Bangladesh's energy crisis: Can FSRU solve it?

AQPS: The Quiet Innovation Inside Malaysia’s Gas Framework Agreement Electricity demand cannot be predicted perfectly Neither can rainfall, renewable generation, plant outages or fuel prices Yet a gas supplier cannot plan production, LNG imports and pipeline capacity based on: “We’ll take whatever the grid happens to need” This was precisely the problem addressed by the Allocated Quantity to the Power Sector (AQPS) under Malaysia’s Gas Framework Agreement (GFA) : https://lnkd.in/guanb2nu AQPS is the daily quantity of gas allocated to the power sector, while the Annual Contract Quantity is simply the sum of AQPS over an entire year At first glance, AQPS appears to be another gas nomination mechanism In reality, it solves a much bigger problem Managing uncertainty without eliminating accountability The Single Buyer decides which plants are dispatched to meet electricity demand. Those dispatch decisions determine how much gas the power sector consumes This means gas demand changes constantly as electricity demand, generation mix, outages and system conditions evolve A fixed annual gas commitment would be too rigid Complete flexibility would transfer almost all demand risk to the gas supplier. AQPS strikes a balance between both However, flexibility does not mean zero commitment The power sector must still take at certain percentage of the net ACQ under the Take-or-Pay provision The result is simple. The power system retains operational flexibility. PETRONAS receives a commercially credible demand commitment Is AQPS unique? Many countries prioritise domestic or regulated gas for electricity generation India pooled domestic gas and LNG to support gas-fired power plants. Indonesia allocates domestic gas to the power sector under government policy. Nigeria imposes domestic gas supply obligations for electricity generation However, I have not found another publicly documented framework combining all these features into a single market design, i.e systemic Sector-wide gas allocation. Daily allocated quantities building into an annual contractual commitment. Periodic re-forecasting and mutual confirmation. Centralised nominations and portfolio-level Take-or-Pay obligations None of these mechanisms is individually new The innovation lies in how they were integrated to support a centrally dispatched electricity market Why AQPS still matters AQPS recognised a fundamental truth : Electricity demand is uncertain. But uncertainty cannot mean the absence of commitment AQPS provided that balance. Commit annually. Adjust periodically. Nominate daily. Settle deviations transparently As Malaysia moves into the post-GFA era, the terminology may change. But the underlying challenge remains exactly the same How do we balance system flexibility with commercial certainty? That, in my view, is the real legacy of AQPS.

Japanese energy group Inpex broke ground Thursday on a liquefied natural gas project in eastern Indonesia that would become one of Asia's largest LNG facilities once operational. The estimated $20.9 billion Abadi LNG project sits in the Masela block in Arafura Sea, off the Tanimbar Islands, Maluku province. The project has been hit with many delays since gas was discovered there in 2000. Now, operator Inpex is targeting production to start in 2030. "Through the supply of energy, [Abadi is] an extremely important project that [will] contribute to energy security in Japan and across the Indo-Pacific region," Inpex President and CEO Takayuki Ueda said during the groundbreaking ceremony in Tanimbar, with Indonesian President Prabowo Subianto joining virtually from Jakarta. The Abadi field is estimated to contain about 18.4 trillion cubic feet of gas reserves. Once operational, the facility is expected to produce approximately 9.5 million metric tons of LNG per year and up to 35,000 barrels of condensate per day and about 150 million cubic feet of pipeline natural gas per day. This will make Abadi the second-largest LNG project in Indonesia after the Tangguh fields operated by British major BP in West Papua. Inpex holds a 65% participating interest in Abadi, followed by Indonesian state-owned energy conglomerate Pertamina with 20% and its Malaysian counterpart Petronas with 15%. The Southeast Asian companies joined the project in 2023 as energy major Shell sold its stake there. However, the long period between discovery and production in Abadi highlights chronic problems in oil and gas investment in Indonesia, where lengthy bureaucratic processes, policy flip-flops and resource nationalism have been blamed for many project delays. Subsequently, Southeast Asia's largest economy is struggling to reverse declines in its oil and gas production while energy import bills continue to rise. Indonesian Energy and Mineral Resources Minister Bahlil Lahadalia last month said Abadi must start production before 2029, when Indonesia will hold its next presidential election. He warned that the government might revoke the permits if the project is hit by more delays. An Inpex representative said the company never committed to the 2029 deadline. CEO Ueda told Nikkei Asia on the sidelines of Thursday's ceremony that "it is a very strong [hope from the] government to accelerate the project as quickly as possible. We got a lot of pressure from the government." https://lnkd.in/gAGR8qq9

The International Energy Agency (IEA) Governing Board has unanimously approved Nigeria’s accession as an Association country, the agency said on Sunday, marking a significant expansion of its ties with Africa’s largest oil producer and most populous nation. Nigeria, home to more than 240 million people and a major producer of oil and natural gas, will deepen cooperation with the IEA on energy security, market resilience and access to energy. The move brings the IEA Family’s coverage of global energy demand to more than 80%, up from 40% in 2015. “I am thrilled that Nigeria is joining the IEA – it is Africa’s most populous country and a major international energy player,” IEA Executive Director Fatih Birol said in a statement. “Nigeria becoming part of the world’s energy authority marks a milestone for global energy governance.” Birol thanked Nigerian President Bola Tinubu and Minister of State for Petroleum Resources (Gas) Ekperikpe Ekpo, saying deeper cooperation would benefit both sides as Nigeria works to strengthen energy security, support economic growth and expand access to electricity and clean cooking. Ekpo welcomed the decision, calling it an honour for Nigeria and urging other African countries to engage with the IEA to advance universal energy access and industrialisation. Nigeria has faced chronic energy challenges, with millions lacking reliable electricity and clean cooking fuels, even as it has emerged as a fast-growing market for decentralised solar solutions. The country has also boosted fuel exports in recent periods of market disruption, helping stabilise supplies in Africa and beyond. The decision builds on cooperation dating back to 2014. In September 2025, the IEA, Nigeria and the African Energy Commission held a joint roundtable in Abuja on reducing methane emissions from the energy sector. Nigeria is the first OPEC member to join the IEA as an associate. The IEA is an intergovernmental organisation established in 1974 that focuses on energy security, data analysis and policy recommendations, largely for energy consuming countries. OPEC, on the other hand, is an organisation of major oil-producing countries that coordinates petroleum production policies among its members. The IEA’s Association programme, launched in 2015, now includes 14 countries and aims to bring together major producers and consumers to promote secure, affordable and sustainable energy systems.

Bad news about Eskom’s gas plan. [We will have to import most of it (like petrol) and it is exposed to currency fluctuations] South Africa is considered to be among the top five best countries for solar generation due to a substantial number of annual hours of sunshine. South Africa was heading in the opposite direction to certain developed countries, which were reducing their reliance on gas. The United Kingdom, in particular, has reduced its demand for the resource as renewable energy has increased, in part due to the volatility of gas prices. Yelland previously highlighted how plunging [solar with] battery energy storage system prices had made the technology a potential contender against gas for peaking power. South Africa is considered to be among the top five best countries for solar generation due to a substantial number of annual hours of sunshine. https://lnkd.in/drUKkQeM

The International Energy Agency (IEA) Governing Board has unanimously agreed to admit Nigeria as an Association country, marking a major step in global energy governance and expanding the IEA Family to represent more than 80% of global energy demand. Nigeria’s importance in international energy markets has been underscored by recent developments in refining and fuel exports from the Dangote Refinery in Lagos. https://lnkd.in/dyabiSFF

The Ministry of Energy of the Republic of Azerbaijan has released its official operational data for the first half of 2026 (January–June), showcasing steady hydrocarbons production alongside significant milestones in green energy generation. Key metrics from the mid-year reports include: 🔹 Hydrocarbon Production & Export Volumes • Natural Gas: Total gas output reached 25.4 billion cubic meters (bcm). Out of this volume, 13.7 bcm came from Shah Deniz, 7.3 bcm from Azeri-Chirag-Gunashli (ACG), 3.6 bcm from SOCAR, and 0.8 bcm from the Absheron field. • Gas Exports: Total gas exports reached 12.7 bcm, with 5.9 bcm directed to Europe, 4.9 bcm to Türkiye (3 bcm via TANAP), 1.2 bcm to Georgia, and 0.7 bcm to Syria. • Oil & Condensate: Country-wide production stood at 13.3 million tons, with ACG contributing 7.9 million tons, Shah Deniz 1.7 million tons, Absheron 0.3 million tons, and SOCAR accounting for 3.4 million tons. Total oil exports for the period reached 10.5 million tons. 🔹 Electricity and Green Energy Surge • Total Power Generation: Azerbaijan generated 13,388.6 million kWh of electricity during the first six months of the year. • Green Energy Footprint: Total renewable energy production reached 2.8 billion kWh. Hydropower plants (HPPs) led the renewable mix with 1,891.7 million kWh, while wind power plants (WPPs) generated 475.7 million kWh, and solar power plants (SPPs) contributed 282.7 million kWh. The solid household waste incineration plant accounted for the remaining 143.6 million kWh. These data points reflect Azerbaijan’s dual role as a reliable supplier of traditional transitional hydrocarbons to global markets and an accelerating force in regional renewable energy deployment. 🔗https://lnkd.in/dNUKpV9M 🔗https://lnkd.in/dMW7pjC2 #Azerbaijan #OilAndGas #GreenEnergy #SOCAR #SOCAR_Turkmenistan

Europe's energy map has been redrawn. Algeria is emerging as one of its most critical gas suppliers. On 17 July 2026, Algeria's state energy company Sonatrach and German energy group VNG signed an expanded pipeline gas agreement in Berlin, with increased volumes commencing 1 January 2027. This builds on a relationship that only began in February 2024, when VNG became the first German company to purchase Algerian pipeline gas directly. What makes Algeria's position distinct from other suppliers? Pipeline gas travels via Transmed, bypassing the Strait of Hormuz entirely. Algeria's first LNG cargo to Germany arrived on 2 July 2026 at the Wilhelmshaven 1 terminal. A dual-route supply architecture is now operational, with pipeline and LNG running simultaneously. Green hydrogen and ammonia cooperation has already been formalised via an MOU signed in June 2026. Both companies are also participating in the SoutH2 Corridor and ALTEH2A hydrogen frameworks. This points to a partnership designed not just for today's gas market, but for the broader energy transition ahead. For context on scale, Germany imported approximately 11.5 billion cubic metres of pipeline gas in just the first four months of 2026. That is roughly one-quarter of Europe's total pipeline imports over that period. With Hormuz closures constraining Persian Gulf LNG since February 2026, Algeria's chokepoint-free overland route has quietly become a structural advantage that buyers are actively pricing in. This is not a temporary bridge arrangement, but a multi-decade commercial alignment being built to span the full energy transition. Enjoy this summary? Hit the like button and follow this page to stay up to date on European energy security and North African gas supply developments. Want to know more? Read the full breakdown of the Sonatrach-VNG deal and what it signals for European energy markets here: https://lnkd.in/g7TzGvh8

Indonesia is short of natural gas, yet this massive project has taken almost 30 years to materialise. The CCS for this project is actually removing CO2 from the natural gas stream and reinjecting it back into the gas field for enhanced gas recovery. "Abadi will be one of Indonesia’s largest sources of natural gas, bolstering domestic energy security for decades while maintaining the country’s position as a major LNG exporter. It is expected to begin production around 2029 or 2030. Bahlil Lahadalia, Indonesia’s minister for energy and mineral resources, said the project is expected to produce 9.5 million tonnes of LNG annually, along with 150 million standard cubic feet per day of pipeline gas and 35,000 barrels of condensate a day. “Around 60 per cent of the gas output will be allocated to the domestic market, with priority given to downstream industries, particularly fertiliser production and other industrial feedstock,” he said during a livestreamed groundbreaking ceremony. The project will also incorporate carbon capture and storage technology, making it one of Indonesia’s first large-scale LNG developments to integrate emissions reduction measures from the outset. The groundbreaking is seen as a key test of Indonesia’s ability to execute large-scale investments and reassure foreign investors that multi-billion-dollar projects can move forward. The project, first conceived in the late 1990s, was repeatedly delayed by regulatory changes, revisions to its development plan and shifting investment priorities." https://lnkd.in/gpJfDxeJ Meanwhile the huge Andaman Block has yet to be commercialised. "Indonesia is evaluating Aceh's proposal to process natural gas from the offshore Andaman Block at the Arun Special Economic Zone, with authorities weighing project economics against regional development goals, Energy Minister Bahlil Lahadalia said. Speaking in Banda Aceh on Saturday, Bahlil said discussions were continuing to find a solution that benefits both the government and investors. "I cannot make a final decision because discussions are still underway....The government cannot approve a plan if development costs make the project commercially unviable, Bahlil said. "No business can operate at a loss. Aceh must benefit through regional revenue, and investors must also earn returns," Bahlil said. Aceh Governor Muzakir Manaf has asked President Prabowo Subianto and the Energy Ministry to delay approval of the field's Plan of Development. The province wants gas processed through an Onshore Receiving Facility at the Arun Special Economic Zone instead of a floating offshore production system. Aceh is also seeking a dedicated gas allocation to support industrial development. Bahlil said the fields lie well beyond Indonesia's 12-nautical-mile territorial limit, making subsea pipelines costly. "If we build the pipeline, capital expenditure will be extremely high. Gas prices could exceed US$10 per MMBtu," he said." https://lnkd.in/gYAch72h

INPEX Launches Construction of Indonesia’s US$21 Billion Abadi LNG Project: A Strategic Milestone for Regional Energy Security. Japan's INPEX has officially commenced construction of the long-awaited Abadi LNG Project in Indonesia's Masela Block, marking a significant milestone for Southeast Asia's energy sector after more than two decades of planning and regulatory evolution. With an estimated investment of US$21 billion, the project is among the largest upstream natural gas developments in the Asia-Pacific region and is targeted to begin production in early 2030. The Abadi LNG Project will feature an onshore liquefied natural gas (LNG) facility with a production capacity of 9.5 million tonnes per annum (MTPA), supported by a 150 million standard cubic feet per day (MMscfd) gas pipeline system. In addition to LNG production, the project includes the construction of offshore wells, processing facilities, terminals, and jetties, all of which will be developed simultaneously to accelerate project delivery. Indonesia's President Prabowo Subianto highlighted the project's strategic importance in strengthening national energy security and urged stakeholders to expedite its completion. Echoing this vision, INPEX President and CEO Takayuki Ueda described Abadi as a critical project that will reinforce long-term energy security not only for Japan but also for the wider Indo-Pacific region. The Masela gas discovery was first announced in 2000, yet its development has faced repeated delays due to changes in government development plans, redesign requirements, the COVID-19 pandemic, and the integration of carbon capture initiatives to reduce project emissions. The groundbreaking ceremony therefore represents the successful transition of one of Asia's most challenging LNG developments from planning into execution. Indonesia also intends to maximize the project's domestic economic value. According to Energy Minister Bahlil Lahadalia, at least 60% of the gas production will be allocated to the domestic market, supporting Indonesia's growing industrial, power generation, and energy needs. The remaining production will strengthen the country's position as a major LNG exporter. Market confidence is already evident, with Indonesian state utility PLN signing a preliminary agreement to purchase 37.5 million tonnes of LNG over a 15-year period, alongside commitments from other prospective buyers. https://lnkd.in/gaj2_KE8