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					                        INPUT DATA FOR DETAILED PROJECT REPORT (DPR)

UTILITY DETAILS
Name of State

Name of Utility (Expanded Name)

Name of Utility (Short Name)
Date of Incorporation
Total Number of Utility Consumers
Contact Details (Utility Nodal Officer)
                                                          Designation
                                                              Address
                                                        Phone Office 1
                                                           Mobile No.
                                                                  Fax
                                                               E-mail
TOWN DETAILS
Name of Project Area/Town
District
Total Number of Consumers
Total Population (as per 2001 census)
Total Area of Coverage
Point of Contact (Town Incharge)
                                                           Designation
                                                               Address
                                                        Phone Office 1
                                                           Mobile No.
                                                                  Fax
                                                               E-mail
Likely Date for Establishment of Baseline Data
(Clause 17 of Guideline Part-B)

Reference for Part A

Loan No. for IT Project under Part-A
Date of Sanction of IT Project under Part-A


Data for AT&C Losses Computation for Project Area                                              Data for Previous FY
                                                                                   Unit
(Available data for Previous FY Before Project Sanction)                                             2009-10
                                                                                          FY                2009-10




                                                                                                                      To be filled
Energy Input(08-09)                                                      M Units
Energy Sales                                                             M Units
Total Revenue Billed                                                     Rs. Lac
Total Revenue Collected (including arrears)                              Rs. Lac
Arrears   {Actual or Total Revenue collected-Revenue billed}             Rs. Lac

Billing Efficiency                                                       %
Collection Efficiency                                                    %
AT&C Losses {Assessed for Base Year-(09-10)}                             %

Loss Reduction Trajectory                                                Unit                      Projection
Year-1                                                                   %
                                                                                                                      To be filled




Year-2                                                                   %
Year-3                                                                   %
Year-4                                                                   %
Year-5                                                                   %
Year-6                                                                   %

Cells with yellow shade only to be filled by Utilities.
Units of energy, amount etc. not to be changed by Utilities
State

Name of Utility

Project Area Name/Town Name



                  Detail Project Report - Part B



Submitted to


    POWER FINANCE CORPORATION LTD.



DPR No./Version




Date of Submission
                                                                                      Submission of DPR for Part-A



POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Index



      Date of Submission of Proposal                             #Date
      DPR No.                                                    Code
      Current Financial Year                                     FY
      Proposed Project Start Date                                #Date
      Proposed Period of Completion                              Months

      Table of Contents                                                        Page Number
  I   Part I: Guidelines for Part-B
 II   Part II
  1   Declaration
  2   Executive Summary
  3   Volume I: Introduction
  4   Volume II: General Detail
  5   Volume III: Project Area Details
  6   Volume IV: SUMMARY Project Cost Estimate
  7   Volume V: Expected Project Benefit
  8   Annexure A: Implementation Schedule
  9   Annexure B: Asset Hirarchy
10    Annexure C: Single Line Diagrams
11    Annexure D: Quality Management System
12    Annexure E : Procurement Procedures/Guildelines
III   Annexure-F: Check List




                                                        Page 3            7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Part I: Guidelines for Part-B

     1 Part B of the R-APDRP covers system improvement works mentioned in the DPR Volume IV. This aims
       at achievement of AT&C losses to 15% in town areas. Any other work may be considered if utility
       justifies that the implementation of the same would lead to Loss Reduction in the project area.
     2 The utilities will be required to achieve target AT&C loss reduction at the entire utility level every year
       starting one year after the year in which first project of the Part-A is completed.
       Utilities having AT&C loss above 30%: Reduction by 3% per year
       Utilities having AT&C loss below 30%: Reduction by 1.5 % per year
     3 Utility shall submit detailed cost benefit analysis of the works planned to be implemented along with the
       DPR. It should include existing loss level, works proposed and loss level after implementation.
     4 The Part-B project shall be completed within three years from the date of its sanction.Fund to be released
       to the Part-B project shall be limited to first three years, from the date of its sanction.
     5 Utility has to appoint a Nodal Officer who shall be involved from concept to commissioning of the system
       and shall also be the contact point for Nodal Agency for any clarification, issue etc.
     6 The Utility will have to certify and sign the DPRs prepared by them stating that the DPR is in line with
       guidlines issued by Ministry of Power/ PFC for Part B, R-APDRP and is aligned completely with the
       Utility’s business processes before the same is forwarded to PFC.
     7 Utility should prepare a comprehensive plan for R-APDRP implementation. All the proposed towns under
       the scheme (both Part-A and Part-B) shall be clearly listed and DPR of each town shall be forwarded to
       PFC for consideration. Any standalone/ piecemeal scheme for any Project Area for subsequent integration
       is liable to be rejected.
     8 Utility has to ensure timely availability of any other infrastructure or facilities that are essential for
       implementation of Part-B works but are not in the scope of Contractor viz. land acqusition, pole location
       etc.
     9 Works in progress should not be included in the new schemes under R-APDRP.
   10 Utility shall provide detailed informantion regarding exisitng infrastrucuture, any bottleneck in
       implementation of the works and the works proposed in the project to the Contractor before award of
       contract.
   11 Utility shall sumbit separate DPR for each Project Area. For all practical purposes, boundaries of the
       Project Area shall be considered as defined in the Part-A of R-APDRP by the Utility.
   12 Utility shall submit DPRs of all Project Areas (Towns) preferably together to nodal agency (PFC) for
       approval of Steering Committee.
   13 DPR shall be annexed with digital single line diagrams (SLD)/Nodal drawings of existing and proposed
       distribution network of the Project Area. DPRs without the same would not be considered for sanction.
   14 The cost estimates should not include any departmental overhead expenses and cost of consultancy. All
       such expenditures should be borne by the utility.
   15 The Utility shall work out the AT&C loss of the project / town and facilitate with independent agency (to
       be appointed by MoP/ Nodal Agency) for validation of the same including providing documents etc. The
       AT&C loss of the project area duly certified by TPIEA before start of Part-B works, will be treated at Base
       Line AT&C loss of the project area for all purposes.
   16 Scope variation on account of increase of consumer base during the currency of contract or any other
       reason would be to Utility’s account.
   17 For the project areas envisaged for implementation of SCADA, distribution system shall be made
       compatible so as to ensure interface with SCADA/DMS system. The cost of such enabling features shall
       be covered in present DPR.
   18 Utility has to ensure Ring Fencing of the project area including establishing the Baseline AT&C losses
       before implementation of Part-B project.The following guidelines have to be adhered to while ring fencing
       is done for project area
    a) All input points shall be identified and metered with downloadable meters for energy inflow accounting in
       scheme area
    b) All outgoing feeders are to be metered in sub-station with downloadable meters
    c) Scheme area should be ring fenced i.e export and import meters for energy accounting shall be ensured
   d) Arrangement for measuring total energy flow in the rural load portion of project area by ringfencing if
       rural load feeder is not seggregated
   19 Cost of consumer meters installed under R-APDRP should not be charged to consumer.
   20 Distribution Transformers procured under R-APDRP scheme, shall have efficiency level equivalent /
       better than that of three star ratings of BEE, where ever BEE standard is applicable. For other DTs, where,
       BEE standard is not applicable, CEA guidelines shall be followed (available on CEA web site).
   21 In case of new 11 KV feeders/sub-stations / DTs are installed at any point of time after sanction of Part-A,
       utility must make provision for installing AMR at appropriate points and ensure integration with IT system
       proposed/installed in Part-A
   22 Return on investment for the project shall not be less than 10%.
   23 Project shall be preferably executed on turnkey basis.
   24 Planning for LT lines, DTs etc shall be done, considering load growth for three years and existing
       utilization of transformation capacity & lines.
   25 Planning for 11 KV lines, Power Transformers and Primary S/S shall be done, considering load growth for
       five years.
   26 For calculation of future Load, the growth may be on the basis of average of last five year load growth.
   27 Total capacity of Distribution Transformers may be upto 200% of the Power Transformer capacity. .
   28 Capacity enhancement of DTs shall not be done in isolation. Capacity enhancement of LT lines shall also
       be clubbed with capacity enhancement of DTs.
   29 All categories of consumer meters can be proposed in Part-B of R-APDRP scheme for replacement from
       electromechanical to electronic meters. AMIs can be considered for deployment. The meters shall be
       tamper proof electronic meter, as per R-APDRP guidelines issued from time to time.
     30 In case of any new asset created at any point of time after sanction of Part-A, utility must make provision
          for installing AMR at appropriate points and ensure integration with IT system proposed / installed in Part-
          A. Utility should also use GPS survey through GPS machine for new assets created during implementation
          of Part-B scheme and subsequent thereof.
     31 The following items may be included by the utilities under PART B:
S. No.                                                    Nature of work                                                           Evaluation method
      a) Replacement of existing HT & LTCT Electromechanical consumer meters with two way (AMR
                                                                                                                               The utility shall provide the
          compatible, open protocol) tamper proof electronic meters. For replacement of whole current
                                                                                                                               number of such consumers.
          electromechanical consumer meters, the guidelines of CEA shall be adopted.
      b) If existing service line is prone to tamper and pilferage the same shall be replaced with armored or XLPE             The replacement of service
          cable for which minimum configuration should be :                                                                    cable for maximum 25%
          (i) Single Phase consumers: min. 4 sq.mm                                                                             consumers of the town may
          (ii) Three Phase consumers: min. 6 sq.mm                                                                             be allowed. In exceptional
      c) Installation of new Distribution Transformers in following cases:
          (i) If the length of LT feeder is more than 300 mtr then new Distribution transformer may be proposed to
          improve HT: LT ratio.
          (ii) If existing peak load on DT is more than 70% of its rated capacity then new DT may be proposed.
          (iii) Even if the length of LT feeder is below 300 meter but the peak load on the feeder is more than 70%
          of rated thermal capacity of the conductor, new DT should be installed or conductor should be replaced by
          higher size.
     d) Provision of Isolator, HT fuse / horn gap & LA at each Distribution Transformer, if not provided earlier.
          Alternatively this isolator, HT fuse / horn gap fuse can be replaced with drop out fuse with On Load
          maintenance facility thereby reducing system interruptions.
     e) Provision of LT distribution box for control and protection of outgoing LT circuits.
       f) Each Distribution Transformer of 25 KVA & above shall be provided with minimum two LT feeders. In
          case of only one existing LT feeder, scheme for laying new LT circuit may be prepared.
      g) If the peak load on existing 11KV feeder is more than 75% of rated thermal capacity of the conductor,                 The load growth of next
          conductor with higher capacity may be proposed or feeder bifurcation may be proposed.                                five years should be worked
      h) If peak load on existing 33/11KV S/S is more than 80% of its transformer capacity or the O/G 11KV                     out for the purpose of
          Feeders have peak load more than 75% of their thermal capacity , new 33/11KV S/S may be proposed.                    calculating the capacity.
       i) 11 Kv feeder segregation may also be proposed for (i) reducing boundary metering points (ii) reduce                  (Load growth shall be
          complexities involved in consumer indexing, GIS based asset mapping (iii) fixing greater accountability              worked out on the basis of
          and responsibility                                                                                                   last five year average load
       j) Intelligent Ring main unit & sectionaliser may be proposed for such town which fulfill any of the
          following criterion :
          (i) Where SCADA is proposed.
          (ii) Population of Town is more than 1 lakh.
          (iii) Annual energy input is more than 100MU.
          (iv) Any other specific requirement.
      k) The Distribution Transformer may be provided with the capacitors of following ratings at LT side:                     The Distribution
          (i) 100 KVA : 12 KVR                                                                                                 Transformer may be
          (ii) 63 KVA : 8 KVR                                                                                                  provided with reactive
          (iii) 40 KVA : 6 KVR                                                                                                 compensation controls
          (iv) 25 KVA : 4 KVR                                                                                                  along with appropriate
       l) Installation of ABC cables in dense, theft prone & congested areas. Both HT & LT ABC may be proposed.
          The capacity of ABC shall be 20% more than that of bare conductor, as thermal overloading capacity of
          ABC is less than Bare conductor.
     m) In theft prone area and to improve HT:LT ratio, HVDS may be proposed. Total capacity of HVDS shall be
          higher by 20% than conventional LT S/S.
      n) For the towns where SCADA has been proposed , the following electrical interfaces shall be included in
          PART B :
          (i) Battery Charger at each 33KV S/S if not available.
          (ii) Conversion of overhead 11 KV line with Underground 11 KV line with installation of Fault Passage
          Indicators.
          (iii) Motorized breaker for all incoming & outgoing feeders at 33 KV substations.
          (iv) Open protocol electronic relays
          (v) Ring Main Unit (SCADA Ready) / sectinaliser.
          (vi) Separate CTs for SCADA purpose may be considered.
      o) 10% line length of 11 KV lines may be considered for auto re-closer (self healing) scheme.
     32 Following documents shall be submitted for cost justification:
          (i) Utility shall provide approved schedule of rate of current financial year for proposed works against
          justification of cost.
                                                                 OR
          (ii) Utility shall provide approved stock issue rate of current financial year for justification of material cost.
     33 Utility shall submit cost estimate of each and every proposed work as annexure. This will ensure the
          preliminary study and preparedness of the utility about the work. This will also help in appraising the
          proposed cost in DPR.
POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Declaration
This is to certify that:
          1 Proposed Project Area has already been covered under Part-A of the R-APDRP. The status of Part-A, R-
            APDRP for the Project Area is mentioned in the Volume III of the DPR.
          2 The X plan project in the concern project area has been completed/ short closed.
          3 The proposed DPR includes only new works and excludes other works under implementation.
          4 All works proposed in the DPR are as per DPR Formats issued by Nodal Agency. Any cost other than
            allowed by Nodal Agency in the DPR formats shall be born by the Utility.
          5 The cost estimates do not include any departmental overhead expenses.
          6 CSPDCL will henceforth, procure all meters as per guidelines/regulations issued by MoP/CEA (circular
            available on APDRP web portal).
          7 Utility shall provide basic infrastructure viz. required space, building, precision air-conditioning, fire
            fighting system, power supply etc. to the contractor/agency involve for erection of system proposed to be
            created under Part-B of R-APDRP Scheme at its own cost. It shall be ready for handing over to
            Contractor as per the requirement.
          8 DPR has been prepared in line with the guidelines of R-APDRP issued by Ministry of Power / PFC to
            strengthen the basic infrastructure in State owned distribution companies of the country and is aligned
            completely with the Utility's business processes.
          9 Following items have been excluded from the scope of the DPR. Utility shall arrange the same from
            their own resources -
            ·     Land/space in accordance with project requirements.
            ·     Fire fighting system
            ·     Any mobile equipment such as Crane, truck, Jeep, filter M/c, etc.
            ·     Any T&P, testing equipments. etc.
            ·     Communication equipments such as mobile phone, telephone etc
            ·     Manpower for managing and maintaining the network, substations, etc.
         10 The Ring Fencing of the project area has been completed and Part-A of the programme has been
            initiated vide Loan No-------- sanctioned on date --------. Further, baseline AT&C losses shall be
            established before start of work of Part-B for this project area.
         11 A Nodal Officer has been appointed by the Utility, who shall be involved from concept to
            commissioning of the system and co-ordinate from the Utility side for all issues related to
            implementation of the project. The detail of the authorised signatory & Nodal Officer are given below -

        12 On basis of model incentive scheme for utility staff as formulated by the MoP, incentive scheme shall be
           submitted for the approval of the Steering Committee in the MoP prior to seeking disbursements under
           Part-B
        13 Cost of consumer meters installed under R-APDRP will not be charged to consumer.
        14 With the implementation of works of Part-B, AT&C Loss shall be brought down to below 15%
           (supplemented by write-up in the DPR for the same).
        15 The Part-B project shall be completed within three years from the date of its sanction.


           Authorised Signatory:
           Signature:
           Name: J.R.Patel                               Tel. No. / Mobile No.
           Designation:Addl.Chief Engineer(EITC)
           (Utility Nodal Officer for Part-B)

           Approved by:
           Signature:
           Name:
           Designation:
                                                                                                                 Submission of DPR for Part-B


POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Executive Summary

    Project objective:-                                         To reduce AT & C losses upto 15%.
    Quadripartite Agreement Date

    Brief Profile of State/Utility
    Name of State
    Name of Utility (Short Name)
    Date of Incorporation
    Total Number of Utility Consumers

    Previous Financial Year
                     Billing Efficiency                  %
                   Collection Efficiency                 %
                       AT&C Losses                       %

    Project Area Profile
    Name of Project Area/Town
    District
    Total Area of Coverage
    Total Number of Consumers
    Total Population (as per 2001 census)

    Loan No. for IT Project under Part-A
    Date of Sanction of IT Project under Part-A
    Scheduled date of completion of Part-A Project
    Location of Data Centre
    Name of Part B Consultant (if any)
    Project Cost                                     Rs. Cr
    Scheduled date of completion (Part-B Project)
    Energy Input(08-09)                              M Units
    AT&C Losses {Assessed for Base Year-(09-10)}     %

    Status of Pre-Conditions
    Approval of Distribution Reforms Committee       Yes/No
    Constitution of SERC                             Yes/No
    Completion/Short closure of X Plan               Yes/No
    Schedule Date of completion of Ring Fencing      Date




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                                                                                                                                                        Submission of DPR for Part-B




        Project Funding

        Recommended Project Cost for Sanction                      Rs. Cr


                                Cost Item                                           Total Cost     GoI (25%) PFC/ FIs       Utility

        Total Setup Cost                                           Rs.Cr

                                                                                   Base Year-0       Year-1     Year-2      Year-3      Year-4     Year-5   Year-6
        Phasing of Capital Expenditure                             Rs.Cr
        Civil works costs will be allwed on an extent as deemed fit by Nodal Agency. For example, work like renovation of sub-station
Note:
        building, installation of meters etc. will not funded under the programme.
        Release of funds will be restricted to 36 months from the date of sanction of project under Part-B


        Project Benefits
        Financial Benefits

                                                                                   Base Year-0       Year-1     Year-2      Year-3      Year-4     Year-5   Year-6
        AT&C Losses                                                      %


        Internal Rate of Return (IRR)                                    %

        Payaback Period                                                 No.              0

Note: The detailed working on cost benefit analysis is provided in Volume V.b




        Other Benefits
        Establishment of base-line data system under Part-A is an outcome in itself. Establishment of baseline data is expected to
        result the following:
        - Accurate & reliable energy accounts on sustainable basis.
        - Accurate segregation & identification of loss making pockets.
        - Better accountability at all level.- Prompt and effective solution to the consumers queries / grievances
        - Increase empowerment of consumers
        - Consumer satisfaction indices can be effectively tracked / monitored.
        - Improve the reliability and quality of the power supply.
        - Improvement in network planning based on load flow study.

        Adherence to Standards
        Quality Management System                                  Utility shall follow standards as cited in Annexure-D for ensuring quality of work

        Procurement Procedures                                     Utility shall follow procurment standards/guidelines as cited in Annexure-E




                                                                                      Page 8                                               7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
                                                                                            Submission of DPR for Part-B


POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Volume I: Introduction
1.1 Background
The Ministry of Power, Government of India initiated Power Sector reforms in the 1990s to invite private
investments for setting up additional generating capacity to bridge the wide gap between demand and supply.
Numerous investors, both Indian and foreign, came forward to set up new generating capacity but little progress
could be achieved due to serious inefficiencies and losses in the electricity distribution business in almost all
states of the country.

Government of India (GOI) initiated reforms in the distribution sector in 2000. Distribution sector provides the
last mile connectivity for power supply and deals with large number of consumers. As a part of distribution
reforms, GOI launched APDP (Accelerated Power Development Program) in 2001 which was later rechristened
as APDRP (Accelerated Power Development and Reforms Program) during the 10th Five Year Plan.

To continue the support to distribution reforms during the 11th Five Tear Plan, GOI has reintroduced R-APDRP
(Restructured APDRP) with revised terms and conditions. The R-APDRP primarily aims at reducing Aggregate
Technical and Commercial (AT&C) losses in urban areas. It is a necessary condition of the scheme that the
utilities would need to demonstrate performance improvement for availing financial benefits provided under the
scheme. This would require collection of accurate data and measurement of loss reduction performance. Data
integrity and performance measurement pose many challenges for the state power utilities. This problem can be
surmounted only by: (i) setting up reliable and “no manual touch” systems for data collection; and (ii) adoption of
Information Technology in the areas of energy accounting.

IT based systems and solutions that measure the loss levels reliably will be essential before regular distribution
strengthening projects are implemented under the next phase of R-APDRP. Once the benefits of the investments
can be measured, the investments would justify themselves.

Projects under the R-APDRP program shall be taken up in Two Parts. Part-A shall include the projects for
establishment of baseline data and IT applications for energy accounting/ auditing & IT based consumer service
centres. Part-B shall include regular distribution strengthening projects.

The R-APDRP program will cover urban areas – towns and cities with population of more than 30,000 (10,000
incase of special category states).
MOP, GOI has appointed Power Finance Corporation as the Nodal Agency for implementing this program.




1.2 Objective of the Project
[Narrate paragraph about objective of the project being proposed in this DPR
including broad scope and coverage of the area etc.]




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                                                                                                                                           Submission of DPR for Part-B



POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Volume II: General Detail


2.1 General Utility Details                                                <<S imilar to Part-A>>
2.2.1 Basic Information
                          Particular                                          Details
      State
      Name of Utility (Expanded Name)
      Name of Utility (Short Name)
      Date of Incorporation
      Contact Details (Utility Nodal Officer)
                                              Designation
                                                  Address
                                            Phone Office 1
                                               Mobile No.
                                                      Fax
                                                   E-mail
      Other Information
      Total Number of consumers

2.2.4 Financial/ Commercial Information
                         Particulars                                                 Previous FY-1            Previous FY-2     Previous FY-3
                                                                                      FY( 10-09)               FY( 09-08)        FY (08-07)
      Peak Demand (Met)                                      MW
      Peak Demand (Unrestricted)                             MW
                         Energy Input                        MU
      Metered Energy Sales                                   MU
      Assessed Energy                                        MU
                      Total Energy Billed                    MU
      Revenue Billed                                         Rs. Cr.
      Revenue collected                                      Rs. Cr.
      Billing Efficiency                                     %
      Collection Efficiency                                  %
      AT&C Losses                                            %

2.2.7 List of the Towns in Distribution Utility
      'Location of Data Center #
      List of the Towns selected by [ name of the Utility] for implementation of Part A of R-APDRP is mentioned below
       List of all Project Areas (Towns) planned to be Population as per                                     Status of Part-A, Location of Data Status of Part-B,
                                                                              Status of APDRP X Plan
                   covered under R-APDRP                 2001 census                                        R-APDRP XI Plan       Center #      R-APDRP XI Plan


      Sarni Town
      Town 2
      Town 3
      Town 4
      Town 5
      Town 6
      Town 7
      Town 8
      Town 9
      Town 10
      Town 11
      Town 12
      ……..
      # Tick against the Town Name where data center is
      located




                                                                           Page 10                                            7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
                                                                                                                   Submission of DPR for Part-B



POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Volume III: Project Area Details


3.1 Project Area
     MPMKVVCL has decided to include this town for funding under R-APDRP. The DPR has been prepared for AT&C
     loss reduction upto 15% , enhancement of system reliability, increased quality of supply, improved customer
     satisfaction etc. along with common requirements and services for covering the entire APDRP Scheme coverage
     area for -------------Town. The details of the project area are placed below:




                                                                    <<S imilar to Part-A>>
3.1.1 Basic Information
                         Particular                        Unit                  Details
      Name of the Project Area
      District
      Nearest Railway Station
      Nearest Functional Airport
      Total Number of Consumers
      Total Population (as per 2001 census)
      Total Area of Coverage
      Point of Contact (Town Incharge)
                                         Designation
                                              Address
                                      Phone Office 1
                                         Mobile No.
                                                Fax
                                             E-mail
      Status of Part A, R-APDRP
      Loan No.
      Date of Sanction of Part-A DPR
      Select option from drop down indicating status
      of the Part-A in Project Area




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                                                                                                       Submission of DPR for Part-B




3.1.2 Asset Information
                                                              <<S imilar to Part-A>>
                                                               Details submitted with the Part
                        Assets**                                                               Current Position
                                                                           A DPR
     Total Number of EHV Sub-stations feeding the   Numbers
     Total Number of EHV Transformers               Numbers
     Total Capacity of EHV Transformers             MVA

     Total Number 66/33 kV Feeders                  Numbers
     Total Length of 66/33 kV Feeders (Overhead)    kM
     Total Length of 66/33 kV Feeders (Under-
                                                    kM
     ground)

     Total Number of 66/11 kV and 33/11 kV Sub-
                                                    Numbers
     stations feeding the Project Area
     Total Number of Power Transformers             Numbers
     Total Capacity of Power Transformers           MVA

     Total Number 11 kV Feeders                     Numbers
     Number of Metered 11 kV Feeders                Numbers
     Total Length of 11 kV Feeders (Overhead)       kM
     Total Length of 11 kV Feeders (Under-ground)   kM

     Total Length of LT Lines (Overhead)            kM
     Total Length of LT Lines (Under-ground)        kM
     Total Number of Distribution Transformers      Numbers
     Total Capacity of Distribution Transformers    mVA

     Total Number of Energy Import Points for the
                                                    Numbers
     Project Area
     Total Number of Energy Export Points for the
                                                    Numbers
     Project Area

     Total Annual (T-1) Energy Input                MUs
     Peak Demand                                    MW
     Average Demand                                 MW

     Project area already has SCADA/DMS in place
     (Yes/No)
     **Detailed asset information is the part of
     Annexure B
3.1.3 Commercial Information
                                                              <<S imilar to Part-A>>
                                                                                              Previous FY-2 (09- Previous FY-3
                       Particulars                                  Previous FY-1(10-09)
                                                                                                     08)            (08-07)
     Peak Demand (Met)                              MW
     Peak Demand (Unrestricted)                     MW
                        Energy Input                MU
     Metered Energy Sales                           MU
     Assessed Energy                                MU
                    Total Energy Billed             MU
     Revenue Billed                                 Rs. Cr.
     Revenue collected                              Rs. Cr.
     Billing Efficiency                             %
     Collection Efficiency                          %
     AT&C Losses                                    %
     DT Failure rate (Yearly)                       %




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                                                                                                   Submission of DPR for Part-B




POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Volume III: Scope of Work


3.2 Scope of Work
             Write-up on system strenthening and other works to be covered in
             the Project along with need and justification
             (Utility shall submit a report of detailed study along with
             survey report to bring down the AT&C loss of project area
             from present level to 15%. This shall be inclusive of all
             proposed works along with justification for the same)



3.2.1     Sub Transmission System Improvement Work
          [Brief Writeup]

3.2.1.1   66/11 or 33/11 KV SS : New/Augumentation
          The works can be of following nature:-
          - Extension of Bays
          - Capacity Augumentation of existing power transfomers
          - Installation of additional Transformer
          - Installation of remote switchable breaker/switches
          - Installation of Intelligent Electronic Devices which can interact with SCADA systems
          - Associated Civil Works
          - Any other work that can lead to loss reduction.




3.2.1.2   66 or 33 KV Line : New Feeder/ Feeder Bifurcation/Augumentation
          [Brief Writeup]
           The works can be of following nature:-
           - Installation of new feeder
           - Augumentation of Conductors
           - Installation of remote communicable FPIs ( O/C,E/F)
           - Installation of remote switchable breaker/switches
          [Brief Writeup]
           - Associated Civil Works
           - Any other work that can lead to loss reduction




3.2.1.3   11 kV Line : New Feeder/ Feeder Bifurcation

          The works can be of following nature:-
          - Installation of automated RMUs alongwith aux power supply to operate sw/breaker -
          - Installation of remote communicable FPIs ( O/C,E/F)
          - Installation of remote switchable breakers
          - Installation of new feeder
          - Augumentation of Conductors
          - Feeder Bifurcation (with proper justification)
          - Associated Civil Works
          - Any other work that can lead to loss reduction




          [Brief write up]




                                                                         Page 13                           Draft DPR Part B v2
                                                                             Submission of DPR for Part-B




3.2.1.4   Distribution Transformer: Capacity Augumentation/ New Transfomer

              The works can be of following nature:-
              - Installation of remote switchable breakers
              - Capacity Augumentation
              - Installation of New Transformers
              - Associated Civil Works
              - Any other work that can lead to loss reduction




3.2.1.5   LT Line : New Feeder/ Feeder Bifurcation


          The works can be of following nature:-
          - Installation of new LT feeders
          - Augumentation of Conductors
          - Associated Civil Works
          - Any other work that can lead to loss reduction
          [Brief write up]


3.2.1.6   Capacitor Bank
          - Installation of remote switchable breakers
          - Capacity Augumentation
          - Associated Civil Works




3.2.1.7   Aerial Bunched Cables

          .




3.2.2     HVDS




3.2.3     Consumer Metering




3.2.4     Mobile Service Centre



3.2.5     Other
                 write-up]
          [Brief write up]




                                                                 Page 14             Draft DPR Part B v2
POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Volume III: Project Area case study findings



          The AT&C loss of the project area (Name of town) is quite high due to high technical & commercial losses, the same shall be
          brought down by implementing following measures:

          (Below mentioned list is of illustrative nature. This can be altered depending upon utility's requirement)

          i) Reason of high technical losses & Measures proposed for improvement

                                                                                                                       Proposed benefit
          S. No.     Reason                               Loss location/ segment                   Proposed measure
                                                                                                                       in MU
              1      Overloading of following 33 KV feeders-


              2      Overloading of following Power Transformers-


              3      Overloading of following 11 KV feeder lines-


              4      Poor Voltage Regulation due to long 11 KV lines


              5      Overloading of following


                   6 Low Power Factor at
              7      Overloading of following LT
                     lines-
              8      Long length of following LT lines-




              9      Poor condition of following 11
                     KV lines


              10     Poor condition of following LT
                     lines


              11     Poor efficiency of following
                     Distribution Transformers


              12     Low HT/LT ratio




              13     Any other field found necessary
                     by utility




          ii) Reason of high Commercial losses & Measures proposed for improvement
                                                                                            Proposed benefit
S. No.               Reason                Loss location/ segment   Proposed measure
                                                                                            in MU
  1      Hooking / Direct tapping from                              Installation of AB
         following LT lines                                         cable

  2      Hooking / Direct tapping from                              Use of HVDS
         following LT lines
  3      Unmetered consumers billed                                 Metering of nos. of
         on assesment basis (category                               consumers
         wise)


  4      Defective consumer meters /                                Nos. of consumer
         Jam meters (Category wise)                                 Meter replacement
  5      Consumer Meter tampering/                                  Shifting of meters to
         bypassing                                                  outside premises




  6      Meters Erroneous/ wrong                                    Vigilance checking
         reading




  7      Any other field found necessary
         by utility
                                                                                      Submission of DPR for Part-B
POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Volume IV: SUMMARY Project Cost Estimate


4.1 Summary of Project Cost (Bill of Quantities)
Sl.                                                                                              Project Cost from
                                             Particular
No.                                                                                                    IVb*
                                                                                                     Rs. Lac

   A   Sub Transmission System Improvement Work
 A1    33/11 KV or 66/11 KV SS : New
 A2    33/11 KV or 66/11 KV SS : Additional Transformer
 A3    33/11 KV or 66/11 KV SS : Transformer capacity enhancement
 A4    New 33 KV feeders/Bifurcation
 A5    33 KV feeders Reconductoring/Augmentation
 A6 33/11 KV or 66/11 KV SS : Installation of remote switchable breaker/switches *

 A7 33 kV or 66 KV Line : Installation of remote switchable breaker/switches*

 A8 33 kV or 66 KV Line KV Line : Installation of remote commnuicable FPIs (O/C&E/F)*
A9 33 kV or 66 KV Line Bay Extension at EHV station
A10 11 kV Line : New Feeder/ Feeder Bifurcation
A11 11 kV Line : Reconductoring/Augmentation
    11 kV Line : Installation of automated RMUs alongwith aux power supply to operate
A12
    sw/breaker - *
A13 11 kV Line :- Installation of remote communicable FPIs ( O/C,E/F)*
    11 kV Line : Installation of remote switchable breakers alongwith aux power supply to
A14
    operate sw/breaker *
A15 11 KV Bay Extension
A16 Renovation & Modernisation of 33/11 kV SS
A17 Installation of Distribution Transformer
A18 Capacity enhancement of LT sub-station
    Installation of remote operable switches for breaker/switches operation for Distribution
A19
    Transformer alongwith aux power supply to operate sw/breaker *
A20 LT Line : New Feeder/ Feeder Bifurcation
A21 LT Line : Augmentation
A22 Capacitor Bank
    Installation of remote operable switches for breaker/switches operation for cap bank
A23
    alongwith aux power supply to operate sw/breaker *
A24 Aerial Bunched Cables

 B     HVDS

 C     Metering

 D     Mobile Service Centre

 E     Others

                                            Grand Total


       * For project area envisaged for SCADA/DMS scheme as per the criteria, town with
       population >=4lac & Input Energy >=350MUs & other potential towns
                                                Page 17                                 Draft DPR Part B v2
                                                                                                                                Submission of DPR for Part-B


POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Estimated Project Cost - Bill of Quantities

4.2    Works Cost Estimate/ Bill of Quantities
                                                                                    Unit   Quantity   Unit Price   Total Cost     Reference
                                    Item Details                                                       Rs. Lac      Rs. Lac      Annexure No.
  A    Sub Transmission System Improvement Work
  A1   33/11 KV or 66/11 KV SS : New
       Utility to provide list of work. Detail cost estimate of each work to
       be provided in Annexure


                                                                                                                           -
                                                                                                Sub Total                  -
  A2   33/11 KV or 66/11 KV SS : Additional Transformer
       Utility to provide list of work. Detail cost estimate of each work to
       be provided in Annexure
                                                                                                                           -
                                                                                                                           -
                                                                                                                           -
                                                                                                Sub Total                  -
  A3
       33/11 KV or 66/11 KV SS : Transformer capacity enhancement
       Utility to provide list of work. Detail cost estimate of each work to
       be provided in Annexure
                                                                                                                           -
                                                                                                                           -
                                                                                                                           -
                                                                                                Sub Total                  -
  A4   New 33 KV feeders/Bifurcation
       Utility to provide list of work. Detail cost estimate of each work to
       be provided in Annexure

                                                                                                Sub Total                  -
  A5   33 KV feeders Reconductoring/Augmentation
       Utility to provide list of work. Detail cost estimate of each work to
       be provided in Annexure




                                                                                                Sub Total                  -
  A6   33/11 KV or 66/11 KV SS : Installation of remote switchable
       breaker/switches *
       Utility to provide list of work. Detail cost estimate of each work to
       be provided in Annexure
                                                                                                                           -
                                                                                                Sub Total                  -
  A7   33 kV or 66 KV Line : Installation of remote switchable
       breaker/switches*
       Utility to provide list of work. Detail cost estimate of each work to
       be provided in Annexure
                                                                                                                           -
                                                                                                                           -
                                                                                                                           -
                                                                                                Sub Total                  -
  A8   33 kV or 66 KV Line KV Line : Installation of remote
       commnuicable FPIs (O/C&E/F)*
       Utility to provide list of work. Detail cost estimate of each work to
       be provided in Annexure
                                                                                                                           -




                                                                               Page 18                             7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
                                                                                                                               Submission of DPR for Part-B


                                                                                   Unit   Quantity   Unit Price   Total Cost     Reference
                                   Item Details                                                       Rs. Lac      Rs. Lac      Annexure No.
                                                                                               Sub Total                  -
A9    33 kV or 66 KV Line Bay Extension at EHV station
      Utility to provide list of work. Detail cost estimate of each work to
      be provided in Annexure
                                                                                                                          -
                                                                                               Sub Total                  -
A10 11 kV Line : New Feeder/ Feeder Bifurcation
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
    Existing 11kv feeders are proposed to be bifurcated




                                                                                               Sub Total                  -
A11 11 kV Line : Reconductoring/Augmentation
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure

                                                                                                                          -
                                                                                               Sub Total                  -
A12 11 kV Line : Installation of automated RMUs alongwith aux
    power supply to operate sw/breaker - *
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure



                                                                                               Sub Total                  -
A13 11 kV Line :- Installation of remote communicable FPIs (
    O/C,E/F)*
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                                                          -
                                                                                               Sub Total                  -
A14 11 kV Line : Installation of remote switchable breakers alongwith
    aux power supply to operate sw/breaker *
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                                                          -
                                                                                               Sub Total                  -
A15 11 KV Bay Extension
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                                                          -
                                                                                               Sub Total                  -
A16 Renovation & Modernisation of 33/11 kV SS
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure

                                                                                               Sub Total                  -
A17 Installation of Distribution Transformer
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure

                                                                                               Sub Total            #REF!
A18 Capacity enhancement of LT sub-station
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                                                          -
                                                                                                                          -
                                                                                                                          -
                                                                                               Sub Total                  -
A19 Installation of remote operable switches for breaker/switches
    operation for Distribution Transformer alongwith aux power
    supply to operate sw/breaker *



                                                                              Page 19                             7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
                                                                                                                               Submission of DPR for Part-B


                                                                                   Unit   Quantity   Unit Price   Total Cost     Reference
                                    Item Details                                                      Rs. Lac      Rs. Lac      Annexure No.
      Utility to provide list of work. Detail cost estimate of each work to
      be provided in Annexure
                                                                                                                          -
                                                                                                                          -
                                                                                                                          -
                                                                                               Sub Total                  -
A20 LT Line : New Feeder/ Feeder Bifurcation
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                                                          -
                                                                                                                          -
                                                                                                                          -
                                                                                               Sub Total                  -
A21 LT Line : Augmentation
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                                                          -
                                                                                               Sub Total                  -
A22 Capacitor Bank
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                               Sub Total                  -
A23 Installation of remote operable switches for breaker/switches
    operation for cap bank alongwith aux power supply to operate
    sw/breaker *
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                                                          -
                                                                                                                          -
                                                                                                                          -
                                                                                               Sub Total                  -
A24 Aerial Bunched Cables
    Utility to provide list of work. Detail cost estimate of each work to
    be provided in Annexure
                                                                                               Sub Total
 B    HVDS
      Utility to provide list of work. Detail cost estimate of each work to
      be provided in Annexure

                                                                                               Sub Total            #REF!
 C    Metering
      Utility to provide list of work. Detail cost estimate of each work to
      be provided in Annexure
                                                                                               Sub Total                  -
 D    Mobile Service Centre
      Utility to provide list of work. Detail cost estimate of each work to
      be provided in Annexure
      Please provide brief details of the work.Detail Cost Estimates to be                                                -
                                                                                                                          -
                                                                                               Sub Total                  -
 E    Others
      Utility to provide list of work. Detail cost estimate of each work to
      be provided in Annexure
                                                                                               Sub Total                  -

                                                                                       Grand Total
     * For project area envisaged for SCADA/DMS scheme as per the criteria, town with population
     >=4lac & Input Energy >=350MUs & other potential towns
Note Unit price and Total Cost are inclusive of all taxes and duties
     The scheduled unit rates to be provided as basis
     Under each sub-head (A1,A2,etc.) additional rows may be added for more items
     Cost of Erection, testing, commissioning may be included under respective sub heads, if applicable
     Cost of Land is not eligible for funding under R-APDRP
     Civil works costs will be allowed on an extent as deemed fit by Nodal Agency. For example, work like renovation of sub-station
     building, installation of meters etc. will not be funded under the programme.


                                                                              Page 20                             7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
                                                                                                                    Submission of DPR for Part-B


POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Volume V: Expected Project Benefit
5.1 Project Benefit (AT&C Losses)
                                                                                      Assessment of
                                                                                        Existing
                            For the Project Area                              Unit
                                                                                       Losses for
                                                                                       Base Year
     Energy Input(08-09)                                                  M Units
     Energy Sales                                                         M Units
     Total Revenue Billed                                                 Rs. Lac
     Total Revenue Collected (including arrears)                          Rs. Lac
     Arrears    {Actual or Total Revenue collected-Revenue billed}        Rs. Lac

     Billing Efficiency                                                   %
     Collection Efficiency                                                %
     AT&C Losses (Assessed)                                               %

     It is envisged that with implementation of the project the AT&C Losses shall be reduced
     progressively as shown below
     Base Year                                                             %
     Year-1                                                                %
     Year-2                                                                %
     Year-3                                                                %
     Year-4                                                                %
     Year-5                                                                %
     Year-6                                                                %

                                                            Project IRR       0%
                                                         Payback Period       0.00




{Description of overall benefits of the project}Reduction in Transmission and distribution losses. Reduction in
commercial losses. Reduction of Voltage Regulation to permissible limits.( 33 KV to LT system). Meeting peak load
demand. Reduction in outages. Load growth considerations.

Expected Benefits from the Project
[Technical Loss Reduction]
Existing System:
Technical A.E.L in Existing System

Modified System:
Technical A.E.L in Modified System

Savings in Technical A.E.L



[                                                                                                                   [
[Other Benefits]




                                                               Page 21                               7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
                                                                                                                                          Submission of DPR for Part-B




POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Volume V: Expected Project Benefit


5.2 Cost Benefits Analysis
    Particulars                            Units                 Base Year               Year-1    Year-2      Year-3      Year-4      Year-5     Year-6

    Total Project Cost (Rs.)               INR Crores
    Project Cost (phasing)                 INR Crores

    Total Input (Units)                    MU

    AT&C Losses                            %

    Total Units for which revenue is
    realised                               MU

    Average Tariff                         (INR/Unit)

    Total Realisation                      INR Crores

    Incremental Benefit                    INR Crores

    Net Cash Flow

                                    IRR
                          Payback Period

    Note:-
    Only cells highlighted in yellow to be filled by utility
    The Input Units shall be assumed to be constant and shall be equal to input considered for base year
    The Average Tariff shall be assumed to be constant and shall be equal to tariff considered for base year. It can be calculated by computing
    weighted average of tariff of different consumer categories and no. of consumers




                                                                               Page 22                                     7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
                                                                                                                                                                                                                                        Submission of DPR for Part-B




POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Annexure A: Implementation Schedule

        Instructions
        Write "1" in the cell if activity is underprogress during the month otherwise leave blank



                                           Activity/ Sub Activity                                                                Q1              Q2             Q3              Q4                Q5                Q6
                                                                                                    Start Date   End Date
                                                                                                                            M1   M2   M3    M4   M5   M6   M7   M8   M9   M10   M11   M12   M13   M14   M15   M16   M17   M18




  1     Issue of NIT
  2     Award of Contract
 3.1    Supply of Material :33/11 KV SS or 66/11 kV New
 3.2    Supply of Material :33/11 kV or 66/11 kV SS Transformer
 3.3    Supply of Material :33/11 KV or 66/11 kV SS Augmentation
 3.4    Supply of Material :11 kV Feeder New
 3.5    Supply of Material :11 kV Feeder Bifurcation
 3.6    Supply of Material :11 kV Feeder Augumentation
 3.7    Supply of Material :Distribution Transformer New
 3.8    Supply of Material :Distribution Transformer Augumentation
 3.9    Supply of Material :LT Line New
3.10    Supply of Material :LT Augumentation
3.11    Supply of Material :Capacitor Banks
3.12    Supply of Material : Aerial Bunched Cables
3.13    Supply of Material : HVDS
3.14    Supply of Material : Consumer Metering
3.15    Supply of Material : Mobile Service Centre
3.16    Supply of Material : Others

 4.1    Installation and commissioning:33/11 KV SS or 66/11 kV SS New
 4.2    Installation and commissioning :33/11 KV SS or 66/11 kV SS Transformer
 4.3    Installation and commissioning: 33/11 KV SS or 66/11 kV SS KV SS Augment
 4.4    Installation and commissioning: :11 kV Feeder New
 4.5    Installation and commissioning: :11 kV Feeder Bifurcation
 4.6    Installation and commissioning::11 kV Feeder Augumentation
 4.7    Installation and commissioning: :Distribution Transformer New
 4.8    Installation and commissioning: :Distribution Transformer Augumentation
 4.9    Installation and commissioning: :LT Line New
4.10    Installation and commissioning: :LT Augumentation
4.11    Installation and commissioning: :Capacitor Banks
 4.12   Installation and commissioning: : Aerial Bunched Cables
 4.13   Installation and commissioning: : HVDS
 4.14   Installation and commissioning: : Consumer Metering
 4.15   Installation and commissioning: : Mobile Service Centre
 4.16   Installation and commissioning: : Others
  5     Acceptance / Performance test to the owners




                                                                                                                                  Page 23                                                                                  7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls
3.1.3)Capacity of DTR 11KV Feeder wise

Capacity of DTR in KVA
   25     50 63 100 150 160        200   250   300   315   500 Total Capacity   Name of 11KV Feeder
POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Annexure C: Single Line Diagrams

        Attach SLDs and Nodal Diagrams wherever necessary
POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Annexure D: Quality Management System

        Brief write up
POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Annexure E : Procurement Procedures/Guildelines

        Brief Write up
                                                                                                         Submission of DPR for Part-B
POWER FINANCE CORPORATION LTD.
Detail Project Report - Part B
Annexure-F: Check List



                     Check the following information required to be filled in the Formats

    Index
    Date of submission                                                          Yes/No

    Guidelines
    We have gone through the Guidelines of Part- B and confirm compliance of the
                                                                                 Yes/No
    same till the completion of the project

    Declaration Form
    Declaration Form has been read and signed by designated authority           Yes/No

    Volume I
    Stated objectives of the Project                                            Yes/No

    Volume II
    Name of the State                                                           Yes/No
    State Power Sector Information                                              Yes/No
    State Map                                                                   Yes/No
    Name of the Utility                                                         Yes/No
    Other basic information related to Utility                                  Yes/No
    Utility's Consumer Information                                              Yes/No
    Utility's Asset Information                                                 Yes/No
    Utility's key Commercial and Financial Information                          Yes/No
    Scope
    Organisational Setup

    Website Information                                                         Yes/No

    Volume III.a
    Basic information about project area                                        Yes/No
    Consumer Information                                                        Yes/No
    Asset Information                                                           Yes/No
    Commercial Information                                                      Yes/No

    Volume IV.a
    Bill of Quantities                                                          Yes/No

    Volume IV.a
    Project Summary                                                             Yes/No

    Volume V.a
    AT&C Loss Computaion- Filled in all the information asked in the Format     Yes/No

    Volume V.b
    Cost Benefit Analysis- Filled in all the information asked in the Format    Yes/No

    Annexure A
    Implementation Schedule completed and attached with the DPR                 Yes/No

    Annexure B
    Assets detail completed and attached with the DPR                           Yes/No

    Annexure C
    Whether hard copy of the SLDs are attached with the DPR?                    Yes/No
    Whether soft copy of the SLDs are attached with the DPR?                    Yes/No
    Whether hard copy of the Nodal Diagrams are attached with the DPR?          Yes/No
    Whether soft copy of the Nodal Diagrams are attached with the DPR?          Yes/No

    Annexure D
    Whether Standards for Quality Management Systems attached with DPR?

    Annexure D
    Whether Standard Procurement Procuredures/Guideline followed by utility
    attached with DPR?

    Annexure F
    Check List completed and attached with the DPR                              Yes/No




                                                                   Page 28                  7b60e4a7-e1c3-48a4-a95d-a1a9a7740ec7.xls

				
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