In this section, we describe the information that a DPR should contain. It may be presented with the following broad headings:
• EXECUTIVE SUMMARY
• BACKGROUND AND PERSPECTIVE
• GOALS AND OBJECTIVES
• ENVIRONMENT, which should have a brief description of the commercial viability of the project, its reproducibility and scalability.
• APPROACH AND METHODOLOGY − a brief description
• FINDINGS AND CONCLUSIONS about the Project, its financial aspects, procurement and implementation plan, funding plan and risk
assessment.
• RECOMMENDATIONS
We now present an example of the broad content headings of the DPR prepared for the Bangalore Electricity Supply Company Limited in 2005. It details the entire information under the following sections:
A. INTRODUCTION, which contains
•Background and perspective
• EXECUTIVE SUMMARY
• BACKGROUND AND PERSPECTIVE
• GOALS AND OBJECTIVES
• ENVIRONMENT, which should have a brief description of the commercial viability of the project, its reproducibility and scalability.
• APPROACH AND METHODOLOGY − a brief description
• FINDINGS AND CONCLUSIONS about the Project, its financial aspects, procurement and implementation plan, funding plan and risk
assessment.
• RECOMMENDATIONS
We now present an example of the broad content headings of the DPR prepared for the Bangalore Electricity Supply Company Limited in 2005. It details the entire information under the following sections:
A. INTRODUCTION, which contains
•Background and perspective
• Project modules
• Project publications
B. UNDERSTANDING THE “AS-IS” CONDITION
C. GAP ANALYSIS
D. FINDINGS AND CONCLUSIONS
E. EVALUATION OF COSTS, BENEFITS AND RISKS
Each of these major sections from B to E in the DPR contains details under the following subsections:
1. Asset Management
2. System Operations and Despatch
3. Field Operations
4. Customer Processes
5. Corporate Processes
The details covered under these sections and subsections are summarised in the following tables. The headings under the first three subsections, viz.,asset management, system operations and despatch and field operations remain the same for the sections B to E and are listed in column 2 of Table.
• Project publications
B. UNDERSTANDING THE “AS-IS” CONDITION
C. GAP ANALYSIS
D. FINDINGS AND CONCLUSIONS
E. EVALUATION OF COSTS, BENEFITS AND RISKS
Each of these major sections from B to E in the DPR contains details under the following subsections:
1. Asset Management
2. System Operations and Despatch
3. Field Operations
4. Customer Processes
5. Corporate Processes
The details covered under these sections and subsections are summarised in the following tables. The headings under the first three subsections, viz.,asset management, system operations and despatch and field operations remain the same for the sections B to E and are listed in column 2 of Table.
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| Content Coverage for Subsections 1 to 3 of Sections B to E in the DPR |
The details within each subsection headings could vary. The coverage in the remaining subsections 4 and 5 differs in the details for sections B to E and is given in Table.
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| Content Coverage for Subsections 4 and 5 of Sections B to E in the DPR |
Notice that the heads of information (Column 2) in the subsections on customer and corporate processes (Column 1) are the same for Sections B, C and Sections D, E, respectively, in the above table.
In addition, the following sections are included in the DPR.
F. RECOMMENDATIONS
G. IMPLEMENTATION PLAN
H. DEPENDENCIES BETWEEN PROJECTS
• Implementation
• Implementation Interaction
• Operational Dependency
I. PRIORITIZATION AND SEQUENCING
J. RESPONSIBILITIES
• Execution
• Procurement
• Funding
• Review of BESCOM Procurement Documents
The following annexures are also included in it:
Annex 1: Abbreviations
Annex 2: Key Performance Indicators
Annex 3: Targets and Performance for KPIs
Annex 4: Detailed Costing and Benefits of Projects
Annexure 4 includes costing and benefit details for upgrading the distribution network, HVDS feeders 12 and 13, network refurbishment, network modernization, rural load management system, load research and power quality, automatic remote monitoring of SAIDI, SAIFI, CAIDI, and voltage,modernization of metering, project management, safety equipment, integrated customer care, customer installations refurbishment, extension of the centralized call centre and IVRS, prepaid meters, best practices, KPIs and KKPIs, training trips, energy audit and revenue protection, enhanced EIS / MIS,and asset management.
The detailed contents of each of these sections and subsections of the DPR prepared by PA Consulting Group, GECE, and KPMG are available in the Distribution Reform, Upgrades and Management (DRUM) Project materials.
We present another case study of DPR preparation.
A Case Study on APDRP DPR for Alwar Circle in Rajasthan
The report developed by MECON was based on extensive field visits for physical examination of the distribution network in the circle and close interaction with SEB officials of various levels.
It was hoped to achieve the following:
• Increase in metered energy through 100% metering of feeders and consumers.
• Reduction in outages and improvement in reliability through renovation of 33/11 kV substations and DTCs, augmentation of transformer capacity, etc.
• Reduction in T&D losses:
− Technical loss reduction through re-conductoring, bifurcations of line, shortening of LT line length, installation of shunt capacitors, etc.
− Commercial loss reduction through improved metering, billing,collection, stoppage of pilferage, etc.
Considerations for the DPR
MECON officials visited all 33 kV substations and obtained information from the SEB which could be refined further for certain locations and sizes of DTRs, 11 kV feeder lengths and sizes, etc. The following considerations form the basis of the present DPR:
• Fair technical assumptions to bridge the data gap, due to inadequate metering in the system, have been made to develop the DPR.
• For identifying the schemes to be included under this DPR for the 33 kV and 11 kV systems, permissible regulation is taken as the guideline. 11 kV feeder renovation and loss reduction, installation of LT capacitors at DTRs, bifurcation of lines for redistribution of loads have been considered in this order.
• For 33 kV system loss reduction, reconductoring, redistribution of feeders, strengthening of existing transformation capacity and establishing new power substations are considered in this order.
Outcome of DPR
The investment of Rs 69.54 crores in R&M of PSS, strengthening of conductors, augmentation of transformers, installation of LT capacitors,improvements in metering system and setting up of new PSS is expected to yield 44.6 MU energy savings equivalent of Rs 13.48 crores per annum, thus promising a good investment.
Circle Profile: The broad parameters of the circle are given ahead.• Peak Power Demand
• 33/11 kV Power Substations : 225 MW
− Number : 64
− Total Transformer Capacity : 308.8 MVA
33 kV Feeders
− Number : 56
− Total Length : 957.365 kms
11 kV Feeders
− Number : 321
− Total Length : 6209.537 km
Distribution Transformers
− Number : 10158
− Total Transformer Capacity : 633.77 MVA
• LT Feeders : 14317.333 km
• LT : HT Line Ratio : 2:3:1
• Annual Energy Import : 1413.182 MU
• Consumer Statistics (effective as on 28.02.2002) : 2,53,306
− Domestic : 169516 Nos.
− Commercial : 30256 Nos.
In addition, the following sections are included in the DPR.
F. RECOMMENDATIONS
G. IMPLEMENTATION PLAN
H. DEPENDENCIES BETWEEN PROJECTS
• Implementation
• Implementation Interaction
• Operational Dependency
I. PRIORITIZATION AND SEQUENCING
J. RESPONSIBILITIES
• Execution
• Procurement
• Funding
• Review of BESCOM Procurement Documents
The following annexures are also included in it:
Annex 1: Abbreviations
Annex 2: Key Performance Indicators
Annex 3: Targets and Performance for KPIs
Annex 4: Detailed Costing and Benefits of Projects
Annexure 4 includes costing and benefit details for upgrading the distribution network, HVDS feeders 12 and 13, network refurbishment, network modernization, rural load management system, load research and power quality, automatic remote monitoring of SAIDI, SAIFI, CAIDI, and voltage,modernization of metering, project management, safety equipment, integrated customer care, customer installations refurbishment, extension of the centralized call centre and IVRS, prepaid meters, best practices, KPIs and KKPIs, training trips, energy audit and revenue protection, enhanced EIS / MIS,and asset management.
The detailed contents of each of these sections and subsections of the DPR prepared by PA Consulting Group, GECE, and KPMG are available in the Distribution Reform, Upgrades and Management (DRUM) Project materials.
We present another case study of DPR preparation.
A Case Study on APDRP DPR for Alwar Circle in Rajasthan
The report developed by MECON was based on extensive field visits for physical examination of the distribution network in the circle and close interaction with SEB officials of various levels.
It was hoped to achieve the following:
• Increase in metered energy through 100% metering of feeders and consumers.
• Reduction in outages and improvement in reliability through renovation of 33/11 kV substations and DTCs, augmentation of transformer capacity, etc.
• Reduction in T&D losses:
− Technical loss reduction through re-conductoring, bifurcations of line, shortening of LT line length, installation of shunt capacitors, etc.
− Commercial loss reduction through improved metering, billing,collection, stoppage of pilferage, etc.
Considerations for the DPR
MECON officials visited all 33 kV substations and obtained information from the SEB which could be refined further for certain locations and sizes of DTRs, 11 kV feeder lengths and sizes, etc. The following considerations form the basis of the present DPR:
• Fair technical assumptions to bridge the data gap, due to inadequate metering in the system, have been made to develop the DPR.
• For identifying the schemes to be included under this DPR for the 33 kV and 11 kV systems, permissible regulation is taken as the guideline. 11 kV feeder renovation and loss reduction, installation of LT capacitors at DTRs, bifurcation of lines for redistribution of loads have been considered in this order.
• For 33 kV system loss reduction, reconductoring, redistribution of feeders, strengthening of existing transformation capacity and establishing new power substations are considered in this order.
Outcome of DPR
The investment of Rs 69.54 crores in R&M of PSS, strengthening of conductors, augmentation of transformers, installation of LT capacitors,improvements in metering system and setting up of new PSS is expected to yield 44.6 MU energy savings equivalent of Rs 13.48 crores per annum, thus promising a good investment.
Circle Profile: The broad parameters of the circle are given ahead.• Peak Power Demand
• 33/11 kV Power Substations : 225 MW
− Number : 64
− Total Transformer Capacity : 308.8 MVA
33 kV Feeders
− Number : 56
− Total Length : 957.365 kms
11 kV Feeders
− Number : 321
− Total Length : 6209.537 km
Distribution Transformers
− Number : 10158
− Total Transformer Capacity : 633.77 MVA
• LT Feeders : 14317.333 km
• LT : HT Line Ratio : 2:3:1
• Annual Energy Import : 1413.182 MU
• Consumer Statistics (effective as on 28.02.2002) : 2,53,306
− Domestic : 169516 Nos.
− Commercial : 30256 Nos.
− LT Industrial : 7439 Nos.
− Agricultural : 44302 Nos.
− HT Industry : 325 Nos.
− Others : 1468 Nos. : 1714
• No. of employees
− Agricultural : 44302 Nos.
− HT Industry : 325 Nos.
− Others : 1468 Nos. : 1714
• No. of employees
• No. of employees per thousand of consumers : App. 7
• Revenue collection/employee : Rs. 18.6 Lac
• Monthly expenditure of the circle : Rs. 190 Lac
• Cost of energy purchased : Rs. 2.30/unit
• Energy consumption per day of the circle : App. 38 Lu
Key Findings
The following key findings resulted from the physical survey and examination of distribution system.
•Health of 33 kV/11 kV substations is poor.
•Presently all energy input and exchange points of the circle are not provided with meters. Large numbers of meters are also non-functional.
•Energy accounting is being carried out based on available energy information.
•The consumption of agricultural and consumers with faulty meters is also based on assessment. It is understood that on an average about 10% of consumers have defective meters.
•Electronic meters are provided in all 11 kV outgoing feeders, but the metered data analysis and report for energy accounting has not been started.
•11 kV are identified with specific coding which leads to identification of feeders with division, sub-division and power substations.
Consumer indexing to link the consumers with 11 kV feeders is being adopted in some parts of the circle.
•33 kV CBs are generally not available except in Alwar City area.
•11 kV CBs are available only in incomer from power transformer secondary in some of the substations.
•Irrigation users are generally flat rate consumers charged for 4 hours 15 minutes at the rate of Rs 0.99 per unit and 3-phase power is supplied for about 6 hours on an average. Lighting power is supplied for another 4 hours on single phase basis.
•Rural feeders are fed supply in blocks to avoid power transformers’ loading.
The status of metering in existing system and consumers was ascertained and the metering requirements were also estimated. All the 64 power substations were visited by MECON and the status of equipment was critically examined to identify the need for immediate replacement, which once implemented would improve the availability of power. During the visits to the power substations it was observed that at a number of substations the transformers were loaded quite heavily, up to 80-90%. Based on this, augmentation of transformer capacity by replacing the existing transformers with higher capacity was proposed.
A sample survey of DTRs in the Circle revealed that most DTs did not have LAs, the HT and LT side connections to the DTs were not done with proper crimping of the cables or conductors and were wound with aluminum wire in several layers. Hence there were chances of loose connections and increased contact resistance. Most DTs were not provided with isolating arrangements like AB switches. The earthing of the DTs was not proper and most DTs were not provided with adequate protection. The failure of Distribution Transformers in the circle was of the order of 19.5% during 2001-02.
• Revenue collection/employee : Rs. 18.6 Lac
• Monthly expenditure of the circle : Rs. 190 Lac
• Cost of energy purchased : Rs. 2.30/unit
• Energy consumption per day of the circle : App. 38 Lu
Key Findings
The following key findings resulted from the physical survey and examination of distribution system.
•Health of 33 kV/11 kV substations is poor.
•Presently all energy input and exchange points of the circle are not provided with meters. Large numbers of meters are also non-functional.
•Energy accounting is being carried out based on available energy information.
•The consumption of agricultural and consumers with faulty meters is also based on assessment. It is understood that on an average about 10% of consumers have defective meters.
•Electronic meters are provided in all 11 kV outgoing feeders, but the metered data analysis and report for energy accounting has not been started.
•11 kV are identified with specific coding which leads to identification of feeders with division, sub-division and power substations.
Consumer indexing to link the consumers with 11 kV feeders is being adopted in some parts of the circle.
•33 kV CBs are generally not available except in Alwar City area.
•11 kV CBs are available only in incomer from power transformer secondary in some of the substations.
•Irrigation users are generally flat rate consumers charged for 4 hours 15 minutes at the rate of Rs 0.99 per unit and 3-phase power is supplied for about 6 hours on an average. Lighting power is supplied for another 4 hours on single phase basis.
•Rural feeders are fed supply in blocks to avoid power transformers’ loading.
The status of metering in existing system and consumers was ascertained and the metering requirements were also estimated. All the 64 power substations were visited by MECON and the status of equipment was critically examined to identify the need for immediate replacement, which once implemented would improve the availability of power. During the visits to the power substations it was observed that at a number of substations the transformers were loaded quite heavily, up to 80-90%. Based on this, augmentation of transformer capacity by replacing the existing transformers with higher capacity was proposed.
A sample survey of DTRs in the Circle revealed that most DTs did not have LAs, the HT and LT side connections to the DTs were not done with proper crimping of the cables or conductors and were wound with aluminum wire in several layers. Hence there were chances of loose connections and increased contact resistance. Most DTs were not provided with isolating arrangements like AB switches. The earthing of the DTs was not proper and most DTs were not provided with adequate protection. The failure of Distribution Transformers in the circle was of the order of 19.5% during 2001-02.
It was proposed to bring down the technical losses by installation of LT capacitors at DTR secondary, introduction of capacitors at LT side of DTRs (the study showed that reduction in losses due to this measure would be of the order of 4.06 MU/annum), bifurcation of 11 kV feeders and redistribution of loads (the study showed that reduction in losses due to these measures would be of the order of 3.49 MU), augmentation of power transformers’ capacity (reduction in losses due to installation of additional transformers were calculated to be 2.04 MU/ annum), and installation of new power substations (the estimated loss reduction due to these measures is 1 % of total energy input, i.e., 14 MU/annum). For commercial loss reduction, it was proposed to introduce high quality meters both at the system level and at consumers and an energy accounting system, which was expected to increase the metered energy sales by about 2% of energy input, i.e., 28 MU, which was the estimated commercial loss.
Proposed administrative measures for reduction of commercial losses included increase of vigilance raids, introduction of heavy penalty for theft/tampering of meters, introduction of tamper proof meters, improvement in billing and collection system by introduction of spot billing or engaging other agencies for this purpose and introduction of regular energy audits for each 11 kv feeder and identification of high theft areas to intensify raids.Summary of Proposal and Benefits of Various Schemes The cost and benefit summary of various schemes is given in Table
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| Cost and Benefit Summary of Various Schemes |
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| Costs of Various Schemes |
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| Benefits of Various Schemes |
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Payback Period or Various Schemes |
You can see that DPR preparation along the lines given in this section requires intensive work and also considerable time than is invested at present. We present an article from the DRUM materials about the writing of the DPR report in an Appendix to this unit.
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