 'columns'. It does not include shared assets such as Stobie poles used to support public lights. \n\nThe first EB RIN (ie from 2006 to 2013) only provided the Public Lighting Luminaires and Public Lighting Poles categories. A separate column category was introduced in 2014. At this time SA Power Networks continued to report the public lighting columns within the poles category, consistent with historical reporting. \n\nWe note that the AER has specifically requested that the Public Lighting Columns category (DPA0703) be used only where this category has been reported historically – with the RIN template stating “This information is not relevant to all NSPs. Only report against this line if reported against previously.”"]
[null,"DPA0703","Public lighting columns ","Non-financial",null,null,null,null,null,"SA Power Networks reports public lighting columns at DPA0702. We note that the AER has specifically requested that the Public Lighting Columns category (DPA0703) be used only where this category has been reported historically – with the RIN template stating “This information is not relevant to all NSPs. Only report against this line if reported against previously.”"]

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[]
[null,"SA Power Networks",null,null,"Basis of Preparation"]
[null,1,1.1000000000000001,2,3,4,null,null,5,6,7,8]
[null,"State the table reference (CA) or Variable Code (EB)","RIN Row/ Column/ Cell or All (entire tab)","Financial /\nNon-Financial","Data Source","Actual / Estimated",null,null,"Justification\n(if estimated)","Methodology \n(actual and estimated)","Assumptions\n(actual and estimated)","SAPN Additional Comments\n(if any)"]
[null,"\nState the table reference (CAT) or Variable Code (EBT)","State the applicable row, column, cell, or entire tab","Select whether the referenced information is financial or non-financial","Explanation of the data source for the referenced information","Select whether the information from data source is either actual or estimated?",null,null,"Explanation of why an estimate is required and why actual data does not exist\n\nFor financial information, explanation of why financial information is not in accordance to the financial reporting framework and any changes, impacts and deviations to accounting policies (for any regulatory years).","\nExplanation of the method applied to provide the requested data. This should include an explanation of how the data was derived from other sources (if applicable) where this was undertaken and explain any allocation the approach applied.","\nExplanation/list of any assumptions made for data source, justification and methodology applied or made.","\nState any additional comments, notes or explanations."]
[null,"3.6.1 - RELIABILITY"]
[null,"INCLUSIVE OF MEDs"]
[null,"DQS0101","Whole of network unplanned SAIDI","Non-financial","OMS / GIS / CIS-OV","Actual",null,null,null,"Reliability data is extracted from OMS from pre-defined standard regulatory reliability reports and calculations are in accordance with our QMS procedures:\no Unplanned SAIDI = Total Unplanned Customer Minutes / Total Customers\no Unplanned SAIFI = Total Unplanned Customers Interrupted / Total Customers\n    -  the required inclusions / exclusions are obtained by applying the appropriate filters to the cause of interruptions e.g. to obtain the figures for ‘excluding excluded outages’ the causes of Planned, ElectraNet, Generation etc. would be excluded.\n    -  MEDs are identified by calculating the daily unplanned SAIDI excluding excluded outages for each day and identifying those days that exceed Tmed – these are then included / excluded as required.","Where an interruption affects a phase(s), the number of customers affected is estimated as follows: 1/3rd if only one LV phase is affected, 2/3rds if two LV phases are affected and 2/3rds if only one HV phase is affected.\nThe only alternative method to the above (with current systems) is to perform a physical field check to determine the actual customers affected where a fuse or fuses have operated.  Not only is this method considered impractical and costly, it is not likely to lead to a materially different outcome to the figures currently reported."]
[null,"DQS0102","Whole of network unplanned SAIDI excluding excluded outages","Non-financial","OMS / GIS / CIS-OV","Actual"]
[null,"DQS0103","Whole of network unplanned SAIFI","Non-financial","OMS / GIS / CIS-OV","Actual"]
[null,"DQS0104","Whole of network unplanned SAIFI excluding excluded outages","Non-financial","OMS / GIS / CIS-OV","Actual"]
[null,"EXCLUSIVE OF MEDs"]
[null,"DQS0105","Whole of network unplanned SAIDI","Non-financial","OMS / GIS / CIS-OV","Actual"]
[null,"DQS0106","Whole of network unplanned SAIDI excluding excluded outages","Non-financial","OMS / GIS / CIS-OV","Actual"]
[null,"DQS0107","Whole of network unplanned SAIFI","Non-financial","OMS / GIS / CIS-OV","Actual"]
[null,"DQS0108","Whole of network unplanned SAIFI excluding excluded outages","Non-financial","OMS / GIS / CIS-OV","Actual"]
[null,"3.6.2 - ENERGY NOT SUPPLIED"]
[null,"DQS0201","Energy Not Supplied (planned)","Non-financial","OMS / GIS / CIS-OV","Estimate",null,null,"o SA Power Networks cannot provide actual data with current metering technology (as it mainly has Type 6 metering and meters are only read every 3 months).\no This is considered the most efficient and cost effective way with current systems.\no The consumption data is based on actual meter readings taken as close to 30 June as possible.","o The energy distributed to customers (GWh) for a 12 month period is extracted from CIS/OV.\no The annual consumption minutes are calculated and exclude the unplanned and planned whole of network SAIDI (excl. excluded outages and incl. MEDs).\no The energy distributed to customers is divided by the annual consumption minutes and is then multiplied by the corresponding whole of network unplanned / planned SAIDI (excl. excluded outages and incl. MEDs)."]
[null,"DQS0202","Energy Not Supplied (unplanned)","Non-financial","OMS / GIS / CIS-OV","Estimate"]
[null,"DQS02","Total","Non-financial","OMS / GIS / CIS-OV","Estimate"]
[null,"3.6.3 - SYSTEM LOSSES"]
[null,"DQS03","System losses","Non-Financial","Sales Model (internal)\n","Actual",null,"Calculated by dividing Total Deliveries (DOPED01) by Total Purchases (extracted from Sales Model). \nData provided is based on SAPN methodology and represents actuals as reported to AER.",null,"System losses are calculated by dividing the total energy lost by the total energy delivered (DOPED01). Total Energy lost is calculated as the difference between Total Deliveries (DOPED01) and the aggregate of Total Energy received from TNSP (3.4.1.2) and received into the system from embedded generation (3.4.1.3)"]
[null,"3.6.4 - CAPACITY UTILISATION"]
[null,"DQS04","Overall utilisation","Non-financial","DPA0604 & DOPSD0201.","Estimate",null,null,"Not all zone substations are SCADA enabled.  Given the need to estimate some zone substation’s demand, the value held within DOPSD0201 are only an estimate","The values submitted were calculated according to the following process:\n1.\tThe utilisation values were calculated based on the value held in DOPSD0201 (Non–coincident Actual Maximum Demand in MVA) divided by the value held in DPA0604 which represent the summation of DPA0601 (ie first step transformation capacity), DPA0602 (ie second step transformation capacity), DPA0603 (ie single step transformation capacity) and DPA0605 (ie cold standby capacity).\n2.\tThe resultant values were then converted to percent.","The following assumptions were made in deriving the values submitted:\n1.\tThe value provided within DOPSD0201 excludes the loads seen by the second step transformations to avoid double counting of the loads seen by the first and second step transformations."]

{"sheet":"3.7 Operating Environment","index":7,"n_rows":26,"n_cols":12,"rows_kept":26,"cut":false,"hidden":false,"merged":[[1,1,1,3],[1,4,1,11],[6,8,8,8],[6,9,8,9]]}
[]
[null,"SA Power Networks",null,null,"Basis of Preparation"]
[null,1,1.1000000000000001,2,3,4,null,null,5,6,7,8]
[null,"State the table reference (CA) or Variable Code (EB)","RIN Row/ Column/ Cell or All (entire tab)","Financial /\nNon-Financial","Data Source","Actual / Estimated",null,null,"Justification\n(if estimated)","Methodology \n(actual and estimated)","Assumptions\n(actual and estimated)","SAPN Additional Comments\n(if any)"]
[null,"\nState the table reference (CAT) or Variable Code (EBT)","State the applicable row, column, cell, or entire tab","Select whether the referenced information is financial or non-financial","Explanation of the data source for the referenced information","Select whether the information from data source is either actual or estimated?",null,null,"Explanation of why an estimate is required and why actual data does not exist\n\nFor financial information, explanation of why financial information is not in accordance to the financial reporting framework and any changes, impacts and deviations to accounting policies (for any regulatory years).","\nExplanation of the method applied to provide the requested data. This should include an explanation of how the data was derived from other sources (if applicable) where this was undertaken and explain any allocation the approach applied.","\nExplanation/list of any assumptions made for data source, justification and methodology applied or made.","\nState any additional comments, notes or explanations."]
[null,"3.7.1 - DENSITY FACTORS"]
[null,"DOEF0101","Customer density","Non-financial","DOPCN02 (Cust Nos), DOEF0301 (route km)","Estimate",null,null,"The other RIN data (specified in Data Source) on which these values has been derived are estimated.","Density factors calculated from other RIN variables as defined"]
[null,"DOEF0102","Energy density","Non-financial","DOPED01 (MWh), DOPCN02 (Cust nos)","Actual"]
[null,"DOEF0103","Demand density","Non-financial","DOPSD0201 (MVA), DOPCN02(Cust nos)","Estimate"]
[null,"3.7.2 - TERRAIN FACTORS"]
[null,"DOEF0201","Rural proportion","Non-financial","GIS circuit length data.","Estimate",null,null,"Estimate of route line length in Table 3.7.3 is based on circuit length data","Snapshot has been taken of GIS circuit length data by feeder . The feeder circuit length is converted into an estimated powerline length by feeder category. Then the estimated overhead powerline length by feeder category is then used to determine the percentage of rural (ie short and long)."]
[null,"DOEF0202","Urban and CBD vegetation maintenance spans","Non-financial","Vegetation clearance contractors","Estimate",null,null,"Assumes two defects per span in NBFRA, and one defect (ie contractor is paid by the span cleared) in BFRAs","Total vegetation maintenance spans are apportioned (estimated) based on number of spans for each feeder category for which SA Power Networks is responsible  Assumes two defects per span in NBFRA."]
[null,"DOEF0203","Rural vegetation maintenance spans","Non-financial","Vegetation clearance contractors","Estimate",null,null,"Assumes two defects per span in NBFRA, and number of spans in BFRAs","Total vegetation maintenance spans are apportioned (estimated) based on number of spans for each feeder category for which SA Power Networks is responsible  Assumes two defects per span in NBFRA."]
[null,"DOEF0204","Total vegetation maintenance spans","Non-financial","Vegetation clearance contractors","Estimate",null,null,"Assumes two defects per span in NBFRA, and number of spans in BFRAs","Number of spans (BFRAs) and trees (NBFRAs) for which SA Power Networks is responsible is recorded by our contractors.  Assumes two defects (trees) per span in NBFRA."]
[null,"DOEF0205","Total number of spans","Non-financial","Based on route length and average span length per base voltage level.","Estimate",null,null,"Number of poles or spans not recorded.","SA Power Networks erects different voltages on the same structures (eg 11kV and LV) and runs underground cables operating at different voltage levels in the same trench.  Consequently, SA Power Networks estimated in 2015 the percentage of higher voltages (ie 11kV and above) that run parrallel (ie on same structures) for each voltage level.  This percentage (or duplication factor) is used to convert the route length of a specified voltage (eg 11kV) to the route length that does not run on the same structures as that of a lower voltage (eg LV).  The same dupication factors have been used  each year.  An estimate in 2015 was made of the average span length for each volatge.  The route length of the lowest volatge is divided by thes average spna lengths to determine the number of spans.  The same span lengths have been used annually.  The average span length varies depending on whether in NBFRAs or BFRAs, with typically longer spans in BFRAs."]
[null,"DOEF0206","Average urban and CBD vegetation maintenance span cycle","Non-financial","Local Network Records","Estimate",null,null,"SAPN does not separately record information in this category","Apportioned based on number of spans for each feeder category "]
[null,"DOEF0207","Average rural vegetation maintenance span cycle","Non-financial","Local Network Records","Estimate",null,null,"SAPN does not separately record information in this category","Apportioned based on the number of NBFRA and BFRA spans by feeder categeory with an annual cycle for BFRA and a three year cycle for NBFRAs. "]
[null,"DOEF0208","Average number of trees per urban and CBD vegetation maintenance span","Non-financial","Vegetation clearance contractors estimate","Estimate",null,null,"SAPN does not separately record information in this category","Expert opinion on number trees per span in NBFRAs and BFRAs\nand then prorata based on feeder circuit length of CBD/Urban feeders in NBFRAs and BFRAs."]
[null,"DOEF0209","Average number of trees per rural vegetation maintenance span","Non-financial","Vegetation clearance contractors estimate","Estimate",null,null,"SAPN does not separately record information in this category","Expert opinion on number trees per span in NBFRAs and BFRAs\nand then prorated based on feeder circuit length of Urban/Rural feeders in NBFRAs and BFRAs."]
[null,"DOEF0210","Average number of defects per urban and CBD vegetation maintenance span","Non-financial","Vegetation clearance contractors estimate\nExpert opinion","Estimate",null,null,"SAPN does not separately record information in this category","Expert opinion on number trees per span in NBFRAs and BFRAs and then prorata based on feeder circuit length of CBD/Urban feeders in NBFRAs and BFRAs."]
[null,"DOEF0211","Average number of defects per rural vegetation maintenance span","Non-financial","Vegetation clearance contractors estimate","Estimate",null,null,"SAPN does not separately record information in this category","Expert opinion on number trees per span in NBFRAs and BFRAs and then prorata based on feeder circuit length of Rural feeders in NBFRAs and BFRAs."]
[null,"DOEF0212","Tropical proportion","Non-financial","http://www.bom.gov.au/jsp/ncc/climate_averages/climate-classifications/index.jsp?maptype=kpngrp","Estimate",null,null,null,"Refer to map"]
[null,"DOEF0213","Standard vehicle access","Non-financial","Internal expert opinion","Estimate",null,null,"SAPN does not separately record information in this category","Approximate estimate of 7% of route line length"]
[null,"DOEF0214","Bushfire risk","Non-financial","Based on route length and average span length per base voltage level.","Estimate",null,null,"Number of spans estimated per feeder type based on average span length","Based on average span length per base voltage level\nThe circuit length of each feeder was determined.  Each feeder is classified into bushfire risk areas and non-bushfire risk areas. An average span length per voltage was used to convert circuit kms to route kms."]
[null,"3.7.3 - SERVICE AREA FACTORS"]
[null,"DOEF0301","Route Line length","Non-financial","GIS and average span length per base voltage level.","Estimate",null,null,"SAPN does not separately record information in this category","SA Power Networks erects different voltages on the same structures (eg 11kV and LV) and runs underground cables operating at different voltage levels in the same trench.  Consequently, SA Power Networks estimated in 2015 the percentage of higher voltages (ie 11kV and above) that run parrallel (ie on same structures) for each voltage level.  This percentageg (or dupication factor) is used to convert the route length of a specified volatge (eg 11kV) that that route length that does not run parrallel to another lower voltage.  The same factors used for overhead conductor route length are used for underground cable length.  The same dupication factors have been used  each year. "]