Point of Connection Methodology for Sharing of Transmission Charges

Point of Connection Methodology

for Sharing of Transmission Charges

Methodology adopted for Sharing of ISTS Charges

• Hybrid Method

----A combination of Tracing and Marginal Participation methods

Tracing of Electricity• Based on a paper published by Bialek in 1996

• Requires base case load flow

• Uses concept of proportional flows

• Attempts to identify which generators are supplying which loads

Marginal Participation

--- changes in line flows due to incremental 1 MW change in generation/load at a node is used to determine the participation of the node on the lines

The Procedure

• Solve Base case LF on basic network….truncated to 400 kv

• Identification of responding buses-tracing• Increment 1 MW Marginal generation/Load at

desired bus absorbed/generated by responding buses

• Calculate line utilization factors• Allocate costs to nodes• Calculate poc rate/nodal prices

slack

Generator #1

Bus 1Bus 2

Bus 4

Bus 5

Bus 3

Line 1

Line 2Line 3

Line 4

Line 5Line 6

1

180 MW

0 Mvar

400 MW

0 Mvar

260 MW

0 Mvar

100 MW

0 Mvar

220 MW

0 Mvar

The LF studies have been done using Power World Simulator evaluation/student edition

P out Records: One MW Marginal drawal at Bus 2, Supplied by Generator at Bus 5Bus FlowsBUS 1 1 400.0 MW GENERATOR 180.00 TO 2 2 1 193.07 0 0.0TO 3 3 1 60.21 0 0.0TO 5 5 1 -73.28 0 0.0

BUS 2 2 400.0 MW LOAD 1 261.00TO 1 1 1 -193.07 0 0.0TO 4 4 1 -67.93 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.21 0 0.0TO 5 5 1 -159.79 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.93 0 0.0TO 5 5 1 -167.93 0 0.0

BUS 5 5 400.0 MW GENERATOR 401.00 TO 1 1 1 73.28 0 0.0TO 3 3 1 159.79 0 0.0TO 4 4 1 167.93 0 0.0

Pout RecordsBase CaseBus FlowsBUS 1 1 400.0 MW GENERATOR 180.00 0.0TO 2 2 1 192.62 0 0.0TO 3 3 1 60.38 0 0.0TO 5 5 1 -73.00 0 0.0

BUS 2 2 400.0 MW LOAD 1 260.00TO 1 1 1 -192.62 0 0.0TO 4 4 1 -67.38 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.38 0 0.0TO 5 5 1 -159.62 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.38 0 0.0TO 5 5 1 -167.38 0 0.0

BUS 5 5 400.0 MW GENERATOR 400.00 0.0TO 1 1 1 73.00 0 0.0TO 3 3 1 159.62 0 0.0TO 4 4 1 167.38 0 0.0

slack

Generator #1

Bus 1Bus 2

Bus 4

Bus 5

Bus 3

Line 1

Line 2Line 3

Line 4

Line 5Line 6

1

180 MW

0 Mvar

400 MW

0 Mvar

260 MW

0 Mvar

100 MW

0 Mvar

220 MW

0 Mvar

60.38 MW

73 MW

192.62 MW

Contribution of 180 MW generator on line 4= 60.38*180/(180+73)= 42.96 MW

• For a large system -----

• ......... It requires the solution of the [A] matrices.

slack

Generator #1

Bus 1Bus 2

Bus 4

Bus 5

Bus 3

Line 1

Line 2Line 3

Line 4

Line 5Line 6

1

180 MW

0 Mvar

400 MW

0 Mvar

260 MW

0 Mvar

100 MW

0 Mvar

220 MW

0 Mvar

P1=253P2=260

P3=220P4=167.38

P5=400

1-2=192.62

1-3=60.38

4-2=67.38

5-4=167.38

5-3=159.62

5-1=73.00

Pi = nodal power at node i = sum of injections = sum of withdrawals

From “The Tracing of Electricity” J.Bialek, 1996

• Contribution of Generator k in line outflow in line i-l emanating from node i=

|Pi-l|*[Au-1]ik*PGk/Pi

[Au] ij = 1 if i=j

-|Pj-i|/Pj if j belongs to set of nodes directly

supplying to node i

0 otherwise

Au Matrix

AuAu Inv

1.000 0 0 0 -0.183 1.000 0 0 0 0.183

-0.759 1.000 0 -0.403 0 0.759 1.000 0 0.403 0.307

-0.239 0 1.000 0 -0.399 0.239 0 1.000 0 0.443

0 0 0 1.000 -0.418 0 0 0.000 1.000 0.418

0 0 0 0 1.000 0 0 0 0 1.000


• Contribution of Generator k to Load at node i=

PLi*[Au-1]ik*PGk/Pi


• Contribution of Load k in line inflow in line i-j into node i=

|Pi-l|*[Ad-1]ik*PLk/Pi

[Ad] ij = 1 if i=j

-|Pj-i|/Pj if j belongs to set of nodes directly

supplied from node i

0 otherwise

Ad matrix

AdAd Inv

1.000 -0.741 -0.274 0.000 0.000 1.000 0.741 0.274 0.000 0.000

0 1.000 0.000 0.000 0.000 0.000 1.000 0.000 0.000 0.000

0 0 1.000 0.000 0.000 0.000 0.000 1.000 0.000 0.000

0 -0.259 0.000 1.000 0.000 0.000 0.259 0.000 1.000 0.000

-0.289 0.000 -0.726 -1.000 1.000 0.289 0.473 0.805 1.000 1.000

Line1(1-2) Line2(4-2) Line3(5-1) Line4(1-3) Line5(5-3) Line6(5-4)

Generator 1 (MW)

137.04 0 0 42.96 0 0

% 71 0 0 71 0 0

Generator 2(MW)

55.58 67 73 17.42 159.62 167.38

% 29 100 100 29 100 100

Total 192.62 67 73 60.38 159.62 167.38

Load line contributionLine1(1-2) Line2(4-2) Line3(5-1) Line4(1-3) Line5(5-3) Line6(5-4)

Load (bus2) 192.6 67.38 55.59 0 0 67.38

% 100 100 76 0 0 40

Load (bus 3) 0 0 17.41 60.38 159.62 0

% 0 0 24 100 100 0

load (bus 4) 0 0 0 0 0 100

% 0 0 0 0 0 60

192.6 67.38 73 60.38 159.62 167.38

Load (bus 2)

Load (bus 3)

Load (bus 4)

Gen 1(bus1)

136.62 43.02 0

% 53 20 0

Gen 2(bus5)

123.38 176.98 100

% 47 80 100

Total 260 220 100

Increase 1 MW load at Bus 2

……… and as per result of tracing Generator 1 will respond with 53% that is 0.53 MW and Generator 2 will respond with 47% that is 0.47

MW

slack

Generator #1

Bus 1Bus 2

Bus 4

Bus 5

Bus 3

Line 1

Line 2Line 3

Line 4

Line 5Line 6

1

181 MW

0 Mvar

400 MW

0 Mvar

261 MW

0 Mvar

100 MW

0 Mvar

220 MW

0 Mvar

Calculation of Seasonal Index & Marginal Participation Factors

Seasonal index (for node i line l):

Ue,i,l =(|Flei| - |Fle|).P ie

|Flei| - |Fle| must be >0

Pout Records: Marginal 1 MW INCR at Bus 2Bus FlowsBUS 1 1 400.0 MW GENERATOR 180.53 0.0TO 2 2 1 193.33 0 0.0TO 3 3 1 60.31 0 0.0TO 5 5 1 -73.11 0 0.0

BUS 2 2 400.0 MW LOAD 1 261.00TO 1 1 1 -193.33 0 0.0TO 4 4 1 -67.67 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.31 0 0.0TO 5 5 1 -159.69 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.67 0 0.0TO 5 5 1 -167.67 0 0.0



BUS 2 2 400.0 MW LOAD 1 260.00TO 1 1 1 -192.62 0 0.0TO 4 4 1 -67.38 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.38 0 0.0TO 5 5 1 -159.62 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.38 0 0.0TO 5 5 1 -167.38 0 0.0


Line Marginal case

Base case

Ue2l

1-2 193.33 192.62 184.6 Ue2(1-2)

1-3 60.31 60.38 0 Ue2(1-3)

5-1 73.11 73.00 28.6 Ue2(5-1)

4-2 67.67 67.38 75.4 Ue2(4-2)

5-3 159.69 159.62 18.2 Ue2(5-3)

5-4 167.67 167.38 75.4 Ue2(5-4)

Seasonal Index for node 2

Seaslonal index for node 2 on line [1-2] = (193.33-192.62)*260


Pout Records Bus 1 INCR 1 MWBus FlowsBUS 1 1 400.0 MW GENERATOR 181.00 0.0TO 2 2 1 193.39 0 0.0TO 3 3 1 60.54 0 0.0TO 5 5 1 -72.93 0 0.0

BUS 2 2 400.0 MW LOAD 1 260.76TO 1 1 1 -193.39 0 0.0TO 4 4 1 -67.37 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.24TO 1 1 1 -60.54 0 0.0TO 5 5 1 -159.70 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.37 0 0.0TO 5 5 1 -167.37 0 0.0



BUS 2 2 400.0 MW LOAD 1 260.00TO 1 1 1 -192.62 0 0.0TO 4 4 1 -67.38 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.38 0 0.0TO 5 5 1 -159.62 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.38 0 0.0TO 5 5 1 -167.38 0 0.0


Line Marginal case

Base case

Ue1l

1-2 193.39 192.62 138.6 Ue1(1-2)

1-3 60.54 60.38 28.8 Ue1(1-3)

5-1 72.93 73.00 0 Ue1(5-1)

4-2 67.37 67.38 0 Ue1(4-2)

5-3 159.70 159.62 14.4 Ue1(5-3)

5-4 167.37 167.38 0 Ue1(5-4)



Pout Records: 1MW INCR in bus 3 (load)Bus FlowsBUS 1 1 400.0 MW GENERATOR 1 180.20 0.0TO 2 2 1 192.48 0 0.0TO 3 3 1 60.81 0 0.0TO 5 5 1 -73.09 0 0.0

BUS 2 2 400.0 MW LOAD 1 260.00TO 1 1 1 -192.48 0 0.0TO 4 4 1 -67.52 0 0.0

BUS 3 3 400.0 MW LOAD 1 221.00TO 1 1 1 -60.81 0 0.0TO 5 5 1 -160.19 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.52 0 0.0TO 5 5 1 -167.52 0 0.0



BUS 2 2 400.0 MW LOAD 1 260.00TO 1 1 1 -192.62 0 0.0TO 4 4 1 -67.38 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.38 0 0.0TO 5 5 1 -159.62 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.38 0 0.0TO 5 5 1 -167.38 0 0.0


Line Marginal case

Base case

Ue3l

1-2 192.48 192.62 0 Ue3(1-2)

1-3 60.81 60.38 94.6 Ue3(1-3)

5-1 73.09 73.00 19.8 Ue3(5-1)

4-2 67.52 67.38 30.8 Ue3(4-2)

5-3 160.19 159.62 125.4 Ue3(5-3)

5-4 167.52 167.38 30.8 Ue3(5-4)




BUS 2 2 400.0 MW LOAD 1 260.00TO 1 1 1 -192.62 0 0.0TO 4 4 1 -67.38 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.38 0 0.0TO 5 5 1 -159.62 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.38 0 0.0TO 5 5 1 -167.38 0 0.0


Pout Records: 1MW INCR Bus 4Bus FlowsBUS 1 1 400.0 MW GENERATOR 1 180.00 0.0TO 2 2 1 193.01 0 0.0TO 3 3 1 60.23 0 0.0TO 5 5 1 -73.24 0 0.0

BUS 2 2 400.0 MW LOAD 1 260.00TO 1 1 1 -193.01 0 0.0TO 4 4 1 -66.99 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.23 0 0.0TO 5 5 1 -159.77 0 0.0

BUS 4 4 400.0 MW LOAD 1 101.00TO 2 2 1 66.99 0 0.0TO 5 5 1 -167.99 0 0.0

BUS 5 5 400.0 MW GENERATOR 1 401.00 0.0TO 1 1 1 73.24 0 0.0TO 3 3 1 159.77 0 0.0TO 4 4 1 167.99 0 0.0

Line Marginal case

Base case

Ue4l

1-2 193.01 192.62 39 Ue4(1-2)

1-3 60.23 60.38 0 Ue4(1-3)

5-1 73.24 73.00 24 Ue4(5-1)

4-2 66.99 67.38 0 Ue4(4-2)

5-3 159.77 159.62 15 Ue4(5-3)

5-4 167.99 167.38 61 Ue4(5-4)



Pout Records: bus 5 INCR 1MWBus FlowsBUS 1 1 400.0 MW GENERATOR 180.00 0.0TO 2 2 1 192.75 0 0.0TO 3 3 1 60.46 0 0.0TO 5 5 1 -73.22 0 0.0

BUS 2 2 400.0 MW LOAD 1 260.31TO 1 1 1 -192.75 0 0.0TO 4 4 1 -67.56 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.44TO 1 1 1 -60.46 0 0.0TO 5 5 1 -159.98 0 0.0

BUS 4 4 400.0 MW 1LOAD 1 100.25TO 2 2 1 67.56 0 0.0TO 5 5 1 -167.81 0 0.0

BUS 5 5 400.0 MW 1GENERATOR 401.00 0.0TO 1 1 1 73.22 0 0.0TO 3 3 1 159.98 0 0.0TO 4 4 1 167.81 0 0.0


BUS 2 2 400.0 MW LOAD 1 260.00TO 1 1 1 -192.62 0 0.0TO 4 4 1 -67.38 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -60.38 0 0.0TO 5 5 1 -159.62 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 67.38 0 0.0TO 5 5 1 -167.38 0 0.0


Line Marginal case

Base case

Ue4l

1-2 192.75 192.62 52 Ue5(1-2)

1-3 60.46 60.38 32 Ue5(1-3)

5-1 73.22 73.00 88 Ue5(5-1)

4-2 67.56 67.38 72 Ue5(4-2)

5-3 159.98 159.62 144 Ue5(5-3)

5-4 167.81 167.38 172 Ue5(5-4)


Marginal Participation Factor( of node i in line l):

Ueil / ∑i Ueil

Node/bus 1

Bus 2 Bus 3 Bus 4 Bus 5

Line

1-2

0.3346 0.4457 0 .0941 0.1255

1-3 0.1853 0 0.6088 0 0.2059

1-5 0 0.1783 0.1234 0.1496 0.5486

2-4 0 0.4231 0.1728 0 0.4040

3-5 0.0454 0.0574 0.3956 0.0473 0.4543

4-5 0 0.2223 0.0908 0.1798 0.5071

slack

Generator #1

Bus 1Bus 2

Bus 4

Bus 5

Bus 3

Line 1

Line 2Line 3

Line 4

Line 5Line 6

1

180 MW

0 Mvar

400 MW

0 Mvar

260 MW

0 Mvar

100 MW

0 Mvar

220 MW

0 Mvar

Zone A

Line Cost Information

Line from bus to bus length in KM Cost of line (in Crs)

1 1 2 160 160

2 2 4 112 112

3 1 5 200 200

4 1 3 80 80

5 3 5 152 152

6 4 5 99 99

Total=803 Cr

Line cost considered as 1 crore/km for indicative purposes only

Calculation of Uniform Charges

= Total Transmission Charges/(Sum of approved Injection+Sum of approved Withdrawal)

=803/(400+180+220+260+100)

=69.22 lakhs/MW

For bus 1 =(69.22*180)=125 Cr

For bus 2=(69.22*260) =180 Cr

For bus 3=(69.22*220) =152 Cr

For bus 4=(69.22*100) = 69 Cr

For bus 5=(69.22*400) =277 Cr

Cost allocation to nodes based on marginal participation

Nodes Marginal Participation case(Cost in Rs Cr)

Uniform Charges(Cost in Rs Cr)

50 % Marginal Participation 50% Uniform Charges

PoC ratesRs Lakh /MW/month

Node/Bus 1

75 125 100 4.62

Node/Bus 2

185 180 182.5 5.85

Node/Bus 3

162 152 157 5.95

Node/Bus 4

70 69 69.5 5.79

Node/Bus 5

311 277 294 6.13

Total 803 803 803

Generator shares

Generator

Loads

Generator Node 1% share

Generator Node 5% share

Load bus 2 10 50

Load bus 3 30 30

Load bus 4 60 20

Nodes

MP-Trace

UC 50 % MP & 50% UC

PoC ratesRs Lakh /MW /month

Monthly Charges to be paid Rs Lakhs/month based on share

Monthly Charges to be paid Rs Lakhs/month based on trace

Node/Bus 1

75 125 100 4.62(3.47)

Generator node

Node/Bus 2

185 180 182.5 5.85(5.93)

2830

2905

Node/Bus 3

162 152 157 5.95(6.14)

2294

2596

Node/Bus 4

70 69 69.5 5.79(5.83)

1568

1192

Node/Bus 5

311 277 294 6.13(6.48)

Generator node

Total 803 803 803Charges to be paid = own drawal*drawal PoC of node+share*generator capacity*injection PoC of generator bus(Figures in brackets are based on MP-Trace only)

Present Issues

• There is no internationally adopted best common method for allocation of transmission costs….. All methods have their pros & cons

• Worldwide a combination of methods is used for allocation such as postage stamp, marginal/nodal pricing, marginal participation, average participation, MW-Mile, peak based, game theory etc

• Requires not only technical expertise but also Econimics concepts such as marginal price, social welfare, etc

• While postage stamp method is the most easiest to understand, it does not capture the congestion costs.

• While marginal participation has some degree of technical backing it is complex to understand and implement

• Selection of slack bus/responding nodes in marginal participation is a contentious issue.

• While we are rightly concerned with congestion. What if there is over capacity/stranded assets in a corridor? What if the constructed lines remain lightly loaded for most part of the year due to error in planning or change in load generation scenario over time? What is the limit of reliability costs?

• In Flow based methods the base case load generation is very important….. More so when the tariff of assets vary widely

• 50 % Uniform charges distort the locational signals

• Slabbing further distorts the results of marginal participation

• Whether a generator/supplier or Load/Consumer is to be penalized for its geographical location?

-----generation zones are predetermined based on availability of resources

----load zones/industrial belts are also result of historical development, resource availability

• Whether generator or Consumer be penalized due to asymmetries in transmission network created during historical development of ISTS ?

Future Concerns

• Integration of Renewables in the Grid

---run of the river hydro, wind and solar run on very low PLF. However, transmission must be developed for entire capacity.

---higher transmission cost/unit due to low PLF which is not under the control of generator may result in disincentive for growth of renewables

• The issue of integration of renewables is being debated worldwide now

• Can such transmission projects be funded by Government under NAPCC?

Changes in Sharing Regulations contemplated in the third amendment regulations

• Transmission charges to be calculated based on peak scenario rather than average scenario

---In selecting those operating scenarios it is important to recognise that the operating conditions that impose most stress on particular network elements may occur at times other than for system peak demand.

• Discontinuation of uniform charges

• Discontinuation of slabbing

• Computation based on full basic network rather than truncated network

• Proportional compensation for use of state lines carrying interstate power

PoC charges under peak conditions

slack

Generator #1

Bus 1Bus 2

Bus 4

Bus 5

Bus 3

Line 1

Line 2Line 3

Line 4

Line 5Line 6

1

180 MW

0 Mvar

530 MW

0 Mvar

390 MW 0 Mvar

100 MW

0 Mvar

220 MW

0 Mvar

Pout Records: NEW BASE CASE::150% peak drawal at node/bus-2---supplied by generator node 5Bus FlowsBUS 1 1 400.0 MW GENERATOR 180.00 0.0TO 2 2 1 251.79 0 0.0TO 3 3 1 37.27 0 0.0TO 5 5 1 -109.06 0 0.0

BUS 2 2 400.0 MW LOAD 1 390.00TO 1 1 1 -251.79 0 0.0TO 4 4 1 -138.21 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -37.27 0 0.0TO 5 5 1 -182.73 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 138.21 0 0.0TO 5 5 1 -238.21 0 0.0


Load (bus 2)

Load (bus 3)

Load (bus 4)

Gen 1(bus1)

156.78 23.22 0

% 40 11 0

Gen 2(bus5)

232.74 197.26 100

% 60 89 100

Total 390 220 100

Pout Records: NEW BASE CASE::150% peak drawal at node/bus-2Bus FlowsBUS 1 1 400.0 MW GENERATOR 180.00 0.0TO 2 2 1 251.79 0 0.0TO 3 3 1 37.27 0 0.0TO 5 5 1 -109.06 0 0.0

BUS 2 2 400.0 MW LOAD 1 390.00TO 1 1 1 -251.79 0 0.0TO 4 4 1 -138.21 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -37.27 0 0.0TO 5 5 1 -182.73 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 138.21 0 0.0TO 5 5 1 -238.21 0 0.0


Pout Records:: INCR 1 MW at bus 1Bus FlowsBUS 1 1 400.0 MW GENERATOR 181.00 0.0TO 2 2 1 252.64 0 0.0TO 3 3 1 37.37 0 0.0TO 5 5 1 -109.01 0 0.0

BUS 2 2 400.0 MW LOAD 1 390.87TO 1 1 1 -252.64 0 0.0TO 4 4 1 -138.23 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.13TO 1 1 1 -37.37 0 0.0TO 5 5 1 -182.76 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 138.23 0 0.0TO 5 5 1 -238.23 0 0.0



BUS 2 2 400.0 MW LOAD 1 390.00TO 1 1 1 -251.79 0 0.0TO 4 4 1 -138.21 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -37.27 0 0.0TO 5 5 1 -182.73 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 138.21 0 0.0TO 5 5 1 -238.21 0 0.0


Pout Records:: INCR 1 MW at bus 2Bus FlowsBUS 1 1 400.0GENERATOR 180.40 0.0TO 2 2 1 252.44 0 0.0TO 3 3 1 37.17 0 0.0TO 5 5 1 -109.21 0 0.0

BUS 2 2 400.0 MWLOAD 1 391.00TO 1 1 1 -252.44 0 0.0TO 4 4 1 -138.56 0 0.0

BUS 3 3 400.0 MWLOAD 1 220.00TO 1 1 1 -37.17 0 0.0TO 5 5 1 -182.83 0 0.0

BUS 4 4 400.0 MWLOAD 1 100.00TO 2 2 1 138.56 0 0.0TO 5 5 1 -238.56 0 0.0

BUS 5 5 400.0 MWGENERATOR 530.60 0.0TO 1 1 1 109.21 0 0.0TO 3 3 1 182.83 0 0.0TO 4 4 1 238.56 0 0.0


BUS 2 2 400.0 MW LOAD 1 390.00TO 1 1 1 -251.79 0 0.0TO 4 4 1 -138.21 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -37.27 0 0.0TO 5 5 1 -182.73 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 138.21 0 0.0TO 5 5 1 -238.21 0 0.0


Pout Records:: 1 MW INCR at Bus 3Bus FlowsBUS 1 1 400.0 MW GENERATOR 1 180.11 0.0TO 2 2 1 251.61 0 0.0TO 3 3 1 37.68 0 0.0TO 5 5 1 -109.18 0 0.0

BUS 2 2 400.0 MW LOAD 1 390.00TO 1 1 1 -251.61 0 0.0TO 4 4 1 -138.39 0 0.0

BUS 3 3 400.0 MW LOAD 1 221.00TO 1 1 1 -37.68 0 0.0TO 5 5 1 -183.32 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 138.39 0 0.0TO 5 5 1 -238.39 0 0.0

BUS 5 5 400.0 MW GENERATOR 1 530.89 0.0TO 1 1 1 109.18 0 0.0TO 3 3 1 183.32 0 0.0TO 4 4 1 238.39 0 0.0


BUS 2 2 400.0 MW LOAD 1 390.00TO 1 1 1 -251.79 0 0.0TO 4 4 1 -138.21 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -37.27 0 0.0TO 5 5 1 -182.73 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 138.21 0 0.0TO 5 5 1 -238.21 0 0.0


Pout RecordsBus FlowsBUS 1 1 400.0 MWGENERATOR 1 180.00 0.0TO 2 2 1 252.19 0 0.0TO 3 3 1 37.11 0 0.0TO 5 5 1 -109.30 0 0.0

BUS 2 2 400.0 MWLOAD 1 390.00TO 1 1 1 -252.19 0 0.0TO 4 4 1 -137.81 0 0.0

BUS 3 3 400.0 MWLOAD 1 220.00TO 1 1 1 -37.11 0 0.0TO 5 5 1 -182.89 0 0.0

BUS 4 4 400.0 MWLOAD 1 101.00TO 2 2 1 137.81 0 0.0TO 5 5 1 -238.81 0 0.0



BUS 2 2 400.0 MW LOAD 1 390.00TO 1 1 1 -251.79 0 0.0TO 4 4 1 -138.21 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.00TO 1 1 1 -37.27 0 0.0TO 5 5 1 -182.73 0 0.0

BUS 4 4 400.0 MW LOAD 1 100.00TO 2 2 1 138.21 0 0.0TO 5 5 1 -238.21 0 0.0


Pout RecordsBus FlowsBUS 1 1 400.0 MW GENERATOR 1 180.00 0.0TO 2 2 1 251.98 0 0.0TO 3 3 1 37.30 0 0.0TO 5 5 1 -109.29 0 0.0

BUS 2 2 400.0 MW LOAD 1 390.44TO 1 1 1 -251.98 0 0.0TO 4 4 1 -138.46 0 0.0

BUS 3 3 400.0 MW LOAD 1 220.37TO 1 1 1 -37.30 0 0.0TO 5 5 1 -183.07 0 0.0

BUS 4 4 400.0 MWLOAD 1 100.19TO 2 2 1 138.46 0 0.0TO 5 5 1 -238.65 0 0.0


Node/bus 1

Bus 2 Bus 3 Bus 4 Bus 5

Line

1-2 0.280 0.463 0.000 0.073 0.1841-3

0.145 0.000 0.727 0.000 0.1281-5

0.000 0.253 0.114 0.104 0.5282-4

0.012 0.437 0.127 0.000 0.4243-5

0.015 0.105 0.350 0.043 0.4874-5

0.008 0.289 0.084 0.127 0.493

Marginal Line Participation Factors peak case and earlier/average case for line 1--2

Total charges allocated to nodes peak case earlier case

Tabulated data for earlier case and peak case

Node Earlier cost allocated to node

Peak scenario cost

% change

Earlier cost/ Lakh/MW/monthMP

Earlier cost/ Lakh/MW/monthMP+UC

Peak Scenario cost/ Lakh/MW/month

1 75 61 18.66 3.47 4.62 2.82

2 185 218 17.83 5.93 5.85 4.66

3 162 157 3.08 6.14 5.95 5.94

4 70 51 27.14 5.83 5.79 4.25

5 311 316 1.61 6.48 6.13 4.97

While the load at bus 2 had increased 1.5 times the total cost allocated to the node has increased only 1.18 times( 1.19 for MP+UC)cost/MW/Month will go down (as MW increased). New entrants/ST customers incentivizedCharges allocated to a node will change only if due to it flow in different lines change. Otherwise the charge may remain same under peak scenario also. May also reduce.

From CERC sharing of ISTS charges (third amendment) draft

TABLE 2

DIC Withdrawal/Load PoC Charges

Scaled PoC Charges

X 45,79,42,697 50,45,52,461

Y 18,96,39,554 20,89,41215

TABLE 3Zone Uniform Charges

(UC)\(Rs./Month)=Uniform Rate*LTA

Scaled PoC

Charges

Rs/Month

50% UC and

50% PoC

Rs./Month

LTA (MW) Withdrawal

Charges

(Rs/MW/Month)

X 25,22,12,087 50,45,52,461 37,83,82,274 2,668 1,41,822

Y 16,44,90,088 20,89,41,215 18,66,46,847 1,741 1,07,280

50.46/20.89= 2.42 ; 37.84/18.66 = 2.07

TABLE- 4

DICDrawal

(MW)

LTA

(MW)Slab Rate

(Rs/MW/Month)

Actual Usage

(Rs/ Month)

Payment

(Rs/ Month) Variation

X 4989 2668 1,09,544 45,79,42,697 29,22,63,392 (-) 36.2%

Y 1414 1741 1,09,544 18,96,39,554 19,07,16,104 0.56%

50.46/20.89= 2.42 ; 37.84/18.66 = 2.07 ; 29.23/19.07 = 1.53 ??

TABLE-5

Zone Generation

(MW)Load (MW)

Generation Charges

(Rs.)

Load Charges

(MW)

LTA (Generation)

(MW)

LTA (Demand)

(MW)

Generation PoC

(Rs./MW/

Month)

Load PoC

(Rs./MW/

Month)

(1) (2) (3) (4) (5) (6) (7) (8) (9)

Z 19429

2916016,64,638

2,160,51,386

280 4784 5945 45166

TABLE-6

Zone

Generation PoC

(Rs./MW/

Month)

Load PoC

(Rs./MW/

Month)

Generation PoC

(Rs./MW/

Month)

Load PoC

(Rs./MW/

Month)

Generation PoC

(Rs./MW/

Month)

Load PoC

(Rs./MW/

Month)

Generation PoC

(Rs./MW/

Month)

Load PoC

(Rs./MW/

Month)

Software Computed LTA BasedAfter 50% Uniform

charge and 50% PoC application

After Slabs

Z 8,594 74,229 5,945 45,166 50,547 72,154 79,544 79,544

TABLE-7

Sl.No. State /DIC % Allocation

1 BIHAR 42.89%

2 JHARKHAND 8.13%

3 DVC 0.31%

4 ODISHA 31.8% plus temp allocation

5 WEST BENGAL 9.1% plus temp allocation

6 SIKKIM 2.4

7 TAMIL NADU 0.85%

8 NER 3.22%

TABLE-8

Sl.No. State /DIC % as per participation factor

1 ODISHA 82.97

3 DVC 12.1

5 WEST BENGAL 4.93

Thank you

Documents

Point of Connection Methodology for Sharing of Transmission Charges