Optimization 
Optimization in EOPS is obtained through the calculation of incremental water values in a single-reservoir model of the system with the help of Stochastic Dynamic Programming. 

Once the water values are calculated, a detailed simulation is performed, with all relevant details modelled. 

Under simulation, an advanced, rule-based drawdown strategy is used to decide a best possible allocation of water between individual reservoirs. 
 
Running Modes 
EOPS may run in two essentially different modes: 

• Isolated mode: all relevant parts of the power system are modelled. An internal “market clearing price” will primarily depend on marginal costs of thermal power, dual fuel boilers or curtailment costs. This mode is well suited for systems of limited size, that operate in isolation, or that are mainly exchanging firm power or fixed price occasional power with other areas. 
• Market mode: the system under consideration is connected to a power market. Price on this market are exogenously given, e.g. by calculation with EMPS. This mode will be used in deregulated systems, or in systems with a lot of “operational interaction”. 

Detailed Hydro Module Description - Each module is desribled by:

• A reservoir 
• Storable and non-storable inflow 
• Waterways for overflow, bypass and plant discharge 
• A powerplant 
• Constraints on reservoir storage and water flow 

Hundreds of plants in the same or different river - basins may be modelled within the same system

Some tasks EOPS may perform: 

• Long-term operational scheduling of hydropower 
• Maintenance planning decisions  
• Probability distribution of production potential 
• Thermal power generation and availability of surplus power 
• Analysis of overflow losses 
• Reservoir operation 
• Additional import from other areas 
• Possibility of exports 
• Analysis of energy shortages 
• Benefits of investing in flexible demand (e.g. dual fuel boilers) 
• Probability distribution of operational costs 
• Calculation of market clearing prices in isolated systems 
• Risk management   

Simulated utilization of flexible demand and thermal production  
 
Simulated “total reservoir” operation 

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