The State of Bangladesh Energy

Chapter 1

Power System: Capacity, Demand, and the Access Milestone

Bangladesh's power sector has undergone a dramatic expansion over the past fifteen years. Installed generation capacity now stands at 28 GW, up from roughly 5 GW in 2009 when the government launched its emergency capacity addition programme. This fivefold increase enabled the country to achieve 100% electrification by March 2022, a milestone that places Bangladesh among the rare developing countries to close the electricity access gap within a single generation. The electrification rate stands at 99.5%, driven by grid extension through the Rural Electrification Board (REB) and IDCOL's off-grid solar home system programme.

However, nameplate capacity is a misleading headline. Derated capacity, adjusted for aging plants, forced outages, maintenance schedules, and chronic gas supply constraints, reduces available generation to roughly 18-20 GW. Peak demand of 17 GW during summer months leaves a nominal reserve margin of 64.0%, but the effective margin during July-August heat peaks is much thinner, routinely triggering load-shedding in industrial zones and rural distribution areas. The gap between installed and available capacity is a direct consequence of building the fleet primarily on gas-fired plants that now lack adequate fuel.

System Loss and Consumption Gap

Transmission and distribution (T&D) losses stand at 8.0%, improved from 15-16% a decade ago but still meaning roughly one unit in twelve generated never reaches a paying consumer. Reducing losses to the 6-7% range achieved by better-performing regional utilities would be equivalent to adding over 1,000 MW of effective capacity without building a single new plant.

Per-capita electricity consumption at 560 kWh remains far behind India (1,200 kWh), Vietnam (2,800 kWh), and the global average (3,500 kWh). Total generation of 101.7 billion kWh serves a population of 170 million, but the low per-capita figure reveals that 100% access has not translated into adequate supply. Industrial consumers face scheduled and unscheduled outages that reduce productivity, increase generator fuel costs, and deter energy-intensive manufacturing that could diversify the economy beyond garments.

Chapter 2

Gas Crisis: Depleting Reserves and the LNG Dependency Trap

The defining energy security challenge for Bangladesh is the depletion of domestic natural gas. Natural gas at 52% of primary energy supply has been the backbone of Bangladesh's development model for four decades, powering electricity generation, fertiliser production, industrial heating, and urban cooking. Domestic production at 2700 MMCFD is declining sharply, with proven reserves of just 8.0 TCF. At current extraction rates, production will decline to marginal levels by approximately 2031.

The major producing fields (Bibiyana, Titas, Habiganj, Rashidpur, Kailashtila) are all on mature decline curves. Bibiyana alone accounts for nearly 40% of total output and has entered plateau production. Exploration in the Bay of Bengal continental shelf has yielded no commercial discoveries despite multiple licensing rounds under successive Production Sharing Contracts. The 2012 and 2022 offshore rounds attracted limited international interest due to a combination of unattractive fiscal terms, geological uncertainty in the deep-water Bengal Fan, and the global capital reallocation away from upstream gas exploration.

LNG Dependency and Price Shock

LNG imports through two floating storage and regasification units (FSRUs) at Moheshkhali have expanded to 1000 MMCFD, representing 27.0% of total gas supply. The cost differential is the core problem: imported LNG at $10-14 per MMBTU costs approximately three times the administered domestic gas price of $2.75 per MMBTU. Every additional molecule of LNG that replaces depleting domestic gas widens the gap between the cost of supply and regulated tariffs that Petrobangla and BPDB must absorb as losses.

A third FSRU and a land-based LNG terminal at Matarbari are planned, but each expansion deepens import dependency and balance-of-payments exposure. With WTI crude at $99.89/barrel and the energy commodity index at 242.28 (change: +52.2%), the petroleum and LNG import bill already stands at approximately $7.0 billion annually, one of the largest single contributors to the merchandise trade deficit.

Pricing Reform Imperative

The dual-price system, where domestic gas is sold at $2.75/MMBTU while imported LNG costs $10-14/MMBTU, creates perverse incentives. Industrial consumers have no price signal to conserve or switch fuels. Fertiliser plants receive gas at subsidised rates that make domestic production cheaper than import alternatives, but the subsidy cost is borne by the energy system rather than the agriculture budget, obscuring true fiscal exposure. Gradual gas price reform, moving toward a blended cost-of-supply pricing, is essential but politically fraught in an economy where gas-intensive industries employ millions.

Chapter 3

Renewable Transition: The Gap Between Ambition and Reality

Bangladesh's renewable energy share at 4.6% of generation capacity stands in stark contrast to the SREDA/IEPP target of 40% by 2041. This is arguably the most consequential policy-implementation gap in Bangladesh's development agenda. At the current pace of deployment, reaching even 10% by 2030 would require an acceleration that has no precedent in the country's energy planning history.

Solar: From Off-Grid Success to Grid-Scale Stall

The IDCOL Solar Home Systems (SHS) programme deployed over 6.5 million units across rural Bangladesh, the world's largest off-grid solar programme and a globally recognised development success. It demonstrated that Bangladeshi consumers and technicians could adopt and maintain solar technology at scale. Yet the transition from distributed off-grid solar to grid-scale renewable generation has stalled.

The barriers are structural rather than technical. Land scarcity in the world's most densely populated major country (1,265 people/km2) limits utility-scale solar farms. Grid infrastructure designed for centralised gas-fired generation cannot easily absorb intermittent renewable output without significant transmission upgrades and storage investment. Policy uncertainty around power purchase agreement (PPA) terms and net metering regulations has deterred private investment. Solar irradiance at 4-5 kWh/m2/day, comparable to southern Spain, confirms that the resource is adequate; the constraints are institutional and financial.

Floating solar on Bangladesh's extensive water bodies (haors, rivers, reservoirs, coastal ponds) represents an underexplored pathway that could bypass the land constraint. Canal-top solar installations and rooftop solar (estimated potential of 3.5 GW in urban areas) offer additional land-neutral capacity. India's competitive auction model, which drove solar tariffs below $0.03/kWh, provides a proven template that Bangladesh has been slow to adopt.

Rooppur Nuclear: The Baseload Bet

The Rooppur Nuclear Power Plant (2.4 GW), Bangladesh's largest single energy investment at approximately $12.6 billion, is intended to provide emissions-free baseload power. Unit 1 commissioning is expected in 2025-2026, with Unit 2 following 12-18 months later. The strategic logic of nuclear diversification is sound: it provides firm, dispatchable capacity that complements intermittent renewables and reduces gas dependency.

However, the project carries significant risks. It introduces long-term dependency on Russian fuel supply chains (TVEL Corporation), with fuel assemblies sourced exclusively from Russia for the VVER-1200 reactor design. Sovereign debt obligations for the $11.38 billion Russian credit line extend over two decades. Operational safety in a flood-prone, seismically active deltaic geography requires world-class regulatory capacity that Bangladesh is still building. Workforce training for reactor operations and maintenance remains a critical readiness concern.

Coal: Stranded Asset Risk

Coal-fired capacity at 3840 MW (Payra 1,320 MW, Rampal 660 MW, Matarbari 1,200 MW under construction) was conceived when coal appeared to be the cheapest pathway to baseload expansion. The economics have shifted. Global capital markets are exiting coal financing, the EU Carbon Border Adjustment Mechanism (CBAM) will penalise carbon-intensive manufacturing exports, and the levelized cost of solar has fallen below coal in most markets. Japan's JICA-funded Matarbari is likely the last major coal project Bangladesh will be able to finance internationally. The $15-20 billion committed to coal infrastructure risks becoming partially stranded within the assets' planned operating lifespans.

Chapter 4

Financial Sustainability: Debt, Subsidies, and the IPP Burden

The financial sustainability of Bangladesh's power sector is in crisis. The Bangladesh Power Development Board (BPDB) has accumulated debt exceeding BDT 1000 billion (approximately $9 billion), driven by the widening gap between generation costs and politically constrained retail tariffs. Each year, the gap grows as more expensive imported LNG and oil replace cheap domestic gas in the fuel mix, while tariff adjustments lag cost increases by 12-24 months.

Annual energy subsidies of BDT 300 billion crowd out productive public investment in education, health, and infrastructure. The subsidy structure is regressive: affluent urban households consuming 300+ kWh/month benefit more in absolute terms than rural households on lifeline tariffs consuming 50-100 kWh/month. The political economy of tariff reform, where any increase triggers public backlash, has trapped successive governments into a cycle of under-pricing electricity, accumulating BPDB losses, and periodically seeking bailouts from the finance ministry.

The IPP Capacity Payment Problem

Independent Power Producers (IPPs) account for 48.0% of installed capacity. The IPP model enabled rapid capacity addition during the 2009-2018 build-out, when the priority was eliminating blackouts. However, it created a structural liability: BPDB must pay capacity charges to IPPs regardless of whether their plants are dispatched. With many gas-fired IPPs unable to run at full load due to gas supply constraints, BPDB pays idle capacity charges estimated at BDT 100+ billion annually, a deadweight fiscal cost for generation capacity that produces no electricity.

The concentration of IPP contracts in oil-fired and furnace-oil plants, originally intended as short-term "rental" capacity, has persisted far beyond planned timelines. These plants generate electricity at 2-3x the cost of gas-fired generation, yet their PPAs guarantee returns to investors while BPDB absorbs the losses. Contract renegotiation and retirement of high-cost rental plants is a fiscal priority that has been politically difficult to execute.

Chapter 5

Energy Security Strategy: Trade, Clean Cooking, Storage, and Policy Priorities

Cross-Border Electricity Trade

Cross-border electricity imports from India currently provide 1160 MW through several interconnection points. This capacity could expand to 3,000-5,000 MW through additional high-voltage DC links and substation upgrades. Trilateral arrangements to import Nepali hydropower through Indian transmission corridors would provide access to clean, dispatchable power at prices competitive with LNG-fired generation.

Regional power trade offers strategic advantages beyond cost: it diversifies supply sources, reduces single-fuel dependency, and provides access to seasonal hydropower surpluses from Nepal and Bhutan that complement Bangladesh's thermal-heavy fleet. The BBIN (Bangladesh, Bhutan, India, Nepal) power trading framework and the emerging SAARC market for electricity provide institutional foundations, though cross-border transmission investment and regulatory harmonisation remain bottlenecks.

Clean Cooking Transition

Clean cooking coverage at 28.0% (LPG or improved cookstoves) means 72% of households still rely on biomass, including wood, cow dung, and crop residues. Indoor air pollution from traditional cookstoves causes an estimated 78,000 premature deaths annually (WHO), disproportionately affecting women and children. Biomass collection consumes hours of daily labor, primarily by women and girls, reducing time available for education and economic activity. Deforestation from fuelwood demand compounds climate vulnerability.

The LPG transition, while progressing in urban areas, faces logistics constraints in rural distribution and affordability barriers for the poorest households. Electric cooking (induction stoves) is an emerging pathway that could leverage grid electrification, but requires reliable supply and affordable tariffs. The clean cooking challenge intersects energy, health, gender, and climate policy, yet remains siloed in institutional mandates.

Energy Storage and Grid Modernisation

Battery energy storage systems (BESS) are absent from Bangladesh's current energy mix, a critical gap for any serious renewable integration strategy. Grid frequency regulation, peak shaving, and renewable intermittency management all require storage capacity that does not exist. The declining cost of lithium-ion batteries (now below $140/kWh for utility-scale systems) makes storage economically viable, but Bangladesh has no procurement framework, grid code provisions, or incentive structure for storage deployment.

Grid modernisation extends beyond storage. The transmission system, designed for centralised thermal generation, needs smart grid technologies, distributed energy resource management systems (DERMS), and upgraded substations to handle bidirectional power flows from rooftop solar and distributed generation. The Power Grid Company of Bangladesh (PGCB) has begun transmission expansion, but the distribution network operated by BPDB, DESCO, DPDC, and the Palli Bidyut Samities requires parallel investment.

Policy Priorities

Toward a Sustainable Energy Future

Bangladesh's energy sector stands at an inflection point. The model that powered three decades of growth, cheap domestic gas feeding a rapidly expanding thermal fleet, is exhausting itself. CO2 emissions per capita at 0.52 metric tons and energy use at 287.8 kg oil equivalent per capita reflect energy poverty rather than efficiency. The transition ahead is not optional; the gas is running out regardless of policy choices. The question is whether the transition will be planned and orderly or forced and disruptive.

1. Emergency renewable auction programme. Launch transparent, standardised auctions for 5-10 GW of solar capacity over 5 years, modelled on India's programme. Prioritise floating solar on haors and water bodies to address land scarcity. Pair with battery storage procurement (target: 2 GW by 2030) and grid code modernisation for intermittent generation.
2. Tariff reform with targeted protection. Move to cost-reflective pricing for commercial and industrial users while maintaining means-tested lifeline tariffs for households below the poverty line. Use the fiscal space created to retire BPDB debt and fund renewable investment. Phase out regressive blanket subsidies that disproportionately benefit affluent urban consumers.
3. Regional power trade expansion. Expand the India-Bangladesh interconnection from 1160 MW to 3,000-5,000 MW. Develop trilateral Nepal-India-Bangladesh arrangements to import hydropower. Regional trade reduces fossil fuel dependency, diversifies supply, and provides clean dispatchable power at prices competitive with LNG generation.
4. IPP contract rationalisation. Renegotiate or retire high-cost rental power plant contracts. Convert viable oil-fired IPPs to dual-fuel capability. Establish a competitive wholesale market mechanism to replace bilateral PPAs, creating price transparency and reducing idle capacity payments that currently exceed BDT 100 billion annually.
5. Clean cooking national programme. Launch a dedicated clean cooking initiative targeting 60% coverage by 2030. Combine LPG distribution infrastructure expansion with electric cooking pilots in grid-connected areas. The health, gender, and climate co-benefits justify public investment at scale.