South Korea is one of the world’s most energy-import-dependent major economies, lacking significant domestic fossil fuel resources and relying on imports for over 90% of its primary energy needs. In this context, liquefied natural gas (LNG) plays a central role — as fuel for power generation, industrial feedstock, and increasingly as a bridge fuel in the country’s complex energy transition. Managing LNG supply security, price exposure, and the balance between long-term contracts and spot market exposure is a critical function of South Korean energy policy. In 2026, the country’s LNG strategy reflects lessons learned from the price volatility of 2021–2022 and evolving views on the long-term role of gas in a decarbonising economy.
Korea’s LNG Import Profile
South Korea is the world’s third-largest LNG importer, behind Japan and China. The country imports approximately 40–45 million tonnes per annum (mtpa) of LNG, primarily to fuel gas-fired power plants, industrial processes, and city gas distribution networks. Korea Gas Corporation (KOGAS), the state utility, manages the bulk of LNG procurement through a portfolio of long-term supply agreements and spot market purchases. Private importers — including power companies such as KEPCO and direct-import industrial customers — account for a growing share of procurement as the market has been partially liberalised.
Korea’s LNG supply sources are deliberately diversified across geographies to reduce concentration risk. Key suppliers include Qatar (under long-term contracts that were recently renegotiated and extended), Australia (multiple projects including Gorgon, Wheatstone, and Queensland LNG), the United States (Henry Hub-linked contracts with several Gulf Coast exporters), Malaysia, and Oman. The diversification strategy means that disruption from any single supplier has limited impact on total supply — a lesson that became acutely relevant during the 2021–2022 global LNG market tightening.
The Price Volatility Lesson
The 2021–2022 LNG price spike — when spot LNG prices in Asia reached record highs of over $70/MMBtu in late 2021, compared to typical pre-crisis levels of $6–$12/MMBtu — exposed the risks of insufficient long-term contract coverage. Korea, like Japan, relies heavily on long-term contracts precisely to mitigate this spot market exposure, but the volume of spot purchasing had grown in the years preceding the crisis as companies sought flexibility and lower-priced spot cargoes during the market surplus of 2019–2020.
The lesson has been taken on board. KOGAS and Korean private importers have since been more active in securing long-term supply agreements, particularly with US LNG exporters offering Henry Hub-linked pricing, which provides a different price exposure to the traditional oil-indexed Asian LNG contracts. A portfolio of pricing formulas — some oil-linked, some hub-linked, some hybrid — provides natural hedging across different market scenarios.
Nuclear: The Shifting Balance
South Korea’s energy mix is significantly influenced by nuclear power, which provides roughly 30% of electricity generation. The country operates 26 nuclear reactors with a combined capacity of approximately 26 GW, and several new units — including the APR-1400 reactors at Shin Hanul — have recently come online or are nearing completion. South Korea’s nuclear programme has a strong domestic industrial base, with Korea Hydro & Nuclear Power (KHNP) developing reactors and actively pursuing export contracts in countries including the Czech Republic and Poland.
The nuclear-LNG balance in Korea’s power sector is consequential for LNG demand. When nuclear plants operate at high utilisation, LNG-fired generation is displaced, reducing import requirements. When nuclear plants are taken offline for maintenance or regulatory inspections — which was a particular issue in 2017–2018 when multiple units were simultaneously offline — LNG demand spikes. Managing the nuclear fleet’s operating schedule and the associated LNG buffer requirements is a key operational challenge for KOGAS and Korea’s electricity system operator.
The Energy Transition and LNG’s Future Role
South Korea has committed to achieving carbon neutrality by 2050 and has set interim targets for renewable energy expansion and emissions reduction. The country’s renewable capacity — particularly solar and wind — has grown, but South Korea’s geography (high population density, limited land availability, mountainous terrain that constrains both onshore wind and large-scale solar) creates genuine challenges for scaling up renewables at the pace needed. Offshore wind is increasingly seen as the key scalable renewable resource, and the government has set ambitious offshore wind targets, with designated development zones in the Yellow Sea and South Sea.
In this context, LNG is widely seen as a medium-term transition fuel — necessary for maintaining grid reliability as coal is phased out but expected to gradually decline as renewables and storage mature. The pace at which LNG demand declines will depend on how quickly offshore wind is built, how the nuclear fleet evolves, and whether hydrogen (potentially produced from LNG with carbon capture) plays a role in the future energy mix. The IEA has noted South Korea as a key market in its Asia gas demand forecasts. Follow the latest in gas markets and energy news across our site.
Green Hydrogen and Ammonia Imports
South Korea has been an early and enthusiastic adopter of the concept of importing green hydrogen and ammonia as clean energy vectors. Given the country’s energy import dependence and its limited domestic renewable potential, the idea of importing hydrogen produced from overseas renewables — from Australia, the Middle East, or Chile — and using it for power generation, industrial processes, and transport has strong strategic appeal. KOGAS, POSCO, and several Korean conglomerates have signed MOUs and investment agreements with potential green hydrogen suppliers globally.
The technology and economics of large-scale green hydrogen trade remain challenging, with production costs, transport infrastructure, and end-use conversion all requiring further development and cost reduction. But South Korea’s policy support for the hydrogen economy — including production incentives, infrastructure investment, and import facilitation — positions it as one of the markets most likely to provide early demand for green hydrogen exports. This is shaping investment decisions by potential suppliers from Australia to Chile, who see Korea alongside Japan as the primary target markets for future hydrogen trade.
