Gulf’s OPEC Producers Open Their Wallets As They Curb Output

Gulf’s OPEC Producers Open Their Wallets As They Curb Output

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OPEC is being marginalized – or, more accurately, is allowing its volumes to be squeezed to protect price. OPEC’s share of global liquids supply has fallen steadily from 42% a decade ago to just over one-third today. The decline, of course, mirrors the rise of US tight oil production.

Yet on my latest visit to the Middle East in December, I was struck, once again, by the commitment to investing in upstream by three Gulf countries that together contribute half of OPEC production – Saudi Arabia, Kuwait and the United Arab Emirates (UAE).

I talked through what’s going on with Jessica Brewer, our Dubai-based Principal Analyst.

How much is the industry spending in the Middle East?

The region has been something of a haven for upstream investment through the downturn. Spend has fallen just 19% from US$83 billion in 2014 to US$67 billion in 2018, whereas global spend is down 40%.

Most of the drop has been in Iraq, where government finances have been affected by lower oil prices, and Iran, where geopolitical uncertainty has cut inward flow of capital.

Investment hasn’t fallen at all in Saudi Arabia, Kuwait and the UAE – spend has been stable at US$40 billion a year. Given that service sector costs have fallen, this indicates activity levels are well up.

Barrels in the bank: even though the Gulf’s producers are adhering to OPEC production cuts, they’re still investingGetty

Where’s the focus of spend?

The dominant theme in the region is the expansion of oil production capacity, which accounts for US$4 of every US$5 spent.

Iran and Iraq have enormous undeveloped resources and significant growth potential in the longer term.

Saudi Arabia, Kuwait and the UAE are focusing on brownfield projects with large-scale reserves around core fields already in production. Saudi Aramco’s Zuluf field is fairly typical. The next phase of development doubles reserves to over 16 billion barrels of oil and condensate, and doubles current production of 600,000 barrels per day (b/d) by 2023.

Developing these resources will tend to be more expensive than in the past, but the projects will still be highly competitive in global terms. All-in costs of the incremental development of Zuluf are around US$17/bbl on our estimates, below those of best-in-class non-OPEC greenfield projects and well below the best of pre-drill Permian tight oil wells.

What are the strategic drivers?

The energy transition and threat that oil demand may peak in the next 20 years has concentrated minds. Even the lowest-cost producers don’t want to run the risk of leaving low-cost oil in the ground. There’s a commercial incentive to develop reserves and be in a position to sell into a market where price is still supported by buoyant demand.

It’s also about regaining market hegemony. Kuwait is committed to increasing capacity from just over 3 million b/d today to 4.75 million b/d in 2040. The UAE is similarly ambitious, aiming to lift capacity from just over 3 million b/d to 4 million b/d by 2020 and then 5 million b/d by 2030. Saudi Arabia has no plans to increase capacity, but will invest to maintain the current 12 million b/d, which makes it OPEC’s biggest producer.

Does the world need more oil from the Gulf?

Yes, but not right now. The call on OPEC crude will edge lower for another year or two to just under 30 million b/d. Beyond 2020, we forecast the market needs more OPEC oil, perhaps an additional 5 million to 6 million b/d by the 2030s. Assuming decline from maturing OPEC countries, there’s potentially sizeable volume growth for Gulf producers to go for.

But there are risks in the strategy. Chief among these in the near-term is from the US. We forecast US tight oil adds another 5 million b/d by 2023, taking volumes to a plateau of 10 million to 11 million b/d by 2023. If the Permian continues to surprise on the upside, then more tight oil volumes would push additional OPEC volumes out into the future.

The other pillar supporting investment in capacity is oil demand. We expect the rate of demand growth to slow in coming years, but cumulative demand to increase by another 10 million b/d before peaking in the late 2030s. Tightening environmental policy and an accelerated penetration of electric vehicles beyond our aggressive base case are threats that could bring forward peak demand.

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