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Which US Lower 48 operators have the largest, low-cost tight oil inventory?
We’ve modelled six mature gas plays to see which assets can offer the most upside to investors.
Smaller, simpler projects and infrastructure-led exploration are emerging as the right mix, with subsea tie-backs and infill drilling leading the way.
The remote region in the Russian north attracts attention with a resource potential of 5 billion boe and a geology similar to that of the prolific West Siberian basin.
With capital scarce, terms must be attractive to win new investment.
The Bureau of Safety and Environmental Enforcement has changed an important aspect of the leasing terms in deepwater GoM, which is likely to affect fields that have been appraised or are being appraised, and where leases are past their primary term or close to expiring.
After a flurry of development activity in the first quarter of 2017, the US Lower 48 onshore sector is beginning to feel the squeeze of cost inflation.
All eyes have been on US tight oil breakevens and the Permian boom during the past few years. But as deep water exploration has become leaner, this part of the industry has been quietly recovering and improving its own economics.
After a flurry of development activity in Q1 2017, the US Lower 48 onshore sector is beginning to feel the squeeze of cost inflation. Although this development was widely anticipated, impacts vary significantly depending on the source as well as project location.
Ben Shattuck, Principal Analyst and upstream expert, discusses the winners of our inaugural "Permian Upstream Awards."
Despite its superstardom in the upstream industry, tight oil remains the subject of debate: can it realise its potential as a profit engine, or will over-investment drive supply up and prices down?
Production from the seven most advanced developments in the Vaca Muerta play is expected to increase by 43% in 2017 to 77 kboed, and to double 2016 levels by 2018.
Downstream continues to demonstrate robust financial performance while upstream struggles.
Although Asian upstream players have been absent over the last 12 months, we believe this might be set to change.
Global oil demand is in for a year of strong growth but even small changes to our forecast could have major implications for price.
In Norway, interest in the sector is still high, but in the UK, the lowest number of exploration wells for 50 years and another 20% drop in capex point to a deeper malaise.
‘Underwhelmed’ sums up investors’ indifferent response to the Majors’ Q1 results. What does upstream have to do to win back favour?
Andrew Latham, our Head of Exploration Research, has built a global creaming curve for conventional exploration outside the USL48. Three themes stand out.
New thinking and new ways are needed if operators are to usher in a new era of investment in conventional projects. A dip in oil prices below US$50/bbl may be just what’s needed to concentrate minds and encourage companies to challenge industry conventions.
Chief Analyst Simon Flowers sees optimism after a flush of project FIDs, a pick up in US drilling and M&A activity.
Majors’ resource capture strategies are already becoming more balanced between exploration, unconventionals, DROs and M&A.
More operators are hinting through this Q3 results season at redeploying rigs in the coming months, potentially kick starting what will be tight oil’s second great growth phase.
Although the Presidency does not officially begin until January 20th 2017, the dearth of concrete policy proposals leaves a high level of uncertainty around the priorities of a Trump administration.
Digital technology has a major part to play in the next stage of structural cost reduction, but oil and gas production is far removed from the leading edge of the 21st century tech revolution.
If oil markets remain oversupplied and prices modest, there’s much Upstream operators can learn from Downstream, which has emerged thriving from the doldrums of a decade ago.
Not long ago, growth was the big thing. This results season suggests growth targets are making a come back.
How did US$20 billion in deals happen in a down market?
Much has been achieved in the past year, as we see prices and costs slowly turning around. But there is more work to be done. Use our 2016-2017 Global Upstream Cost Survey to understand North Sea cost evolution from 2014 to 2020.
Although 2017 brings a myriad of uncertainties, the new year also ushers in much-anticipated optimism for the global upstream industry.
This acquisition — the largest ever for Hi-Crush — is in direct response to increased drilling activity in West Texas.
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