Abstract: Apparatus and methods are disclosed for solving Mixed Integer Programming (MIP) problems, such as Security Constrained Unit Commitment (SCUC) problems used by power grid authorities to perform day-ahead market clearing. In certain examples, a plurality of threads of a software tool implementing a concurrent optimizer can be executed concurrently and sequentially to generate new solutions to a SCUC problem for an upcoming planning horizon. Data can be shared among the concurrently executing threads, such as intermediate/incumbent solutions and hints regarding the fixing of variables and constraints to reduce the size of the SCUC problem. In some examples, the threads are seeded with historical solutions from prior planning horizons. The software tool can select a best solution from the solutions generated by the threads, and determine dispatch instructions for a device coupled to the power grid for the upcoming planning horizon based at least in part on the selected solution.

Abstract: A method, system and computer-readable medium of directed towards improving battery storage is provided. In some embodiments, battery storage formulations are provided and an impact of the constraints on the computational performance of security constrained unit commitment (SCUC) is determined. For example, binary variables may be generally required due to mutual exclusiveness of charging and discharging modes. In some embodiments, valid inequalities may be used to improve state of charge (SOC) constraints. Adding batteries to the Regional Transmission Organizations (RTOs)/Independent System Operators (ISOs) day ahead market clearing cases may reveal an impact of binary variables and the valid inequalities on SCUC solving time. Warm start and lazy constraint techniques may be applied to improve the performance and make the valid inequalities more effective, reducing computation time to acceptable levels for implementation.

Abstract: The present disclosure pertains to a system that may be configured to operate a power grid, including generation participants, consumers, and a controller that administers a market for the power generation participants and the consumers on the power grid. The operation of the power grid may include: performing power grid coordination calculations based upon, at least in part, constraints that pertain to the flow and/or congestion of power on the grid; and managing the coordination calculations by reducing a number of constraints used in the coordination calculations, the managing including a first step of coarse screening of the constraints, a second step of deterministic fine screening of the constraints, and a third step of statistical fine screening of the constraints. This second step may cause identification of constraints that are redundant and/or dominated by other constraints.

Abstract: One or more systems and methods according to the present disclosure may apply a model for integrating distribution systems having proliferated distributed energy resources into the independent system operator energy market, particularly when one or more distribution systems are connected to a transmission system via multiple interconnection buses. Additionally, systems and methods for applying a compact multi-port model for power exchanges and associated bidding strategies are described. A the multi-port power exchange model may be constructed based on the operational feasible region of a distribution system; describing physical operation characteristics of distributed energy resources, flexible loads, and the distribution network; and the bidding strategy model may describe total operating cost of the distribution system, while recognizing electrically coupled injections of multiple interconnection buses.

Abstract: A method for operating an electrical power grid system is provided. The electrical power grid system includes an electrical power grid, a plurality of power generation participants providing electrical power to the electrical power grid, and a plurality of consumers drawing electrical power from the electrical power grid, where at least a portion of the power generation participants include fast-ramping power generation resources and at least a portion of the power generation participants include slow-ramping power generation resources. The method involves controlling dispatch of electricity on the electrical power grid including enabling fast-ramping resources.

Abstract: A method for operating a combined-cycle electrical power grid by: accepting, from combined cycle power generation participants, combined cycle offers for valid combined cycle configurations, each including identification of power generator type(s) for the configuration and the offers including at least three levels of parameter information pertaining for the valid combined cycle configurations, the three levels including, (a) resource level parameters that describe transition information between the valid combined cycle configurations, (b) configuration level parameters that describe operating parameters for each valid configuration; and (c) component level parameters that describe operating parameters for specific power generator components included in a valid configuration; selecting commitments from the combined cycle offers based upon the resource level parameters, the configuration level parameters and the component level parameters; and controlling dispatch of electricity based upon the commitments.

Abstract: A method for operating an electrical power grid, which includes an electrical power grid, a plurality of power generation participants providing electrical power to the electrical power grid, a plurality of consumers drawing electrical power from the electrical power grid, and a controller that administers the market for the power generation participants and the consumers on the electrical power grid. The method may include providing, by the controller, a short-term reserve (STR) product for the consumers. The STR may be provided by the power generation participants through online resources and offline resources. And the controller may share a ramp capability product (RCP) capacity and a resource capacity.

Abstract: The present disclosure pertains to a system that may be configured to operate a power grid, including generation participants, consumers, and electric storage resources (ESRs), by: managing, via the generation participants, a state of charge (SOC) for the ESRs, an operational constraint, minimum and maximum offer parameters, minimum and maximum SOCs, and transition times between charging and discharging, the parameters including charge or discharge time and charge or discharge limits; treating different online modes as a must run commitment status, the modes including discharging, charging, and continuous; and committing an ESR offering an emergency discharge commitment status or an emergency charge commitment status to address a maximum generation emergency condition or a minimum generation emergency condition, respectively.

Abstract: Reducing uplift payments has been a challenging problem for most wholesale markets in US. The main difficulty comes from the unit commitment discrete decision makings. Recently convex hull pricing has been shown promising to reduce the uplift payments. Meanwhile, however, the computation could be heavy to decide the convex hull price. This disclosure shows how to utilize a derived integral formulation of the single-generator unit commitment problem to facilitate the calculation of the optimal convex hull price by solving a linear program.

Abstract: The present disclosure pertains to a system that may be configured to operate a power grid, including generation participants, consumers, and a controller that administers a market for the power generation participants and the consumers on the power grid. The operation of the power grid may include: performing power grid coordination calculations based upon, at least in part, constraints that pertain to the flow and/or congestion of power on the grid; and managing the coordination calculations by reducing a number of constraints used in the coordination calculations, the managing including a first step of coarse screening of the constraints, a second step of deterministic fine screening of the constraints, and a third step of statistical fine screening of the constraints. This second step may cause identification of constraints that are redundant and/or dominated by other constraints.

Abstract: A method may improve commercial optimization solver performance on day ahead security constrained unit commitment through warm start and lazy constraint settings. Data analytics is performed to greatly improve the quality of the initial commitment solution and lazy constraint setting. A distributed optimization framework is provided to take advantage of the diversity from prevalent solvers (GUROBI and CPLEX) under different warm start settings. A systematic distribution profile based benchmarking method is also provided.

Abstract: A method for operating an electrical power grid, which includes an electrical power grid, a plurality of power generation participants providing electrical power to the electrical power grid, a plurality of consumers drawing electrical power from the electrical power grid, and a controller that administers the market for the power generation participants and the consumers on the electrical power grid. The method may include providing, by the controller, a short-term reserve (STR) product for the consumers. The STR may be provided by the power generation participants through online resources and offline resources. And the controller may share a ramp capability product (RCP) capacity and a resource capacity.

Abstract: The present disclosure pertains to a system that may be configured to operate a power grid, including generation participants, consumers, and electric storage resources (ESRs), by: managing, via the generation participants, a state of charge (SOC) for the ESRs, an operational constraint, minimum and maximum offer parameters, minimum and maximum SOCs, and transition times between charging and discharging, the parameters including charge or discharge time and charge or discharge limits; treating different online modes as a must run commitment status, the modes including discharging, charging, and continuous; and committing an ESR offering an emergency discharge commitment status or an emergency charge commitment status to address a maximum generation emergency condition or a minimum generation emergency condition, respectively.

Abstract: A method for operating an electrical power grid system is provided. The electrical power grid system includes an electrical power grid, a plurality of power generation participants providing electrical power to the electrical power grid, and a plurality of consumers drawing electrical power from the electrical power grid, where at least a portion of the power generation participants include fast-ramping power generation resources and at least a portion of the power generation participants include slow-ramping power generation resources. The method involves controlling dispatch of electricity on the electrical power grid including enabling fast-ramping resources.

Abstract: A method for operating a combined-cycle electrical power grid system including the steps of: accepting, from a plurality of combined cycle power generation participants, combined cycle offers for a set of valid combined cycle configurations, each combined cycle configuration in the set including identification of power generator type(s) for the configuration and the offers including at least three levels of parameter information pertaining for the valid combined cycle configurations, the three levels of parameter information including, (a) resource level parameters that describe transition information between the valid combined cycle configurations, (b) configuration level parameters that describe operating parameters for each valid combined cycle configuration in the set; and (c) component level parameters that describe operating parameters for specific power generator components included in one or more of the valid combined cycle configurations; selecting commitments from the combined cycle offers based upo