1 SCOPE OF THE PRESENTATION Grid operation - overview Availability Based Tariff Benefits to Region &...

11

SCOPE OF THE PRESENTATIONSCOPE OF THE PRESENTATION

• Grid operation - overview• Availability Based Tariff• Benefits to Region & it’s

constituents • Intra_state ABT – it’s necessity• Issues• How to implement?

22

GRID STATUS – PRE - ABTGRID STATUS – PRE - ABT• Very wide Frequency fluctuations

48.0Hz to 52 Hz. • Low Grid Voltages

400kV going down up to 330kV• Frequent Grid Disturbances• Sub-Optimal Operation• High Technical loss• Overdrawals at low frequency – might is right

Grid Operation on fire fighting instead of Optimisation

& Economy

33

AVAILABILITY BASED TARIFFAVAILABILITY BASED TARIFFSpearheaded by POWERGRID Features:Unique commercial mechanism linked with

frequencyFixed Charges i.e. Capacity charges

As per Plant Availability.Variable Charges i.e. Energy charges

As per Schedule.Unscheduled Inter change (UI) i.e. deviations from

schedule ( Schedule – Actual) Price as per prevailing system frequency

SCH-ACT GRAPHS

44

0

100

200

300

400

500

600

700UI RATE

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

Above 50.5 0

50.0 150

49.8 210

49.0 and below 570

Till 31.03.2004

From 01.10.2004 to till date

From 01.04.2004 to 30.09.2004

55

• Achievements

– Implemented between July 2002 and Nov.’2003 – Improved quality of supply.– Unutilised capacity harnessed-Pumped Storage– Merit order Operation.– Grid discipline – Emphasis on load forecasting– Discourage overdrawals during low frequency – Facilitate bi-lateral trading

– Maximisation of generation availability

AVAILABILITY BASED TARIFF

66

Need for intra-State ABTNeed for intra-State ABT

• Accountability of utilities after reforms• Passing on UI payment

– Intra State ABT to identify agencies responsible for overdrawal/underdrawal, overgeneration/ undergeneration, resulting in UI payment to regional pool.

• Proper Demand forecast and load management by DISCOMs

• To establish a framework for bilateral trading at intra-State level

• To achieve overall merit order operation.

•ISGS: Inter State Generating Stations•SGS: State Generating Stations•CTU: Central Transmission Utility•STU: State Transmission Utility

Inter-State ABT

Intra-State ABT

•Distribution Control Centre – One for each Discom

IPPs CPPs

Non-conventional source of energy e.g., wind energy

ISGS-1 ISGS-2 ISGS-3

CTU / ISTS SYSTEM RLDC CORDINATES

INTER- STATE

INTRA STATE

STU/INTRA STATE SYSTEM

SGS-1 SGS-2 SGS-3

DISCOM-1 DISCOM-2 DISCOM-3

SLDC CO-ORDINATES

OPEN ACCESS CUSTOMER

~ ~ ~

~ ~ ~

88

Intra-state ABT Intra-state ABT ..what it achieves ?what it achieves ?

. Unbundling of Vertically Integrated State Utilities• Mechanism to price power based on

Demand/Supply• Harness surplus generating capacity available in

state with CPPs/IPPs• Operation of grid on economic principles –Merit

Order Despatch • Open Access in Intra-state Transmission and

Distribution.

99

Intra state ABT Intra state ABT

• Pre – requisites– Allocations from ISGS/ other state owned generators to

various Discoms by State Govt

– control centres in each Discom

– Rtus at required locations

- generating stations, drawal points from state transcos

- on various tie-lines lines, various other critical lines

-scada information to discom control centres

-SEMs at required locations

1010

Intra-state ABT Intra-state ABT ––what it achieves ?what it achieves ?

• Generate signals for efficient grid operation at the intra-state level.– Overdrawals at low frequency by Discoms duly priced.– Encourage serving of higher consumer demand – Encourage maximisation of generation during deficit

conditions.– Each Discom and state generating station

responsible for its actions – a profit centre– Commercial signals available to large consumers

capable of regulating drawal

1111

……Intra-state ABT Intra-state ABT – what it – what it achieves ?achieves ?

• UI mechanism at the intra-state level.– UI to be applied on the deviations from the

schedules of the DISCOMS/State generators/IPPs/CPPs.

– State Utilities to be collectively liable for the States’ liabilities with the regional UI pool account.

– Achieves merit order operation for all the entities under ABT

– Commercial viability of running Pumped Storage Stations.

1212

Issues needs to be addressed for Issues needs to be addressed for intra-State ABTintra-State ABT

• Restructured SEBs• Identification of entities for intra-State ABT• Scheduling Principles & Procedures• Commercial Principle

– Metering Philosophy• Treatment of existing Agreements• Organisational Development• Regulatory Issues

1313

INTRA-STATE ABTINTRA-STATE ABTCOMMUNICATION REQUIREMENTSCOMMUNICATION REQUIREMENTS

• SLDC TO DISCOM COMMUNICATION TO BE ON A STRONG REDUNDANT BACKBONE

• VISIBILITY OF DATA TO SYSTEM OPERATOR– INTERCHANGE FLOWS– EMBEDDED GENERATORS– WIND FARMS, MINI HYDEL, CPP TO BE

TELEMETERED IN STAGES– AND FINALLY, DMS SYSTEM FOR LOAD

MANAGEMENT

• DATA ARCHIVAL AND ANALYSIS COULD HELP IN ACCURATE SCHEDULING

1414

The main steps involved to implement intra-State ABT are:

• Listing of entities on which ABT/UI mechanism to be applied

• Listing of Metering locations and assess the requirement of meters and accessories

• Finalize the specifications for meters and accessories

• Presentation of the mechanism to all concerned

• Finalisation of the tariff for all generating stations in ABT format.

Implementation of intra-State Implementation of intra-State ABTABT

1515

Implementation of intra-State ABTImplementation of intra-State ABT

• Finalisation of shares of each distribution zones and other commercial arrangements

• Organize installation & commissioning of meters and accessories.

• Organising meter reading, data transfer and computation at SLDC

• Establishment of the scheduling process along with scheduling software

• Presentation/training to all concerned

1616

Implementation PlanImplementation Plan• 1st Phase Activities

– Finalisation of listing of entities– Listing of Metering locations– Finalisation of quantities of SEMs,

DCDs/MTEs– Finalisation of technical specifications of

SEMs/DCDs– Initiate tendering process for procurement

of meters

1717

• 2nd Phase Activities – Finsalisation of Tariff of State Generating

Stations as per ABT parameters/norms– Finalisation of Reactive Charge scheme– Finalisation of commercial mechanism for

CPPs, Wind farms, Wheeling and banking, Open Access Customers etc.

– Determination of Allocations of different Discoms in State Genco/ ISGS/ IPPs.

Implementation PlanImplementation Plan

1818

• 3rd Phase Activities – Supply and commissioning of meters at

different locations– Installation of software for data processing – Installation of software for scheduling /

energy accounting– Training– Estimate time for implementation – 12 to

18 months


1919

Some of the features of New National Some of the features of New National

Electricity Policy – Feb.’05Electricity Policy – Feb.’05

• Appropriate Commissions to undertake development of power market

• SERCs to notify GRID CODE by September 2005, if not yet notified

• State Commissions to ensure upgradation of SLDCs by June 2006

• SERCs are advised to introduce ABT regime at the State level within one year i.e. by February 2006.

2020

Status on intra-State ABTStatus on intra-State ABT• Many SEBs restructured, others in process• State Utilities looking for benefits of intra-

State ABT• Gujarat took lead for intra-State ABT• Punjab took lead in Northern Region• Road-map for Maharashtra is ready• POWERGRID assisting these States by

providing consultancy• Other States like MPSEB & Haryana to

follow.

2121

CASE STUDY FOR GUJARAT STATE

2222

……Current IssuesCurrent Issues

• Market model for power procurement by Discoms

• Single Buyer Model • Multi Buyer Model

• ABT parameters/norms

• Treatment for Open Access Transactions– CPP/IPP/Wind Farms/Banking transactions

and Bulk consumers

2323

West DISCOM

GUJARAT STATE POWER POOL : Single Buyer Model

GEN 1

GEN 2

GEN 3

IPP 1

IPP 2

SouthDISCOM A

CentralDISCOM

North DISCOM

External Purchases

s

STATE GENCO

SELLS THROUGH GETCO SYSTEM

RESIDUAL GEB/TRADECO TO POOL ALL GENERATION

ISGS Allocations

SEC

AECo

Power Purchases/Sales

2424

GUJARAT STATE POWER POOL : Multiple Buyer Model

GEN 1

GEN 2

GEN 3

IPP 1

IPP 2

TRANSMISSION SYSTEM OF GETCO

STATE GENCO

SouthDISCOM A

CentralDISCOM

North DISCOM

West DISCOM

SEC

AECo

TRADECO

External Purchases

Power Purchases/Sales

2525

Metering philosophy Metering philosophy

GENCO Power Stations• One main meter for each Generator Transformer/ Station

Transformer • One (standby) meter for each outgoing feederLines connecting Discom-Discom• One meter each at both endsIPPs• One Meter (main) at IPP-end• One meter (standby) at Discom endOpen Access Customers• One Meter (main) at Injection-end• One meter (standby) at customers end

2626

Meter Location - philosophyMeter Location - philosophyLines connecting CPP-Discom• One meter (main) at CPP end• One meter (standby) at Discom endLines connecting embedded licensees with Discom• One meter (main) at Discom end• One meter (standby) at licensee’s endLines connecting CTU and STU points • Meters already provided

2727

Assessment of Meters/DCDs Assessment of Meters/DCDs - Alternatives- Alternatives

Alternative 1 :• Discom boundary at 11 kV feeder from 66/11 kV X’ers

– Metering at 11 kV side of 66/11 kV Xers.– More meters and data recording at lower voltage level would

add to inaccuracies.– Data collection would be exhaustive and unnecessary. Since

66kV network is owned by GETCO, proportionate losses would be borne by all Discoms.

– Lot of bulk customers are connected above 11kV and are consumers of Discoms. Metering requirement would be high.

– No. of meters exceed 3600 Nos. (incl 20% spares)– No. of DCDs/MTEs would be high

2828

DISCOM B

DISCOM A

400kV

220kV

132kV

66kV

11kV

M

Alternative 1: Metering at electrical Discom boundaries

MM

M

GENCO

CPP

GETCO/ ISTS Ties

GETCO/ ISTS Ties

S S

M

S

M

SM

S

M

S

No of meters>3600

2929


Alternative 2 :

• Metering at 66kV side of X’ers of 220/66kV, 132/66kV.– Losses in 66kV transmission network included in actual

drawal.

– Inter-discom lines 66kV and below to be metered.

– Customers connected at 132kV and above to be metered ….?

– No. of meters 1195 (incl 20% spares)

– No. of DCDs 203 ( incl 20% spares)

3030

No of meters = 1195

DISCOM A

CPP

DISCOM B

400kV

220kV

132kV

66kV

11kV

Alternative 2: Metering at 66kV side of Xers

MM

M

GENCO

GETCO/ ISTS Ties

GETCO/ ISTS Ties

S S

M

S

M

S

M

S

M

S

LB

L = Losses in 66kV GETCO system borne by DISCOM , would be included in drawal of Discom

M

M

3131


Alternative 3 :

• Metering at 220kV side of 220/66kV, 220/132kV X’ers .– Inter-discom lines at 132kV and below to be metered.

– Bulk customers connected at 220kV to be metered.

– Losses below 132kV and 66kV network included in the drawal

– No. of meters 772 (incl 20% spares)

– No. of DCDs 133 (incl 20% spares)

3232

No of meters = 772

DISCOM B

400kV

220kV

132kV

66kV

11kV

Alternative 3: Metering at 220kV side of220/132 and 220/66 Xers

MM

M

GENCO

GETCO/ ISTS Ties

GETCO/ ISTS Ties

S S

LB

M

S

M

S

M

S

M

S

M

M

3333


Alternative 4 : RECOMMENDED ALTERNATIVE• Metering at Discom’s boundaries (the network dedicated to Discom)

– Metering at GETCO (Dedicated to Discom) – GETCO (dedicated to other discom)

– Metering at inter-Discom, Discom-to-Genco, Discom-to-IPP, Discom-to-CPP feeders

Advantages– Cost of metering and infrastructure for data communication would reduce

drastically.– Losses of dedicated overlayed GETCO network included in Discom drawal,

which anyway has to be apportioned. – Losses of common GETCO network shall be pooled.– As such differences between estimated and actual losses becomes

negligible.– No. of meters reduces to 614 (incl 20% spares)– No. of DCDs 114 (131 with 20% spares 131)

3434

No of meters = 614

L = Losses in GETCO system to be borne by DISCOM , would be included in drawal of Discom

DISCOM B

DISCOM A

400kV

220kV

132kV

66kV

11kV

M M

M

M

M

Alternative 4: Proposed Alternative Metering at notional Discom boundaries

M

MM

M

GENCO

CPP

MMGETCO/ ISTS Ties

GETCO/ ISTS Ties

L

S S

3535

Summary of Meter requirement for intra-state ABT in GujaratAlternative-4

No. DCDs

Main Standby Check Total

GSEC Power Stations 66 82 0 214 12

IPPs 21 0 0 21 5

DISCOMs

DGVCL 59 20 0 79 26

MGVCL 48 1 0 49 20

UGVCL 27 16 0 43 19

PGVCL 29 34 0 63 26

AECo 6 0 0 6 2

SECo 15 0 0 15 10

Windfarms 11 11 0 22 11

Sub-total 195 82 0 277 114

TOTAL 282 164 0 512 131

20% spares 102

Total 614

No. of Meters

3636

Intra-State ABT Intra-State ABT Parameters/norms…Parameters/norms…

– UI rate• Same as inter-state UI rate• Higher than inter-state UI rate• Lower than inter-state UI rate

– UI rate curve - slope• Multi-slope Curve

Options Option 1 : Two-part tariff with UI mechanism

• Capacity Charges – linked to availability• Variable Charges – linked to schedule• UI Charges – linked to deviations

Option 2 : Single part tariff with UI mechanism• GENCO to recover its costs through single-part (CC+VC) – linked to

schedule. In such a case, merit order suffers.• UI Charges – linked to deviations

3737

1. Higher UI Rate than region

2. Lower UI Rate than region

3. Differential UI Rate (Different UI rates for injection and drawal)

4. Regional UI Rate

Recommended UI Rate :

“Regional UI Rate” to start with

Options for UI Options for UI RateRate

3838

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


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

3939

Options for UI Options for UI RateRate

Rationale:1. It is important that we avoid the problem of different and

inconsistent mechanisms at inter-state and intra-State levels. The uniformity in two mechanisms are stressed for the following reasons:

• Intra-State balancing mechanism should result in matching UI charges to be paid/received to/from State UI pool from/to regional UI Pool.

• Pricing signals received from inter-State balancing and spot market should be passed downward to intra-State level so as to avoid seams across State boundaries. Different State and regional commercial mechanisms would cause host of other issues caused by inconsistent mechanisms.

• The electricity available within the State should not be priced in a different manner so that one is preferred over another specially when the cost of generation is the same.

4040

– Allocations to Discoms from shared generating plants -to be notified by State government

• State generators• Central Sector generators• IPPs

– Criteria to be finalised • In percentages, not in MW terms• No capacity to remain unallocated

Intra-State ABT Parameters/norms…

4141

– STU’s role in collection and disbursement of

• STU’s transmission charges• CTU’s transmission charges • Intra-State UI charges• Regional UI charges• Intra-State Reactive Energy charges• Regional Reactive Energy charges• RLDC fees and charges


4242

– Tariff norms for State Generating Plants

• Financial Norms – similar to ISGS – Depreciation, Rate of return, O&M Cost,

Debt : Equity ratio, etc.• Operational Norms – similar to ISGS

– Auxiliary power consumption– Target availability

• Can be reviewed in 5 years.• Scheme for incentives – based on plant

availability.


4343

– Re-negotiation of existing contracts with IPPs….?

• Financial Norms – as per ISGS – Depreciation, Rate of return, O&M Cost, D:E ratio etc.– Incentives

• Operational Norms – as per ISGS – Auxiliary power consumption– Target availability 80%


4444

Scheme for Reactive Energy ChargeScheme for Reactive Energy Charge

Proposal 1: Similar to scheme for Regional ISTS• Discom pays/receives for VAR drawal/absorption for Var

exchanges at inter-utility connection point – Pays for Var drawal when voltage is below 97%.– Receives for VAR return when voltage is below 97%– Receives for VAR drawal when voltages above 103% and– Pays for VAR return when voltages above 103%.– No charges for VAR drawal/return between 97%-103%

• Charges payable/receivable by IPPs/ State Genco – variation from Regional scheme – so as to incentivse them to inject/absorb for better system operation

• Use 0.5 class meters being installed by SML/Elster/L&T. As per Option 4, metering is proposed at notional boundaries of Discom network and not at actual drawal points.

• Pricing at about 10p/kVarh to incentivise installation of HT Capacitors

4545

Scheme for Reactive Energy ChargeScheme for Reactive Energy Charge

Proposal 2: Hybrid Scheme

• Payment of Var charges to ISGS as per Regional scheme – Use ABT meters at SGS-Discom tie-points

• Payment of Var charges by Discoms to Transco as per scheme similar to HT consumers.– Use normal meters at Transco-Discom tie-points

4646

Category 1 :

– CPPs having net injectable capacity > 5MW would be under ABT/UI mechanism

– Net Injection = Injection –(Consumption + Wheeling Losses)

Wheeling losses will depend on voltage level of connection points. Typical cases

Case 1 : When Injection and Consumption at the same bus – Wheeling Loss = 0

Case 2 : When Injection and Consumption in same Discom

Wheeling Losses = Average Distribution Loss of Discom

Case 3 : When Injection and Consumption points at Transco

Wheeling Losses = Average Transmission Loss of Transco

Proposed Scheme for CPPs

4747

– CPPs divided in two Categories for their applicability for ABT

Category 1: CPPs having net injection > 5MW– All deviations to be treated at UI rates, ABT Meters would

be required.

Two Proposals for accounting for CPPs

Proposal 1• Consider pre-fixed Schedules at both connection points as NIL• Measure Actual Injection at Injection-point (time-block wise)• Actual Consumption at Consumption-point (time-block wise)• Fix Post-facto Schedule at Injection-point = Actual

Consumption +Wheeling Losses• Calculate UI = Actual Injection at Injection-point - Post facto

Schedule at Injection point

Proposed Scheme for CPP

4848

Proposal 2

– Fix Schedules as given by CPP

– We may decide the procedure for fixing schedule production and consumption ends

• Whether schedule to be collected every day? And allow different schedules at different times of day? OR

• Fixed schedule for a period (say 3 months) and no change within day and during currency of transaction allowed.

OR• Treat as Open Access Transaction to be approved by SLDC

and all wheeling and Scheduling/Operation charges collected by SLDC in advance


4949

Category 2 : CPPs having net injection < 5MW including those whose drawal > injection

• Existing commercial mechanism• HT rates of GEB • Ordinary meters would be sufficient


5050

Large Consumers

1. Large Consumers >20MW not desiring Open Access• ABT/UI mechanism to apply.

• Rationale: Consumers with demand more than 1% of average Discom (average load 2000MW) would affect the UI of Discom.

2. Large Consumers <20MW not desiring Open Access• Same as at present.

Wind Farms not desiring Open Access • Not under UI

• Renewable Energy Obligations under GERC regulations would apply.

Commercial Mechanism for Commercial Mechanism for Large Consumers / Wind FarmsLarge Consumers / Wind Farms

5151

a) Treatment of Existing Banking Transactions

• Injection and drawals would be treated at prevailing UI rates

• Netting of injection and drawals not in terms of enrgy but in rupees terms

• Payment receivable by the agency for its Injection = 0.9 x UI charges for injection

• Payment payable by the agency for its Drawal = 1.1 x UI charges for drawals

• 10% will go towards wheeling since no such wheeling charges are being charged. Schedule = 0.

Net payment would be the sum of above two charges.

b) Treatment for new Banking Transactions

• To be discouraged and

• other stipulations for CPP/Co-gen would apply.

Commercial Mechanism for Banking Arrangements

5252


• 1st Phase Activities By end October,04– Finalisation of listing of entities– Listing of Metering locations– Finalisation of quantities of SEMs, DCDs/MTEs– Finalisation of Reactive Charge scheme– Finalisation of technical specifications of SEMs/DCDs– Initiate tendering process for procurement of meters– Explanation of Intra-state ABT

5353


• 2nd Phase Activities By end December,04– Finsalisation of Tariff of State Generating Stations as

per ABT parameters/norms– Determination of Allocations of different Discoms in

State Genco/ ISGS/ IPPs.– Formulation of market structure – Conversion of existing PPAs into ABT-compliant form– Finalisation of commercial mechanism for CPPs,

Wind farms, Wheeling and banking, Open Access Customers etc.

5454


• 3rd Phase Activities By end March,05

– Supply and commissioning of meters at different locations

– Training the field staff for meter reading/data collection

– Installation of software for data processing – Installation of software for scheduling– Organising UI and REC Pool Account Operation

5555

Concluding remarks…Concluding remarks…

• Listing of Entities for ABT Implementation

• Finalise the State Power Pool – Single/Multi Buyer

• Alternative for Metering Scheme

• Meter Data Collection Mechanism – Manual/AMR

• Generation Tariff Notification by GERC

5656

Concluding remarks…Concluding remarks…

• Open Access Notification by GERC

• UI Rate for Intra-State ABT

• Renegotiation of Existing Contracts with IPPs/CPPs

• Meter procurement process to commence at the earliest

• Listing of SEMs to be checked by GEB

5757

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



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

5858

Schedule Vs Actual Injection at ISGSSchedule Vs Actual Injection at ISGS

Declared Capability ά Capacity Charges

Schedule ά

Energy Charges

Actual InjectionU I

Frequency

NEXT

5959

Schedule Vs Actual Drawal by StateSchedule Vs Actual Drawal by State

Entitlement ά

Capacity Charges

Schedule ά

Energy Charges

Actual Drawal

Frequency

U I

6060

Schedule Vs Drawal by GEBSchedule Vs Drawal by GEB

600

800

1000

1200

1400

1600

1800

2000

2200

00:00

00:45

01:30

02:15

03:00

03:45

04:30

05:15

06:00

06:45

07:30

08:15

09:00

09:45

10:30

11:15

12:00

12:45

13:30

14:15

15:00

15:45

16:30

17:15

18:00

18:45

19:30

20:15

21:00

21:45

22:30

23:15

SCHLD DRAWL ENTIT

Frequency & GEB Schedule / Drawal(27.07.2002)

WRLDC MUMBAIMW

47.5

49

50.5

FREQ

Frequency

Drawal

Schedule

Overdrawal at High Frequency

UI

6161

Flattening of Load CurveFlattening of Load Curve

5000

5500

6000

6500

7000

7500

80001 3 5 7 9

11

13

15

17

19

21

23

Hrs

De

man

d in

Mw

GUJ DEM ON 20.06-02 GUJ DEM ON 20.09.02

Demand Curve in Sep,02

Demand Curve in June,02

6262

Open Access Open Access Within Discom :Within Discom :

Captive Generation Load

Open Access within Discom

Discom Boundaries

Issue:To ensure X = Y+ Wheeling LossesAnd Method for pricing deviations

X Y

6363

Within Discom :• Issues:

– Wheeling Charges to be decided by SERC

– Wheeling losses to be decided by SERC

– Pricing of deviations between X (injection into grid) and sum of Y(drawal from grid) +Wheeling Losses

– Pricing of deviations depending on ‘Size’ ?

– Metering similar to SEMs installed for ABT

ABT for embedded utilities -ABT for embedded utilities -

6464

Open Access Open Access Across Discoms :Across Discoms :

Captive Generation Load

Open Access across Discoms

Discom A Discom B

X Y

6565

Open Access and ABT for embedded Open Access and ABT for embedded utilities - Case Studies utilities - Case Studies

Across Discoms :• Issues:

– Wheeling Charges to be decided by GERC– Wheeling losses payable to STU/Discoms as

decided by SERCs– Scheduling by SLDC– Pricing of deviations between X (injection into grid)

and sum of Y(drawal from grid) +Wheeling Losses.– Pricing of deviations depending on ‘Size’ ?

6666

EXISTING STU TARIFF (effective from 21.07.2004)EXISTING STU TARIFF (effective from 21.07.2004)

• Applicable to all ST consumers having contracted demand more than 100 KVA

1. Demand Charges

1.1 For billing demand upto contract demand:

For first 500 KVA of billing demand Rs.89.25 per kVA per month

For next 500 kVA of billing demand Rs.126 per kVA per month

For next 1500 kVA of billing demand

Rs.189 per kVA per month

For billing demand in excess of 2500 kVA

Rs.215.25 per kVA per month

1.2 For billing Demand in Excess of Contract Demand:

For billing demand in excess over the contract demand

Rs.335 per kVA per month

6767

PLUS

Energy Charges

For entire consumption during the month

Upto 1000 kVA contract demand 380 paise per unit

For 1001 kVA to 2500 kVA contract demand

400 paise per unit

Above 2500 kVA contract demand 410 paise per unit

PLUSTime of Use Charges(These charges shall be levied from a consumer having contract demand or actual demand of 500 kVA and above):

For energy consumption during the two peak periods, viz., 0700 Hrs to 1100 Hrs and 1800 Hrs to 2200 Hrs

75 paise per unit

6868

Billing Demand

The billing demand shall be the highest of the following:

• Actual maximum demand established during the month

• Eighty-five percent of the contract demand

• One hundred kVA

• Power Factor– Power Factor Adjustment Charges:

• The power factor adjustment charges shall be levied at the rate of 1% on the total amount of electricity bills for the month under the head “Demand Charges” and “Energy Charges” for every 1% drop or part thereof in the average power factor during the month below 90% upto 85%.

• In addition to the above clause, for every 1% drop or part thereof in average power factor during the month below 85% at the rate of 2% on the total amount of electricity bill for that month under the head “Demand Charges” and “Energy Charges” will be charged.

6969

49.0 49.8 50.249.4 50.6 Hz

Incremental Cost (Paise/kWH)U

I

Pri

ce

System Frequency

Sta

tion

Gen

erat

ion

75 %

25 %

0 %

50 %

420

280

140

0

100 %

Pool Price

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D C

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Typical Graph Depicting Pricing of Unscheduled Interchanges Typical Graph Depicting Pricing of Unscheduled Interchanges w.r.t. System Frequencyw.r.t. System Frequency

7070

AP KAR KER TN PONDY

Total UI exported(-) /

Imported(+) in MUs

-4441 4132 1210 1163 -140

Total amount paid in Crores

Rs.-899 768 204 344 28

Average rate of UI in paise/unit 202 186 169 296 203

SUMMARY OF UI – 124 WKSSUMMARY OF UI – 124 WKS

7171

UI IN SRUI IN SR

• TOTAL UI TURNOVER :- 7792 MU

• TOTAL UI AMOUNT DISBURSED:- 1600 CR

• AVG WEEKLY TRANSACTION:- 63 MU

• AVG WEEKLY UI AMOUNT DISBURSED:- 13 CR

ABT, Intra-State ABT, Intra-State ABTABT

SRLDCSRLDC

Power Grid Corporation of India Ltd.Power Grid Corporation of India Ltd.

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1 SCOPE OF THE PRESENTATION Grid operation - overview Availability Based Tariff Benefits to Region &...

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