Twelve fuel and power companies trade on the Dhaka Stock Exchange. Their combined fundamentals — revenue, margin, capacity, fuel mix — explain almost nothing about what their share prices will do next. What explains it is a stack of government decisions made far above any boardroom: how much LNG Petrobangla can afford to import this month, whether BPDB will honour a capacity payment, when the next tariff hike clears BERC, and which IPP contract gets renewed without the capacity charge that the post-2023 framework no longer permits.
Bangladesh has built 31,389 MW of installed power generation capacity. The maximum it has ever produced in a single moment is 16,477 MW. The gap between those two numbers — over 14,000 MW of contracted but idle generation — is the entire story of why every listed power stock is a policy bet, not a fundamentals bet.
That gap is also where the money goes.
The Capacity Payment Trap
The Quick Enhancement of Electricity and Energy Supply (Special Provision) Act 2010 let the government bypass open bidding and sign secretive dollar-based power purchase agreements with private developers. Those contracts require capacity payments regardless of whether a single megawatt is dispatched. In FY2024-25, those payments reached Tk 38,000 crore — roughly $3.1 billion. BPDB’s revenue shortfall the same year was Tk 55,600 crore.
The interim government doubled subsidy disbursements to private producers in 2025 to clear arrears: Tk 600 billion in a single year, paid out to keep plants on standby that the grid does not need. This is the line item that determines whether SUMITPOWER, BPPL, KPCL, BARKAPOWER, EPGL, SPCL, DOREENPWR, and GBBPOWER report profits.
CPD has called for phasing out quick rental and inefficient plants by December 2025. The policy already shifted in a quieter way: no capacity charges for contract renewals from FY2023-24 onward. Read that twice. The single largest revenue line on every IPP’s income statement is being unwound on renewal — and that has not yet shown up in the income statements of the companies still operating under legacy PPAs.
Fuel Costs the Companies Cannot Pass Through
Bangladesh imports 65% of its primary energy. Domestic gas production has collapsed from 2,500 mmcf per day in 2018 to roughly 1,750 mmcf today. Daily demand is 4,000 mmcf. The shortfall — 1,350 to 1,400 mmcf — is filled by LNG imports against a contracted capacity of 7.6 MTPA, while 2026 demand is projected at 8 MTPA.
Then the Iran war broke supply. QatarEnergy declared Force Majeure on LNG cargoes to Petrobangla in March 2026. The country was forced onto the spot market at $21 per MMBtu — nearly double the long-term contract price. Petrobangla’s LNG import bill for April 2026 alone required a Tk 45 billion subsidy.
This matters for power stocks in two ways. First, the same fuel shock is hitting industrial users and has forced five of six fertiliser factories offline since March. Second, TITASGAS — the largest gas distributor — sees revenue evaporate when there is no gas to distribute, and SPCL and other gas-fired generators run below capacity through no fault of their own.
The pass-through clause in the PPA decides who eats the loss. The government decides whether to honour it.
The Tariff Decision That Overrides Everything
In April 2026, the government announced it was preparing to raise both bulk and retail electricity tariffs, citing an “unsustainable surge in subsidies.” BERC sets the rates. Politics sets the timing.
A tariff hike helps POWERGRID — the state-owned transmission monopoly — earn its regulated return. It helps DESCO recover system losses. It hurts demand at the industrial users that UPGDCL and KPCL sell into through economic zones. And it does almost nothing for the IPPs locked into legacy PPAs that pay capacity charges regardless of consumption.
Every listed power stock responds to the same announcement differently. None of them control the announcement. Compounding the uncertainty, the Fitch downgrade to negative outlook has narrowed the government’s fiscal room to keep subsidising what it cannot tariff.
What Reshapes the Sector Next
Rosatom began loading fuel into the first reactor at Rooppur in April 2026. Two VVER-1200 units will deliver 2,400 MW combined — roughly 15% of national demand at peak production. That capacity displaces existing thermal baseload, which means it directly reduces the dispatch case for the same gas and HFO plants the government is still paying capacity charges to keep idle.
Summit Power signalled the direction in August 2025, agreeing to sell its 102 MW Narayanganj HFO plant to UAE-based Sabson Energy. The largest private power producer in the country is exiting heavy fuel oil. Renewables target 20% of generation by 2030 from 2.9% today.
The structural shift is already priced into the policy. It is not yet priced into the stocks. That is the entire investment thesis — and the entire risk — for every name on the DSE fuel and power list. The fundamentals you can read in an annual report are not the fundamentals that move the price. The fundamentals that move the price are written in a different building, signed by different people, and paid for in dollars Bangladesh increasingly does not have.