REGIONAL ENERGY ACCOUNT BASED ON AVAILABILITY BASED TYARIFF

REGIONAL ENERGY ACCOUNT BASED ON AVAILABILITY BASED TYARIFF
T. SRINIVAS MANAGER,SRLDC BANGALORE

BRIEF ABOUT SR BRIEF ON ABT CONVENTIONAL REA SCHEDULING REA

SOUTHERN REGIONAL GRID
▀ Centre Generating Stations in the Region are RSTPS STAGE I & II : 2,100 MW (200x x3) RSTPS STAGE III : MW (500x1) NLC TPS2 STAGE I : MW (210 x 3) NLC TPS2 STAGE II : MW (210 x 3) Madras Atomic Power Station : MW (170 x 2 ) Kaiga Atomic Power Station : MW (220x2) NLC EXPANSION TPS : MW (210X2) TALCHER STAGE II : 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 STATISTICS
KARNATAKA INSTALLED CAPACITY – MW MAX DEMAND MET – 5612 MW DAILY CONSUMPTION MAX – 125 MU DAILY CONSUMPTION AVG – 95 MU CONSUMER PROFILE – INDS -26%, DOM-19%, COMM-7%, IRRI-39% & OTHERS-9% ANDHRA PRADESH INSTALLED CAPACITY – 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% KERALA INSTALLED CAPACITY – 2280 MW MAX DEMAND MET – 2519 MW DAILY CONSUMPTION MAX – 41 MU DAILY CONSUMPTION AVG – 34 MU CONSUMER PROFILE – INDS -34%, DOM-44%, COMM-13%, IRRI-2%& OTHERS-7% TAMIL NADU INSTALLED CAPACITY – 9322 MW MAX DEMAND MET – 7902 MW DAILY CONSUMPTION MAX – 166 MU DAILY CONSUMPTION AVG – 135 MU CONSUMER PROFILE – INDS -39%, DOM-25%, COMM-7%, IRRI-24% & OTHERS-5% TALA PROJECT-LARGE CENTRAL GRID ARUNACHAL TO GUJARAT ON SAME FREQ

SR STATES – GEOGRAPHY ALL INDIA KARNATAKA ANDHRA PRADESH KERALA
POPULATION :- 5.3 CRORES AREA :- 192 (‘000 SQ KM) NO OF CONSUMERS :- 105 LAKHS PER CAPITA CONS. :- 642 UNITS MAIN AGRICULTURE CROP :- COFFEE & RAGI CLIMATIC CONDITION :- HOT AND HOT & HUMID 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 KERALA POPULATION :- 3.2 CRORES AREA :- 39 (‘000 SQ KM) NO OF CONSUMERS :- 61 LAKHS PER CAPITA CONS. :- 386 UNITS MAIN AGRICULTURE CROP :- COCONUT & SPICES CLIMATIC CONDITION :- HUMID ALL INDIA TAMIL NADU POPULATION :- 6.2 CRORES AREA :- 130 (‘000 SQ KM) NO OF CONSUMERS :- 152 LAKHS PER CAPITA CONS. :- 866 UNITS MAIN AGRICULTURE CROP :- SUGAR CANE & OIL SEEDS CLIMATIC CONDITION :- HOT AND HOT & HUMID TALA PROJECT-LARGE CENTRAL GRID ARUNACHAL TO GUJARAT ON SAME FREQ

GROWTH OF INSTALLED CAPACITY OF SR
IN MW Average Growth ~ 5 %

INSTALLED CAPACITY IN SR
SUMMARY OF INSTALLED CAPACITY(MW) AS ON AGENCY HYDRO THERMAL GAS/DIESEL WIND/OTHERS NUCLEAR TOTAL ANDHRA PRADESH 2962.5 272 2 --- KARNATAKA 1470 127.8 4.55 4988.9 KERALA 1831.1 234.6 2.025 TAMILNADU 2970 422.88 19.355 PONDICHERRY 32.5 CENTRAL SECTOR 8090 359.58 830 IPP 278.13 387.01 3627.2 7289.8 11219 (31%) 15880 (44%) 4447 (12%) 3655 (10%) 830 (2%) 36031 (100%)

SOURCE-WISE INSTALLED CAPACITY OF SR
NUCLEAR WIND/OTHERS HYDRO GAS THERMAL TOTAL 33,162 MW All Figures In MW

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

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

400KV GRID MAP OF SOUTHERN REGION
ORISSA TALCHER BHADRAVATI MAHARASHTRA JEYPORE AP SIMHADRI RSTPP KALPAKKA KHAMMAM P MMDP GAZUWAKA HYDERABAD P P VEMAGIRI MAHABOOB NAGAR GMR GVK P N’SAGAR VIJAYAWADA NARENDRA KAR RAICHUR KURNOOL P MUNIRABAD SSLMM P KAIGA N P GOOTY 1000 MW HVDC BACK TO BACK LINK GUTTUR P KADAPA NELLORE 2000 MW HVDC BIPOLE HIRIYUR TALGUPPA NELAMANGALA `HOODY CHITTOOR MADRAS 500 KV HVDC LINE BANGALORE KOLAR P MAPS HOSUR 400 KV LINE POWERGRID 400 KV LINE APTRANSCO SALEM NEYVELI 400 KV LINE KPTCL NEYVELI TPS – 1 (EXP) TN UDUMALPET P TRICHY 400 KV LINE OPERATED AT 220 KV TRICHUR P THERMAL GENERATING STATION MADURAI 400KV SUB-STATION KER NUCLEAR STATION SRLDC, BANGALORE MARCH 2006 THIRUVANANTHAPURAM

CONTROL AREAS CS - 2 CS - 1 CS -3 REGIONAL GRID SEB - A SEB -B SEB -C
RLDC COORDINATES SEB - A SEB -B SEB -C STATE IPP STATE GENR CENTRAL SHARE SEB’S GRID SLDC COORDINATES DIRECTS DISTR - A DISTR B DISTR - C

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.

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

Demarcation of Responsibilities 2.0 The system of each State shall be treated and operated as a notional 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 8.0 Provided that when the frequency is higher than 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 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

Demarcation of Responsibilities 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. SRLDC/Comml/IEGC/33

Scheduling And Despatching Proceedure
On 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

On Day-0 In case of forced outage of a unit, the RLDC shall revise the schedules 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

On Day-0 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 the first 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

On Day-0 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. SRLDC/Comml/IEGC/41

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.

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.

On 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

On Day-0 In case of forced outage of a unit, the RLDC shall revise the schedules 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 the first one. SRLDC/Comml/IEGC/41

On Day-0 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. SRLDC/Comml/IEGC/41

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

INTER STATE LINES METERING LOCATIONS

Karnataka's drawl in Raichur-Hoody section:
RAICHUR SECTION 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)

NOTE: SEMS ON FEEDERS NOT CARRYING ISGS POWER NOT TO BE CONSIDERED
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

Unscheduled Interchange (UI)
Payment to Inter State Generating Stations (ISGS) from beneficiaries under Availability Based Tariff (ABT) Capacity charges Energy charges Unscheduled Interchange (UI)

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.

UI RATE Rate of Unscheduled Drawal/Injection Frequency (Hz) Rate (p/u)
Above 50.5 50.0 150 49.8 210 49.0 and below 570

AVAILABILITY BASED TARIFF
CAPACITY CHARGE ENERGY CHARGE 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 : No complication regarding deemed generation.
(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: Energy 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 ADJUSTMENT FOR DEVIATIONS (UI CHARGE) = a function of Ex-bus MW availability of power plant for the day declared before the day starts x SEB’s % share . = MWh for the day as per ex=bus drawl schedule for the SEB finalized before the day starts x Energy charge rate =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)

For a particular 15 minute time block
SETTLEMENT SYSTEM For the day: 0000 hrs. to 2400 hrs. Central Generating Stations Ex-Bus Capability x1 x2 x3 (Forecast) ____ ___ ___ SEB-A’s share a1 a2 a3 SEB-B’s share b1 b2 b3 SEB-C’s share c1 c2 c3 For a particular 15 minute time block SEB-A’s requisition a’1 a’2 a’3 SEB-B’s requisition b’1 b’2 b’3 SEB-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-3 Total Energy charge payable by SEB-A for the day = (a1’) * Energy charge rate of CGS-1 ( 4 ) + (a2’) * do CGS-2 + (a3’) * do CGS-3 All capacity charge and Energy charge payments to be made by SEBs directly to CGS. SRLDC/Comml/IEGC/38

Actual (metered) injection of CGS-1 in the time block = X1 MWh.
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. 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 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 =
DCi/ {NxICx(100-Auxn) }% % Availability = 10000 i=1 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 N PLF = SGi/ {NxICx(100-Auxn) }% 10000 i=1

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 % % NLC % %

Monthly Capacity charges receivable by an ISGS: 1 st Month = (1xACC1)12 2 nd Month = (2xACC2-1ACC1)12 …. …. 12 th month = (12xACC12-11ACC11)12 where 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)12 2 nd Month = (2xACC2xWB2-1ACC1xWB1)12 …. …. 12 th month = (12xACC12xWB12-11xACC11xWB11)12 where 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/2 100 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

Incentive as per existing norms
Flat rate of 25ps/u For ex-bus Schedule Energy in Excess of ex-bus energy corresponding to Target PLF

On weekly basis : Settlement Systems*
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 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 (LATEST TUESDAY MORNING ) THURSDAY NOON : RLDC CONVEYS PROCESSED DATA TO REB Tues day : WEEKLY UI a/c & Reactive charges issued BY REB BILLING 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

Unscheduled Interchanges (UI)
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 up to UI rate (Paise per KWh) Average Frequency of time block 50.5 Hz. and above Below 50.5 Hz. and upto Hz. 5.6 Below Hz. and upto Hz Below Hz Between 50.5 Hz. and Hz. Linear in 0.02 Hz. step

UI rate w.e.f to UI rate (Paise per KWh) Average Frequency of time block Hz. and above Below 50.5 Hz. and upto Hz Below Hz. and upto Hz Below Hz Between 50.5 Hz. and Hz. Linear in 0.02 Hz. step

UI rate w.e.f UI rate (Paise per KWh) Average Frequency of time block (Hz,) Below Not below (Each 0.02 Hz. Step is equivalent to 6.0 paise/kWh in the Hz. Frequency range and to 9.0 paise/kWh in the Hz. Frequency range).

UI Rate Energy transactions of UI from/to Pool Under drawl by SEB-A
Over Gen. By ISGS-1 UI import from IR-1 Regional Pool System frequency UI Rate Under gen. By ISGS-2 UI Export to IR-2 Over drawl by SEB-B No one to one correspondence Energy transactions of UI from/to Pool

Operation of Pool Separate Pool a/cs operated by RLDCs on behalf of REBs for UI, IRE and Reactive charges Payable by SEB-B Payable by IR-2 at its UI rate Payable by ISGS-2 Regional Pool Receivable by ISGS-1 (up to DC) Receivable by IR-1 at its UI rate Receivable by SEB-A No one to one correspondence No cross adjustments allowed between the constituents

Where do SEMs come into picture?
Only measuring Deviations from Schedule i.e. UI To measure 15 min block-wise Energy and Frequency Issues concerned : -Specifications -Location criterion -Main/Check/Standby philosophy

Metering Philosophy under ABT regime
NTPC Station SEB-B ISGS-II injection Main = (M1+M2) Check=(C1+C2) Standby = (S1+S2) ISGS -I Aux. ISTS SEB-A A B D E C F F' G H J J' K K' L M S T U V W X Y N O P Q R C1 C2 M1 M2 S1 S2 Main Meter Standby Meter Check Meter Other than NTPC Station ISGS -II ISTS ISGS-I injection Main = (F+G+H+J+K) Check=(F'+L+M+J'+K') Standby = (A+B+C+D+E) SEB-A drawal Main = (G+H+N+O+Y) Standby = (L+M+Q+R+X) SEB-B drawal Main = (T+U+X) Standby = (V+W+Y)

Points for Energy Accounting
Injection 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 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 data WEEK FROM 0000 HRS OF 06-01-01 TO 0837 HRS OF 15-01-01
NP-0185-A …. … … … … … NP-0185-A … … … … … … NP-0185-A

Special Energy Meter Various Checks
CHECKS for DATA VALIDATION : NOMINAL VOLTAGE CHECK FREQUENCY TIME CORRECTION WATTHOUR CHECK PREVIOUS WEEK DATA ALGEBRAIC SUM

Special Energy Meter Data Computing
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.

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) - (Sum of Drawals by all beneficiaries from Central Grid) X 100 (Sum of all Injections from ISGS + net IR imports)

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 SAVINGS

TYPICAL %AVERAGE LOSS FIGURES
FOR CENTRAL GRID IN SR Loss for the week Loss % Week applied for 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 3.73 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 2.92 22-Aug-05 28-Aug-05 OTHER REGIONS %Average losses In other Regions : NR to 4.5 ER to 3.5 WR to 6.0

METERING LOCATIONS IN SR
Total No Of SEMS in SR USED FOR REA No.s Total No Of SEMS in KPTCL USED FOR REA No.s

INTER STATE LINES METERING LOCATIONS

Karnataka's drawl in Raichur-Hoody section:
RAICHUR SECTION 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)

NOTE: SEMS ON FEEDERS NOT CARRYING ISGS POWER NOT TO BE CONSIDERED
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% VAR INJECTION AT VOLTAGES ABOVE 103% RECEIVABLE FOR: 1. VAR INJECTION AT VOLTAGES BELOW 97% 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 /MVArh (for ) Basic Rate : 4 paise/kvArh ( for the year ) 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 BOARD
ABT based U.I. Account FOR 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

( UI figures in Rs. Lakhs)
A. ABSTRACT OF UNSCHEDULED INTERCHANGES ( UI figures in Rs. Lakhs) Utilities UI Payable UI Receivable KPTCL TNEB KSEB APTRANSCO PONDY ER NLC_II_2 RSTPS NLC_II_1 GOA TALCHER_II NLC_I_EXP WR TOTAL

(UI figures in Rs. Lakhs)
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 UI Receivable KPTCL TNEB KSEB APTRANSCO PONDY ER NLC_II_2 RSTPS NLC_II_1 GOA TALCHER_II NLC_I_EXP WR TOTAL

REGIONAL ENERGY ACCOUNT BASED ON AVAILABILITY BASED TYARIFF

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