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Power-to-gas (P2G) facilities and natural gas fired power units provide flexibility to integrated electricity and natural gas systems (IENGS) for wind power accommodation and ramp deployment. This paper proposes a stochastic coordinated scheduling model for IENGS considering ramping costs with P2G storage and wind power. The operation model of natural gas system with P2G is presented, and the benefits of P2G integration are analyzed. To address the uncertainties of wind power and energy loads, multiple representative scenarios are generated. The flexible ramping requirements and costs are incorporated and analyzed, and flexible ramp can be provided by P2G in this work. The coordinated scheduling model for IENGS is formulated as a two-stage stochastic programming problem, in which day-ahead scheduling for electricity systems is modeled in the first stage model and scheduling of natural gas systems is carried out in the second stage model. Numerical case studies on a modified PJM 5-bus electricity system with a 7-node natural gas system and the IEEE 118-bus system with a 20-node Belgian natural gas system verify that P2G can help accommodate wind power, provide additional flexible ramping capacities, and reduce the gas supply from gas suppliers and gas load shedding.

Wind power and carbon capture power plants (CCPPs) are two important viable options to reduce CO2 emission in low-carbon power systems. Especially, the combination of the two options, i.e., the CCPP integrating wind power, can effectively cut the CO2 emission of the power plant. This paper presents a low-carbon dispatch model for a CCPP integrating wind power, considering the ramping cost, fuel cost, and carbon emission cost. To simplify the model, the flexibility of the CCPP is defined as the capture percentage. Then, the impact of the ramping cost on the operation of the CCPP integrating wind power is studied under different carbon taxes. Numerical examples based on an IEEE 30-bus tested system show that the carbon taxes for the dispatch model including the ramping cost can be divided into two zones: the flexible zone and the inflexible zone. The simulation results demonstrate that within the flexible zone, considering the ramping cost for the dispatch model can effectively improve the economy of the CCPP integrating wind power. [ABSTRACT FROM AUTHOR]

Ramp rates of generators are. generally specified within elastic range of the strength of the shaft to safeguard the rotor from fatigue. These limits can, however, be exceeded, albeit at the risk of reducing the rotor life. Such effects on the rotor life can be compensated by incorporating appropriate ramping costs. Power demand and power price in deregulated power markets have shown a tendency of sudden wide excursions over short intervals of time. The ability to respond to such fast change in demand and price can be quite rewarding. This provides the motivation to utilize the ramping rates beyond traditional elastic limits. This paper studies the strategic use of ramping rates beyond elastic limits in a power producer's self-dispatch in a power market with price and demand volatility A set of ramping processes has been developed. from ramping-cost versus ramping time relationships to derive the total operation cost including ramping costs for various levels of ramping rates exceeding elastic limits. A thorough theoretical analysis has been conducted for the selection of the optimal ramping process under different conditions. A numerical example is presented to highlight the potential benefits from the optimal use of these ramping processes. It is seen that the benefit from the strategic use of lamp rates beyond elastic limits not only depends on the high price in the power market hut also on the initial loading of the generator which limits the capacity available for dispatch. [ABSTRACT FROM AUTHOR]