Q1. Could you start by giving us a brief overview of your professional background, particularly focusing on your expertise in the industry?

I have 30 years of experience in the energy sector, mainly in oil and gas. I spent my first 10 years at British Gas and the last 20 years at Shell.

I have worked with two major oil companies, Shell and British Gas. For 25 years, I focused on the commercial side of gas and LNG, including pricing, contracts, disputes, negotiations, and long-term sales. I also have experience with infrastructure like transmission, terminals, and networks, as well as stakeholder management. I have worked closely with both government and private sector leaders, often at the C-suite level, to build transactions. In the last five years, I shifted to low-carbon solutions, helping set up manufacturing for products that reduce carbon emissions compared to traditional fossil fuels. These include renewable diesel, which can replace regular diesel, and second-generation ethanol, which can be blended with petrol or gasoline for vehicles and buses. There is also sustainable aviation fuel, which replaces traditional jet fuel and helps lower carbon emissions. Another example is renewable natural gas, sometimes called CVG.

In India, biomethane can be used to generate power, fuel vehicles as a CNG alternative, or serve as an industrial fuel. Over the past five years, I learned how to set up low-carbon businesses, understand feedstock markets, and use technology to turn feedstocks into useful products. While these products are still developing in Asia, the market in North America is more advanced. Europe and the ACA are also making progress. I spent about 5 years learning how different governments support demand through regulations and how the ACA can serve as a supply source for these products in the growing market.

Q2. How is the rise of domestic industrialization in the GCC impacting the 'uncommitted' LNG volumes available for the 2028–2030 window? Is the market underestimating a supply squeeze?

In the GCC countries, domestic industrialization and power needs are being met by both gas and renewables. While demand for gas is rising, a significant share of energy is now coming from renewables. Countries like Saudi Arabia, the UAE, and Oman are building large renewable capacities, helping industries rely less on gas. Although gas demand is increasing, it is not yet high enough to threaten the supply positions of these countries. For example, Saudi Arabia has increased its focus on LNG. While they have domestic gas needs, they have also set up a separate company and trading desk to handle LNG trading globally.

This approach is expected to strengthen their market position in the coming years. I do not expect supply shortages from GCC countries; in fact, more supply will likely come from places like the UAE. The US is also increasing its supply. Supply is growing rapidly and is expected to provide more volumes to global markets, including Europe and Indonesia. Russia also remains a significant supplier, regardless of its relationship with Europe. Taking all these factors into account, a supply squeeze is highly unlikely. That's my view on this topic.

Q3. Everyone is betting on Sustainable Aviation Fuel (SAF), but the feedstock (UCO/Tallow) is finite. From your ground-level experience, which specific SAF technology pathway is currently 'bankable' without 100% reliance on government subsidies?

HEFA is currently the most reliable technology. It allows you to repurpose existing refineries and use feedstocks like used cooking oil, animal fat, and certain plant oils. While corn oil is not widely available in Asia, it is common in the US and South America and is easily used by HEFA to produce sustainable aviation fuel. HEFA is a proven and commercially available technology with a strong track record.

Q4. With the Strait of Hormuz effectively closed, Qatari and Emirati volumes are 'trapped.' Based on experience, how do you see portfolio players managing their 'back-to-back' obligations to Asian utilities?

Portfolio players have a distinct opportunity when structuring downstream contracts. Entering into downstream agreements does not prevent them from linking specific volumes to a supply source. If the portfolio player has contractually tied downstream volumes to a particular supply source—such as Qatari LNG—this explicit reference allows them to invoke force majeure on those volumes if Qatar declares a force majeure event. In such cases, the contractual link means the portfolio supplier can pass through the force majeure from Qatar up to their downstream customers.

However, if there is no such explicit linkage between the downstream volume and a supply source, the portfolio player remains obligated to supply those volumes to the downstream market, regardless of disruptions in Qatar. In that scenario, the portfolio player is exposed and may have to source replacement LNG from the market to meet their contractual obligations.

This is the core exposure for portfolio players: without explicit contractual links to a supply source, they must fulfill their downstream obligations regardless of upstream disruptions. While managing a diversified portfolio allows them to optimize supply, the absence of such linkages means they bear the risk and must source the required volume—either from uncommitted inventory within their own portfolio or, if that is insufficient, by purchasing LNG from the market.

For example, a portfolio player selling volumes from Qatar and also holding uncommitted Australian LNG can potentially redirect this uncommitted volume to fulfill obligations originally tied to Qatari supply, if needed. The key takeaway is that the ability to declare force majeure and pass through upstream events depends on the contract's explicit language. Many contracts do allow for such references, but in their absence, the portfolio player must rely on their own supply flexibility. If their portfolio lacks uncommitted volumes, they are forced to buy from the market. If they have sufficient uncommitted supply—from, say, the US or Australia—they can manage obligations internally. In summary: always ensure explicit contractual arrangements for supply-source linkage to manage risk effectively.

Q5. With QatarEnergy declaring Force Majeure, how do legacy contracts typically define 'hostilities' versus 'blockades'? If the Strait is physically open but 'commercially deterred' by insurance withdrawals, does that legally sustain a long-term FM claim?

Force majeure is not limited to issues with transportation or access to shipping channels. It also encompasses situations in which the physical safety and integrity of the LNG facility are at risk, making it unsafe or unwise to continue operations. In the case of Qatar, after experiencing hostile incidents such as drone and missile attacks, the authorities would have conducted a thorough risk assessment. If they determined that continuing LNG operations would threaten the safety of the plant and its personnel, it would be reasonable—and responsible—to halt production. Under such circumstances, the inability to access or produce LNG due to ongoing threats would trigger force majeure provisions in downstream contracts.

Ultimately, force majeure is about the discontinuity of operations under hostile or unsafe conditions that endanger the plant or project as a whole. When force majeure is claimed, the burden is on the party making the claim to demonstrate that they acted as a reasonable and prudent operator, taking all possible steps to mitigate the situation before stopping operations. The onus is on Qatar to show that halting production was the only viable option after exhausting all reasonable measures.

In summary, force majeure should be viewed more broadly than just a loss of transportation access. It also includes operational shutdowns for safety reasons, provided the operator can justify the decision in accordance with industry standards for reasonable and prudent conduct.

Q6. Is there a realistic prospect of a 'Dark Fleet' for LNG emerging? Based on your ground experience in India, how would the regulatory framework handle 'uninsured' or 'shadow-insured' cargoes to prevent a national blackout?

The prospect of a so-called 'dark fleet' or 'shadow fleet' emerging in the LNG business is highly unlikely. To date, the only credible example is the small fleet transporting Russian LNG to China via a single terminal. Even within this fleet, the recent reported bombing of a tanker near Libya—reducing the already limited fleet by about 20%—demonstrates just how fragile and marginal this segment is. With very few such vessels in operation, and one now out of circulation, their presence in the LNG space is diminishing even further.

There are also not enough sanctioned projects globally to incentivize the expansion of such shadow operations. Unlike in oil markets, there is little motivation or opportunity for LNG shipping participants to engage in such activities. As a result, it is extremely unlikely that shadow or dark fleets will gain any meaningful momentum in the LNG sector.

Turning to the Indian context, all LNG received on a delivered-ship basis must meet strict compatibility and compliance requirements—including technical specifications, vessel flag, and country of origin. Indian customs authorities must be informed in advance of each incoming LNG carrier, including its ownership and operational history. This level of transparency and regulation makes it virtually impossible for a shadow or uninsured tanker to deliver LNG undetected into India.

Furthermore, many Indian LNG import deals use dedicated ships owned or long-term chartered by Indian companies such as Petronet and GAIL. Even if a third-party vessel were to be used, port and customs regulations in India ensure rigorous oversight. Beyond primary compliance, there are significant secondary compliance and financial system checks that further reduce the risk of shadow fleet operations in the Indian LNG market.
In summary, the emergence of a dark or shadow fleet in LNG is highly improbable globally, and especially so in India due to comprehensive regulatory and compliance frameworks.

Q7. If you were an investor looking at companies within the space, what critical question would you pose to their senior management?

If I were investing in an LNG portfolio player, I would focus on several critical questions for management. First, I would want to understand their supply sources and the nature of their contracts—both firm and flexible arrangements. It’s essential to know which markets they serve, their downstream commitments, and the volume that remains uncommitted or open.

I would also examine whether their supply sources are high-carbon or low-carbon, especially as regions like Europe are imposing more stringent carbon requirements on LNG imports. Supplying to Europe in 2026–2028 could bring unexpected challenges if carbon intensity is not proactively managed.

If I were investing in regasification terminals, my focus would shift to the physical location, climate risks, and long-term mitigation plans. Regasification infrastructure is typically a 20–30 year investment, so understanding evolving environmental risks—such as rising sea levels—is crucial. One must also consider local environmental impacts, the port’s characteristics, market access, and the extent of regulatory oversight, including tariff restrictions or flexibility.

Connectivity is another key factor: how is the regas terminal linked to main transmission systems, and are there any disputes or challenges with grid access or direct connections to key customers? Grid integration issues can significantly impact commercial performance.

If looking at downstream city gas distribution companies, I would want to know about their supply portfolio, the basis for their LNG purchases, the proportion of domestic gas, contract terms, and the composition of their customer base—industrial, commercial, domestic, and CNG. I’d also ask about pricing structures, benchmark references (such as Henry Hub or oil indexation), and how their upstream contract terms align with downstream obligations. Understanding exposure on either side of the value chain is vital.

These are just some of the high-level considerations that would apply to portfolio companies, regas terminals, and distribution businesses. Similar approaches can be taken for transportation and liquefaction segments, though those may be less relevant depending on the investment focus.