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As of May 12, 2026, Bangladesh’s power sector is far bigger than the one the country inherited at independence. Installed capacity has reached nearly 32,500MW, including imports, captive generation and off-grid systems, and the system served peak demand of roughly 17,200MW in May 2026. But the debate in Dhaka has shifted. The real question is no longer “where will the next megawatt come from?” It is whether the entire system can move power reliably, affordably and sustainably from one end of the grid to the other.
After the 1947 partition, the area that became East Pakistan had only about 21MW of generation capacity and no transmission network. The Kaptai hydropower plant and the 132kV Kaptai–Siddhirganj line, both completed in 1962, gave the system its first real backbone. After independence in 1971, natural gas became the dominant fuel as domestic reserves were developed. In the 1990s, reforms opened the sector to private investment through independent power producers, and later governments added liquid-fuel plants, coal and imported electricity to meet rising demand.
That expansion produced impressive gains in electricity access. But it also left a generation-heavy system in which network investment did not always keep pace. Large installed capacity is not the same as reliable supply. If fuel is scarce, expensive or hard to import, or if transmission and distribution lines cannot deliver power where it is needed, big numbers do not protect consumers from outages or high costs.
The challenge, therefore, is no longer “how do we generate more electricity?” It is “how do we generate the right electricity and deliver it efficiently?” That requires treating generation, transmission and distribution as one interconnected system. An inadequately planned fuel mix can create excess capacity, capacity payment obligations and stranded assets when plants sit idle. Rising dependence on imported fossil fuels also exposes the economy to global price shocks and geopolitical risks.
Bangladesh’s solar history is genuinely remarkable. The IDCOL-led Solar Home System programme, launched in 2003, installed more than 6.5 million off-grid systems at its peak and provided electricity to millions of rural households. Yet that success did not translate into a comparable build-out of grid-connected renewable power. Renewables still make up only about 5.7% of the power mix, with roughly 1,852MW of capacity.
The Renewable Energy Policy 2025 targets 20% renewable supply for power demand by 2030 and 30% by 2040. The government is also considering a larger goal of about 10,000MW of renewable capacity by 2030. Those are ambitious numbers, but they will remain academic unless grid planning catches up. Large solar and wind projects face limited land, financing constraints, lengthy approvals, tariff uncertainty, weak evacuation capacity and poor coordination with national grid expansion. Too often, renewable energy in Bangladesh has been treated as a project problem rather than a system challenge.
Pakistan shows what happens when consumers act faster than utilities. Expensive, unreliable grid service has pushed households and businesses toward rooftop solar and batteries. That shrinks utility revenue while the network still has to be maintained for everyone. The answer is not to resist distributed generation but to redesign tariffs, network charges and grid-service rules so that customer-owned solar strengthens the system.
Vietnam demonstrates the power of policy certainty. A 2017 feed-in tariff produced extraordinary solar deployment. By the end of 2020, Vietnam had connected 5.7GW of ground-mounted solar and about 9.7GW of rooftop solar across roughly 102,000 installations. The boom, however, outpaced the network. Transmission congestion, reverse power flows and curtailment followed where solar expanded faster than grid capacity. The lesson is clear: generation, transmission, storage, forecasting and demand management must be planned together.
Solar and wind are weather-dependent. If Bangladesh adds several gigawatts of solar without flexibility, high midday output can cause voltage swings, congestion and curtailment. In the evening, solar generation drops while household and commercial demand stays high—the familiar “duck curve.” California’s grid operator has documented that pattern for years, and Texas has learned that price signals plus storage can help absorb more renewables. Bangladesh can borrow those playbooks.
A renewable-ready grid needs stronger transmission corridors, modern distribution with two-way power flow, accurate forecasting, flexible generation, demand response, regional electricity trading and battery storage. Smart meters also deserve attention. They are not just billing devices; they are sensors for a digital grid. Real-time visibility, automated fault detection and distributed-energy integration are the foundations of the network Bangladesh will need by the 2030s.
Energy storage is equally central. Batteries can absorb excess midday solar, discharge during evening peaks and provide frequency and voltage support. The Renewable Energy Policy 2025 already recognises storage as a tool for peak reduction, congestion management and curtailment. The next step is to embed storage in renewable procurement auctions instead of treating it as an afterthought.
The International Energy Agency describes the current period as an “Age of Electricity.” Industrialisation, cooling, data centres, electric vehicles and electric cooking are pushing electricity toward the centre of economic life. In that world, energy security increasingly means electricity-system security. A resilient grid is one with diverse generation, domestic renewable resources, storage, efficiency, secure equipment supply chains, digital infrastructure and regional interconnection.
For Bangladesh, renewables are not only an environmental priority. Solar and wind generated domestically reduce exposure to volatile international fossil-fuel prices and do not require a continuing fuel-import bill. But the country cannot phase out gas overnight. Natural gas can remain a flexibility source during the transition. The objective should be progressive diversification, not a sudden shift that destabilises supply.
The transition will not stop at power stations. Transport remains heavily dependent on petroleum, and electrifying two- and three-wheelers, buses and railways can reduce oil imports—provided charging infrastructure and grid capacity grow together. Bangladesh already has an Electric Vehicle Charging Guideline and a registration policy. The next step is integrated planning for charging tariffs, smart charging, renewable-powered hubs and, eventually, vehicle-to-grid technology.
Electric cooking is another overlooked opportunity. As renewable generation grows, induction cooking can shift demand to times when solar power is abundant. That makes new electricity loads an asset for the grid rather than a burden. It does, however, require tariff design that encourages people to use power when supply is high.
Bangladesh needs a roadmap that treats energy policy as one system. First, human resources: engineers, grid operators, regulators and planners need training in solar, storage, digital networks and data analysis. Second, transmission and distribution investment should be planned ahead of large renewable additions. Third, tariffs and market rules must reward flexibility while keeping the network financially viable. Fourth, regional electricity trading and coordinated import planning should reduce stranded assets. Fifth, gas policy should treat natural gas as a transition fuel rather than a permanent anchor. Sixth, demand planning must include transport, cooking, cooling and industry, not just household lighting.
For U.S. readers, Bangladesh’s next decade is also an investment story. American suppliers of battery systems, smart meters, grid software and renewable components may find an expanding market as utilities move to modernise in a hurry. More broadly, Bangladesh is becoming a test case for the developing world: can a country with a strong gas-and-coal legacy, limited land and rapidly rising demand leap-frog into a flexible, distributed, digital electricity system? The answer will matter far beyond South Asia.
