REGIONAL ENERGY ACCOUNT BASED ON AVAILABILITY BASED TYARIFF

REGIONAL ENERGY ACCOUNTBASED ON

AVAILABILITY BASED TYARIFF

T. SRINIVASMANAGER,SRLDC

BANGALORE

BRIEF ABOUT SR BRIEF ON ABT

REA

CONVENTIONAL REA

SCHEDULING

SOUTHERN REGIONAL GRID▀ Centre Generating Stations in the Region are

• RSTPS STAGE I & II : 2,100 MW (200x3 + 500x3)

• RSTPS STAGE III : 500 MW (500x1)

• NLC TPS2 STAGE I : 630 MW (210 x 3)

• NLC TPS2 STAGE II : 630 MW (210 x 3)

• Madras Atomic Power Station : 340 MW (170 x 2 )

• Kaiga Atomic Power Station : 440 MW (220x2)

• NLC EXPANSION TPS 1 : 420 MW (210X2)

• TALCHER STAGE II : 2000 MW (500X4) situated

in ER

SOUTHERN REGIONAL GRID

▀ Beneficiaries in southern Region are

• ANDHRA PRADESH• KARNATAKA• KERALA• TAMIL NADU• Union Territory of Pondicherry• NLCMINES• GOA has share of 100MW from RSTPS

SR STATES – POWER SYSTEM STATISTICSANDHRA PRADESH

INSTALLED CAPACITY – 8939.7 MW

MAX DEMAND MET – 8241 MW

DAILY CONSUMPTION MAX – 171 MU

DAILY CONSUMPTION AVG – 142 MU

CONSUMER PROFILE –

INDS -27%, DOM-22%, COMM-5%, IRRI-39% & OTHERS-7%

KARNATAKA

INSTALLED CAPACITY – 6177 MW






KERALA






INDS -34%, DOM-44%, COMM-13%, IRRI-2%& OTHERS-7%

TAMIL NADU







ANDHRA PRADESH

POPULATION :- 7.6 CRORES

AREA :- 275 (‘000 SQ KM)

NO OF CONSUMERS :- 162 LAKHS

PER CAPITA CONS. :- 719 UNITS

MAIN AGRICULTURE CROP :- RICE

CLIMATIC CONDITION :- HOT AND HOT & HUMID

SR STATES – GEOGRAPHYKARNATAKA


AREA :- 192 (‘000 SQ KM)



MAIN AGRICULTURE CROP :- COFFEE & RAGI


KERALA


AREA :- 39 (‘000 SQ KM)



MAIN AGRICULTURE CROP :- COCONUT & SPICES

CLIMATIC CONDITION :- HUMID

TAMIL NADU


AREA :- 130 (‘000 SQ KM)



MAIN AGRICULTURE CROP :- SUGAR CANE & OIL SEEDS


GROWTH OF INSTALLED CAPACITY OF SR

1947

5

1983

0

2030

4

2129

8

2213

3

2298

3

2417

3

2616

3 2850

1

2952

6 3273

3 3603

1

10000

15000

20000

25000

30000

35000

40000

1994-95 1995-96 1996-97 1997-98 1998-99 1999-00 2000-01 2001-02 2002-03 2003-04 2004-05 2005-06

YEARS - - ->

IN MW

INSTALLED CAPACITY IN SR

SUMMARY OF INSTALLED CAPACITY(MW)

AS ON 01.03.2006

AGENCY HYDRO THERMAL GAS/DIESEL WIND/OTHERS NUCLEAR TOTAL

ANDHRA PRADESH 3586.36 2962.5 272 2 --- 6822.86

KARNATAKA 3386.55 1470 127.8 4.55 --- 4988.9

KERALA 1831.1 --- 234.6 2.025 --- 2067.725

TAMILNADU 2137.35 2970 422.88 19.355 --- 5549.585

PONDICHERRY --- --- 32.5 --- --- 32.5

CENTRAL SECTOR --- 8090 359.58 --- 830 9279.58

IPP 278.13 387.01 2997.46 3627.2 0 7289.8

TOTAL11219 (31%)

15880 (44%) 4447 (12%) 3655 (10%) 830 (2%)

36031 (100%)

15880 (45%)

11219 (31%)830 (2%)

3655 (10%)

4447 (12%)

SOURCE-WISE INSTALLED CAPACITY OF SR

All Figures In MW

TOTAL 33,162 MW

HYDRO

THERMAL

WIND/OTHERS

NUCLEAR

GAS

RSTPS Stage I

& II

RSTPS Stage III

Talcher Stage II

NLC2 Stage I

NLC2

Stage II

NLC TPS1 Exp.

MAPS KGS FARAK

KAKAHALG

AONTALCH

ER

IC 2100 500 2000 630 840 420 340 440 1600 840 1000APTRANSCO 32.25 32.14 22.50 16.78 22.80 --- 9.34 --- --- --- --- 21.71

KPTCL 19.88 21.68 21.55 23.12 23.35 27.29 7.65 29.93 --- --- --- 21.09KSEB 14.74 15.77 23.00 11.63 12.32 18.53 6.27 13.12 --- --- --- 15.87TNEB 25.25 27.17 28.35 29.57 33.16 50.44 75.39 54.49 5.25 5.20 5.25 34.71

PONDY 3.01 3.24 4.40 10.96 2.42 3.74 1.35 2.46 --- --- --- 3.86GOA 4.76 --- --- --- --- --- --- --- --- --- --- 1.34

NLCMINES --- --- --- 7.94 5.95 --- --- --- --- --- --- 1.34PG HVDC 0.11 --- 0.20 --- --- --- --- --- --- --- --- 0.08

100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 5.25 5.20 5.25 100.00

ISGSWeighted Average

NTPC NLC NPC NTPC (ER)

% ALLOCATED CAPACITY SHARE OF BENEFICIARIES FROM ISGS AS PER GOI ORDER

MW ALLOCATED CAPACITY SHARE OF BENEFICIARIES FROM ISGS AS PER GOI ORDER

RSTPS Stage I &

II

RSTPS Stage III

Talcher Stage 2

NLC2 Stage 1

NLC2

Stage II

NLC TPS1 Exp.

MAPS KGS FARAK

KAKAHALG

AONTALCH

ER

IC 2100 500 2000 630 840 420 340 440 1600 840 1000APTRANSCO 677.25 160.70 450.00 105.71 191.52 --- 31.76 --- --- --- --- 1616.94

KPTCL 417.48 108.40 431.00 145.66 196.14 114.62 26.01 131.69 --- --- --- 1571.00KSEB 309.54 78.85 460.00 73.27 103.49 77.83 21.32 57.73 --- --- --- 1182.02TNEB 530.25 135.85 567.00 186.29 278.54 211.85 256.33 239.76 84.00 43.50 52.50 2585.87

PONDY 63.21 16.20 88.00 69.05 20.33 15.71 4.59 10.82 --- --- --- 287.91GOA 99.96 --- --- --- --- --- --- --- --- --- --- 99.96

NLCMINES --- --- --- 50.02 49.98 --- --- --- --- --- --- 100.00PG HVDC 2.31 --- 4.00 --- --- --- --- --- --- --- --- 6.31

2100.00 500.00 2000.00 630.00 840.00 420.00 340.00 440.00 84.00 43.50 52.50 7450.00

NPC NTPC (ER)

ISGSTOTAL

MW

NTPC NLC

NUCLEAR STATION

KHAMMAM

VIJAYAWADAN’SAGAR

GAZUWAKA HYDERABAD

RAICHUR

GOOTY

BANGALORE

SALEM

UDUMALPET

TRICHUR

MADURAI

TRICHY

MADRAS

NEYVELI

GUTTUR

KAIGA

RSTPP

BHADRAVATI

`HOODY

MUNIRABAD

P

P

P

P

P

P

P

PP

P

P

N

KOLAR

TALCHER

JEYPORE

HOSUR

SSLMM

MMDP

THIRUVANANTHAPURAM

NELLORE

NELAMANGALA

KURNOOL

KALPAKKA

SIMHADRI

HIRIYURTALGUPPA

KADAPA

1000 MW HVDC BACK TO BACK LINK

2000 MW HVDC BIPOLE

500 KV HVDC LINE

400 KV LINE POWERGRID

400 KV LINE APTRANSCO

400 KV LINE KPTCL

400 KV LINE OPERATED AT 220 KV

THERMAL GENERATING STATION

NEYVELI TPS – 1 (EXP)

400KV SUB-STATION

NARENDRA

MAHABOOB NAGAR

CHITTOOR

VEMAGIRI

GVKGMR

MAPS

SRLDC, BANGALORE

MARCH 2006

CONTROL AREAS

REGIONAL GRID

SEB’S GRID

CS -3CS - 2

CS - 1

CENTRALSHARE

STATEGENR

STATEIPP

DISTR-B

DISTR- A

DISTR- C

SEB - A SEB -CSEB -B

SLDCCOORDINATESDIRECTS

RLDCCOORDINATES

CONVENTIONAL METHOD OF OPERATION

• SHARE BASED ON ACTUAL GENERATION:-

– DOES NOT REFLECT THE AVAILABILITY OF

ISGS –RATHER ITS EX-BUS GENERATION– IS FIXED AND TIME INVARIANT– INSENSITIVE TO CONSTRAINTS– DOES NOT ALLOW FOCUSED CHANGES

• SUB OPTIMAL UTILIZATION OF RESOURCES

CONVENTIONAL METHOD OF ENERGY ACCOUNTING

• PAYMENTS ARE MADE AS PER THE DRAWALS

• OVER AND UNDER DRAWALS - UNAVOIDABLE

• UNUTILISED RESOURCES ARE OFTEN BILLED.

• INFLEXIBLE – BILATERALS, SHORT TERM

CONTRACTS – NOT ALLOWED

ADVANTAGES OF SCHEDULING

• SCHEDULE REFLECTS BOTH –AVAILABILITY OF ISGS & REQUIREMENT OF CONSTITUENT

• FLEXIBILITY• TIME VARIANT - MIRRORS GRID BEHAVIOUR• SENSITIVE TO CONSTRAINTS• FOCUSED – SCHEDULE IS NON GENERIC• OPTIMAL UTILIZATION OF RESOURCES• ECONOMIC OPERATION• INDEPENDENT OF SETTLEMENT SYSTEM.

INDIAN ELECTRICITY GRID CODE (IEGC)

• CERC HAS ISSUED THE REVISED INDIAN ELECTRICITY GRID CODE (IEGC) on 29th DECEMBER 2005 WHICH WILL BE EFFECTIVE FROM 01st APRIL 2006.

C H A P T E R - 6 SCHEDULING & DESPATCHING CODE

SRLDC/Comml/IEGC/33

The Procedures to be adopted for scheduling of the inter-State generating stations (ISGS) and net drawals of concerned constituents on a daily basis with the modality of the flow of information between the ISGS/ RLDCs /beneficiaries of the Region.

The procedure for submission of capability declaration by each ISGS and submission of drawal schedule by each beneficiary is intended to enable RLDCs to prepare the dispatch schedule for each ISGS and drawal schedule for each beneficiary.

It also provides methodology of issuing real time dispatch/drawal instructions and rescheduling, if required, to ISGS and beneficiaries along with the commercial arrangement for the deviations from schedules, as well as, mechanism for reactive power pricing.

SCHEDULING & DESPATCHING CODE

SRLDC/Comml/IEGC/33

Demarcation of Responsibilities

1.0 The Regional grids shall be operated as loose power pools (with decentralized scheduling and dispatch), in which the States shall have full operational autonomy, and SLDCs shall have the total responsibility for

(i) Scheduling/dispatching their own generation (including generation of their embedded

licensees),

(ii) Regulating the demand of their customers (iii) Scheduling their drawal from the ISGS

(within their share in the respective plant’s expected capability)

(iv) Arranging any bilateral interchanges (v) Regulating their net drawal from the regional

grid


SRLDC/Comml/IEGC/33


2.0 The system of each State shall be treated and operated as anotional control area.

The algebraic summation of scheduled drawal from ISGS and any bilateral inter-change shall provide the drawal schedule of each

State, and this shall be determined in advance on daily basis.

While the States would generally be expected to regulate their generation and/or consumers’ load so as to maintain their actual drawal from the regional grid close to the above schedule, a tight control is not mandated.

The States may, at their discretion, deviate from the drawal schedule, as long as such deviations do not cause system parameters to deteriorate beyond permissible limits and/or do not lead to unacceptable line loading.


SRLDC/Comml/IEGC/33


3.0 The above flexibility has been proposed in view of the fact that all States do not have all requisite facilities for minute-to-minute on-line regulation of the actual net

drawal from the regional grid. Deviations from net drawal schedule are however, to be appropriately priced through the Unscheduled Interchange (UI) mechanism.

4.0 Provided that the States, through their SLDCs, shall always endeavour to restrict their net drawal from the grid to within their respective drawal schedules, whenever the system frequency is below 49.5 Hz. When the frequency falls below 49.0 Hz, requisite load shedding shall be carried out in the concerned State(s) to curtail the over-drawal.


SRLDC/Comml/IEGC/33


5.0 The SLDCs/STUs shall regularly carry out the necessary exercises regarding short-term and long-term demand estimation for their respective States, to enable them to plan in advance as to how they would meet their

consumers’ load without overdrawing from the grid.

6.0 The ISGS shall be responsible for power generation generally according to the daily schedules advised to them by the RLDC on the basis of the requisitions received from the SLDCs, and for proper operation and maintenance of their generating stations, such that these stations achieve the best possible long-term availability and economy.


SRLDC/Comml/IEGC/33


7.0 While the ISGS would normally be expected to generate power according to the daily schedules advised to them, it would not be mandatory to follow the schedules

tightly. In line with the flexibility allowed to the States, the ISGS may also deviate from the given schedules

depending on the plant and system conditions. In particular, they would be allowed / encouraged to generate beyond the given schedule under deficit

conditions. Deviations from the ex-power plant generation schedules shall, however, be appropriately priced through the UI mechanism.


SRLDC/Comml/IEGC/33


8.0 Provided that when the frequency is higher than 50.5 Hz, the actual net injection shall not exceed the scheduled dispatch for that time. Also,while the frequency is above 50.5 Hz, the ISGS may (at their discretion) back down without waiting for an advice from RLDC to restrict the frequency rise. When the frequency falls below 49.5 Hz, the generation at all ISGS (except those on peaking duty) shall be maximized, at least upto

the level which can be sustained, without waiting for an advise from RLDC.


SRLDC/Comml/IEGC/33


9.0 However, notwithstanding the above, the RLDC may direct the SLDCs/ISGS to increase/decrease their drawal/generation in case of contingencies e.g. overloading of lines/transformers, abnormal voltages,

threat to system security. Such directions shall immediately be acted upon. In case the situation does not call for very urgent action, and RLDC has some time for analysis, it shall be checked whether the situation has arisen due to deviations from schedules, or due to any power flows pursuant to short-term open access. These shall be got terminated first, in the above sequence, before an action which would affect the scheduled supplies from ISGS to the long term customers is initiated.


SRLDC/Comml/IEGC/33


10.0 For all outages of generation and transmission system, which may have an effect on the regional grid, all

constituents shall cooperate with each other and coordinate their actions through Operational Coordination Committee (OCC) for outages foreseen sufficiently in advance and through RLDC (in all other cases), as per procedures finalized separately by OCC. In particular, outages requiring restriction of ISGS generation and/or restriction of ISGS share which a beneficiary can receive (and which may have a commercial implication) shall be planned carefully to

achieve the best optimization.


SRLDC/Comml/IEGC/33


11.0 The regional constituents shall enter into separate joint/bilateral agreement(s) to identify the State’s shares in ISGS projects (based on the allocations by the Govt. of India, where applicable), scheduled drawal pattern, tariffs, payment terms etc. All such agreements shall be filed with the concerned RLDC(s) and RPC Secretariat, for being considered in scheduling and regional energy accounting. Any bilateral agreements between constituents for scheduled interchanges on long- term/short-term basis shall also specify the interchange schedule, which shall be duly filed in advance with the RLDC.


SRLDC/Comml/IEGC/33


12.0 All constituents should abide by the concept of frequency-linked load dispatch and pricing of deviations from schedule, i.e., unscheduled interchanges.

13.0 It shall be incumbent upon the ISGS to declare the plant capabilities faithfully, i.e., according to their best

assessment. In case, it is suspected that they have deliberately over/under declared the plant capability

contemplating to deviate from the schedules given on the basis of their capability declarations (and thus make money either as undue capacity charge or as the charge for deviations from schedule), the RLDC may ask

the ISGS to explain the situation with necessary backup data.


SRLDC/Comml/IEGC/33


14.0 The CTU shall install special energy meters on all inter connections between the regional constituents and

other identified points for recording of actual net MWh interchanges and MVArh drawals. The type of meters

to be installed, metering scheme, metering capability, testing and calibration requirements and the scheme for collection and dissemination of metered data are detailed in the enclosed Annexure-2. All concerned

entities (in whose premises the special energy meters are installed) shall fully cooperate with the CTU/RLDC and extend the necessary assistance by taking weekly meter readings and transmitting them to the RLDC.


SRLDC/Comml/IEGC/33


15.0 The RLDC shall be responsible for computation of actual net MWh injection of each ISGS and actual net drawal of each beneficiary, 15 minute-wise, based on the above meter readings and for preparation of the Regional Energy Accounts. All computations carried out by RLDC shall be open to all constituents for checking/ verifications for a period of 15 days. In case any mistake/omission is detected, the RLDC shall forthwith

make a complete check and rectify the same.

16.0 RLDC shall periodically review the actual deviation from the dispatch and net drawal schedules being issued, to check whether any of the constituents are indulging in unfair gaming or collusion.


SRLDC/Comml/IEGC/33


17.0 In case the State in which an ISGS is located has a predominant share in that ISGS, the concerned parties may mutually agree (for operational convenience) to assign the responsibility of scheduling of the ISGS to the state’s LDC. The role of the concerned RLDC, in such a case, shall be limited to consideration of the schedule for inter-state exchange of power on account of this ISGS while determining the net drawal schedules

of the respective states.

Scheduling And Despatching ProceedureOn Day-l

09 AM ISGSs advise foreseen plant-wise ex- . power plant MW, MWh * capability for next day

10 AM RLDC advises SEBs their MW, MWh* shares in foreseen ISGSs' availability

3 PM SLDCs furnish their ,time-wise MW requisition from the above, and schedule of bilateral exchanges, if any

5 PM RLDC issues' despatch schedules' for ISGSs and 'net drawal schedules' for SEBs, for each hour the next day starting at midnight

10 PM SLDCs may inform any change of the above or bilateral exchanges to RLDC, if required by any new development during the day

11 PM Schedules frozen for the next day. RLDC Issues final drawal schedules to each State & Despatch schedule to each ISGS

SRLDC/Comml/IEGC/41

Scheduling And Despatching ProceedureOn Day-0

SRLDC/Comml/IEGC/41

In case of forced outage of a unit, the RLDC shall revise theschedules on the basis of revised declared capability. The revised declared capability and the revised schedules shall become effective from the 4th time block, counting the time block in which the revision is advised by the ISGS to be the first one.In the event of bottleneck in evacuation of power due to any constraint, outage, failure or limitation in the transmission system, associated switchyard and sub- stations owned by the Central Transmission Utility or any other transmission licensee involved in interstate transmission (as certified by the RLDC) necessitating reduction in generation, the RLDC shall revise the schedules which shall become effective from the 4th time block, counting the time block in which the bottleneck in evacuation of power has taken place to be the first one. Also,during the first, second and third time blocks of such an event, the scheduled generation of the ISGS shall be deemed to have been revised to be equal to actual generation, and the scheduled drawals of the beneficiaries shall be deemed to have been revised to be equal to their actual drawals.


SRLDC/Comml/IEGC/41

In case of any grid disturbance, scheduled generation of all the ISGS and scheduled drawal of all the beneficiaries shall be deemed to have been revised to be equal to their actual generation/drawal for all the time blocks affected by the grid disturbance. Certification of grid disturbance and its duration shall be done by the RLDC.

Revision of declared capability by the ISGS(s) and requisition by beneficiary(ies) for the remaining period of the day shall also be permitted with advance notice. Revised schedules/ declared capability in such cases shall become effective from the 6th time block, counting the time block in which the request for revision has been received in the RLDC to be thefirst one.If, at any point of time, the RLDC observes that there is need for revision of the schedules in the interest of better system operation, it may do so on its own, and in such cases, the revised schedules shall become effective from the 4th time block, counting the time block in which the revised schedule is issued by the RLDC to be the first one.


SRLDC/Comml/IEGC/41

To discourage frivolous revisions, an RLDC may, at its sole discretion, refuse to accept schedule/capability changes of less than two (2) percent of the previous schedule/ capability.

On Day + 1

.

RLDC to issue before-the- fact Capacity Declaration/Schedules finally implemented by RLDC (Datum for accounting and working out average ex-power plant capability).

The procedure for scheduling and the final schedules issued by RLDC, shall be open to all constituents for any checking/verification, for a period of 5 days. In case any mistake/omission is detected, the RLDC shall forthwith make a complete check and rectify the same.

While availability declaration by ISGS may have a resolution of one (1) MW and one (1) MWh, all entitlements, requisitions and schedules shall be rounded off to the nearest decimal, to have a resolution of 0.1

MW.SRLDC/Comml/IEGC/42

SCHEDULING METHODOLOGY

The station-wise (Ex-bus) capability would be submitted by the ISGSs in the specified format. ISGSs would declare the capability i.e. the MW and MWH quantum in the absolute values and not in the form of some relative percentages or in any other manner.


Based on the declared capability & the allocations of different States / Beneficiaries in different ISGSs, the station wise entitlements would be worked out and intimated to all the States/Beneficiaries by SRLDC.


The requisitions would be submitted by the States in the specified format. The States would submit the requisitions indicating the quantum desired against the given entitlement, and not the quantum surrendered. The requisitions in case of nuclear and run of the river hydro stations would be equal to the entitlements.


The details of the despatch and drawal schedules and Unrequisitioned, surpluses shall be made by SRLDC and the information would be exchanged through fax and/or through FTP.


In the event of any unrequisitioned surpluses, the Owner State ( the State to which the share actually belongs and pays the capacity charges) may find out a suitable Buyer/ Willing State to take such unrequisitioned surplus and/or the Buyer/Willing State may contact the Owner State for such exchange. The agreed Short Term Open Access Transactions be intimated / consented to SRLDC by both the States for incorporating in the final schedules.


Any unrequisitioned surpluses still available, can be agreed for Short Term Open Access Transactions between the concerned ISGS and one or more desiring States. The agreed Short Term Open Access Transactions from ISGS to a State be intimated to SRLDC by both the agencies (ISGS as well as States) for incorporation in the final schedule.


During the current day in case the Owner State requisitions back its surrendered share, then the same is withdrawn from the other State/ States to which it was allocated as surplus energy and the schedules are revised in line with the Grid Code.


While making or revising their declaration of capability the generators shall ensure that the declared capability during peak hours is not less than during other hours.

SCHEDULING METHODOLOGY While communicating the requisitions, the States shall ensure that:

maximum economy and efficiency in the operation of the power system in the State is achieved while requisitioning and /or surrendering power from different ISGSs vis-à-vis from their own stations.

the requisitions are operationally reasonable, particularly in terms of ramping-up / ramping-down rates and ratio between minimum and maximum generation levels, and are in line with the agreed philosophy in the region amongst different agencies.


In the event of despatch schedule in respect of a particular ISGS, (as agreed between ISGS and the State constituents in respect of thermal units it would be taken as 70%) the changes in requisition between two successive blocks is higher than a ramp up/down quantum, then the State/States due to which such anomaly is being experienced would be requested by SRLDC to change its/their requisition in that particular ISGS, to make the schedule operationally reasonable.


While issuing the final schedules, SRLDC shall check that the schedules do not give rise to any transmission constraints. In case any imperssible constraints/ anomalies are foreseen, the RLDC shall moderate the schedules to the required extent , under intimation to the concerned agencies.


During the periods of low demand in the region, in spite of all efforts if the despatch schedule of an ISGS(s) during certain blocks in the off-peak period remains below the minimum agreed value, and the concerned ISGS (s) is not able to operate the units due to technical constraints, then the concerned ISGS(s) may close down some unit(s) in consultation with SRLDC and the despatch schedule of the ISGS(s) shall be revised accordingly. Under such a situation the net drawal schedule of the beneficiary (ies) having share in the ISGS(s), may get reduced during peak hours also.


If at any point of time SRLDC observes that there is need for revision of schedules in the interest of better system operation, it may do so on its own and make it effective in line with the grid code provisions.


While entering into a bilateral agreement, the concerned parties shall ensure that the agreements are clear and explicit and contains all the relevant details which may be necessary from scheduling and computation of energy flow.

Scheduling And Despatching ProceedureOn Day-l

09 AM ISGSs advise foreseen plant-wise ex- . power plant MW, MWh * capability for next day

10 AM RLDC advises SEBs their MW, MWh* shares in foreseen ISGSs' availability

3 PM SLDCs furnish their ,time-wise MW requisition from the above, and schedule of bilateral exchanges, if any

5 PM RLDC issues' despatch schedules' for ISGSs and 'net drawal schedules' for SEBs, for each hour the next day starting at midnight

10 PM SLDCs may inform any change of the above or bilateral exchanges to RLDC, if required by any new development during the day

11 PM Schedules frozen for the next day. RLDC Issues final drawal schedules to each State & Despatch schedule to each ISGS

SRLDC/Comml/IEGC/41


SRLDC/Comml/IEGC/41

In case of forced outage of a unit, the RLDC shall revise theschedules on the basis of revised declared capability. The revised declared capability and the revised schedules shall become effective from the 4th time block, counting the time block in which the revision is advised by the ISGS to be the first one.

Revision of declared capability by the ISGS(s) and requisition by beneficiary(ies) for the remaining period of the day shall also be permitted with advance notice. Revised schedules/ declared capability in such cases shall become effective from the 6th time block, counting the time block in which the request for revision has been received in the RLDC to be thefirst one.


SRLDC/Comml/IEGC/41

To discourage frivolous revisions, an RLDC may, at its sole discretion, refuse to accept schedule/capability changes of less than two (2) percent of the previous schedule/ capability.

On Day + 1

.

RLDC to issue before-the- fact Capacity Declaration/Schedules finally implemented by RLDC (Datum for accounting and working out average ex-power plant capability).

The procedure for scheduling and the final schedules issued by RLDC, shall be open to all constituents for any checking/verification, for a period of 5 days. In case any mistake/omission is detected, the RLDC shall forthwith make a complete check and rectify the same.

While availability declaration by ISGS may have a resolution of one (1) MW and one (1) MWh, all entitlements, requisitions and schedules shall be rounded off to the nearest decimal, to have a resolution of 0.1

MW.SRLDC/Comml/IEGC/42

METERING LOCATIONS IN SR

• Total No Of SEMS in SR USED FOR REA 350

No.s• Total No Of SEMS in KPTCL USED FOR REA

50 No.s

KAKINADA

PO 05

REA METERING LOCATION OF STATE OWNED INTER STATE LINES IN SOUTHERN REGION

HOSUR

HOSUR

YERANDAHALLY

2

20 KV .

YERANDAHALLY

2

20 KV .

MANJESWAR

UPPATI

KADAKOLA

KNYMPTTAKONEJA

ARAKU

BALIMELA

OS

AP

TN

KERKAR

GOA

LOW

ER

SIL

ER

U

BA

RS

UR

HVDC

KO

LLA

PU R

K'T

HA

RA

I

UD

UM

ALP

ET

KA

YA

TH

AR

TH

EN

I

BELLARY

TANDUR GOOTY

SEDAM

CH

IKK

OD

I

MO

OZ

HIY

AR

ED

MO

N

IDU

KK

I

PA

RA

SA

LA

MH

MP

220

KV

220

KV

220

KV

220

KV

220

KV

220

KV

110

KV

220

KV

132

KV

66 K

V

110

KV

220 KV

110 KV

AP57

AP55

AP56

OS 58

P0 06

TN 56

AP 54 TN 57

TN 54

TN51

TN52

TN53

TN58

KL52

KL53

KL51

TN 55

CK 54

CK 51

CK 52

KL 55

KL 56CK56

CK59

CK58

GO01

GO02

GO03

CK57

AP 58AP 52

CK 60

CK 61

CK 55

CK 53KL58

PONDY(Yanam)

132

KV 21

XELDEM

21

GO04

UPPERSILERU

PONDA

PONDA

AMBEWADI SUPA

MACHKHUNBALIMELA

AP 53CHITOOR TIRUVALEM

SULURPET

G'P

UN

DI

KOOTHAMUNDA

220 KV

220 KV

220 KV

220 KV

220 KV

132 KV

220

KV

110

KV

INTER STATE LINES METERING LOCATIONS

METERING LOCATIONS IN KPTCL'S INTERCONNECTED SYSTEM

AP-51CK-53

TANDUR

GOOTY

A PAP-52CK-55

BELLARY

SEDAM

TN-55CK-54HOSURYERANDAHALLI

T N

CK-22CK-21

CK-05CK-06

CK-03CK-04

BANGALORE

RAICHUR N'SAGAR

MBD

N'SAGAR

MBD

CENTRAL TR. SYSTEM

CK-51KL-55

KL-56 CK-52

KONAJE

KADAKOLA

MANJESWAR

KANIAMPETTA

KSEB

GO-03

GO-04

GO-01

GO-02AMBEWADI

XELDEMXELDEM

PONDA

PONDA

PONDA SUPA

GOA(SR)

KG-24

KG-23

KG-22

KG-21

KODASALLI

KADRA

SIRSI-2

SIRSI-1

KGS

CK-60

CK-61CHIKKODI

KolhapurWR/MSEB

CK-01CK-02

HOODY

SR-63

SR-64

BANGALORE

BANGALORE

CK-57CK-57

CK-58

CK-56

CK-57

KOLAR

220kV

220kV

220kV

110kV

110kV

220kV

220kV

220kV

220kV

220kV

220kV

220kV

220kV

400kV

220/400kV

220/400kV

220/400kV

CK-11CK-12

KOLARKOLAR

220/400kV

110kV

400kV

GOOTY

CK-21RAICHUR

4 5 6 7

CK-23

CK-05

CK-06

CK-24

CK-27

CK-25

SR-81

DAVANAGERE

CK-26

NELAMANGALA

CK-28

CK-09

CK-10

CK-30

CK-31

HOODY

CK-07

CK-08

CK-15

CK-16

HIRIYUR

CK-29

CK-32 CK-33

CK-13

CK-14

BANGALORE

SR-11

N'Sagar

Kolar

Munirabad

CK-35

CK-34

CK-36

CK-37

Temporary Configuration :Karnataka's drawl in Raichur-Hoody section:Raichur = -(CK-21) -(CK-23) -(CK-25); Muniarabd=(CK-05) ; Davanagere=(CK-07); Hiriyur=(CK-15); Nelamangala= -(CK-29)-(CK-30)-(CK-35) -(CK-36) -(CK-38);Hoody = (CK-09)+(CK-13)

CK-30

CK-31

CK-38

Karnataka's drawl in Raichur-Hoody section:

Raichur = -(CK-21) -(CK-23) -(CK-25);

Muniarabd=(CK-05) ;

Davanagere=(CK-07); Hiriyur=(CK-15);

Nelamangala= -(CK-29)-(CK-30)-(CK-35)

-(CK-36) -(CK-38);

Hoody = (CK-09)+(CK-13)

RAICHUR SECTION

KPTCL'S DRAWL ON 400kV RAICHUR-DAVANAGERE SECTION

(CK-RC)=-(CK-21)-(CK-23)-(CK-25) -(CK-29)-(CK-30)+ (CK-35)+ (CK-36) (CK-38) + (CK-05)+ (CK-07) +(CK-09) + (CK-13) + (CK-15)

KPTCL'S DRAWL ON 400kV

(CK-91)= (CK-01)+(CK-03)+(CK-RC) +(CK-11)

CK'S DRAWL ON 220kV

(CK-92)= -(CK-51)-(CK-53)-(CK-54)-(CK-55)-(CK-58)-(CK-59)+(KG-21)

+(KG-22)+(KG-23)+(KG-24)

CK'S DRAWL ON 132kV

(CK-93)=-(CK-52)-(CK-56)

TOTAL DRAWL (CK-94)=(CK-91)+(CK-92)+(CK-93)NOTE: SEMS ON FEEDERS NOT CARRYING ISGS POWER NOT TO BE CONSIDERED

Payment to Inter State Generating Stations (ISGS) from beneficiaries under

Availability Based Tariff (ABT)

Capacity chargesEnergy chargesUnscheduled Interchange (UI)

1000

900

800

700

600

500

400

300

200

100

0

0 2 4 6 8 10 12 14 16 18 20 22 24

Forecast ex-bus capability of Power Plant

Hours

MW

Net Injection Schedule

SEB - A's Requisition

SEB - A's Entitlement - (40%)

SCHEDULING

CAPACITY CHARGE

Capacity charge will be related to ‘availability’ of the generating station and the percentage capacity allocated to the state. ‘Availability’ for this purpose means the readiness of the generating station to deliver ex-bus output expressed as a percentage of its rated ex-bus output capability.

ENERGY CHARGE

Energy charges shall be worked out on the basis of a paise per kwh rate on ex-bus energy scheduled to be sent out from the generating station as per the following formula

Energy charges = Rate of energy charges

(paise/kwh) x Scheduled Generation (ex-bus MWh)

UNSCHEDULED INTERCHANGE (U I) :

Variation in actual generation / drawal with respect to scheduled generation / drawal shall be accounted for through Unscheduled Interchange (UI).

UI for generating station shall be equal to its total actual generation minus its scheduled generation.

UI for beneficiary shall be equal to its total actual drawal minus its total scheduled drawal.

UNSCHEDULED INTERCHANGE (U I) :

UI shall be worked out for each 15 minute time block.

Charges for all UI transactions shall be based on average frequency of the time block.

UI rates shall be frequency dependent and uniform throughout the country.

0

50

100

150

200

250

300

350

400

450

500

550

600

650

48.9 49 49.1 49.2 49.3 49.4 49.5 49.6 49.7 49.8 49.9 50 50.1 50.2 50.3 50.4 50.5 50.6 50.7 50.8 50.9 51

Frequency ----------->

UI ra

te

-----

------

------

>

Below 49.0 Hz UI rate =570 p/u

At 50.0 Hz UI rate =150 p/u

At 49.8 Hz UI rate =210 p/u

Above 50.5 Hz UI rate =0 p/u

UI RATE

Rate of Unscheduled Drawal/InjectionFrequency (Hz) Rate (p/u)

Above 50.5 0

50.0 150

49.8 210

49.0 and below 570

AVAILABILITY BASED TARIFF

(A) CAPACITY CHARGE

(B) ENERGY CHARGE

(C) ADJUSTMENT FOR DEVIATIONS

(U I CHARGE)

(A) = a function of the Ex-Bus MW availability of Power Plant for the day declared before the day starts x SEB’s % allocation from the plant

(B) = MWh for the day as per Ex-Bus drawal schedule for the SEB finalised before the day starts x Energy charge rate

(C) = Σ (Actual energy interchange in a 15 minute time block – scheduled energy interchange for the time block) x UI rate for the time block

TOTAL PAYMENT FOR THE DAY = (A) + (B) ± (C)

FEATURES :

(A) and (B) do not depend on actual plant generation / drawal. No metering required for this as they are based on off-line figures. All deviations taken care of by (C)

No complication regarding deemed generation.

Perpetual incentive for maximizing generation and reducing drawal during deficit, but no incentive to over generate during surplus.

Settlement System under ABT Regime

WHAT IS SETTLEMENT ?

• “ Settlement means Closing the payment/receipt/adjustment process of

bill for the period under consideration”• To be FAIR and EQUITABLE• To RECOVER DUES at the EARLIEST

(Billing Cycle)• TRANSPERANCY• Dispute Resolution• Reconciliation

Capacity charge:

Capacity charge is based on Annual Fixed Charge and will be related to availability of generating station. Availability means the readiness of the generating station to deliver ex-bus output expressed as a percentage of its rated ex-bus output capability.

Energy charge:

Energy charge is related to the scheduled ex-bus energy to be sent out from the generating station and will be worked out on the basis of paise per KWh.

AVAILABILITY TARIFF(ABT)(a) CAPACITY CHARGE(b) ENERGY CHARGE(c) ADJUSTMENT FOR DEVIATIONS

(UI CHARGE)

(a) = a function of Ex-bus MW availability of power plant for the day declared before the day starts x SEB’s % share

.(b) = MWh for the day as per ex=bus drawl schedule for the SEB

finalized before the day starts x Energy charge rate

(c) =Σ(Actual energy interchange in a 15 min time block – scheduled energy interchange for the time block) x UI rate for the time block.

TOTAL PAYMENT FOR THE DAY =(a) + (b)± ( c)

SETTLEMENT SYSTEMFor the day: 0000 hrs. to 2400 hrs.

Central Generating Stations 1 2 3

Ex-Bus Capability x1 x2 x3(Forecast) ____ ___ ___

SEB-A’s share a1 a2 a3SEB-B’s share b1 b2 b3SEB-C’s share c1 c2 c3

For a particular 15 minute time block

SEB-A’s requisition a’1 a’2 a’3SEB-B’s requisition b’1 b’2 b’3SEB-C’s requisition c’1 c’2 c’3

___ ___ ___CGS’s schedule x1’ x2’ x3’

MW

SRLDC/Comml/IEGC/37

SETTLEMENT SYSTEM

Total capacity charge payable to CGS-1 for the day= x1 * capacity charge rate of CGS-1

Total Energy charge payable to CGS-1 for the day

= x1’ * Energy charge rate of CGS-1 4

Total capacity charge payable by SEB-A for the day

= a1 * capacity charge rate of CGS-1

+ a2 * -do- CGS-2

+ a3 * -do- CGS-3Total Energy charge payable by SEB-A for the day

= (a1’) * Energy charge rate of CGS-1 ( 4 )

+ (a2’) * -do- CGS-2 ( 4 )

+ (a3’) * -do- CGS-3 ( 4 )

All capacity charge and Energy charge payments to be made by SEBs directly to CGS.

SRLDC/Comml/IEGC/38

SETTLEMENT SYSTEM

Actual (metered) injection of CGS-1 in the time block = X1 MWh.

Excess injection = (X1 – x1’ ) MWh.

4

Amount payable to CGS-1 for this =(X1-x1’) * pool price for the block.

4

SEB-A’s scheduled drawl for time block = a1’+a2’+a3’ = a’ MW (ex-CGS Bus)

SEB-A’s NET drawal schedule = (a’ – Notional Transm. Loss) MW

= (a’ – Notional Transm. Loss) = A’ MWH

4

Actual (metered) net drawal of SEB-A during time block = A MWH

Excess drawal by SEB-A = (A-A’) MWh.

Amount payable by SEB-A for this = (A-A’) * pool price for the block.

All above payments for deviations from schedules to be routed through a pool A/C operated by RLDC

SRLDC/Comml/IEGC/39

AVAILABILITY

• Availability in relation to a generating station for any period means the average of the DCs for all the days during that period expressed as a percentage of the installed capacity of generating station minus normative auxiliary consumption in MW and shall be computed as per the following formula:

AVAILABILITY AND PLF

% Availability = i=1

N

DCi/ {NxICx(100-Auxn) }%10000

Where DCi = Average Declared Capacity for i th day of the period in MW N = Total no. of days during the period Auxn = Normative Auxiliary Consumption as % of gross Gen.

IC= installed capacity in MW

% Availability forms the basis for calculations

i=1

N

SGi/ {NxICx(100-Auxn) }%10000PLF =

Recovery of Annual fixed charges 100% recovery if % Availability >=Target Availability

- Pro-rata reduction if %Avb<T.Avb.

- Target Availability For Fixed charges recovery - Target PLF for incentive

-Both to be Notified by CERC-Financial Year forms the basis for calculations

ISGS Target Availabilty Target PLF

RSTPS 80% 80%

NLC 75% 75%

Monthly Capacity charges receivable by an ISGS:

1 st Month = (1xACC1)122 nd Month = (2xACC2-1ACC1)12….….12 th month = (12xACC12-11ACC11)12where ACC1,ACC2…….ACC12 = Annual capacity charges corresponding to the cum. Availability up to the corresponding month.

Monthly Capacity charges payable by a beneficiary :

1 st Month = (1xACC1xWB1)122 nd Month = (2xACC2xWB2-1ACC1xWB1)12….….12 th month = (12xACC12xWB12-11xACC11xWB11)12where WB1,WB2…..WB12 = Weighted average % share up to the corresponding month.

Name Of ISGS Aux.

Consumption

Variable

Charges (Ps)

RSTPS STAGE I & II 7.93% 98

RSTPS STAGE III 7.5% 104

NLC II/1 10.00% 75

NLC II/2 10.00% 100

NLC TPS 1 (EXP) 9.50% 131

TALCHER STAGE II 7.50% 74

Energy charges

The Energy Charges Payable by beneficiary to the ISGS =

Variable Charge of ISGS X Requisition of beneficiary from the ISGS

The Energy Charges Receivable by ISGS from beneficiaries =

Variable Charge of ISGS X Despatch schedule of ISGS

• Flat rate of 25ps/u

• For ex-bus Schedule Energy in Excess of ex-bus energy corresponding to Target PLF

Incentive as per existing norms

Settlement Systems* On weekly basis : For seven day period ending on penultimate Sunday

•RLDC to furnish Scheduling & Metering data to REB• Sectt. by Thursday noon

•REB Sectt. to issue Weekly UI a/c by Tuesday

•Pool a/c operated by RLDC•Settlement for UI on weekly basis•All accounts open for 20 days

SRLDC/Comml/IEGC/34

Settlement System contd..

• On monthly basis :• REB to issue REA specifying % Avb, %

Net Entitlement, % Energy charges, Wt. Avg. Ent. for Tr. Ch. etc.

• Capacity and Energy Charges, Incentive etc.

• –billed directly by ISGS based on REA issued by REB

WEEKLY ENERGY ACCOUNTING:

WEEKLY CYCLE : 00 HRS OF EACH MONDAY TO 24 HRS; OF THE THE FOLLOWING SUNDAY

ACTIVITIES MONDAY MORNING : SEM DATA DOWNLOADED TO DCD

: DCD DATA LOADED TO A LOCAL PC: DATA SENT TO RLDC via E-MAIL

(LATEST TUESDAY MORNING )THURSDAY NOON : RLDC CONVEYS PROCESSED DATA TO

REBTues day : WEEKLY UI a/c & Reactive charges

issued BY REBBILLING

Cap. Charge : BILLED MONTHLY based on DAILY DC BY ISGS

ENERGY CHARGE : BILLED MONTHLY based on DAILY DRAWL SCHEDULES ISSUED BY RLDC

UI a/c Paid/Disbursed as per UI a/c issued by REB

REACTIVE a/c

Variations in actual generation/drawal and scheduled generation /drawal are accounted through UI. This is a frequency linked charge which is worked out for each 15 minute time block.

Charges for all UI transaction, based on average frequency have following rate of paise per KWh from 01.01.03 up to 31.03.04.

UI rate (Paise per KWh)

Average Frequency of time block50.5 Hz. and above 0.0Below 50.5 Hz. and upto 50.48 Hz. 5.6Below 49.04 Hz. and upto 49.02 Hz. 414.4Below 49.02 Hz. 420.0Between 50.5 Hz. and 49.02 Hz. Linear in 0.02 Hz. step

Unscheduled Interchanges (UI)

UI rate w.e.f 01.04.04 to 30.09.04 UI rate (Paise per KWh)

Average Frequency of time block50.5 Hz. and above 0.0Below 50.5 Hz. and upto 50.48 Hz. 8.0Below 49.04 Hz. and upto 49.02 Hz. 592.0Below 49.02 Hz. 600.0Between 50.5 Hz. and 49.02 Hz. Linear in 0.02 Hz. step

• UI rate w.e.f 01.10.04 UI rate (Paise per KWh)

Average Frequency of time block (Hz,)Below Not below ----- 50.50 0.050.50 50.48 6.050.48 50.46 12.0----- ----- ----- ----- ----- ----- 49.84 49.82 204.049.82 49.80 210.049.80 49.78 219.049.78 49.76 228.0----- ----- ----- ----- ----- ----- 49.04 49.02 561.049.02 ----- 570.0(Each 0.02 Hz. Step is equivalent to 6.0 paise/kWh in the 50.5-49.8 Hz. Frequency range and to 9.0 paise/kWh in the 49.8-49.0 Hz. Frequency range).

Energy transactions of UI from/to Pool

Over Gen. By ISGS-1

Under drawl by SEB-A

UI import from IR-1

Under gen. By ISGS-2

No one to one correspondence

System frequency UI

RateRegional Pool

Over drawl by SEB-BUI Export to IR-2

Operation of Pool

Separate Pool a/cs operated by RLDCs on behalf of REBs for UI, IRE and Reactive charges

Regional Pool

Payable by ISGS-2

Payable by SEB-BPayable by IR-2at its UI rate

Receivable by ISGS-1 (up to DC) Receivable by SEB-A Receivable by IR-1

at its UI rateNo one to one correspondence

No cross adjustments allowed between the constituents

Where do SEMs come into picture?

• Only measuring Deviations from Schedulei.e. UI

• To measure 15 min block-wise Energy and Frequency

Issues concerned :-Specifications-Location criterion-Main/Check/Standby philosophy

ISTS

ISGS -II

SEB-B drawalMain = (T+U+X)

Standby = (V+W+Y)

SEB-A drawalMain = (G+H+N+O+Y)Standby = (L+M+Q+R+X)

Metering Philosophy under ABT regime

Other than NTPC Station

ISGS-I injectionMain = (F+G+H+J+K)Check=(F'+L+M+J'+K')Standby = (A+B+C+D+E)

NTPC Station

SEB-B

ISGS-II injectionMain = (M1+M2)Check=(C1+C2)Standby = (S1+S2)

ISGS -I

Aux. Aux.

ISTS

ISTS

SEB-A

SEB-A

A B D EC

FF'

G HJJ'

KK'

L M

SEB-A

ST U

VW

X

Y

SEB-B

N O P

Q R

C1 C2

M1 M2

S1 S2

Aux.

Main Meter

Standby Meter

Check Meter

Points for Energy AccountingInjection by NTPC Generating Stations :

Main &check meters on Outgoing feeders Standby meters on HV side of GT/TT

Injection by other Generating Stations :

Main &check meters on HV side of GT/TT Standby meters on Outgoing feeders

Drawl by SEBs

Main -HV side of ICTs at GS and CTU S/S, Receiving end of Lines directly connected to ISGS

Respective ends of Lines connected to other SEBs Standby – LV/ Tertiary side of ICTs

Other end of lines connected to other SEBs

Special Energy Meter FeaturesSpecial Energy Meter Features

• STATIC TYPE

• COMPOSITE METER

• HIGHEST ACCURACY IN POWER INDUSTRY

• 3 PHASE-4 WIRE CONNECTIONS / MEASUREMENT

• DIRECT MEASUREMENT AS PER CT/PT SECONDARY QUANTITIES

- 110V PH TO PH/63.51 V PH-N

- 1 AMP OR 5 AMP

- VA BURDEN NOT >10 ON ANY OF THE PHASES

• WORKS ON REAL TIME CLOCK

• NO CALIBRATION REQUIRED

• TIME ADJUSTMENT FACILITY

• HIGH SECURITY OF DATA STORAGE

Raw dataWEEK FROM 0000 HRS OF 06-01-01 TO 0837 HRS OF 15-01-01NP-0185-A 91858.5 99968.5 39195.5 06-01-01 00 51 +21.57 48 +21.68 50 +21.71 49 +21.33 …. 04 19 +20.61 23 +20.80 19 +21.05 00 +21.35 … 08 00 +24.95 00 +24.95 00 +25.09 00 +24.38 … 12 71 +24.38 52 +23.98 30 +23.81 13 +24.03 …16 00 +23.37 00 +23.52 00 +22.87 00 +21.66 … 20 00 +25.75 00 +25.32 00 +25.40 00 +25.37 … NP-0185-A 94117.2 99968.5 40313.5 07-01-01 00 59 +20.94 54 +21.01 59 +20.79 58 +21.05 … 04 33 +20.05 38 +20.17 37 +20.49 28 +20.90 …08 00 +22.99 06 +23.10 00 +22.81 00 +22.94 … 12 85 +20.93 51 +20.65 21 +20.79 00 +19.89 … 16 07 +20.14 01 +20.53 00 +20.72 00 +20.66 …20 05 +23.62 08 +23.23 16 +23.25 27 +23.40 … NP-0185-A 96172.2 99968.5 41236.9 08-01-01

Special Energy Meter Various ChecksSpecial Energy Meter Various Checks

CHECKS for DATA VALIDATION :

• NOMINAL VOLTAGE CHECK• FREQUENCY• TIME CORRECTION• WATTHOUR CHECK• PREVIOUS WEEK DATA• ALGEBRAIC SUM

• RAW DATA IN WHr

• MWhr = RAW DATA x CT RATIO x PT RATIO

• PAIR CHECK DONE FOR MAIN/ CHECK/ STANDBY/ FICTMETERS ( ex. : for both sides of ICTs, Lines, GT side & Line side at ISGS.

Special Energy Meter Data ComputingSpecial Energy Meter Data Computing

Reactive Energy Accounting

Reactive Energy is measured

when system voltage is

> 103% of Nominal Voltage< 97% of Nominal Voltage

Loss computations

15 min block-wise % loss =

(Sum of all Injections from ISGS + net IR imports)

X 100

(Sum of all Injections from ISGS + net IR imports) -

(Sum of Drawals by all beneficiaries from Central Grid)

Use of Notional Loss in scheduling

• % Average loss (15 min. blockwise) aggregated over the last week will be used in Scheduling Process for the next week.

(for arriving at the ex-periphery Drawal Schedules of Beneficiaries)

0.5% REDUCTION MEANS MORE THAN 100 CR ANNUAL SAVINGS0.5% REDUCTION MEANS MORE THAN 100 CR ANNUAL SAVINGS

Loss for the week Loss % Week applied for

From To From To

16-Sep-02 22-Sep-02 4.83 30-Sep-02 6-Oct-02

6-Jan-03 12-Jan-03 3.9 20-Jan-03 26-Jan-03

20-Oct-03 26-Oct-03 3.38 3-Nov-03 9-Nov-03

19-Jan-04 25-Jan-04 3.92 2-Feb-04 8-Feb-04

24-May-04 30-May-04 2.55 7-Jun-04 13-Jun-04

9-Aug-04 15-Aug-04 2.54 23-Aug-04 29-Aug-04

17-Jan-05 23-Jan-05 3.25 31-Jan-05 6-Feb-05

7-Feb-05 13-Feb-05 3.04 21-Feb-05 27-Feb-05

30-May-05 5-Jun-05 2.95 13-Jun-05 19-Jun-05

27-Jun-05 3-Jul-05 3.49 11-Jul-05 17-Jul-05

11-Jul-05 17-Jul-05 3.73 25-Jul-05 31-Jul-05

25-Jul-05 31-Jul-05 3.53 8-Aug-05 14-Aug-05

1-Aug-05 7-Aug-05 3.3 15-Aug-05 21-Aug-05

8-Aug-05 14-Aug-05 2.92 22-Aug-05 28-Aug-05

TYPICAL %AVERAGE LOSS FIGURES FOR CENTRAL GRID IN SR

%Average losses In other Regions :

NR 3.5 to 4.5

ER 3.0 to 3.5

WR 5.0 to 6.0

OTHER REGIONS

%loss for different weeks from 2003- 2005

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

5.0

1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 33 35 37 39 41 43 45 47 49 51

Week No.

%lo

ss

2003-042004-05

2005-06

METERING LOCATIONS IN SR

• Total No Of SEMS in SR USED FOR REA 350

No.s• Total No Of SEMS in KPTCL USED FOR REA

50 No.s

KAKINADA

PO 05

REA METERING LOCATION OF STATE OWNED INTER STATE LINES IN SOUTHERN REGION

HOSUR

HOSUR

YERANDAHALLY

2

20 KV .

YERANDAHALLY

2

20 KV .

MANJESWAR

UPPATI

KADAKOLA

KNYMPTTAKONEJA

ARAKU

BALIMELA

OS

AP

TN

KERKAR

GOA

LOW

ER

SIL

ER

U

BA

RS

UR

HVDC

KO

LLA

PU R

K'T

HA

RA

I

UD

UM

ALP

ET

KA

YA

TH

AR

TH

EN

I

BELLARY

TANDUR GOOTY

SEDAM

CH

IKK

OD

I

MO

OZ

HIY

AR

ED

MO

N

IDU

KK

I

PA

RA

SA

LA

MH

MP

220

KV

220

KV

220

KV

220

KV

220

KV

220

KV

110

KV

220

KV

132

KV

66 K

V

110

KV

220 KV

110 KV

AP57

AP55

AP56

OS 58

P0 06

TN 56

AP 54 TN 57

TN 54

TN51

TN52

TN53

TN58

KL52

KL53

KL51

TN 55

CK 54

CK 51

CK 52

KL 55

KL 56CK56

CK59

CK58

GO01

GO02

GO03

CK57

AP 58AP 52

CK 60

CK 61

CK 55

CK 53KL58

PONDY(Yanam)

132

KV 21

XELDEM

21

GO04

UPPERSILERU

PONDA

PONDA

AMBEWADI SUPA

MACHKHUNBALIMELA

AP 53CHITOOR TIRUVALEM

SULURPET

G'P

UN

DI

KOOTHAMUNDA

220 KV

220 KV

220 KV

220 KV

220 KV

132 KV

220

KV

110

KV

INTER STATE LINES METERING LOCATIONS

METERING LOCATIONS IN KPTCL'S INTERCONNECTED SYSTEM

AP-51CK-53

TANDUR

GOOTY

A PAP-52CK-55

BELLARY

SEDAM

TN-55CK-54HOSURYERANDAHALLI

T N

CK-22CK-21

CK-05CK-06

CK-03CK-04

BANGALORE

RAICHUR N'SAGAR

MBD

N'SAGAR

MBD

CENTRAL TR. SYSTEM

CK-51KL-55

KL-56 CK-52

KONAJE

KADAKOLA

MANJESWAR

KANIAMPETTA

KSEB

GO-03

GO-04

GO-01

GO-02AMBEWADI

XELDEMXELDEM

PONDA

PONDA

PONDA SUPA

GOA(SR)

KG-24

KG-23

KG-22

KG-21

KODASALLI

KADRA

SIRSI-2

SIRSI-1

KGS

CK-60

CK-61CHIKKODI

KolhapurWR/MSEB

CK-01CK-02

HOODY

SR-63

SR-64

BANGALORE

BANGALORE

CK-57CK-57

CK-58

CK-56

CK-57

KOLAR

220kV

220kV

220kV

110kV

110kV

220kV

220kV

220kV

220kV

220kV

220kV

220kV

220kV

400kV

220/400kV

220/400kV

220/400kV

CK-11CK-12

KOLARKOLAR

220/400kV

110kV

400kV

GOOTY

CK-21RAICHUR

4 5 6 7

CK-23

CK-05

CK-06

CK-24

CK-27

CK-25

SR-81

DAVANAGERE

CK-26

NELAMANGALA

CK-28

CK-09

CK-10

CK-30

CK-31

HOODY

CK-07

CK-08

CK-15

CK-16

HIRIYUR

CK-29

CK-32 CK-33

CK-13

CK-14

BANGALORE

SR-11

N'Sagar

Kolar

Munirabad

CK-35

CK-34

CK-36

CK-37

Temporary Configuration :Karnataka's drawl in Raichur-Hoody section:Raichur = -(CK-21) -(CK-23) -(CK-25); Muniarabd=(CK-05) ; Davanagere=(CK-07); Hiriyur=(CK-15); Nelamangala= -(CK-29)-(CK-30)-(CK-35) -(CK-36) -(CK-38);Hoody = (CK-09)+(CK-13)

CK-30

CK-31

CK-38

Karnataka's drawl in Raichur-Hoody section:

Raichur = -(CK-21) -(CK-23) -(CK-25);

Muniarabd=(CK-05) ;

Davanagere=(CK-07); Hiriyur=(CK-15);

Nelamangala= -(CK-29)-(CK-30)-(CK-35)

-(CK-36) -(CK-38);

Hoody = (CK-09)+(CK-13)

RAICHUR SECTION

KPTCL'S DRAWL ON 400kV RAICHUR-DAVANAGERE SECTION

(CK-RC)=-(CK-21)-(CK-23)-(CK-25) -(CK-29)-(CK-30)+ (CK-35)+ (CK-36) (CK-38) + (CK-05)+ (CK-07) +(CK-09) + (CK-13) + (CK-15)

KPTCL'S DRAWL ON 400kV

(CK-91)= (CK-01)+(CK-03)+(CK-RC) +(CK-11)

CK'S DRAWL ON 220kV

(CK-92)= -(CK-51)-(CK-53)-(CK-54)-(CK-55)-(CK-58)-(CK-59)+(KG-21)

+(KG-22)+(KG-23)+(KG-24)

CK'S DRAWL ON 132kV

(CK-93)=-(CK-52)-(CK-56)

TOTAL DRAWL (CK-94)=(CK-91)+(CK-92)+(CK-93)NOTE: SEMS ON FEEDERS NOT CARRYING ISGS POWER NOT TO BE CONSIDERED

REACTIVE ENERGY CHARGE :

PAYABLE FOR :

1. VAR DRAWALS AT VOLTAGES BELOW 97%2. VAR INJECTION AT VOLTAGES ABOVE 103%

RECEIVABLE FOR:

1. VAR INJECTION AT VOLTAGES BELOW 97%2. VAR DRAWAL AT VOLTAGES ABOVE 103%

APPLIED FOR VAR EXCHANGES BETWEEN :

A) BENEFICIARY SYSTEM AND ISTS- THROUGH A POOL ACCOUNT

B) TWO BENEFICIARY SYSTEMS ON INTER-STATE TIES- BY THEMSELVES

RATE: @ Rs. 51.05/MVArh (for 205-06)Basic Rate : 4 paise/kvArh ( for the year 2000-01 )

5% ESCALATION PER YEAR

Issues in Reactive Energy charges

• Deficit in pool (SR & ER)-due to continuous High voltages in SR

Surplus in Pool (NR &WR)

Utilization of Accruals

Disputes in payments between Beneficiaries for Reactive charges in Inter-state Lines

SOUTHERN REGIONAL ELECTRICITY BOARDABT based U.I. AccountFOR A TYPICAL WEEK

NNOTE:

1. MAPS & KGS not covered under ABT; hence UI reduced to zero, under all conditions. IR Exchanges: - Metering points – For WR it is Chandrapur South Bus.

- For ER it is Gazuwaka East Bus & Talcher stage I&II interconnecting bus. ii) UI for IR exchanges with ER has been calculated at ER frequency.iii) UI charges with WR and ER has been taken as first charge, as per decision taken in Special Committee meeting held on 17.12.2002.

A. ABSTRACT OF UNSCHEDULED INTERCHANGES ( UI figures in Rs. Lakhs)

Utilities UI

PayableUtilities UI Receivable

KPTCL 720.47741 TNEB 641.48459

KSEB 457.19673 APTRANSCO 269.73260

PONDY 124.38710 ER 188.40533

NLC_II_2 14.72798 RSTPS 84.30154

NLC_II_1 13.81846 GOA 10.67606

TALCHER_II 2.36108 NLC_I_EXP 2.25996

WR 1.32476

TOTAL1332.9687

6TOTAL 1198.18484

A. ABSTRACT OF UNSCHEDULED INTERCHANGES (restricting to the lesser of the two as per the 126th SRE Board decision). (UI figures in Rs. Lakhs)Utilities UI Payable Utilities UI Receivable

KPTCL 647.62591 TNEB 641.48459

KSEB 410.96701 APTRANSCO 269.73260

PONDY 111.80962 ER 188.40533

NLC_II_2 13.23876 RSTPS 84.30154

NLC_II_1 12.42120 GOA 10.67606

TALCHER_II 2.12234 NLC_I_EXP 2.25996

WR 1.32476

TOTAL 1198.18484 TOTAL 1198.18484

payable to Pool

receivable from

APTRANSCO 516417KPTCL 1998690KSEB 231733TNEB 3185840

B.NET REACTIVE ENERGY CHARGES BETWEEN BENEFICIERIES:

280

0

APTRANSCOKPTCLKSEBAPTRANSCOKPTCL

11,410

0235,924

KPTCLTNEB

00

TNEBGOA

04,853

APTRANSCOKSEB

0APTRANSCO0

TNEBPONDY

0

A.REACTIVE ENERGY CHARGES WITH THE POOL :

( Amount in Rupees)

BY BENEFICIERY

FROM BENEFICIERY

KPTCL

AMOUNT RECEIVABLE

in Rupees

Beneficiaries Beneficiaries

GOA

KPTCL

KSEB

TNEB

PONDY

0

(as per decision in the 132nd meeting of SRE Board)

REGIONAL ENERGY ACCOUNT BASED ON AVAILABILITY BASED TYARIFF

Documents

mw max demand met

mw 500x4

mwdaily consumption

mw 210x2talcher stage

mw 500x1nlc tps2 stage

mudaily consumption

mw 200x3 500x3rstps

growth of demand