This year’s second quarter will see the largest volume of liquids production cuts, including shut-in production, in the history of the oil industry, according IHS Markit analysis.
As much as 17 million b/d total liquids output (including nearly 14 million b/d of crude oil production) is now expected by IHS Markit to be cut or shut-in between April and June 2020.
“The Great Shut-In, a rapid and brutal adjustment of global oil supply to a lower level of demand is underway. All producing countries are subject to the same brutal market forces. Some will be impacted more than others. But there is nowhere to hide,” said Jim Burkhard, vice-president and head of oil markets, IHS Markit.
Oil demand in the second quarter of 2020 is expected to be 22 million b/d less than a year ago.
This collapse in demand combined with low oil prices, storage constraints, and government ordered cuts are driving what is an extraordinary level of liquids production cuts and shut-ins around the world.
North America and OPEC members, as well as countries in the Commonwealth of Independent States—particularly Russia—are expected to be the source of most of the cuts.
Key factors
Exactly where, why, and how supply cuts will take place is a complex matter. Oil is produced in a wide variety of environments, which means there is no fixed equation and decision factors vary. However, IHS Markit has identified three key factors that shape production cut decisions:
Technical and logistical factors—including restart complexity: Technical factors relate to the degree of operational complexity such as terrain, field depletion, reservoir drive, production system configuration and reservoir fluid composition. Complexity and field maturity influence how easy or difficult restarting production could be, including whether output could be forever lost or simply deferred. Other technical-related factors are health, safety, and worker availability. Logistical factors are offtake demand, transport options, and oil storage availability.
Financial considerations: These include operating margins, current oil price levels, future expectations of the oil price, financial health of the operator, capital availability and alternative spending options—such as deciding to spend money on other projects.
Regulatory and contractual conditions: These include ensuring compliance with government requirements for shutting-in wells, government orders to adjust production, and contractual obligations. Government orders to comply with the OPEC+ agreement to cut production fall into this category. Obligation to deliver associated gas is an example of a contractual condition that could impact production decisions. For upstream operations that are integrated with downstream assets—such as refineries and petrochemical facilities—downstream market conditions and needs of downstream assets could impact decisions about upstream output, especially when the assets are under combined ownership.
