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  Power System Reliability Program

EDSA’s Power System Reliability program uses the state enumeration approach to assess the adequacy of generation and distribution/transmission facilities.
   
  The program enumerates and examines a list of contingencies that cause the outage of generating units and/or lines/cables or transformers. For each contingency, the power system state is examined using a power flow to identify the system deficiencies and assess the effects of remedial actions
   
 
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Program User Interface
 
   
  Reliability analysis of power systems is based on a structure that divides the system into three functional regions, i.e., generation, transmission, and distribution. The ability to generate sufficient power to satisfy the loads and to transport it without violating the power system operational constraints can be measured by one or more reliability indices. Power system reliability, both deterministic and probabilistic, can be divided into two basic categories: system adequacy and system security. Adequacy relates to the existence of sufficient generation, transmission and distribution facilities within the power system to satisfy the loads. Adequacy is associated with static conditions that do not include system disturbances.
   
  The program has been successfully used for evaluating the adequacy indices of power systems containing several thousand buses The current release is constrained to adequacy considerations only; even with this constraint, planning and operating decisions can be improved considerably with the additional quantitative information derived from adequacy assessments.
   

 
     
    Key Program Features:
     
  • Unlimited buses;
  • User friendly interface and easy to use;
  • The program can consider overlapping independent outages up to the following levels:
    o Third level of branch contingencies (outages of one, two or three branches at a time)
    o Fourth level of generator contingencies (loss of one, two, three or four units at a time)
    o Third level of combined branch and generator contingencies. This includes one generator and one branch, two generators and one branch and one generator and two branches
  • The reliability indices can be computed using either a single load level or a multi-step load duration curve.
  • Three power flow techniques can be used (network transport flow, DC powerflow, and AC power flow)
  • The remedial actions include:
    o Phase-shifter adjustments;
    o Generator rescheduling;
    o Reactive power injection;
    o Load shedding. A combination of aforementioned actions is used to alleviate branch overloads, capacity deficiencies and voltage violations.
  • The reliability study can be conducted for the entire system or for a select part of the system.
  • Extensive report facilities allow the user to produce a wide range of reports for summarizing the reliability indices (buses, branches, and the entire system).
  • The load outage costs at individual load buses and for the entire system
  • To minimize the number of possible contingencies, the following are used:
    o A contingency ranking algorithm is used to select those contingencies that have a significant impact on the system.
    o Ignoring contingencies having extremely small frequency of occurrence (less than a user-defined frequency cut-off limit)
    o Identical generating unit contingencies are recognized and analyzed only once.
  • The program can be used to create a bus summary, a branch summary and a system summary as individual reports.
  • The voltage violation indices can also be calculated. The indices are calculated before and after the reactive power injection together with the amount of injection required at each bus.
  • The customer outage costs at each load bus and for the whole system are calculated
  • The expected reliability indices, the maximum and average values of these indices can be calculated
     
     
     
 
     
     
 
     
     
 
     
     
 
     
     
 
   
 
     
    The program computes:
     
  • System indices:
    o System expected indices;
    o System maximum indices;
    o System average indices;
  • Branch indices:
    o Branch expected overload;
    o Branch maximum overload;
    o Branch average overload;
  • Bus indices:
    o Bus availability checking;
    o Bus expected indices;
    o Bus voltage violation;
    o Bus outage cost indices;
    o Bus maximum load curtailed;
    o Bus maximum energy curtailed;
    oTo Bus maximum duration;
    o Bus maximum MVAR injection;
    o Bus maximum outage cost;
    o Bus average indices.
     
 
   

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