Congestion management: Re-dispatch and application of FACTS
Congestion management: Re-dispatch and application of FACTS
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拥塞管理：重新调度和FACTS的应用
DOI：
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发表时间：
2006
期刊：
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通讯作者：
M. Tran
中科院分区：
文献类型：
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作者：
M. Tran
本文研究了多个节点的传输拥塞问题，
在放松管制的电力市场交易。两种拥塞管理方法
（重新调度和灵活交流输电系统（FACTS）的应用）已被
研究了三种市场模式（联营、双边和混合）。最佳
电力潮流（OPF）框架已被用来模拟所考虑的市场模型
以及交通堵塞问题。IEEE 14总线和CIGRE 32总线测试系统具有
被用来证明方法的鲁棒性。拥堵的目标
在不同的市场中，管理是不同的。在池市场中，目标函数
最小化重新调度的功率量。在双边市场上，
最小化交易偏差被认为是目标。在混合模型中，
目标函数是两个方面，最小化池重新调度和最小化
双边合同的偏差。此外，最小化成本的目标
在所有的市场模型中，都应用了拥塞的概念。使用串联FACTS装置，
缓解拥塞也得到了证实。
在联营市场中，阻塞需要重新调度发电，因此偏离
市场结算。已经表明，重新调度增加了系统成本，因为
绩效外发电机的参与比预定的要多。最大限度地减少再派遣
因此，在池中确保偏离经济解决方案
市场被最小化。在双边市场上，利益是保持所需的
缔约方之间的交易。以解决这个市场出现的拥挤问题
模型中，重新调度的事务被迫尽可能接近预定的事务
越好.对合同的修改是非歧视性的，因此只有
对拥塞的影响进行了修改。为了满足负载要求，电源必须
由市场调节供给。在混合市场模型中，加权因子为
在池和双边重新调度之间使用。游泳池可以重新分配更多
与交易相反，反之亦然，这取决于加权因子。
已经发现，当FACTS被包括在网络中时，
池中的功率大大降低，从而产生最佳操作点
更接近于市场结算所决定的水平。在双边市场，结果显示，
当我们有事实时，交易可能不需要修改。的成本
当采用FACTS时，对ISO的拥塞也减少。为了证明使用
关于阻塞管理，一个简单的成本效益分析，
当FACTS的好处被认为是避免拥堵成本时，
否则系统将不得不承受的压力。
由此产生的重新调度发电计划是最佳的，只要拥挤是
在正常操作条件下，即，N-0应急。班期为
因此在N-1标准下进行了安全性测试。应急案例
使用过载指数和由过载引起的总功率违规来模拟和排名。
停电。一个直流潮流和线路停电分布系数已被用于测试
各种应急条件下的系统行为。DC和AC的比较
潮流计算结果表明，平均绝对误差较小。
This thesis deals with the transmission congestion problem arising from multiple
transactions in deregulated electricity markets. Two congestion management approaches
(re-dispatch and the application of Flexible ac transmission systems (FACTS)) have been
studied in three market models (pool, bilateral and the combined (hybrid)). An optimal
power flow (OPF) framework has been used to simulate the considered market models
and the congestion problems. The IEEE 14-bus and the CIGRE 32-bus test systems have
been used to demonstrate the robustness of the approaches. The objectives of congestion
management are different in different market. In the pool market, the objective function
is the minimisation of the amount of re-dispatched power. In the bilateral market,
minimising the transaction deviations is considered as the objective. In the hybrid model,
the objective function is two pronged, minimising the pool re-dispatch and minimisation
of deviations of the bilateral contracts. Furthermore, the objective of minimising the cost
of congestion is applied in all the market models. The use of series FACTS devices to
alleviate congestion is also demonstrated.
In the pool market, congestion requires re-dispatch of generation hence deviating from
the market settlement. It has been shown that re-dispatch increases the system cost since
the out of merit generators are involved more than scheduled. The minimisation of redispatch
in the pool therefore ensures that the deviation from the economical settlement
of the market is minimised. In the bilateral market, the interest is to maintain the desired
transactions between contracting parties. To solve the arising congestion in this market
model, the rescheduled transactions are forced to be as close to the scheduled transactions
as possible. The changes to contracts are non-discriminatory, hence only contracts that
affect the congestion are modified. In order to meet the load requirements, power has to
be supplied from the regulation market. In the hybrid market model, a weighting factor is
used between the pool and bilateral re-dispatch. The pool could be re-dispatched more
than the transactions and vice versa, depending on the weighting factor.
It has been found that when FACTS are included in the network, the amount of redispatched
power in the pool is greatly reduced resulting in an optimal operating point
closer to that dictated by the market settlement. In the bilateral market, the results show
that the transactions may not need to be modified when we have FACTS. The cost of
congestion to the ISO also reduces when FACTS are employed. In order to justify the use
of FACTS with regards to congestion management, a simple cost benefit analysis has
been proposed where the benefit from FACTS is considered as avoided congestion costs
that the system would have to bear otherwise.
The resulting re-dispatched generation schedules are only optimal as far as congestion is
concerned under normal operating conditions i.e., N-0 contingency. The schedule is
therefore tested for security under the N-1 criterion. The contingency cases have been
simulated and ranked using an overload index and total power violations arising from the
outages. A dc load flow and line outage distribution factors have been used for testing
system behaviours under various contingency conditions. A comparison of the dc and ac
load flow methods has been made and the results indicate a small average absolute error.