A Methodology for Constructing Hourly Electricity Demand Database by Municipality and Sector Using Publicly Available Statistics in Korea

Abstract

This study develops a 2024 PPA-adjusted grid-facing electricity-demand database for Korea using public data: Korea Power Exchange demand, KEPCO district sales, and industrial load profiles. It covers 229 districts, 38 use-sectors, and 8,784 hours. Industry-code mapping, regionally weighted profiles, and two-stage proportional scaling preserve district-sector-monthly sales and align with the national load shape. Sales are preserved exactly by construction (0.000%), with an intraday shape residual of 0.059%. A partial external cross-check against total-demand estimates separately published by KPX for Nov. 23 to Dec. 31, 2024 yielded an hourly MAPE of 0.79% at the national aggregate level. Applied to KPG 193, industrial buses show peak-to-valley ratios of 1.12–1.24 (group mean 1.18) versus 1.85–2.08 (mean 1.94) for service-dominated metropolitan buses. Compared with allocation using a single national load shape across buses, the metropolitan summer-peak share rises from 7.6% to 10.6%, whereas the industrial-complex share falls from 19.2% to 14.1%. The results support regionally differentiated demand modeling for long-term transmission planning.