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Economic dispatch analysis of regional Electricity–Gas system integrated with distributed gas injection

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  • He, Gui-Xiong
  • Yan, Hua-guang
  • Chen, Lei
  • Tao, Wen-Quan

Abstract

With the development of energy conversion technologies such as combined heat and power and gas power generation, various forms of energy, such as the electricity, gas, and heat of regional integrated energy systems have become highly coupled. Aiming at regional electricity–gas systems (REGS), this paper focuses on the interaction between an electricity power system and a natural gas system. A comprehensive analytical model of the REGS combined with distributed gas injection is proposed, where a regional energy station (RES) is considered as an energy coupling link. The REGS’s energy flow is optimized to minimize the operation cost of the RES by comprehensively considering the cost of distributed gas injection, the penalty of wind curtailment, and the constraints of the energy network. Furthermore, multiple RESs and distributed gas injections are used as a control to study the effects of various adjustable resources on the economics of REGS′ operating costs, flexibility of renewable energy consumption, and safety of pressure support capabilities. Subsequently, a system optimization scheduling strategy without considering gas injection point and the corresponding strategy considering hydrogen or upgraded biogas as gas injection temperament are studied. Numerical example shows that with the introduction of distributed gas injection points, the economic dispatch strategy considering the upgrade of biogas and hydrogen injection improved the economic, pressure reduction level, and wind power consumption rate of the system, which are important for improving the stability and flexibility of REGSs.

Suggested Citation

  • He, Gui-Xiong & Yan, Hua-guang & Chen, Lei & Tao, Wen-Quan, 2020. "Economic dispatch analysis of regional Electricity–Gas system integrated with distributed gas injection," Energy, Elsevier, vol. 201(C).
    • Handle: RePEc:eee:energy:v:201:y:2020:i:c:s0360544220306198
    DOI: 10.1016/j.energy.2020.117512
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    References listed on IDEAS

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    Cited by:

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    2. Zhou, Dengji & Yan, Siyun & Huang, Dawen & Shao, Tiemin & Xiao, Wang & Hao, Jiarui & Wang, Chen & Yu, Tianqi, 2022. "Modeling and simulation of the hydrogen blended gas-electricity integrated energy system and influence analysis of hydrogen blending modes," Energy, Elsevier, vol. 239(PA).
    3. Wang, Chong & Ju, Ping & Wu, Feng & Lei, Shunbo & Hou, Yunhe, 2021. "Coordinated scheduling of integrated power and gas grids in consideration of gas flow dynamics," Energy, Elsevier, vol. 220(C).
    4. Cavana, Marco & Mazza, Andrea & Chicco, Gianfranco & Leone, Pierluigi, 2021. "Electrical and gas networks coupling through hydrogen blending under increasing distributed photovoltaic generation," Applied Energy, Elsevier, vol. 290(C).
    5. Zhao, Baining & Qian, Tong & Tang, Wenhu & Liang, Qiheng, 2022. "A data-enhanced distributionally robust optimization method for economic dispatch of integrated electricity and natural gas systems with wind uncertainty," Energy, Elsevier, vol. 243(C).
    6. Yu, Haiquan & Zhou, Jianxin & Si, Fengqi & Nord, Lars O., 2022. "Combined heat and power dynamic economic dispatch considering field operational characteristics of natural gas combined cycle plants," Energy, Elsevier, vol. 244(PA).
    7. Sayed, Ahmed Rabee & Wang, Cheng & Chen, Sheng & Shang, Ce & Bi, Tianshu, 2021. "Distributionally robust day-ahead operation of power systems with two-stage gas contracting," Energy, Elsevier, vol. 231(C).

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