WTI/Brent Spread has Crude by Rail on the Ropes

Rail has been integral to moving Bakken crude out of the basin since 2012 when production very quickly outstripped pipeline takeaway capacity, causing differentials to blowout as wide as $49/Bbl between Bakken field prices and Brent.  As designated by the yellow shading in the graphic below, the historical cost of moving Bakken to Gulf Coast, West Coast, and East Coast markets via crude by rail ranged between $7/Bbl and $18/Bbl, creating a significant arbitrage opportunity for Bakken crude by rail movements.

Crude by Rail - Bakken vs Brent Differentials

Bakken crude by rail facilities allowed crude to flow to the East and West Coast refining complexes which remained isolated from growing domestic crude production due to a lack of pipeline connectivity.  Bakken crude by rail volumes quickly sky-rocketed to 700 Mb/d and, even in June, provided almost half of the light supply into the 1 MMb/d light refining market on the East Coast.  Previously, pipeline constraints in the Permian and the Eagle Ford had created wide differentials in the Gulf Coast as well, which once supported Bakken to Gulf Coast crude by rail movements.  However, as Permian pipeline projects like Longhorn and Sunoco’s West Texas Gulf expansions added significant takeaway capacity in mid to late 2013 to the Gulf Coast, it became more difficult for the Bakken to compete into the Gulf Coast markets and as a result, Bakken to Gulf Coast crude by rail volumes have been declining since mid-2013.

Bakken Crude by Rail Volumes by Destination

After prices collapsed late last year, the spread between WTI, Brent, and Bakken field prices have tightened, challenging the economics of rail.  The arbitrage opportunities created by using crude by rail to capture the spread between WTI and Brent are all but eliminated.  Producers are trying to minimize loses, and for many, that means moving more crude via pipelines.   While pipeline capacity has been limited for years now, historically, Enbridge’s pipeline from North Dakota to Clearbrook, MN, has had spare capacity when Brent and WTI spreads were wide and rail to the East Coast was a more profitable option.

Enbridge ND Flows and Brent/WTI Spreads

However, when spreads collapse, as they did in the summer of 2013 and now, flows on this pipeline increase.  Pipelines are typically a cheaper mode of transportation and when Brent/WTI differentials are at sub $5/Bbl, crude by rail margins are razor thin.

Over the next few years, projects like Dakota Access and Enbridge’s Sandpiper will add over 675 Mb/d of new pipeline takeaway capacity to the Williston Basin and will likely disrupt traditional rail flow patterns .  The addition of these pipelines will create an overbuild of infrastructure in the Williston Basin, and as rail and pipelines compete for volumes, Williston Basin differentials are likely to remain tight, squeezing the margins of shippers.  The story of Bakken infrastructure mirrors that of the Northeast – firm commitments that were once viewed as an asset will soon become a liability.

SD Slide

To follow these items and more, subscribe to BTU Analytics’ Energy Market Commentary here.

Share This Article

Share on facebook
Share on twitter
Share on linkedin
Erika Coombs is Manager of Consulting Services at BTU Analytics. She leads the team to deliver customized energy-market analysis and provides BTU Analytics’ customers with critical information for a variety of energy markets including oil, gas, and NGLs from wellhead to downstream markets. She also leads research on upstream analysis, crude oil midstream infrastructure, breakeven economics, and commodity pricing dynamics for several BTU Analytics’ reports. She holds a M.S. in Mineral and Energy Economics from the Colorado School of Mines.

Recommended for You

Log In

Energy Market Insights

Receive Free Energy Market Insights When They Are Published