Breakdown of consumer surplus and supplier surplus per bidding area
Consumer and surplus breakdown are given as yearly totals in Euro (€) in each Run. Yearly totals are the sum over the 363 days of result, except when the bidding area exists less days in the result data set (then yearly totals cover the period it exists only).
The following table shows the breakdown of producer surplus per bidding area.
Example. In Run#1, the yearly total producer surplus of FR is € 54 111 493 326; this value depends on the price in supply curve (especially price taking orders) and on the market clearing price: in itself, this absolute value should not lead to any interpretation; what can be analyzed is the variation of this surplus in the
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The following table shows the breakdown of consumer surplus per bidding area.
Consumer
The following table shows the breakdown of total surplus per bidding area (sum of consumer and supplier surplus).
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Congestion rent breakdowns are given as yearly totals in Euro (€) in each Run. Yearly totals are the sum over the 363 days of result, except when the interconnector exists less days in the result data set (then yearly totals cover the period it exists only).
The congestion rents below are calculated on the basis of unrounded prices and flows; then they do not exactly correspond to effective congestion rents which would result from the operational coupling process.
The Net Congestion Rent is split into a positive and a negative part: the sum of these two parts might not be exactly equal to the Net Congestion Rent because of rounding (calculated figures have decimals, whereas figures below are rounded).
Below are the yearly totals of gross congestion rent for each interconnector.
Example. DE-DK2 is subject to ramping constraints and has losses included (for some runs); in Run#1, the yearly total gross congestion rent is € 18 718 028.
Total Gross
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Table 18: Total Gross Congestion Rent Below are the yearly totals of Net Congestion Rent for each interconnector.
Total Net
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Table 19: Total Net Congestion Rent
Below are the yearly totals of the Positive part of Net Congestion Rent for each interconnector.
Example. In Run#1, the sum of DE-FR congestion rent over hours when this congestion rent is positive
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Table 20: Positive Net Congestion Rent
Below are the yearly totals of the Negative part of Net Congestion Rent for each interconnector.
Example. In Run#1, the sum of DE-FR congestion rent over hours when this congestion rent is negative amounts to 0€; which is expected since no adverse flow occurs on this interconnection.
Negative Net
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Table 21: Negative Net Congestion Rent
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Flow Result Table
The table below shows flow indicators (totals over the sample results i.e. 363 days for most interconnections). Flows are in MW (but can be seen as energy in MWh if we consider that flow values are hourly values). Number of hours is non-dimensional indicators.
In the table below, an interconnection is always defined by two bidding areas bd1 and bd2; by definition, the up direction is from bd1 to bd2 and the down direction is from bd2 to bd1 (this definition is arbitrary and does not change the conclusions which can be derived from the results).
Example. SE-FI has a direction up which is from SE to FI; and a direction down which is from SE to FI. In Run#3, the yearly total (counted over hours the interconnection exists i.e. here until Oct 31) of flow SE->FI over hours when the direction up (SE->FI) is not congested amounts to 240 085MW “in” (i.e. seen from the sending end side i.e. from SE) and to 234 323MW “out” (i.e. seen from the receiving end side i.e. from FI).
In Run#3, the direction SE->FI is congested during 1656 hours; 856 hours have the direction up not congested although the SE price is lower than the FI price; 4068 hours experience a reduction of sending end flow SE->FI or FI->SE compared to Run#1; in 2568 hours, this reduction is a reduction down to zero.
Example. In Run#1, the interconnection DK1A-DK1 experience 318 hours with an increase of flow which is equal to the up constraint; and 261 hours with a decrease of flow which is equal to the ramping-down constraint. The yearly total of flow DK1->DK1A over hours when the direction ramping-down (DK1->DK1A) is congested amounts to 113 400MW (seen both from DK1 sending end or DK1A receiving end).
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LINE RUN UPIN-NCG UPOUT-NCG DOWNIN-NCG
DOWNOUT-NCG UPIN-CG UPOUT-CG DOWNIN-CG
DOWNOUT-CG
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37 Flows on this interconnection are forced to a given value (possibly zero) every hour by means of negative ATCs; non-relevant figures are greyed.
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38 Low values of flows in the up direction (from NO3 to NO4) are due to frequent zero up capacity; non-relevant figures are greyed.
39 Capacities up (from EE to ELI) are always zero; which artificially makes the line congested in the up direction; non-relevant figures are greyed.
40 Capacities down (from ELE to EE) are always zero; which artificially makes the line congested in the down direction; non-relevant figures are greyed.
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41 The FI-NO4 interconnection exists in the data but always with zero capacities up and down; non-relevant data are greyed.
42 Capacities are sometimes zero; which artificially makes the line congested; non-relevant figures are greyed.
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Net Position Table
The table below shows the yearly sum of net positions in MWh for each bidding area. The Total Pos NP (resp. Total Neg NP) represents the total exporting (resp. importing) net position over hours which have an exporting (resp. importing) net position. The Total NP represents the sum of exporting and importing net positions: it is positive (resp. negative) when yearly net position is exporting (resp. negative).
The table allows seeing whether a bidding area is exporting or importing on a yearly basis because it follows the same trend every hour or because exporting and importing net positions are balanced over the year.
Example. In Run#1, the sum over hours when FR is exporting amounts to 11 672 025MWh exporting exchanges; similarly, FR imports 4 491 516MWh over the other hours. The total yearly exchange amounts to an exporting net position of 7 180 509MWh; FR exports 11 004 354MWh to other CWE bidding areas and imports 4 438 647MWh from other CWE bidding areas.
BIDDINGAREA Net Position RUN#1 RUN#2 RUN#3 RUN#4 RUN#5
FR
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Price Convergence Table - Price Convergence at the ends of interconnectors
Example. In Run#1, prices in SEA and DK2 are equal in 3436 hours; which represents 47.41% of the hours which both bidding areas exist.
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80 Table of Hourly Price Variations for each Run compared to Run#1
Run#2 compared to Run#1
Example. In Run#2, in FR, at least one hour experiences a decrease of price compared to Run #1 which amounts to € 4.7582 in absolute value; this amount is the minimum absolute variation which is observed.
At least one hour experiences an increase of price compared to Run#1 which amounts to € 3.6144, which is the maximum absolute variation which is observed. On average, in the same given hour, prices in Run#2 are greater of € 0.0096 than in Run#1. In 98% of hours, the change in price in Run#2 compared to Run#1 remains between -€ 1.0473 and € 1.1069.
Bidding
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Table 27: Run#4 compared to Run#1 Run#5 compared to Run#1
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DK1A 0.0070 0.5132 -2.1546 24.6223 0.0000 -0.8467 0.8715
SE -0.0053 0.1529 -1.5208 2.8118 0.0000 -0.6585 0.4413
SEA -0.0037 0.1505 -1.5208 2.8118 0.0000 -0.6254 0.4668
FI -0.0013 0.1697 -1.5208 5.7168 0.0000 -0.5501 0.4063
NO1 -0.0032 0.1074 -1.5208 1.9401 0.0000 -0.4219 0.3064 NO2 -0.0047 0.1068 -1.5208 1.9401 0.0000 -0.4228 0.2927 NO3 -0.0054 0.1329 -1.5208 2.8118 0.0000 -0.5588 0.3524 NO4 -0.0053 0.1305 -1.5208 2.8118 0.0000 -0.5509 0.3383 NO5 -0.0010 0.0992 -1.5208 1.9401 0.0000 -0.3693 0.2914
PL -0.0178 0.1777 -5.4838 2.2575 0.0000 -0.8458 0.2100
GB 0.0669 0.6740 -8.4873 10.5338 0.0018 -1.3874 1.4774
BE 0.0006 0.3397 -4.7582 2.5685 0.0000 -1.0257 1.0663
NL 0.0243 0.3951 -3.5224 5.6074 0.0000 -1.0509 1.2244
Table 28: Run#5 compared to Run#1
Graphs of Hourly Price Variations for each Run compared to Run#1 – per bidding area
Example. In Run#2, in FR, at least one hour experiences a decrease of price compared to Run #1 which amounts to € 4.758 in absolute value; this amount is the minimum absolute variation which is observed. At least one hour experiences an increase of price compared to Run#1 which amounts to € 3.614, which is the maximum absolute variation which is observed. On average, in the same given hour, prices in Run#2 are greater of € 0.01 than in Run#1. In 98% of hours, the change in price in Run#2 compared to Run#1 remains between -€ 1.047and € 1.107. Almost 3500 hours experience a price change around 0€ in Run#2 compared to Run#1. The distribution of price changes does not look as a normal distribution.
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Tables of Price Differences – Number of hours the relative price difference is greater / equal / lower than the loss factor whereas it was lower than the loss factor in the reference Run#1
Number of hours which have a relative price difference in Run#1 lower than loss factor and in current Run greater than loss factor:
Example. Between NL-NO2, 94 hours experience a price difference in Run#2 which is greater than Run#2 loss factor (i.e. 2%), whereas the price difference in Run#1 is lower than Run#2 loss factor (i.e. 2%). These hours represent 5.90% of hours which have a price difference in Run#1 lower than Run#2 loss factor (i.e.
2%).
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Number of hours which have a relative price difference in Run#1 lower than loss factor and in current Run equal to loss factor:
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Number of hours which have a relative price difference in Run#1 lower than loss factor and in current Run still lower than loss factor:
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