US Shale Oil Boom and Bust
Behind the US Shale Oil Boom and Bust
Since 2014, U.S. shale oil has created a boom in domestic crude oil production.Shale oil comprises more than a third of the onshore production of crude oil in the lower 48 states. It drove U.S. oil output from 5.7 million barrels per day in 2011 to 9.2 million mbd in 2014. The U.S. Energy Information Agency forecasts U.S. oil production will reach 9.6 mbd in 2018.
Thanks to shale oil production, U.S. reliance on foreign oil imports has plummeted.
The EIA projects foreign oil will only account for 34 percent of U.S. oil by 2019. That's down from 45 percent in 2011, and a whopping 60 percent in 2005.
But oil prices are volatile due to commodities traders. They trade oil futures contracts at an auction similar to the options market. That mentality can make them bid prices up during a shortage, and bid them down during a surplus. The history of oil prices showed they that in 2008. They created an asset bubble, driving prices up to $145 a barrel in July. By December, they had bid oil prices down to $35.59 a barrel. Commodities markets was one of the reasons for the shale oil boom and bust.
US Shale Boom
Two factors drove the U.S. shale oil boom. First, oil prices averaged above $90 a barrel for three years (2011- 2014). That's was enough to allow shale exploration and production to be profitable.
Second, low-interest rates gave banks and private equity investors a strong incentive to lend to shale oil companies.
The total amount of loans totaled nearly $250 billion in 2014. (Source: "Debt and Alive," The Economist, October 10, 2015.)
The sudden jump in oil production created an oversupply that sent prices plummeting. Prices for West Texas Crude fell from $106/barrel in June 2014 to $32 a barrel in January 2016.
That's nearly as low as the bottom during the Great Recession ($30.28 on December 23, 2008).
Shale oil producers kept drilling. They became better at cutting costs the more they drilled. Their bankers kept rolling over their debt as long as interest rates remained low. Many producers had previously sold their oil at higher prices on the futures market. That hedged their income. To maintain market share, OPEC also kept pumping oil. Normally, it would cut production as oil prices fell. (Source: "As Oil Keeps Falling, Nobody Is Blinking," The Wall Street Journal, December 7, 2015.)
That situation could only continue for so low. Banks used oil reserves as collateral. As oil prices fell, so did the value of the collateral. As a result, many drillers became "upside-down." The same thing happened to many homeowners during the subprime mortgage crisis. As a result, drillers didn't add rigs as fast as they previously did. (Source: "U.S. Shale Juggernaut Shows Signs of Fatigue," The Wall Street Journal, October 5, 2017.)
In December 2015, the Fed began raising interest rates. Lenders became less willing to roll over debt. As a result, many shale companies desperately pumped enough oil to make their monthly debt payments.
They did this no matter how low prices got, even sacrificing profitability. Smaller companies, such as Sandridge Energy Inc., Energy XXI, and Halcón Resources, used 40 percent of revenue in 2015 to make monthly payments. (Source: "Oil Plunge Sparks Bankruptcy Concerns," The Wall Street Journal, January 11, 2016.)
Eventually, low prices caught up with the industry. Many stopped drilling. In October 2015, about half were sitting idle. Dozens filed for bankruptcy, and 55,000 workers were laid off. On January 20, 2016, oil prices fell to a 13-year low of $26.55/b. But the EIA accurately predicted that oil prices would rise again in time. (Source: "Frackers Who Drove Boom Struggle to Survive," The Wall Street Journal September 24, 2015).
A New Boom and Bust Cycle?
Oil prices began to rise. In April 2018, global oil prices averaged $72/b. Prices will average $63 a barrel in 2018 and in 2019, according to the EIA's oil price forecast.
But the high prices may not help the fracking industry. In the first three months of 2018, the top 20 companies by market capitalization had a $2 billion loss. Many of them were stuck with low revenue. They had accepted futures contracts when oil prices were low. They couldn't take advantage of high oil prices when they returned. Others suffered from transportation bottlenecks, as well as labor and material shortages that raised costs. Investors sentiment is shifting. They want the companies to become profitable. They aren't as willing to continue buying shares from losing companies.
US Shale Oil Reserves
The Bakken Field in North Dakota and Montana is the largest producing shale oil reserve. The field has layers of dense, oil-bearing rock about two miles underground. The field is roughly the size of West Virginia and produced 770,000 barrels of oil a day (as of December 2012). Although production started to take off in 2006, levels doubled by 2014. Horizontal wells provide 95 percent of production.
As a result, North Dakota extracts more oil than Alaska. It's closing in on the 2 million barrels a day produced by Texas. In 20 years, its number of wells could increase from the current 8,000 to at least 40,000. Part of the reason for expansion is that each well runs dry after about two years. That's because the oil is trapped in pockets that don't hold as much oil as traditional wells. However, in total, the field could contain nearly 4 billion barrels of shale oil. (Source: "Bakken formation oil and gas drilling activity mirrors development in the Barnett," EIA, November 2, 2011. "Bakken Emerges as Contender for US Oil Drilling Crown," CNBC, March 23, 2013.)
The Eagle Ford field in Texas produced 750,000 barrels/day as of 2011, nearly all from horizontal wells. The U.S. Geological Survey estimates there are 853 million barrels in undiscovered reserves. Drillers are searching for both oil and natural gas. (Source:"Trends in Eagle Ford drilling highlight the search for oil and natural gas liquids," EIS, November 2011.)
The Utica field in Ohio has anywhere from 1.3 and 5.5 billion barrels of oil. Ohio is currently producing 5 million barrels of oil a year. So far, the oil reserve is still being explored. (Source: "Oil and natural gas drilling in Ohio on the rise," EIS, September 2011.)
The largest U.S. reserve is the Monterey Shale formation near Bakersfield, California. It has four times the oil as the Bakken Field in North Dakota. It's 1,750 square mile area contains 15.4 billion barrels of oil. It's about 2/3 of the nation's total shale reserves.
But the California shale oil is much more difficult to extract than the Bakken. Its geological formation requires more intensive fracking and deeper horizontal drilling. That's a concern in a state that lies on the San Andreas fault, and already gets more than its fair share of earthquakes. As a result, environmental groups are adamentally opposed. (Source: Vast Oil Reserve May Now Be Within Reach," The New York Times, February 4, 2013.)
US Shale Oil Companies
The top five shale oil companies areEOG Resources, Anadarko Petroleum, Apache Corp., Chesapeake Energy, and Continental Resources. In 2014, they pumped 10 percent of total U.S. crude production. While smaller shale oil companies that took on debt may go bankrupt, these five will probably survive, if not prosper. (Source: "U.S. Producers Ready New Oil Wave," The Wall Street Journal, March 14-15, 2015.)