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A large amount of wind power has to be curtailed due to the inflexibility of the combined heat and power (CHP) system in the heating season in northern China. The power-to-gas (P2G) technology, which uses electricity to produce hydrogen or synthetic natural gas, has become a promising energy conversion option for the utilization of surplus power energy. In this paper, an integrated natural gas, heat, and power dispatch (INGHPD) model which balances natural gas, heat, and power demand considering wind power and a P2G unit, is proposed. A natural gas network and P2G are modeled and integrated into the dispatch model. To demonstrate the effectiveness of the proposed model, an integrated energy system consisting of a six-bus power system, a six-node natural gas system, and a district heating system is simulated. The benefits of P2G are investigated in terms of reducing wind power curtailment, as well as system operation cost and CO2 emissions. The results in the deterministic model show that with the introduction of 40 MW P2G, the wind power curtailment rate decreases from 24.0% to 9.7%. The daily wind power energy consumed by P2G reaches 256 MWh and the daily CO2 emissions reduction reaches 46,080 kg. Additionally, the impact of the power and heat demand on the gas production of P2G and of the P2G capacity on the wind power curtailment are also investigated. P2G tends to generate more natural gas when the power demand is low and the heat demand is high.
Jun Ye; Rongxiang Yuan. Integrated Natural Gas, Heat, and Power Dispatch Considering Wind Power and Power-to-Gas. Sustainability 2017, 9, 602 .
AMA StyleJun Ye, Rongxiang Yuan. Integrated Natural Gas, Heat, and Power Dispatch Considering Wind Power and Power-to-Gas. Sustainability. 2017; 9 (4):602.
Chicago/Turabian StyleJun Ye; Rongxiang Yuan. 2017. "Integrated Natural Gas, Heat, and Power Dispatch Considering Wind Power and Power-to-Gas." Sustainability 9, no. 4: 602.
Wind power has achieved great development in Northern China, but abundant wind power is dissipated, rather than utilized, due to inflexible electricity production of combined heat and power (CHP) units. In this paper, an integrated CHP system consisting of CHP units, wind power plants, and condensing power plants is investigated to decouple the power and heat production on both the power supply side and heat supply side, by incorporating electrical energy storage (EES) and thermal energy storage (TES). Then the integrated CHP system dispatch (ICHPSD) model is formulated to reach the target of reducing wind power curtailment and primary energy consumption. Finally, the feasibility and effectiveness of the proposed ICHPSD model are verified by the six-bus system, and the simulation results show that EES has a better effect on wind power integration than TES. The annual net benefits by incorporating EES and TES increase with increasing wind penetration, but they gradually approach saturation. Introducing both EES and TES can largely increase the amount of wind power integration and improve the operation efficiency of the system.
Rongxiang Yuan; Jun Ye; Jiazhi Lei; Timing Li. Integrated Combined Heat and Power System Dispatch Considering Electrical and Thermal Energy Storage. Energies 2016, 9, 474 .
AMA StyleRongxiang Yuan, Jun Ye, Jiazhi Lei, Timing Li. Integrated Combined Heat and Power System Dispatch Considering Electrical and Thermal Energy Storage. Energies. 2016; 9 (6):474.
Chicago/Turabian StyleRongxiang Yuan; Jun Ye; Jiazhi Lei; Timing Li. 2016. "Integrated Combined Heat and Power System Dispatch Considering Electrical and Thermal Energy Storage." Energies 9, no. 6: 474.
In the traditional paradigm, large power plants provide active and reactive power required for the transmission system and the distribution network purchases grid power from it. However, with more and more distributed energy resources (DERs) connected at distribution levels, it is necessary to schedule DERs to meet their demand and participate in the electricity markets at the distribution level in the near future. This paper proposes a comprehensive operational scheduling model to be used in the distribution management system (DMS). The model aims to determine optimal decisions on active elements of the network, distributed generations (DGs), and responsive loads (RLs), seeking to minimize the day-ahead composite economic cost of the distribution network. For more detailed simulation, the composite cost includes the aspects of the operation cost, emission cost, and transmission loss cost of the network. Additionally, the DMS effectively utilizes the reactive power support capabilities of wind and solar power integrated in the distribution, which is usually neglected in previous works. The optimization procedure is formulated as a nonlinear combinatorial problem and solved with a modified differential evolution algorithm. A modified 33-bus distribution network is employed to validate the satisfactory performance of the proposed methodology.
Rongxiang Yuan; Timing Li; Xiangtian Deng; Jun Ye. Optimal Day-Ahead Scheduling of a Smart Distribution Grid Considering Reactive Power Capability of Distributed Generation. Energies 2016, 9, 311 .
AMA StyleRongxiang Yuan, Timing Li, Xiangtian Deng, Jun Ye. Optimal Day-Ahead Scheduling of a Smart Distribution Grid Considering Reactive Power Capability of Distributed Generation. Energies. 2016; 9 (5):311.
Chicago/Turabian StyleRongxiang Yuan; Timing Li; Xiangtian Deng; Jun Ye. 2016. "Optimal Day-Ahead Scheduling of a Smart Distribution Grid Considering Reactive Power Capability of Distributed Generation." Energies 9, no. 5: 311.