© The Institution of Engineering and Technology
This study provides an analysis of the potential for a sub-energy system to provide an electricity balancing service to, in this case, a national energy system with a large share of variable renewable electricity generation. By comparing electricity balancing capacity, CO2, eq-emissions, and costs, three different local residential energy system setups are assessed. The setups contain different combinations of district heating, combined heat and power, thermal energy storage, electric battery storage, heat pumps, and electric boilers. The analysis focuses on system-level integration, heat and electricity cross-sectoral operations, and unconventional production strategies for district heating production. The results show that local sub-energy systems with heat pumps, combined heat and power, and thermal energy storage has the potential to reduce national electricity balancing demand in an economically feasible way, and with modest CO2, eq-emissions. It was also shown that electricity-based heat production without district heating is economically unfavourable, even in the most optimistic scenario; it is not likely to be feasible within a 30-year period.
References
-
-
1)
-
42. Paulus, M., Borggrefe, F.: ‘The potential of demand-side management in energy-intensive industries for electricity markets in Germany’, Appl. Energy, 2011, 88, pp. 432–441, doi:10.1016/j.apenergy.2010.03.017.
-
2)
-
34. Swedish Energy Markets Inspectorate, 2019. .
-
3)
-
4)
-
43. Kies, A., Schyska, B., von Bremen, L.: ‘The demand Side management potential to balance a highly renewable European power system’, Energies, 2016, 9, p. 955, doi:10.3390/en9110955.
-
5)
-
15. Monie, S.W., Nilsson, A.M., Åberg, M.: ‘Electricity balancing capacity, emissions, and cost comparison of three storage-based local energy systems for variable power generation’. Conf. Proc. 9th Solar and Storage Integration Workshop, Dublin, Ireland, 15–16 October 2019.
-
6)
-
33. Swedish Environmental Protection Agency, 2019: ‘National inventory report’. .
-
7)
-
35. Reidhav, C., Werner, S.: ‘Profitability of sparse district heating’, Appl. Energy, 2008, 85, pp. 867–877, doi: 10.1016/j.apenergy.2008.01.006.
-
8)
-
48. Åberg, M., Lingfors, D., Olauson, J., et al: ‘Can electricity market prices control power-to-heat production for peak shaving of renewable power generation? The case of Sweden’, Energy, 2019, 176, pp. 1–14, doi:10.1016/j.energy.2019.03.156.
-
9)
-
10)
-
16. Monie, S.W., Nilsson, A.M., Lingfors, D., et al: ‘Thermal energy storages in residential areas – a potential to increase renewable power generation?’. Conf. Proc. ACEEE Summer Study on Energy Efficiency in Buildings 2018, Pacific Grove, CA, USA, 12–17 August 2018.
-
11)
-
36. Gudmundsson, O., Thorsen, J.E., Zhang, L.: ‘Cost analysis of district heating compared to its competing technologies’. Presented at the ENERGY AND SUSTAINABILITY 2013, Bucharest, Romania, 2013, pp. 3–13. doi:10.2495/ESUS130091.
-
12)
-
17. Böttger, D., Götz, M., Lehr, N., et al: ‘Potential of the power-to-heat technology in district heating grids in Germany’, Energy Procedia, 2014, 46, pp. 246–253, doi:10.1016/j.egypro.2014.01.179.
-
13)
-
44. The Swedish Consumer Energy Markets Bureau, 2020. .
-
14)
-
15)
-
16)
-
17)
-
40. Viswanathan, V., Crawford, A., Stephenson, D., et al: ‘Cost and performance model for redox flow batteries’, J. Power Sources, 2014, 247, pp. 1040–1051, doi:10.1016/j.jpowsour.2012.12.023.
-
18)
-
20. Schmidt, T., Mangold, D., Müller-Steinhagen, H.: ‘Central solar heating plants with seasonal storage in Germany’, Sol. Energy, 2004, 76, pp. 165–174, doi:10.1016/j.solener.2003.07.025.
-
19)
-
3. IPCC, 2014: ‘Climate change 2014: synthesis report’. ..
-
20)
-
21)
-
26. Lu, R., Yang, A., Xue, Y., et al: ‘Analysis of the key factors affecting the energy efficiency of batteries in electric vehicle’, World Electr. Veh. J., 2010, 4, pp. 9–13, doi:10.3390/wevj4010009.
-
22)
-
23)
-
24. Claesson, J., Eftring, B., Eskilson, P., et al1985. .
-
24)
-
37. Arvay, P., Muller, M.R., Ramdeen, V., et al: ‘Economic implementation of the organic Rankine cycle in industry’. Conf. Proc. ACEEE Summer Study on Energy Efficiency in Industry 2011, Niagara Falls, NY, USA, 26–29 July 2011.
-
25)
-
18. Schweiger, G., Rantzer, J., Ericsson, K., et al: ‘The potential of power-to-heat in Swedish district heating systems’, Energy, 2017, 137, pp. 661–669, doi:10.1016/j.energy.2017.02.075.
-
26)
-
25. Cunha, Á, Martins, J., Rodrigues, N., et al: ‘Vanadium redox flow batteries: a technology review’, Int. J. Energy Res., 2015, 39, pp. 889–918, doi:10.1002/er.3260.
-
27)
-
21. Widén, J., Wäckelgård, E.: ‘A high-resolution stochastic model of domestic activity patterns and electricity demand’, Appl. Energy, 2010, 87, pp. 1880–1892, doi:10.1016/j.apenergy.2009.11.006.
-
28)
-
29. Zottl, A., Nordman, R., Miara, M., 2012. .
-
29)
-
38. Pieper, H., Ommen, T., Buhler, F., et al: ‘Allocation of investment costs for large-scale heat pumps supplying district heating’, Energy Procedia, 2018, 147, pp. 358–367, doi:10.1016/j.egypro.2018.07.104.
-
30)
-
39. IVT Heat pumps, (2019). .
-
31)
-
28. Schmidt, O., Hawkes, A., Gambhir, A., et al: ‘The future cost of electrical energy storage based on experience rates’, Nat. Energy, 2017, 2, p. 17110, doi:10.1038/nenergy.2017.110.
-
32)
-
49. Muratori, M., Calvin, K., Wise, M., et al: ‘Global economic consequences of deploying bioenergy with carbon capture and storage (BECCS)’, Environ. Res. Lett., 2016, 11, p. 095004, doi:10.1088/1748-9326/11/9/095004.
-
33)
-
34)
-
22. Lingfors, D.: ‘Solar variability assessment and grid integration’. , 2015.
-
35)
-
36)
-
37)
-
50. Heck, V., Gerten, D., Lucht, W., et al: ‘Biomass-based negative emissions difficult to reconcile with planetary boundaries’, Nat. Clim. Chang, 2018, 8, pp. 151–155, doi:10.1038/s41558-017-0064-y.
-
38)
-
39)
-
47. Kirkerud, J.G., Bolkesjø, T.F., Trømborg, E.: ‘Power-to-heat as a flexibility measure for integration of renewable energy’, Energy, 2017, 128, pp. 776–784, doi:10.1016/j.energy.2017.03.153.
-
40)
-
45. Kaspar, F., Borsche, M., Pfeifroth, U., et al: ‘A climatological assessment of balancing effects and shortfall risks of photovoltaics and wind energy in Germany and Europe’, Adv. Sci. Res., 2019, 16, pp. 119–128, doi:10.5194/asr-16-119-2019.
-
41)
-
42)
-
19. Salpakari, J., Mikkola, J., Lund, P.D.: ‘Improved flexibility with large-scale variable renewable power in cities through optimal demand side management and power-to-heat conversion’, Energy Convers. Manage., 2016, 126, pp. 649–661, doi:10.1016/j.enconman.2016.08.041.
-
43)
-
12. Rinne, S., Syri, S.: ‘The possibilities of combined heat and power production balancing large amounts of wind power in Finland’, Energy, 2015, 82, pp. 1034–1046, doi:10.1016/j.energy.2015.02.002.
-
44)
-
10. Mollenhauer, E., Christidis, A., Tsatsaronis, G.: ‘Increasing the flexibility of combined heat and power plants with heat pumps and thermal energy storage’, J. Energy Res. Technol., 2017, 140, (2), doi: 10.1115/1.4038461. .
-
45)
-
46)
-
47)
-
51. Bioenergy International (2019). .
-
48)
-
31. Sarbu, I., Sebarchievici, C.: ‘Ground-source heat pumps: theory and experimental research’ (Elsevier Science & Technology, London, 2015), , p. 13. .
-
49)
-
46. Widén, J., Carpman, N., Castellucci, V., et al: ‘Variability assessment and forecasting of renewables: A review for solar, wind, wave and tidal resources’, Renew. Sustain. Energy Rev., 2015, 44, pp. 356–375, doi:10.1016/j.rser.2014.12.019.
-
50)
-
27. Pistoia, G.: ‘Battery operated devices and systems - from portable electronics to industrial products’. (Elsevier, The Netherlands, 2009), p. 66. . .
-
51)
-
9. Wang, J., Zong, Y., You, S., et al: ‘A review of Danish integrated multi-energy system flexibility options for high wind power penetration’, Clean Energy, 2017, 1, pp. 23–35, doi: 10.1093/ce/zkx002.
http://iet.metastore.ingenta.com/content/journals/10.1049/iet-rpg.2020.0574
Related content
content/journals/10.1049/iet-rpg.2020.0574
pub_keyword,iet_inspecKeyword,pub_concept
6
6