Wednesday, 23 February 2011
Market Outcomes: South Australia experienced several negative energy prices for trading intervals (TIs) ending 0330 hrs to 0500 hrs on Wednesday 23 February 2011, recording a minimum price of -$550.92 per MWh for TI ending 0400 hrs.
Frequency Control Ancillary Services (FCAS) prices for South Australia and FCAS and energy prices for the other NEM regions were not affected.
Principal Contributors: The South Australian demand was less than 1350 MW with between 1749 MW and 2109 MW of generation capacity in South Australia offered in negative price bands and substantial wind generation of up to 713 MW.
Flow into Victoria on the Murraylink and Heywood interconnectors combined was approximately 580 MW, the maximum transfer limit for the two interconnectors for transfer into Victoria.
With excess generation capacity in South Australia, negatively priced generation offers set the price for a number of dispatch intervals during the affected TIs.
Market Performance: Outcomes appear to be consistent with the dispatch offers and power system conditions during the event.
Saturday, 5 February 2011
Market Outcomes: New South Wales experienced an energy price of $2,149.59 per MWh for the trading interval (TI) ending 1600 hrs. Victoria and South Australia experienced energy prices of ‑$141.61 per MWh and -$153.18 per MWh for TI ending 1600 hrs.
In a separate incident South Australia recorded energy prices of -$41.24 per MWh for TI ending 1400 hrs.
Energy prices for Tasmania and Queensland and Frequency Control Ancillary Services (FCAS) prices for the all NEM regions were not affected.
Principal Contributors: New South Wales experienced a price of $12,500 per MWh for dispatch interval (DI) ending 1540 hrs. Victoria and South Australia experienced negative 5 minute prices of -$921.93 per MWh and -$1,000 per MWh respectively for DI ending 1540 hrs.
During DI ending 1540 hrs a constraint equation, managing the post-contingent overload of the Marulan–Dapto no 8 on trip of Marulan–Avon no 16 330 kV line, violated due to a significant change in dynamic rating of the Marulan–Dapto no 8 line.
The constraint equation constrained off approximately 285 MW of generation capacity in New South Wales and reduced the interconnector flows from Queensland to New South Wales and from Victoria to New South Wales. Generation offers in higher price bands in New South Wales were dispatched for DI ending 1540 hrs when lower priced generation was limited by the ramp-up rate of change or was constrained off. South Australia and Victoria experienced negative prices for DI ending 1540 when the negative price bands could not be cleared in full due to the reduced interconnector transfer from Victoria to New South Wales (the target flow reduced from 1073 MW to 35 MW).
In an unrelated event South Australia recorded a negative price of -$41.24 per MWh for TI ending 1400 hrs. From dispatch interval ending 1355 hrs more than 1,850 MW of generation capacity in South Australia was offered in negative price bands, when the South Australian demand was approximately 1,500 MW. Interconnector flow to Victoria was limited to 172 MW and 92 MW during DIs ending 1355 hrs and 1400 hrs, when the negative 5-minute prices were recorded. The region experienced negative energy prices when the negative price bands could not be cleared in full.
Market Performance: Outcomes appear to be consistent with the dispatch offers and power system conditions during the event.
Friday, 4 February 2011
Market Outcomes: New South Wales experienced high energy prices from trading intervals (TIs) ending 1200 hrs to 1530 hrs with a maximum price of $1,686.58 per MWh in TI ending 1200 hrs. Queensland experienced high energy prices TIs ending 1200 hrs to 1500 hrs with a maximum price of $1,663.09 per MWh in TI 1200 hrs.
Energy prices for Victoria, Tasmania and South Australia and Frequency Control Ancillary Services (FCAS) prices for the all NEM regions were not affected.
Principal Contributors: New South Wales experienced high energy demand reaching 13,833 MW for TI ending 1530 hrs. Queensland experienced high energy demand of 7,884 MW for TI ending 1500 hrs.
New South Wales experienced 5-minute prices of $8,664.42 per MWh and $6,961.97 per MWh, and Queensland experienced 5-minute prices of $8,538.55 per MWh and $435.93 per MWh in dispatch intervals (DIs) ending 1150 hrs and 1445 hrs respectively. Without these price spikes, New South Wales 5-minute prices averaged around $300 per MWh from dispatch intervals (DIs) 1135 hrs to 1530 hrs, and Queensland 5-minute prices averaged around $270 per MWh from DIs 1135 hrs to 1500 hrs.
Queensland and New South Wales demand increased by 77 MW and 67 MW respectively during DI 1150 hrs, whilst a New South Wales generating unit reduced its availability by 80 MW. A constraint equation, managing the post-contingent overload of the Upper Tumut–Canberra 330 kV line on trip of the Lower Tumut–Canberra 330 kV line, reduced the transfer on the VIC-NSW interconnector from 1137 MW to 524 MW for DI ending 1150 hrs and constrained off 15 MW of generation in New South Wales. As a result, generation offers in higher price bands in New South Wales and Queensland were dispatched for DI 1150 hrs.
During DI ending 1445 hrs a constraint equation, managing the post-contingent overload of the Marulan–Avon (16) 330 kV line on trip of Marulan–Dapto (8) line 330 kV line, constrained off approximately 230 MW of generation capacity in New South Wales. An additional 660 MW of generation capacity was offered at -$1,000 per MWh causing the binding constraint to reduce transfer on the VIC-NSW interconnector from 379 MW to 191 MW. Generation offers in higher price bands in New South Wales were dispatched for DI ending 1445 hrs when lower priced generation was either fully cleared or constrained off.
Market Performance: Outcomes appear to be consistent with the dispatch offers and power system conditions during the event.
Thursday, 3 February 2011
Market Outcomes: New South Wales experienced high energy prices from trading intervals (TIs) ending 1400 hrs to 1630 hrs with a maximum price of $2968.96 per MWh in TI ending 1430 hrs. Queensland experienced high energy prices from TIs ending 1400 hrs to 1530 hrs with a maximum price of $662.31 per MWh in TI ending 1430 hrs.
Energy prices for Victoria, Tasmania and South Australia and Frequency Control Ancillary Services (FCAS) prices for the all NEM regions were not affected.
Lack of Reserve Level 1 (LOR1) was declared for New South Wales from 1350 hrs to 1610 hrs (Market Notices 34358 and 34360).
In a separate incident Tasmania experienced negative energy prices from trading intervals (TIs) ending 1030 hrs to 1300 hrs with a minimum price of -$104.31 per MWh in TI ending 1030 hrs.
Principal Contributors: New South Wales experienced high energy demand of 14502 MW for TI ending 1600 hrs. The maximum temperature at Bankstown Airport was 36.40 at 1500 hrs. Queensland experienced high energy demand of 7647 MW for TI ending 1630 hrs.
Interconnector flows from Queensland and Victoria to New South Wales were limited to an average of 1214 MW and 338 MW respectively during the period.
High-priced energy offers were cleared in New South Wales and Queensland when all lower price tranches were fully dispatched.
Prices for New South Wales and Queensland returned to normal levels as the demand reduced.
In Tasmania, from dispatch interval ending 0955 hrs more than 1600 MW of generation capacity in Tasmania was offered in negative price bands. The region experienced negative energy prices when the negative price bands could not be cleared in full.
Market Performance: Outcomes appear to be consistent with the dispatch offers and power system conditions during the event.
Wednesday, 2 February 2011
Market Outcomes: New South Wales experienced high energy prices from trading intervals (TIs) ending 1230 hrs to 1630 hrs with a maximum price of $10417.07 per MWh in TI ending 1530 hrs. Queensland experienced high energy prices from TIs ending 1230 hrs to 1630 hrs with a maximum price of $9043.67 per MWh in TI ending 1600 hrs.
Energy prices for South Australia and Victoria exceeded $200 per MWh from TIs 1600 hrs to 1700 hrs during the afternoon demand peak. Tasmania and Frequency Control Ancillary Services (FCAS) prices for the all NEM regions were not affected.
Lack of Reserve Level 1 (LOR1) was declared for New South Wales from 1425 hrs to 1635 hrs (Market Notices 34327 and 34330).
Principal Contributors: New South Wales experienced high energy demand of 14450 MW for TI ending 1600 hrs. Queensland experienced high energy demand of 7940 MW for TI ending 1430 hrs.
Interconnector flows from Queensland and Victoria to New South Wales were limited to an average of 891 MW and 400 MW respectively during the period.
High-priced energy offers were cleared in New South Wales and Queensland when all lower price tranches were fully dispatched.
Prices returned to normal levels as the demand reduced.
Market Performance: Outcomes appear to be consistent with the dispatch offers and power system conditions during the event.
Tuesday, 1 February 2011
Market Outcomes: New South Wales experienced high energy prices from trading intervals (TIs) ending 1230 hrs to 1630 hrs with a maximum price of $12136.17 per MWh in TI ending 1600 hrs. Victoria experienced high energy prices from TIs ending 1200 hrs to 1400 hrs with a maximum price of $5332.68 per MWh in TI ending 1330 hrs. Queensland experienced high energy prices from TIs ending 1300 hrs to 1630 hrs with a maximum price of $7349.99 per MWh in TI ending 1600 hrs.
Energy prices for South Australia and Tasmania, and Frequency Control Ancillary Services (FCAS) prices for the all NEM regions were not affected.
Lack of Reserve Level 1 (LOR1) was declared for Victoria from 1140 hrs to 1235 hrs (refer to Market Notices 34299 and 34303), and for New South Wales from 1500 hrs to 1805 hrs (Market Notices 34305 and 34310).
Principal Contributors: New South Wales experienced a record energy demand of 14744 MW for TI ending 1630 hrs (the previous record was 14101 MW on 6 February 2009). The maximum temperature at Bankstown Airport was 41.30C at 1500 hrs. The demand in Victoria reached 9914 MW for TI 1230 hrs. The maximum temperature in Melbourne was 39.40 at 1300 hrs.
Expensive energy offers were cleared in New South Wales, Victoria and Queensland when all lower price tranches were fully dispatched.
Prices returned to normal levels as the demand reduced.
Market Performance: Outcomes appear to be consistent with the dispatch offers and power system conditions during the event.
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