Guyana - a new planet in oil’s solar system
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"I felt like some watcher of the skies when a new planet swims into his ken."
John Keats, "On First Looking into Chapman's Homer"
It’s that "watcher-of-the-skies-when-a-new-planet" stuff, to borrow from PG Wodehouse, who borrowed from Keats. The discovery of a major new oil play like Guyana instils the same sense of wonder on we oil industry devotees. What’s the story? How big could it be? Will it change the oil market?
Few oil producing countries produce more than 1 million b/d. Outside of OPEC you can count them on two hands: Canada, USA and Mexico; UK and Norway; China, Brazil and Oman; Russia and most recently Kazakhstan – the only new member in the 21st century. New admissions to the group don't happen very often.
Guyana, with no upstream oil industry four years ago, has a very good chance of joining this elite group.
What’s the story?
The Hammerhead find last month is the ninth discovery offshore Guyana in three years. The oil-bearing Miocene sandstone formation is the third play unlocked by ExxonMobil, Hess and CNOOC in the Guyana basin following seven discoveries in Cretaceous turbidite sandstone reservoirs and one in Late Cretaceous carbonate reservoirs.
Latin America analyst Ruaraidh Montgomery reckons total reserves on the huge Stabroek block are now in excess of 4 bn boe, most of it oil.
The exploration success rate for commercial discoveries on the block is an astronomical 82%; the global industry average is under 20%.
These reserves will be commercialised in double-quick time. The partners envisage a phased development using floating platforms that will deliver over 750,000 b/d of oil by 2025. The size of reserves and reservoir quality underpin the economics, with project NPV,15 break-even under US$40/bbl.
Production ramp up would be faster than anything ever achieved in a complex of giant fields in frontier deep water. The timing in the cycle is good, the joint venture has been able to leverage spare capacity in the supply sector, and best practice in project execution was honed in the downturn.
Even so, delivering these targets will be a challenge, reflected in our own more cautious forecasts of just under 700,000 b/d two years later.
Exploration is back making money with a long-overdue recovery to double-digit returns. Our latest view of exploration results confirms all the hard work to cut costs and commercialise discoveries is bearing fruit. We already see exploration returns of 13% in 2018, the highest calculated in well over a decade. As these discoveries are appraised and projects move through the development cycle, we can expect these economics to improve further. Get our complete analysis of the global exploration industry.
Global exploration review of 2018: Back in the blackBuy now
How big could it be?
The Guyana basin is the westerly ‘third’ of the wider Equatorial Margin, and includes Suriname (a modest onshore heavy oil producer) and French Guiana (one sub-commercial offshore discovery) as well as Guyana. The basin as a whole may hold another 8-10 bn boe of reserves, our estimate of yet-to find (YTF) reserves using creaming curve analysis. This would take the total to three times what’s been found so far in Guyana’s Stabroek block.
A health warning: extrapolating success from a handful of sweet spots can be pretty unreliable, in both directions. It’s worth bearing in mind too the ups and downs explorers have had over the last decade in proving up early breakthroughs across the Atlantic on the analogous West African Transform Margin.
The rest of the Equatorial Margin is in Brazil - the extensive Foz de Amazonas basin and smaller basins where small discoveries have been made in shallow water. These cover a vast area and deep water zones are only lightly explored. There are some doubts as to the source rock quality in places. The industry though is all over the Equatorial Margin - forty-two IOCs and NOCs hold acreage with Total, ExxonMobil, Anadarko, Hess and Equinor the biggest players. We expect around 50 exploration wells to be drilled over the next five years.
The last breakthrough play of similar scale was the Brazilian Santos basin pre-salt. In 2009, three years after the first discoveries, we forecast peak production of 0.9 million b/d.
Today, after 49 pre-salt exploration wells yielding many more discoveries, we expect over 2 million b/d.
This simple metric suggests Guyana itself might be headed for over 1 million b/d of production if exploration succeeds in converting YTF; the broader basin higher still if the plays extend into Suriname and French Guiana.
Will it change the oil market?
Not much on its own, for now at least. Guyana doesn’t look like rivalling Permian tight oil, well on the way from scratch towards 5 million b/d. But it is oil that the market will need to fill the supply gap in the early 2020s as mature provinces decline and demand still growing. And we need more Guyanas, many more.
Perhaps the biggest lesson from Guyana is that it shows the way forward for conventional explorers emerging from the downturn looking for growth opportunities. There are new plays out there, giant oil discoveries waiting to be unearthed and which can compete on full cycle economics.