technology advances increase drilling efficiency
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Technology Advances Increase Drilling EfciencyKey Energy Servicesby Jeremy Handeland,
District Manager Drilling Operations
Rocky Mountain Marketplace
Driven by the desire to increase protability and
enhance efciency, advances in engineering, tools
and technology continue to evolve the exploration and
production (E&P) landscape. Limitations that once
plagued E&P ventures have been alleviated by new
software, equipment and automation systems. The
benets of these technologies can be seen in the form
of increased savings, safety and speed.
The invention of Rotary Steerable Systems (RSS) in the
late 90s proved as a signicant step forward in the
advancement of directional drilling and provided the
opportunity for increased Rate of Penetration (ROP),
control and accuracy. Adding to this success, the
industry continued to make strides with real-time
technologies such as advanced Measurement While
Drill ing (MWD) and Logging While Drilling (LWD) Systems;
visualization and reservoir characterization systems; and
automation systems.
According to Baker Hughes rotary rig count, in North
America alone, oil and gas drilling has increased 214
percent over the last decade to reach a total rig count
of approximately 1,859. These numbers have been in-
uenced by directional drilling which has seen a 1,165
percent increase in horizontal wells. Additionally, US
drilling onshore has shifted its attention to shale activity
with focuses on the Bakken, Eagle Ford, Marcellus,
Utica, Permian, Williston and Niobrara formations.
Benets from technology can be seen in the form of
prolonged production from greenelds and brown-
elds, elevated return on investments, safety on the
jobsite and accuracy while dril ling. Technological ly
advanced avenues for collecting data have positively
affected where, how, when and what people drill.
Historical setbacks
The historical focus on improving drilling efciency has
been highly technical. Innovations in the 90s introducedthe use of computers, enabling reservoir modeling
and imagery in addition to increased control. The use
of computers has created synergy between downhole
machinery located thousands of feet below the earths
surface and people at the wellsite, in the lab or even
hundreds of miles away in a corporate ofce. Previously,
costs in conjunction with the uncertainty and unreli-
ability of directional drilling prevented its popularity. The
lack of real-time data to determine appropriate depths,
pressure, mud weight and uid loss hindered the drilling
engineers ability to control or mitigate risks to improveefciency and productivity.
Made manageable by todays technologies, Non-
Productive Time (NPT) events reduce drilling productivity
while increasing costs. NPT events include downhole
trips to replace drill bits, downhole tools, drive systems
and bottomhole assemblies. These events may be either
planned based on estimated rates of equipment wear or
unplanned due to equipment failure for various reasons.
The longest and most expensive NPT events are typically
unplanned and are often associated with well safety.
NPT events such as well blowouts can be extremely
costly in terms of lost productivity, environmental damage
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and adverse publicity. Other NPT events such as stuck
pipe can also be costly and can cause operators to
abandon the well.
Operator errors, equipment wear and failure to clean
the wellbore in a timely fashion all can cause equipment
to become stuck or lost in the well. Fishing is the pro-
cess of removing this equipment. On an industry-wide
basis, shing may account for 25 percent of drilling
costs. Fishing is often time-consuming, complex and
risky. Dealing with stuck or lost equipment may be more
complex in wells containing both vertical and horizontal
well sections. At times, it may be more cost-effective to
sidetrack or even abandon a well rather than engaging
in shing operations.
Key Energy Services extensive arsenal of shing tools
include a wide range of equipment from whipstocks and
mills to an exclusive line of Johnston Jars and proprietary
drilling tensile shear subs. Each is available with ancillary
equipment, depending on situation and site needs.
Geoscience advances
Today, much drilling involves reentering vertical wells in
old elds, cutting windows and drilling horizontal wells
penetrating old producing horizons. There is just as
much of this type of drilling as drilling of completely new
grassroot wells to penetrate old producing formations
with horizontal wells. This is the case in areas such as in
the Permian Basin, North Dakotas Bakken Shale and
areas of Kansas and Appalachia (the Marcellus Shale).
Forecasts are that extended reach horizontal drilling will
become increasingly common in California.
Previous drilling and production data and geological
information are available for these old elds. Together,
they provide information on how geology impacts the
drilling process. This information guides operators in
drilling these formations more productively thus improving
drilling efciency and production economics.
Many of the wells in these elds, particularly shale plays,
are shallow and can be drilled or redrilled using rigs that
are lighter and physically smaller than rigs used in new
eld development. To optimize drilling rig design for old
drilling areas and most shale formations, rig operators
are using single- or double-mast rigs.
Key Energy Services extensive eet of service rigs
includes a wide range of classes including 1000+ hp,
Class V self-propelled carrier or trailer-mounted rigs.
Each is available with ancillary equipment depending
on class and site needs.
While well life varies by formation, horizontal drilling
has given life to wells that were once declared tapped
out. For example, the Eagle Ford shale formation in
Texas, once considered an old formation, is predicted
to remain productive to approximately 2028. The for-
mation covers 23 counties, and expenditures in 2011
reached approximately $14.6 billion. Horizontal drilling
and hydraulic fracturing have made it possible to tap
into shale to extract hydrocarbons. Unconventional
petroleum deposits in Canada, dubbed oil sands, have
also grown to become an attractive source of energy.
While governmental regulations prohibit drilling in
geographical regions with respect to the environment,
modern technology affords drilling engineers with the
knowledge and technology to drill almost anywhere in
the world.
Advances in technology
Advancements made in the drilling and recovery of oil
and gas coupled with the exploration of new formations
and the rediscovery of older, once less productive
formations have broadened drilling opportunities. In
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the Williston Basin, multi-stage fracing sleeves and
packers allow the wellbore to be fractured in many
different segments which greatly increase the penetration
and efciency of the fracturing process. This process
is also making its way to other hot oil and gas plays.
In terms of transportation and distribution, pipelines
and gas plants are being built to move the product to
the market more efciently.
Rigs are constantly being built and upgraded with
safer, more efcient tools and equipment; automation
in equipment such as top drives, iron roughnecks
and hydraulic catwalks have all greatly reduced the
involvement of employees in dangerous situations
while handling drill pipe during drilling operations,
said Handeland. This multi-use equipment also
eliminates the need for switching tools for certain
jobs and eliminates costly time spent rigging up and
down third party companies to run pipe.
Todays tools have transformed planning and accuracy.
Once drilling operations commence, several engineer-
ing parameters can contribute to or reduce drilling
efciency. Seismic graphing and geological studies
have helped companies pinpoint the best locations
for drilling wells; this gives the companies a very high
success rate along with the geological sampling and
MWD surveys throughout the drilling of well ensure
that the hole stays in the pay zone.
Horizontal wells
Horizontal wells are drilled to better penetrate productive
formations. The exposed length of wellbore penetrating
the productive interval is far greater than that provided
by a vertical well. Increasing the overall length of well-
bore penetrating the production interval reduces the
amount of bypassed oil and gas that is never produced;
thereby, horizontal drilling increases both hydrocarbon
production rate and the ultimate reservoir depletion.
Deviated wellbores permit penetrating production
formations where vertical access is not possible due to
topography or pre-existing human activities. Horizon-
tal drilling allows more wells to be drilled from a single
pad; in many cases, this limits environmental impact
while allowing drilling and production activities to be
managed from a central complex instead of many
separate locations.
The rst signicant use of horizontal well drilling technol-
ogy occurred in the 1970s. During this time, the use of
downhole drilling motors driven by the hydraulic power
of circulating drilling mud became common. Most of
the vertical pipe was held in a stationary position while a
piece of bent drill pipe allowed the drill bit at the bottom
of the wellbore to be rotated, changing the direction
of drilling. MWD tools allow the change in the drilling
direction to be determined and adjusted accordingly.
Including MWD tools in the drill string allows this to be
done on a near-real-time basis. By closely monitoring
operations, other MWD tools allow operators to prevent
premature equipment failure.
LWD techniques and tools are employed to increase
drilling precision. LWD tools assist the MWD system
and allow engineers to make adjustments in mud
weights, uids and real-time steering. LWD tools
generate 3-D images to provide the engineer with
prot- and time-saving information. In conjunction with
MWD tools, LWD tools provide the engineer with an
accurate reading of the reservoir.
The rst commercial vertical well drilled in the United
States occurred in 1859 in Venango County, Penn., and
was completed under the instruction of Colonel Edwin
L. Drake. Since then and up until the 1970s, this form
of drilling served as the primary method. Vertical drilling
requires less pad space, water, time and resources but
is also less productive. The typical vertical well requires
two to four acres of land compared to ten
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and up for a horizontal well. Additionally, the average
cost for a vertical well rests at about $750,000 to $1.1
million while the average cost for a horizontal well costs
anywhere from $6 million to $8 million.
The completions phase includes the processes or tools
required to prepare the wellbore for production. Edge
Oileld Services, a subsidiary of Key Energy Services,
provides high pressure rental equipment and services
which support well completion activities. Group opera-
tions emphasize the necessary completion activities
and subsequent remediation work required. Equipment
and services offered by Edge include frac stack
spreads, well testing/hydraulic choke services, and re-
verse unit services. Additional completions equipment
include, but are not limited to: packers, ow control
mechanisms, liner systems, sand control devices and
uids. Fluid hauling plays a crucial role in effective reservoir
management. Key Energy Services also offers a variety
of drilling uids and disposal solutions.
Automation
Automated drilling rigs reduce safety hazards; subse-
quently, the industry has pushed to remove employees
from the drilling process. Rig Automation replaces the
highly strenuous conditions of the rig oor by the more
pleasant environment of a climate-controlled room.
People remain more alert under these more comfortable
working conditions, thus contributing to safe rig operations.
The same or fewer number of people can monitor several
drilling rigs simultaneously which, in-turn, improves
drilling economics.
Supervisory Control and Data Acquisition (SCADA)
control systems are computer-controlled systems that
monitor and control industrial processes. These control
systems are installed on rigs to control drilling equipment
and used in conjunction with drilling automation systems.
In addition to improving safety, technology has also
made it possible to drill in extreme, new environments
all over the world. New equipment and advances in
automation have made drilling and production possible in
areas such as the Middle East where temperatures can
reach up to 113 degrees Fahrenheit and in the Arctic
where temperatures can dip as low as -50 degrees
Fahrenheit. High Pressure/High Temperature (HP/HT)
situations can involve a combination of high depth,
temperature and pressure situations. Todays high
performance technologies including uids, casing
materials and well completion systems are developed
to withstand these instances.
With the strong focus on the North American shale
plays, Key Energy Services provides the services and
equipment needed to perform in the cold of the
Williston and Bakken regions and the heat of the
Eagle Ford, said Handeland. Dependent on the en-
vironment and situation, Key has an extensive array
of rental equip- ment and services, from hard items
such as pipe, rods, or even Blow Out Preventers, to
our proprietary services such as SmartTong Rod
Connection Services, Hydra-Walk Pipe Handling
System, and the Sand-X system.
Safety
Safe operations mean fewer drilling process interruptions,
thereby improving drilling productivity and economics.
In recent years, Health, Safety and Environment policies
have become more stringent as a result of the BP Deep-
water Horizon Explosion. While this occurred offshore,
it has also affected the industrys perception onshore.
Enhanced safety precautions have been developed to
better prevention, intervention and response procedures.
Several American Petroleum Institute (API) Standards
have been developed and amended as a result. Many
of these procedures concern well design and blow out
preventer regulations. Automation has helped to alleviate
the concern for safety as fewer employees are required
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on the rig site. (Figure 1)
Future plans
Advances in technology have in-turn equated into
advances in production and increased drilling efciency.
These strides have allowed drilling in areas once con-
sidered too harsh and extreme. As technology evolves,
developments will continue to be seen internationally.
Horizontal wells make it possible to raise productionwithout drilling several vertical wells; however, the
in- creased demand for energy and the emerging
shale plays still have the rig count rising. Customers
recognize Keys willingness to provide the best and
most reliable equipment in the industry; preventive
maintenance, training and rst-class operational
supervision ensure that equipment is always kept up
to standards. Key Energy Services is the largest on-
shore, rig-based well servicing contractor based on the
number of rigs owned. Key provides a complete range
of well intervention services and has operations in allmajor onshore oil- and gas-producing regions of the
continental United States and internationally in Mexico,
Colombia, the Middle East and Russia.
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