Gas demand is on the rise. In 2018, global demand grew by nearly five per cent, driven largely by Asia. This growth is set to continue for the next five years and more according to the IEA. In China alone demand for gas increased by almost 18%, as Beijing pursues its goal of improving local air quality and cutting pollution.
The fact that China’s gas demand is in part driven by environmental concerns is indicative of a much broader trend. Government commitments to carbon reduction and greater public awareness are contributing to this growing demand - whether it is for residential use (a key part of China’s strategy), power generation, or to meet industrial demand for electricity and chemical feedstocks.
The gas market in South East Asia, and elsewhere, is expanding because it can: the challenges surrounding transportation and logistics that have traditionally favoured oil over gas, have found solutions – albeit limited ones. LNG plants have transformed the economics of gas by making it far more transportable, as evidenced by Australia’s mega production facilities and Japan’s extensive liquification and regassification plants. Although not yet mainstream, compression technology offers the potential, at least, for another effective cost-efficient transportation of gas.
The cost of first gas
However, none of this disguises the fact that developing new gas fields remains complex and expensive in its current form. Consider Thailand: its thriving onshore and near-shore gas production is primarily driven by the requirements of onshore power generation, where it fuels 65% of the electricity generation. It is easier to distribute electricity to the point of consumption than it is to send the gas inland down lengthy pipelines.
It is not just electricity that is easier to distribute. Oil is still the main competitor for the growing gas market, not least because transporting oil in a barrel is more straightforward than moving gas. LNG, compression, or laying pipeline for gas distribution all require significant outlay, and can incur more indirect costs. For example, not every vessel is able to carry LNG or compressed gas and not every shipping lane or port is open to ships with these cargos. This changes journey times, transport costs, boil-off rates, bunker fuel needs and the associated financial calculations.
Unless producers are sitting very close to existing infrastructure in the form of platforms and existing pipelines, it can simply take longer to produce gas than oil in the same waters. Whereas oil producers can have a platform offloading first oil to a tanker within a year, that’s just not as feasible with first gas.
The financial risks with gas are compounded by uncertainty about the end product. It is straightforward to find a buyer for sweet dry gas, and charge a premium for it, but if the output is sour, it will come with smaller profits and far greater processing requirements. Scrubbing carbon dioxide and hydrogen sulphide can rapidly eat into margins.
The costs to first gas and the financial risks of securing it are therefore substantial, and many of these infrastructure costs are all but impossible to eliminate safely. So much so, that transmittal costs have been the breaking point for numerous proposed gas developments in South East Asia and elsewhere.
Large and small players
These financial risks have mostly shaped the industry to date. Once up and running, offshore gas platforms can be unmanned, and can need comparatively little operational intervention and resource in comparison to oil platforms. But getting to that point can be prohibitively expensive, with development costs alone running into tens of millions of dollars.
The result is the domination of large consortia developing mega fields. Although these projects have done much to enable gas-market growth, they also have a distorting effect.
The economics of ‘big gas’ tends to favour ‘big power-gen’, which leaves smaller producers, smaller generating plants and smaller industrial users out of the loop. A single methanol producer looking to optimise gas supply through its infrastructure may find itself cut out of preferential arrangements, for example.
Potential customers like these either need to find smaller operators to supply their needs or cease to be customers completely and become small producers in their own right.
Here we come back to environmental drivers. Smaller, localised generation fits into the more distributed power model that the electricity industry believes will reduce carbon emissions while ensuring security of supply. What’s more, the geography and population distribution in many countries in South East Asia lends itself to smaller power generation.
A flexible, modular, and intelligent approach
There is a diverse potential gas market in South East Asia that is currently not well served. To fill this gap, however, potential producers need to:
- Reduce CAPEX for exploration and production in the face of non-negotiable transport, logistics and essential safety requirements;
- Navigate the region’s diverse regulatory landscape, which ranges from full control of hydrocarbon production and supply to open, liberalised markets;
- Adapt to the availability of local content, fabrication yards, engineering expertise, and raw materials.
Flexibility is therefore key. Potential producers can certainly make marginal cost reductions by adjusting pipeline lays and other similar modifications. These can shave a million dollars or two off final costs. But that’s not enough of a game-changer when budgets can reach US$100 million. And if CAPEX for pipelines and transport cannot be safely reduced, it is time to look elsewhere to eliminate unnecessary costs.
Traditional offshore platforms – inflexible and monolithic in design – do not lend themselves to this diverse kind of market. But modular, conductor-supported platforms, such as our Sea Swift platform do.
These modern offshore platforms do more than shave costs here and there. Deploying tried and tested technologies they offer a degree of agility that leads to significant cost efficiencies which can fundamentally alter the financial dynamics of first-gas production.
Modular thinking can reduce the steel requirement, potentially allowing existing local logistics and fabrication facilities to be used. Furthermore, flexible lean designs can be adapted for fast-tracked implementation and simplified installation – lowering the total cost of ownership and, critically, accelerating time to first gas.
Smaller producers around the world are already using this approach to flip previously perceived unprofitable developments, into commercially viable projects. Intelligent flexible designs are ideal for South East Asia, where mature markets like Indonesia – home to some of the world’s earliest oil exploration – co-exist with industrial powerhouses like China and Japan, and emerging countries like Cambodia.
The reality is that if gas is to be the fuel of the future, traditional thinking is not going to deliver. The region has huge reserves of history, expertise and experience to draw on. The key to success will be calling on this capability and combining it with forward-looking offshore platform design. That way, the region’s other great reserve – it’s vast gas supply – can make a sustainable contribution to its economic growth.
Read the article online at: https://www.oilfieldtechnology.com/special-reports/27122019/asia-and-the-golden-age-of-gas/
You might also like
Serica Energy has announced the completion of the acquisition by its wholly owned subsidiary, Serica Energy (UK) Limited, of 30% non-operated interests in the P2498 and P2170 licences (together the Greater Buchan Area (‘GBA’)) from Jersey Oil & Gas (‘JOG’).