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Rev. Dec. 6, 2018
BE Oil
One morning in late January 2015, Quentin Bell was facing some hard truths about the near-term prospects
for his four-year-old oil company, BE Oil. The company had leased drilling rights on land in Colorado that
would potentially generate six new shale oil wells. Just five months earlier, with oil prices near $100 per barrel,
these wells appeared profitable. But in late 2014, oil prices plummeted to under $45 per barrel, dragging Bell’s
anticipated drilling profits down with them. In fact, on that cold January morning, Bell had to determine if any
of the six wells he had planned to drill were even worth starting. The only bit of good news was a slight
anticipated increase in oil prices over the next six months. He hoped this would presage a more dramatic rise
over time—otherwise, the market forces that drove oil prices might very well drive him out of business!
The Economics of Shale Oil Drilling1
In 2003, a technological breakthrough combined horizontal drilling with hydraulic fracturing (“fracking”),
enabling development of natural gas shale. In 2009, the innovation extended into oil development and
dramatically reshaped the US oil industry. Before 2009, shale oil production contributed minimally to the global
oil supply, but the technological change resulted in an increase of US oil production from 5.4 million barrels
per day in 2009 to 9.4 million barrels per day by the end of 2014. This increase represented over half of the
overall increase in oil production globally.
By early 2014, approximately 70 public oil and gas firms and more than 120 private firms were using
fracking technology. In fact, by mid-2014, these companies were producing oil from over 200,000 oil wells
across the five states that had shale oil fracking operations: Texas, Oklahoma, North Dakota, Colorado, and
New Mexico.
Shale oil could be found in geologic formations up to two miles below the earth’s surface. To extract these
reserves, firms first had to secure mineral rights from respective property owners. These oil leases allowed
energy companies to drill and then frack shale formations to free oil from shale rock. Shale oil well drilling was
somewhat unique relative to other types of oil extraction in that it required two distinct project steps. A
company first drilled the well and then, at a later date, it fracked the well.2 To drill a well, the majority of firms
in the industry rented a drilling rig from specialized service providers. It took between three days and three
weeks to drill onshore wells. The average cost was about $3.5 million, but it varied greatly based on geology.
Fracking typically occurred months after drilling and was usually performed by a specialized contractor, such
1 This section draws heavily from Erik Gilje, Elena Loutskina, and Daniel Murphy, “Drilling and Debt” (working paper, Darden School of Business,
2017).
2 In the parlance of the industry, to drill a well was to “spud” the well, and hydraulic fracturing was referred to as “completing” the well. Spudding
involved drilling the well into the shale and inserting steel well casings and cement.
This fictional case was prepared by Daniel Murphy, Assistant Professor of Business Administration, and Marc L. Lipson, Robert F. Vandall Professor
of Business Administration. It was written as a basis for class discussion rather than to illustrate effective or ineffective handling of an administrative
situation. Copyright  2018 by the University of Virginia Darden School Foundation, Charlottesville, VA. All rights reserved. To order copies, send an email
to sales@dardenbusinesspublishing.com. No part of this publication may be reproduced, stored in a retrieval system, used in a spreadsheet, or transmitted in any form or by
any means—electronic, mechanical, photocopying, recording, or otherwise—without the permission of the Darden School Foundation. Our goal is to publish materials of the
highest quality, so please submit any errata to editorial@dardenbusinesspublishing.com.
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as Halliburton, Baker Hughes, or Schlumberger. Fracking took two or three days and cost about $3.0 million.
As with drilling costs, this could vary greatly from well to well.
Once a well was completed, the high starting pressure led to high initial production levels, which declined
quickly as pressure was released. Consequently, the majority of output occurred in the first few months of
production, and oil prices at the beginning of a well’s productive life were critical in determining the well’s
economic returns.
Oil Production and Costs for BE’s Six Possible Wells in Colorado
Production costs for the six wells in Colorado were almost entirely related to drilling and fracking. The
leasing payments had already be made and were therefore a sunk cost. Once oil was flowing, additional costs
were negligible.
From 2012 through 2014, the revenues to BE Oil from a well generally exceeded the costs. However, the
drop in oil prices late in 2014 (see Figure 1) dramatically changed the landscape. While the decline in oil prices
had also reduced the average cost of drilling and fracking, this cost reduction was not enough to make up for
the drop in revenues. Furthermore, the cost of drilling each well depended on the accessibility of the oil. Wells
containing oil further in the ground or within denser rock formations tended to have a higher up-front cost of
extraction.
Figure 1. Real price of oil in 2009 US dollars per barrel.
Real Price of Oil (2009 USD per barrel)
140
120
100
80
60
40
20
1990‐01‐01
1991‐01‐01
1992‐01‐01
1993‐01‐01
1994‐01‐01
1995‐01‐01
1996‐01‐01
1997‐01‐01
1998‐01‐01
1999‐01‐01
2000‐01‐01
2001‐01‐01
2002‐01‐01
2003‐01‐01
2004‐01‐01
2005‐01‐01
2006‐01‐01
2007‐01‐01
2008‐01‐01
2009‐01‐01
2010‐01‐01
2011‐01‐01
2012‐01‐01
2013‐01‐01
2014‐01‐01
2015‐01‐01
0
Source: All figures created by authors.
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Exhibit 1 summarizes the relevant data for the six possible wells and shows the anticipated drilling and
fracking costs for each of them, along with the amount of oil each was expected to produce.3 All Bell needed
to establish the economic value of a well was an estimate of oil prices at the time of completion. Given the
expected lag between drilling and fracking any individual well, Bell estimated that it would be six months from
the start of the process until oil began flowing. Thus Bell’s decision on each well, if he were to make a decision
that January, would depend on oil prices anticipated for July 2015.
Oil Prices
The trajectory of oil prices was unclear as of the beginning of 2015. Futures prices predicted an appreciation
of over 10% in the next six months (see Figure 2).4 Bell had to decide whether his expectations for changes in
oil prices were aligned with the futures market. He also needed to determine how much BE Oil might lose if
oil prices remained low.
Bell was aware of research indicating that the recent drop in oil prices was due to both supply and demand
factors.5 A surprise increase in oil production from US shale oil producers contributed to a glut in the global
oil market. This supply-side effect was exacerbated by a slowdown in the world economy, which reduced
demand for oil. The relative importance of each of these effects was debatable, but Bell was sure that similar
global oil supply and demand factors would contribute to the future evolution of oil prices. Would Saudi Arabia
and other members of the Organization of Petroleum Exporting Countries (OPEC) restrict their oil production
to prop up prices? Would China continue its investments in oil-intensive infrastructure projects? Would global
economic growth pick up over the next year? The answers to these questions would guide Bell’s expectations
about the trajectory of oil prices, and hence, about the profitability of drilling and fracking each of his potential
wells.
3 The cost estimates recognized any anticipated changes in the costs due to inflation or demand for equipment. Given that any changes in drilling and
fracking costs related to oil prices occurred slowly and with a delay, Bell could reasonably treat those costs as independent of the oil price for his decisions
on the Colorado wells.
4 Futures contracts were financial instruments that allowed traders to lock in a price at which to buy or sell a fixed quantity of the commodity on a
predetermined date in the future. For example, the six-month futures prices specified the price at which traders of the six-month contract would buy or
sell oil for delivery in six months’ time. Researchers and analysts often equated the current futures price with the expected future price. For more on
futures prices and expected spot prices, see Ron Alquist and Lutz Kilian, “What Do We Learn from the Price of Crude Oil Futures?,” Journal of Applied
Econometrics 25 (2010): 539–73.
5 Christiane Baumeister and Lutz Kilain, “Understanding the Decline in the Price of Oil Since 2014,” Journal of the Association of Environmental and
Resource Economists 3, no. 1 (2016), 131–58.
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Figure 2. Percentage difference between futures price and spot price in the oil market.
30
20
10
0
‐10
‐20
2015m1
2014m9
2014m11
2014m7
2014m5
2014m3
2014m1
2013m11
2013m9
2013m7
2013m5
2013m3
2013m1
2012m9
2012m11
2012m7
2012m5
2012m3
2012m1
2011m11
2011m9
2011m7
2011m5
2011m3
2011m1
‐30
Six‐Month Futures Price
Summary
Bell did not let the chill in the air dampen his spirits. Until recently, oil prices had been much higher. Bell
hoped for a return to those levels. The long term, he believed, was bound to be brighter. But he did have to
make a decision on the six wells in Colorado. Due to the specific nature of the leases, he either had to drill or
give up the lease. And the decision had to be made in the next few weeks—before he would know for certain
where oil prices would go.
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Exhibit 1
BE Oil
Production, Costs, and Anticipated Revenue Projections for Wells Leased by BE Oil
Well
A
B
C
D
E
F
Barrels of Oil
(thousands)
30
110
15
30
30
30
Drilling and Fracking
Cost (millions of
US dollars)
2.00
6.00
1.00
1.50
1.00
3.00
Anticipated
Revenue at
$50/Barrel Oil
1.50
5.50
0.75
1.50
1.50
1.50
Anticipated
Revenue at
$60/Barrel Oil
1.80
6.60
0.90
1.80
1.80
1.80
Anticipated
Revenue at
$70/Barrel Oil
2.10
7.70
1.05
2.10
2.10
2.10
Source: Created by authors.
This document is authorized for use only by JAY HUH in Copy of Economic Analysis taught by Jun Auh, Georgetown University from Apr 2024 to Sep 2024.