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Expected Revenue from Charges (ERC) & Tariff Formats


             Tariff Petition before KERC              ERC for FY2002              ERC for FY2003          

 

Proposed Electric Tariff for 2002-03  |  Tariff formats   |  Table of Contents 

 

 
  1. Expenses of KPTCL in FY02

The cost coverage of KPTCL has been deteriorating over the years and it has been depending on subsidy support from the GoK to meet its expenditure. The cost coverage, which was 85% in FY95, has deteriorated to 68% in FY01.

In FY02, the financial position of KPTCL has deteriorated with increased revenue deficit, primarily due to the following reasons:

  • Decrease in availability of cheap Hydel power on account of bad monsoon
  • Purchase of more power from IPPs and other states to meet the demand.

The expenses of KPTCL in FY02 are estimated at Rs 6622.33 Cr. without the 3% Return on NFA. Major component of this expense is the power purchase cost constituting almost 74% of the total expenditure. KPTCL in the following paragraphs has sought to explain the expenses for FY02 in detail.

  1. Power Purchase Procurement Plan & Costs

Currently, KPTCL is in a supply shortage situation and is unable to meet its unconstrained demand. The Power Procurement Plan for KPTCL in FY02 has been developed on an annual forecast of restrained demand and available supply to reflect the reality of load dispatch and demonstrate merit order procurement. The procurement of power and costs varies every month depending on the demand, availability of the stations and rainfall. KPTCL procures more from the relatively expensive IPPs stations during certain months, when the cheaper sources are not available, to match supply and demand in the state. The procurement plan is designed to average out the monthly variations and project an aggregate plan for FY02.

Similarly, the cost of procurement is not linear and depends on the magnitude of purchase in a month from different stations. The power procurement plan drawn up for KPTCL is based on the actual power drawal for the last 7 months and expected drawal in the next 5 months from various stations.

The station-wise procurement plan is determined by the following factors.

  • Provisions of the Power Purchase Agreements and relevant Government of India Notifications,
  • For Hydro stations, current status of generating machines, their performance and water level in the reservoirs,
  • Availability of generators, considering their maintenance schedules

The current application does not consider the impact of Availability Based Tariffs to KPTCL in the year FY02.

The cost of the power purchase has been determined on the basis of existing costs, PPAs and Government notifications. The escalation estimated for variable charges in certain stations for FY02 over FY01 is based on the actual escalation of costs in FY01 over FY00. KPCL has filed a petition before the Commission for revision of tariff for its existing stations. KPTCL has estimated the tariffs for various KPCL stations based on the existing power purchase costs from these stations. Any subsequent change in KPCL generation tariffs would affect the revenue requirement of KPTCL.

For FY02, the total energy procurement is 28,406 MU and cost is Rs 5029.83 Cr. The details of some of the major stations and the rates are enumerated below. The power purchase details have been submitted to the Commission in D-1 in the Tariff Filing Formats.

      1. Station Wise Power Procurement Plan and Cost
        1. KPCL Hydel
        2. In FY02, as seen from till date, is a poor monsoon year for Karnataka, with rains failing in catchments areas of reservoirs. The latest available data (as on 800 hrs on 19th November 2001) on reservoir levels shows a significantly worse position (Table 12) at all reservoirs compared to previous year.

          Table 12: Reservoir Details

          Reservoir

          Linganamakki

          Supa

          Mani

          2000-01 2001-02 2000-01 2001-02 2000-01 2001-02
          Level (ft)

          1812.90

          1789.15

          549.96

          537.89

          590.43

          587.62

          Equivalent Energy (MU)

          3958

          2145

          1979

          1230

          676

          550

          Inflow progressively from 1st June (Mcft)

          178519

          114174

          94830

          70981

          23870

          19614

          The water inflow into the major reservoirs has been substantially less in comparison to the corresponding period in previous year. Subsequently, the equivalent energy, which can be generated from the stations, is less than previous year.

          Power purchased from KPCL Hydel Stations for FY01 was 10397 MU at an average cost of 35.42 p/u. The power purchase cost was Rs 368.29 Cr. On account of poor monsoon and the existing reservoir levels, the expected power drawal from KPCL Hydel Stations has been estimated at 9054 MU in FY02. The weighted average cost is estimated at 46.14 p/u. The increase in the weighted average cost in FY02 over FY01 is due to the cost of Sharavathi Tail Race Project. The power purchase cost on account of KPCL Hydel Stations has been estimated at Rs 417.75 Cr.

          1. Sharavathi Complex
          2. The Sharavathi Complex consists of Linganamakki Dam Power House, Mahatma Gandhi Hydro Electric Project (VVNL), Sharavathi Generating Station and Sharavathi Tail Race Power Project. Linganamakki dam, the main storage dam across river Sharavathi is at the core of the project. Two diversion schemes channelise the water flow from the Chakra & Savehaklu streams into the Linganamakki reservoir to generate additional energy to the tune of 500 MU at the Linganamakki Dam Power House and the Sharavathi Generating Station.

            The installed capacity of this Sharavathi Hydel station is 1035 MW of 10 units each having a capacity of 103.5 MW. The annual generation at the station varies from 4200 MU to 5500 MU based on the inflow in a particular year. The annual generation in FY01 from Sharavathi Generating Station was 5161.66 MU. But due to failed monsoon, the expected availability from the station in FY02 is 4115 MU.

            The generation of stations at Linganamakki DPH (2*27.5 MW), Sharavathi TRP (4*60 MW) is matched with discharge from the Linganamakki Dam and local inflows. Due to reduced inflows, generation at these stations is expected to be lower than normal. The generation at Linganamakki DPH was 271.65 in FY01. The expected generation from this station in FY02 is 143 MU.

            3 units of Sharavathi TRP have already been commissioned until now. The generation at this station in FY01 was 41.53 MU. The expected generation from this station in FY02 is 419 MU.

            The cost of the power generated at each of the Hydel stations and the Government orders specifying the same have been detailed below (Table 13). The cost of power from these sources taken for tariff filing is the same.

            Table 13 Tariff Details of stations in Sharavathi Hydro Electric Project

            Hydel Project Tariff fixed (p/u)+ Royalty (p/u) GO No. & date Effective Date
            Sharavathi Generating Station 8.60+4.00=12.60 DE 216 EEB 92/8.6.93 Apr ’93
            Linganamakki Powerhouse 17.18+4.00=21.18 DE 216 EEB 92/8.6.93 Apr ’93
            Sharavathi Tail Race Project 269+4.00=273.00 Provisional Tariff Feb ’01
            Chakra 28.12+0.00=28.12 DE 216 EEB 92/8.6.93 Apr ’93
          3. Kalinadi Hydro-Electric Project
          4. The Kali Complex consists of Supa Dam Site Power House, Nagjhari Power House, Kodasalli and Kadra Power House. The Supa Dam across river Kali is the main storage reservoir for the complex. The upper Kaneri dam and water conductor system divert Kaneri River into the Supa reservoir. This combined water source is used to generate energy at the Supa dam powerhouse.

            The Bommanahalli dam situated 32 km downstream of Supa dam is the key component for the Nagjhari powerhouse. The discharge of Nagjhari is input to Kodasalli Power House and discharge of Kodasalli is input to Kadra Power House.

            The installed capacity at Supa is 100 MW (2*50 MW). The annual generation at this station in FY01 was 416.97 MU but on account of poor monsoon, the generation expected for FY02 is 355 MU.

            The installed capacity of Nagjhari Hydel station is 840 MW with 6 units having a capacity of 135 MW each. Two units have been upgraded to 150 MW. The annual generation from this station varies from 2000 – 3200 MU based on the inflow into the reservoir. The annual generation from this station in FY01 was 2536.77 MU. But in FY02 on account of poor inflow of water the availability is reduced to 2379 MU.

            The generation of stations at Kodasalli & Kadra is matched with discharge from the Supa dam and local inflows. Because of the reduced inflow the generation at Kodasalli (3*40 MW) & Kadra (3*50 MW) generating stations are expected to be 269 MU and 295 MU respectively in FY02. In FY01, the generation from these stations was 302.63 MU and 341.58 MU respectively.

            The tariff details of stations in Kalinadi Hydro-Electric Project have been detailed below (Table 14).

            Table 14: Tariff Details of stations in Kalinadi Hydro-Electric Project

            Hydel Project Tariff fixed (p/u)+ Royalty (p/u) GO No. & date Effective Date
            Nagjhari Powerhouse 31.60+4.00=35.60 DE 216 EEB 92/8.6.93 Apr ‘93
            Supa Powerhouse 31.60+4.00=35.60 DE 216 EEB 92/8.6.93 Apr ‘93
            Kadra 146.61+4.00=150.61 DE 147 EEB 96/27.7.96 Jun ‘97
            Kodasalli 118.67+4.00=122.67 Provisional Tariff Jun ‘98

            KPCL has been claiming 118.67 p/u plus royalty of 4 p/u for Kodasalli generating station, which has not been admitted by KPTCL. The rate is dependent on the finalization of PPA between KPCL and KPTCL. The rate proposed for the current tariff filing is 122.67 p/u subject to revision on finalization of the PPA.

          5. Varahi Hydro-Electric Project
          6. The Varahi Hydro-Electric project consists of Varahi Hydel Station and Mani Dam Power House. The installed capacity of Varahi Hydel station is 230 MW with 2 units of 115 MW each. The annual generation at Varahi Station varies from 700 – 1100 MU based on the inflow. The annual generation in FY01 was 1078.59 MU. In FY02, the expected generation at this station is 883 MU on account of poor monsoon.

            The Mani Dam Power House consists of 2 units of 4.5 MW each having an installed capacity of 9 MW. The generation from this source in FY01 was 52 MU. The expected generation in FY02 is 30 MU.

            The expected cost of these Hydel stations as per government orders taken for the tariff filing has been detailed below (Table 15):

            Table 15: Tariff Details of stations in Varahi Hydro-Electric Project

            Hydel Project Tariff fixed (p/u)+ Royalty (p/u) GO No. & date Effective Date
            Varahi Hydro-Electric Project 52.00+4.00=56.00 DE 216 EEB 92/8.6.93 Apr ‘93
            Mani Dam 52.00+0.00=52.00 DE 216 EEB 92/8.6.93 Apr ‘93
          7. Other Stations

          Karnataka Power Corporation Limited has other small Hydel stations from which KPTCL sources its power requirements. The expected generation from these sources and the cost of these generations are detailed below (Table 16)

          Table 16: Generation & Cost details of other KPCL Stations

          Hydel Project Generation in FY01 (MU) Expected Generation in FY02 (MU) Tariff (p/u)+ Royalty (p/u) GO No. & date Effective Date
          Bhadra Hydro Electric Project

          77.00

          66.00

          8.60+4.00=12.60 DE 216 EEB 92/8.6.93 Apr ’93
          Ghataprabha Hydro-Electric Project

          84.70

          79.00

          64.19+4.00=68.19 DE 216 EEB 92/8.6.93 Oct ’91
          Sirwar

          0.83

          0.02

          116.00 Provisional Tariff
          Mallapur & Others

          25.80

          21.00

          116.00 Provisional Tariff
          Bhadra RBC Powerhouse

          31.00

          0.00

          167.85+4.00=171.85 Provisional Tariff Mar ’98
          Kappadagudda W. F.

          4.94

          0.00

          300.98 Tariff based on MNES guidelines
          Kalmala P.H.

          0.56

          0.00

          120.00 Provisional Tariff
          Genekal

          0.56

          0.00

          116.00 Provisional Tariff
          Total
        3. KPCL Thermal - Raichur Thermal Power Station
        4. On account of meeting the increased power requirement of the state, KPCL embarked upon the construction of Raichur Thermal Power Station. The 1st stage consisting of 2 units of 210 MW each was successfully synchronized in 1985 and 1986 respectively.

          In the 2nd Stage, the third unit of 210 MW was synchronized in 1991.

          Currently 6 units of 210 MW each have been installed with a capacity of 1260 MW. The tariff paid to each unit varies depending upon the time of commissioning of the unit. The auxiliary consumption for the thermal power station has been estimated at 8.5% for tariff filing purposes.

          The details of the tariff notified by various Government orders for Units 1 to Units 4 have been detailed below in Table 17. The tariff for Unit 5 & 6 is being paid by KPTCL as per the Interim PPA signed between the parties.

          Table 17: RTPS Tariff details for 4 units

          Unit Tariff (p/u) GO No. & date Effective Date
          Units 1&2 93.74+FEC* DE 216 EEB 92/3.4.93 Apr ‘93
          Unit 3 115.00+FEC* DE 216 EEB 92/8.6.93 Oct ‘91
          Unit 4 230.00+FEC* DE 121 EEB 95/6.2.96 Sep ‘94

          The tariff estimated for the 6 units of RTPS may undergo a change following the finalization of the Thermal PPA between KPTCL and KPCL, which is currently under preparation. The generation at various units at RTPS and the cost details for the FY01 and estimated for FY02 are detailed below in Table 18.

          Table 18: RTPS Generation & Cost details for FY01 & FY02

          FY01 FY02
          Units Quantity (MU) Cost per unit (p/u) Power purchase cost (Rs Cr.) Quantity (MU) Cost per unit (p/u) Power purchase cost (Rs Cr.)
          Unit 1 & 2 2758 140.32 387.00 2743 143.38 393.30
          Unit 3 1319 164.00 216.23 1419 168.28 238.70
          Unit 4 1459 261.00 380.81 1404 265.47 372.90
          Unit 5 1331 226.22 301.15 1299 237.57 308.62
          Unit 6 1297 204.47 265.10 1512 249.90 377.83
          Total 189.91 201.90

          In FY01, power purchase cost was Rs 1550.30 Cr. for 8164 MU of power purchased at an average rate of 189.91 p/u. In FY02, the power purchase cost has been estimated at Rs 1691.35 Cr. for 8377 MU at an average rate of 201.90 p/u.

        5. Central Generating Stations
        6. KPTCL has a share in NTPC Southern Region station of Ramagundam and other stations like Neyveli Lignite Corporation, Kaiga Atomic Power Station and Madras Atomic Power Station. The energy available to KPTCL depends on the generation and share in the station in a month. The parameters of available capacity, forced outages, auxiliary consumption, spinning reserve and net energy available for Central Generating Stations as provided by SREB are taken into consideration for preparing the procurement plan.

          From the unallocated share of 15% in the Southern Grid, share of Karnataka varies from 20 – 25% every month.

          The power drawal from the Central Sector Generating Stations is through the PGCIL lines to all the states in the region. KPTCL pays a transmission charges to PGCIL for transmission of the CGS power. The transmission and other incidental charges for FY01 amounted to Rs 102.21 Cr.

          KPTCL power drawal from the CGS in FY01 was 5820.06 MU at an average cost of 175.80 p/u inclusive of the transmission and other incidental charges. In FY01, the power purchase cost from Central Generating Stations was Rs 1023.16 Cr. inclusive of the transmission and other incidental charges.

          In FY02, the transmission and other incidental charges have been estimated to be Rs 114.4 Cr. The increase of these charges over FY01 has been estimated similar to the rate of increase from FY00 to FY01.

          The cost of central sector power for Karnataka estimated in the following sections is inclusive of the transmission losses in PGCIL lines in the Southern Region. The losses in the PGCIL Transmission lines have been estimated to be 4% for FY02.

          1. Ramagundam, NTPC
          2. The installed capacity of Ramagundam Super Thermal Power Station is 2100 MW and the allocated share for Karnataka is 340 MW. The power purchased from Ramagundam in FY01 was 3117.14 MU at an average cost of 130.88 p/u amounting to Rs 407.97 Cr.

            In FY02, the power purchased from Ramagundam is estimated to be 3026 MU. The fixed charges has been estimated at Rs 160.5 Cr. and income tax payable is estimated at Rs 23.92 Cr. similar to the amount paid by KPTCL in FY01. The total fixed cost component amounts to Rs 184.42 Cr. The fixed cost has been estimated at 60.94 p/u.

            In FY02, the variable charge for the station is 37.66 p/u as per the Government notification. The fuel escalation charges for FY02 have been increased to 59.16 p/u from 47.2 p/u in FY01. The increase of these charges over FY01 has been estimated similar to the rate of increase from FY00 to FY01. The other components of the variable charges like incentives, air & water consent fee have been kept at FY01 levels. The total variable charges have been estimated at 101.64 p/u for FY02.

            In FY02, the power purchased from Ramagundam is estimated at an average cost of 162.59 p/u. The power purchase cost has been estimated to be Rs 492 Cr.

          3. Neyveli Lignite Corporation TS - I
          4. The NLC TS – 1 is a dedicated station for Tamilnadu. Karnataka does not have any share in this power station.

          5. Neyveli Lignite Corporation TS - II
          6. The Neyveli Thermal Power Station consists of 2 stages. The first stage comprises of 3 units of 210 MW each, out of which Karnataka has allocated share of 84 MW.

            In FY01, the power purchased from NLC (Neyveli – I) was 866.40 MU at an average cost of 143.31 p/u amounting to Rs 124.16 Cr.

            The variable cost estimated for FY02 is 5% higher than the variable cost in FY01. In FY02, the drawal from NLC (Neyveli – I) is estimated to be 850.46 MU at a cost of 150.46 p/u. The power purchase cost has been estimated to be Rs 127.96 Cr.

            In the Second Stage of the project, 4 units of 210 MW each were installed. The allocated share of Karnataka is 115 MW from the installed capacity of 840 MW.

            The power purchase from NLC (Neyveli – II) in FY01 was 1023.17 MU at an average cost of 186.91 p/u amounting to Rs 191.24 Cr.

            The variable cost estimated for FY02 is 5% higher than the variable cost in FY01. In FY02, the power purchase from NLC (Neyveli – II) is estimated to be 1078 MU at a cost of 201.60 p/u amounting to Rs 217.30 Cr.

          7. Madras Atomic Power Station (MAPS), Kalpakkam
          8. There are 2 units of 170 MW each. The allocated share of Karnataka is 21 MW only. The power purchase from MAPS in FY01 was 451.61 MU at an average cost of 202.98 p/u amounting to Rs 91.67 Cr.

            In FY02, the drawal from MAPS is estimated to be 319 MU at a cost of 221.53 p/u amounting to Rs 70.67 Cr. The increase of these charges over FY01 has been estimated similar to the rate of increase from FY00 to FY01.

          9. Kaiga Atomic Power Station

          There are 2 units of 220 MW each and the allocated share of Karnataka is 108 MW. The power purchase from KAPS in FY01 was 361.74 MU at an average cost of 292.78 amounting to Rs 105.91 Cr.

          In FY02, the drawal from KAPS is estimated to be 646 MU at a cost of 307.42 p/u amounting to Rs 198.6 Cr. The increase of these charges over FY01 has been estimated similar to the rate of increase from FY00 to FY01 (Table 19).

          Table 19: Central Sector Stations Details

          FY01 FY02
          Stations Quantity (MU) Rate (p/u) Cost (Rs Cr.) Quantity (MU) Rate (p/u) Cost (Rs Cr.)
          Ramagundam

          3117.00

          130.88

          407.97

          3026.00

          162.59

          491.99

          Neyveli – I

          866.40

          143.31

          124.16

          850.46

          150.46

          127.96

          Neyveli – II

          1023.17

          186.91

          191.24

          1078.00

          201.60

          217.32

          MAPS

          451.61

          202.98

          91.67

          319.00

          221.53

          70.67

          KAPS

          361.74

          292.78

          105.91

          646.00

          307.42

          198.59

          Transmission Charges

          102.21

          114.41

          Total

          175.80

          206.26

        7. Other States
        8. In FY01, KPTCL had drawn power from various states like Maharashtra State Electricity Board, Western Region Electricity Board, Eastern Region Electricity Boards, etc. The total power purchased was 800.70 MU at an average cost of 195.56 p/u. The total power purchase cost from other states amounted to Rs 156.59 Cr. in FY01.

          In FY02, KPTCL to meet its requirement of power has drawn up power procurement plans from other states. It has planned to source power from Eastern Region and Power Trading Corporation. The total drawal pf power from these sources is estimated to be 1145 MU. The power purchase cost from these sources is estimated to be Rs 292.40 Cr.

          1. Eastern Region
          2. CEA has allotted 500 MW of surplus power in Eastern Region to Southern Region and there is HVDC transmission link between Jeypore in Orissa of Eastern region and Gazuwaka in AP of Southern region. KPTCL has a share of 21.2% and will be availing 80-100 MW depending upon its requirement and power flow in the system.

            In FY02, the drawal from Eastern region is estimated to be 730 MU at an average cost of 230 p/u. The power purchase cost has been estimated at Rs 167.90 Cr.

          3. Power Trading Corporation

          Due to failure of monsoon in FY02, KPTCL has signed a MOU with PTC to transfer surplus power of 100 MW from Western Region at a tariff of Rs 2.50 per unit at Chandrapur point in Western Region. The effective tariff for KPTCL with transmission losses and transmission charges to PGCIL is estimated at Rs 3.00 per unit.

          Depending upon the requirement, power purchase would be increased to 150 MW. In FY02, power purchase from PTC has been estimated at 415 MU. The power purchase cost for the power supplied by PTC amounts to Rs 124.50 Cr.

        9. IPPs
        10. Karnataka being a power shortage state has entered into PPAs with a number of IPPs for drawal of power. The power purchased from the IPPs in FY01 was 1230.85 MU at an average cost of 243.08 p/u. In FY01, the power purchase cost was Rs 299.20 Cr.

          In FY02, the power drawal from these IPPs has been estimated at 2492 MU. The power purchase cost has been estimated at Rs 885.01 Cr. at an average cost of 355.14 p/u. The fixed charges paid to IPPs in FY02 amounts to Rs 235.44 Cr and variable costs amounts to Rs 649.57 Cr.

          The details of station wise power generation and cost of power is enumerated below.

          1. Rayala Seema
          2. Sree Rayalaseema Alkalis and Allied Chemicals Ltd has established a LSHS/LFO DG power plant at Bellary. KPTCL has entered into a PPA with Rayalaseema to off take power amounting to 27.1 MW. The Commercial Operation Date (COD) for this station was declared on 22nd September 2000.

            In FY01, power drawal from Rayalaseema was 45.10 MU at an average cost of 376.92 p/u. The cost of power purchase from this IPP was Rs 17 Cr. in FY01. The drawl was necessary because of failure of the RTPS on 8th – 9th March 2001.

            In the FY02, the power drawal from Rayalaseema has been estimated at 179 MU.

            The fixed cost of this IPP has been estimated to be Rs 21.06 Cr. for the year FY02 as per the PPA. The fixed cost of this IPP amounts to 117.65 p/u in FY02.

            The variable cost of this IPP for FY02 has been estimated to be 292.82 p/u based on the variable cost for the month of June 2001. The cost of power purchase from this IPP in FY02 has been estimated at Rs 73.47 Cr at average tariff of 410.45 p/u.

          3. Jindal
          4. The installed capacity of the Corex based thermal plant is 2*130 MW, out of which 100 MW of power will be supplied to KPTCL for which a PPA has been initialed. The approval of the PPA is awaited from the Commission. The charges estimated in FY02 are as per the GoK order and the negotiated rate.

            In FY01, power drawal from JTPCL was 1179.76 MU at an average cost of 239.20 p/u. The cost of power purchase from this IPP was Rs 282.20 Cr. in FY01.

            The tariff is escalated at 5% every year. The effective start of the tariff period is month of August for this IPP. The tariff of JTPCL is 273-p/u upto power drawal of 657 MU per year beyond which the tariff reduces to 231 p/u. The power drawal by KPTCL has been estimated at 809 MU from this IPP for FY02. The effective tariff is estimated at 265.11 p/u. The cost of power purchase from this IPP in FY02 has been estimated at Rs 214.47 Cr.

          5. Tanir Bavi
          6. Tanir Bavi Power Company Ltd has established a 220 MW Naphtha Based Combined cycle power plant in Mangalore. The Commercial Operation Date (COD) for the simple cycle of 170 MW has been declared on 8th June 2001. The plant is expected to run in simple cycle for 170 days and in combined cycle for 127 days in FY02.

            KPTCL has estimated power purchase of 935 MU from Tanir Bavi in FY02.

            As per Lr. No. DE 27 PPC 97 dated 1st Dec. 2001 from the Principal Secretary to Govt., Energy Dept, the fixed cost to be paid by KPTCL to Tanir Bavi has been estimated at Rs 261.98 Cr. In the 21st meeting of Board of Directors of KPTCL held on 29th December 2001 it was decided to revise the rates for Tanir Bavi.

            In the variable charge calculations furnished by Tanir Bavi (reference RRM/KPTCL/01/510), the charges has been calculated to be 247.64 p/u. KPTCL has admitted the variable charge calculation submitted by Tanir Bavi.

            The cost of power purchase from this IPP in FY02 has been estimated at Rs 493.52 Cr at average tariff of 527.83 p/u.

          7. Tata

          Tata Power Company Ltd has established a 79.1 MW LSHS/LFO DG power plant at Belgaum. The Commercial Operation Date (COD) for this station was declared on 20th February 2001.

          KPTCL has estimated drawal of power to the tune of 569 MU from Tata in FY02.

          The fixed cost of this IPP has been estimated to be Rs 74.19 Cr. for the year FY02 as per the PPA. The fixed cost has been estimated at 130.39 p/u.

          The variable cost of this IPP has been estimated to be 265.62 p/u taking the average of the variable cost incurred in the months of April, May and June 2001.

          The cost of power purchase from this IPP has been estimated at Rs 225.33 Cr at an average tariff of 396.01 p/u.

        11. Non-conventional Energy Source Projects
        12. KPTCL has been purchasing power from Non-conventional energy sources like Co-generation power plants, Wind Electric farms, Biomass based projects and Mini-Hydel schemes. These plants are environment friendly and being nearer to load centers helps in improving voltage conditions and reducing T & D losses.

          In FY01, power purchase from these sources was 376.12 MU at an average cost of 301.80p/u. The power purchase cost from these sources was Rs 113.51 Cr.

          In FY02, power purchase from these sources has been estimated at 443.94 MU at an effective rate of 314.46 p/u, an escalation of 5% over FY01 rates. The power purchase cost from these sources is estimated at Rs 139.60 Cr.

        13. VVNL
        14. VVNL consists of 4 Hydel stations namely Shivasamudram generating station (42 MW), Shimshapura Generating Station (17.2 MW), Munirabad Generating Station (27 MW), Mahatma Gandhi Hydroelectric power station at Jog (120 MW) and 1 diesel power plant namely Yelahanka Diesel power plant.

          In FY01, power drawal from these stations amounted to 872.01 MU. The power purchase cost, which has been calculated assuming a tariff rate of 308 p/u, amounts to Rs 268.58 Cr.

          In FY02, the rate of power purchased from VVNL has been estimated at 276 p/u as per the MOU signed between KPTCL and VVNL on 31st October 2001.

          1. Yelahanka
          2. Yelahanka D.G. plant with an installed capacity of 127.92 MW LSHS fuel based plant.

            In FY01, power purchase from this station amounted to 639.08 MU. In FY02, the power purchase from this plant has been estimated at 719 MU.

          3. Hydel Stations

          In FY01, KPTCL purchased 232.93 MU of power from the Hydel stations of VVNL. In FY02, power drawal from these Hydel stations has been estimated at 223 MU.

        15. Other Stations (T. B. Dam)

        The T. B. Dam power is a shared power source between AP and Karnataka. The power purchased from this source by KPTCL in FY01 was 40.25 MU at an average cost of 22.11 p/u. In FY02, the power purchase from T. B. Dam has been estimated to be 32 MU. The procurement cost is estimated to be Rs 1 Cr.

      2. Summary of Power Procurement Plan
      3. KPTCL plans to procure 28406 MU of power from various sources in FY02 as shown in the Table 20 below

        Table 20: Power Procurement Plan for FY02

        Actual power drawal in FY01 Estimated power drawal in FY02
        KPCL Hydel

        10396.86

        9054.02

        KPCL Thermal (RTPS)

        8163.38

        8377.28

        Central Projects

        5820.06

        5919.46

        Other states

        800.70

        1145.00

        IPPs

        1230.85

        2492.00

        Non-conventional & Cogeneration

        376.12

        443.94

        VVNL

        872.01

        942.00

        T. B. Dam

        40.25

        32.00

        Total
      4. Summary of Power Purchase Cost

The cost of procuring 28406 MU of power would cost KPTCL Rs 5029.83 Cr. in FY02. The details of power purchase costs from major sources have been provided in the following Table 21. KPTCL pays fixed charges for Ramagundam Station (Rs 184.42 Cr.) and IPPs (Rs 357.23 Cr.). The fixed cost component has been estimated at Rs 541.65 Cr in FY02.

Table 21: Power purchase cost for KPTCL in FY01 and expected in FY02

 

Generators Power purchase cost in FY01 (Rs Cr.) Estimated power purchase cost in FY02 (Rs Cr.)
KPCL Hydel

368.29

417.75

KPCL Thermal (RTPS)

1550.30

1691.35

Central Projects

1023.16

1220.94

Other states

156.59

292.40

IPPs

299.20

1006.80

Non-conventional & Cogeneration

113.51

139.60

VVNL

268.58

259.99

T. B. Dam

0.89

1.00

Total
 

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