Case 27 To Use or Not to Use?
Beaufort Sea Production Company (BSPC) operates a medium-sized oil
field on Alaska’s north coast. The field is still producing at its
maximum rate, 325,000 barrels of oil per day (BOPD). However, to
sustain this rate the company started a waterflood of the reservoir
two years ago. Now a capacity bottleneck in the water disposal
process is threatening to curtail production. In waterflooding,
salt water from the Beaufort Sea is treated to remove debris,
impurities, and oxygen (to minimize corrosion problems). It is then
pressurized to 2800 psig for injection into the reservoir, where it
serves two purposes. First, it sweeps the oil toward nearby
production wells, which increases oil recovery from the swept area.
Second, it maintains the reservoir pressure for all wells by
replacing the oil that is removed. The injected water also becomes
part of the fluids that are brought up through the production
wells. Over time the wells steadily produce more and more water,
which must be re-injected. They are now making 200,000 barrels of
water per day (BWPD), and they can dispose of up to 380,000. Over
the next three to four years, they expect the produced water rate
to increase to around 600,000 BWPD before leveling out. This
produced water does replace an equal volume of seawater as the
injection fluid. But due to the incompatibility of the seawater and
the produced water (mixing causes immediate precipitation of
calcium carbonate scale), different pump modules must be used. More
pump modules must be added.
Case 27 To Use or Not to Use?
133
The lead time on new facilities is about 2 years, so alternatives
to increase the disposal capacity of the produced-water system must
be evaluated now. If the capacity is added too late, then oil
production rates must be reduced to match the existing capacity.
The economic penalties of deferred production are heavy. In fact,
if the production is deferred too long, some of it may still be
unrecovered when it becomes uneconomic to produce the field. Fred,
the lead project design engineer, has identified two primary
options for the expansion. The first and lowest capital cost option
is to complete construction of a module started three years earlier
as part of the initial water flood facilities. The company had
already spent $12.5 million on this module, when a new water flood
plan reduced the area to be flooded. This made the third module
unnecessary, construction was immediately stopped, and the module
was mothballed. The pump and aero derivative gas turbine had
already been purchased and the module partially constructed. Since
then, the mothballed module has been stored at the construction
site. The design engineers estimate that it would cost an
additional $22.5 million to complete, modify, and install it.
Modifications include another produced-water tank and booster pumps
to supply the water at the proper pressure for the suction of the
high-pressure pump. Management at BSPC sees this as a chance to
salvage a useless module. The pump more than meets the
requirements, since it has a design rate of 400,000 BWPD at 3375
psig. At the required pressure (2800 psig), it can pump up to
480,000 BWPD. If not used for this, the module’s only value is for
spare parts for the two installed units. The book value of these
spares (essentially only the pump and turbine, since the module is
unusable) is $4.4 million. An extra $1.9 million is required for
this option for replacement of the gas generator spare. The second
alternative is to add more pumps similar to BSPC’s two largest
producedwater disposal pumps. There are eight total. Each pump in
the largest pair uses a 4600 horsepower (hp) industrial-type gas
turbine to pump up to 85,000 BWPD. Three of these pumps would be
needed. Fred’s estimate for total costs is $30.1 million. Fred
realized that he needed some operation and maintenance (O&M)
costs. Since he has had very little operating experience, he asked
some engineers with the BSPC production facility to help. He was a
bit surprised with their response. Operations had experienced many
problems with the two 400,000 BWPD waterflood modules, especially
during the first year. Correcting several manufacture-related
problems had helped, but the pumps still did not run as smoothly as
planned. Luckily, short interruptions of the injection of “new”
seawater have minimal impact on the production of oil.
Cases in Engineering Economy 2nd by Peterson & Eschenbach
134
The production engineers were concerned with using such a large
machine where shutdowns impact production greatly and quickly.
Initial calculations of “residence times” indicated that there
would be less than an hour to respond to an unexpected loss of the
pump. With such a short response time, they would have to
immediately shut-in a large number of production wells (80 to 90,
if it were running at full capacity). They felt very strongly that
they would operate the pump at a reduced capacity, probably less
than 340,000 BWPD. Even at this reduced capacity, a number of the
smaller pumps would be shut down. On the positive side, they noted
that the excess capacity could be useful should they have to shut
down one of their smaller pumps for maintenance. In fact, it could
actually serve as an on-line spare. Since the two 85,000 BWPD pumps
had only been installed for six months, little O&M data were
available. They did know that when these pumps shut down
unexpectedly, the operators only needed to cut back the wells with
the highest water production rates. No wells had to be completely
shut-in. The addition of three more small pumps would give them
eleven pumps with no full spares. With that many pumps, the chances
of one or more being down was substantial. They estimated that the
more numerous “minor” cutbacks in production would about equal the
shut-in production from a loss of the bigger pump. There is only a
negligible difference between the quantities of “deferred” oil for
the two options. To give Fred some numbers for his analysis, the
production engineers roughly estimated the O&M costs of each
machine. They estimated that the operators spend about half an hour
each day conducting routine checks on the large waterflood
machines. They figured the smaller disposal pumps take only about
20 minutes per day per machine. They also informed Fred that, when
estimating their engineering projects, they generally use $150/hour
for operator man-hours, which includes all associated overhead and
burden. In addition, they have been given guidelines that indicate
that an 8% discount rate should be used for any economic analysis.
Based on the last year, they estimate that routine maintenance on
the large pump system will be about $65,000 per year. This includes
normal preventive maintenance. Because of their smaller size, they
figure that the preventive maintenance on an 85,000 BWPD pump will
only cost about $25,000 per year. Periodic major overhauls are
required. In the large aero derivative turbines (used for the
400,000 BWPD modules) the manufacturer recommends replacing the gas
generator every three years at a cost of $250,000. The
industrial-type turbines have a longer overhaul interval, six
years, with an expected cost of $75,000 per overhaul.
Case 27 To Use or Not to Use?
135
Major overhauls are needed for the pumps every five years. The
large pump overhaul costs $80,000 and a small pump $30,000,
exclusive of routine and preventive maintenance. The control
systems need revamping every 10 years. Again, the large system is
more expensive at $50,000. The smaller systems would each cost
about $20,000. With so much horsepower involved, fuel costs matter.
BSPC pays $0.75 per thousand standard cubic foot (103 SCF) for
their fuel, which has a heating value of 900 BTU/SCF. The aero
derivative turbine at 8100 BTU/hp-hour is much more fuel-efficient
than the industrialtype engines planned for the small pumps (9250
BTU/hp-hour). The small pumps would require the full 4600-hp rating
of their turbines to put out 85,000 BWPD. Based on the pump curves
for the existing water flood modules, the large pump would require
18,650 hp to pump 340,000 BWPD. Another concern of the production
engineers was freeze protection when the large pump is shut down.
Depending on duration and the time of the year, displacement of oil
with methanol might be required. (Below-freezing weather occurs
nine months of the year). In addition, the frequent shutdown of
equipment tends to increase repair costs for the wellhead chokes.
Freeze protection and extra maintenance costs due to shutdowns of
the large pumps would be on the order of $350,000 per year. Since
past experience has indicated that wells would not be shut-in when
a smaller pump is lost, no freeze protection costs were estimated.
Freeze protection costs for the water injectors themselves were not
included. The original seawater pumps can maintain sufficient flow
to each injector to keep the lines from freezing. Fred must put all
of this information together and make a recommendation to the
company management. Should he recommend use of the existing
module?
Option Even though the value of the uncompleted waterflood module
has been declining over time, BSPC has not yet been able to take a
tax deduction for it. BSPC cannot depreciate the module until it
enters service, and the company cannot simply expense it until it
has actually begun to dismantle it. Furthermore, if the module is
not utilized for the produced water disposal, all investment tax
credits originally taken must be "given back" to the government.
This applies to any booked costs not officially transferred to
operations. It excludes costs such as the book value of the spare
parts that must be depreciated along with other capital equipment
when they are placed in service.
Cases in Engineering Economy 2nd by Peterson & Eschenbach
136
The expenditure patterns expected for the two options are as shown
in Table 27-1.
Case 27 To Use or Not to Use? Beaufort Sea Production Company (BSPC) operates a medium-sized...
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