RBN Energy

For the U.S. oil patch, exports are the lifeblood of today’s market. U.S. refineries are operating at more than 90% of their rated capacity and using as much domestically produced light-sweet shale oil as their sophisticated equipment will allow. That means that virtually all of the incremental U.S. unconventional light-sweet crude oil production will need to be piped to export terminals along the Gulf Coast, loaded onto tankers, and shipped to refineries overseas. In today’s RBN blog, we discuss what this undeniable link between crude oil exports and production growth means for U.S. E&Ps and midstream companies — and the future of the oil and gas industry.

Consider this fact: Three of every five barrels of crude oil produced in the U.S. are exported, either as crude oil or in the form of gasoline, diesel, jet fuel or other petroleum products. Sure, large volumes of crude and products are still being imported, but the net import number is dwindling toward zero — and if you count NGLs (ethane, propane, etc.) in the liquid fuels balance, the U.S. has been a net exporter since 2020. Yes, folks, exports are now calling the shots, and the role of exports is only going to become larger over the next few years. In today’s RBN blog, we discuss highlights from our new Drill Down Report on crude oil and product exports and why they matter more now than ever.

The energy industry’s upstream products — crude oil, natural gas and NGLs — are commodities, so the lowest-cost producers generally do best, especially if they are well-connected to downstream markets. Due in large part to the intensity of competition, finite drilling locations, the constant need for capital investment and the chilling effect of political headwinds, the industry is in the middle of a consolidation cycle that has enabled a select group of top-tier E&Ps to build scale — and longer-lasting inventories — in the most productive parts of the most lucrative shale plays. That scale, in turn, helps these Shale Era winners reduce their costs, gain market share and — important in 2023 and beyond — return a big slice of their free cash flow to investors as dividends and stock buybacks. In today’s RBN blog, we discuss what’s driving that “urge to merge” and what it means for industry players large and small.

Since the start of this year, Canadian heavy crude oil prices have been steadily improving relative to the light crude oil benchmark of West Texas Intermediate (WTI). Improved access to and through the U.S. as far south as the Gulf Coast has contributed to these better conditions. At the same time, the traditional driver of increasing refinery demand after the end of the most recent maintenance season is being aided by the restart of two Midwest refineries that have typically been consumers of Canadian heavy oil. With international competitive pressures also easing and export buyers remaining active in the Gulf Coast, heavy oil prices could remain in a sweet spot for a good portion of this year. In today’s RBN blog, we look at why international competition for Canadian heavy crude will only intensify next year as vastly increased export access from Canada’s West Coast becomes available.

May the 4th be with you! Today — Star Wars Day to many of us — we borrow (and bastardize) one of the most memorable quotes from that epic collection of movies, “May the Force be with you,” to make the point that, like the “Force” that shapes events in the Star Wars universe, for the U.S. oil patch, exports are the lifeblood of today’s market. U.S. refineries are operating at more than 90% of their rated capacity and using as much domestically produced light-sweet shale oil as their sophisticated equipment will allow. That means that virtually all of the incremental U.S. unconventional light-sweet crude oil production will need to be piped to export terminals along the Gulf Coast, loaded onto tankers, and shipped to refineries overseas. In today’s RBN blog, we discuss what this undeniable link between crude oil exports and production growth means for U.S. E&Ps and midstream companies — and the future of the oil and gas industry.

The Shale Revolution transformed the U.S. oil and gas industry operationally and functionally in the late 2000s and early 2010s, but the most significant changes occurred years later. Through the middle and latter parts of the last decade, E&Ps continued to improve their drilling-and-completion techniques and significantly increased production as they gained experience. This production growth was enabled by — or driven by, depending on the perspective — midstream companies’ aggressive efforts to build out the pipelines, gas processing plants and other infrastructure required to handle higher production volumes and exports. More recently, capital market constraints, the Covid pandemic and a looming ESG narrative have propelled the industry into the next phase of its evolution, highlighted by fiscal discipline, which delivers improved shareholder returns through managed capital spending. But how long will this stage last — and what’s next? In today’s RBN blog, we examine the energy industry’s maturation and the differences between this transformation and those in other industries.

Russia has long been a significant supplier of refined intermediates and finished products to Europe, just as it has been of crude oil. That changed, however, in the wake of Russia’s invasion of Ukraine in February 2022 as the European Union (EU) implemented a formal embargo on imports of Russian crude oil in December 2022, followed by refined products in February 2023. In today’s RBN blog, we review the reduction in imports of Russian refined products and intermediates into Europe and the specific replacement sources.