Innovations™ Magazine April - June 2014

®
Making the Impossible
Possible
V O L . V I , N O. 2 | A P R I L - J U N E 2 0 1 4

® Registered trademark of T.D. Williamson, Inc. in the United States and in other countries.
™ Trademark of T.D. Williamson, Inc. in the United States and in other countries. ©
Copyright 2014 All rights reserved.T.D.Williamson, Inc.
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Topside laptop control
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1
INNOVATIONS•APRIL-JUNE2014
2 | EXECUTIVE OUTLOOK
From the Land, to the Sea.
4 | GLOBAL PERSPECTIVE
Pipeline challenges meet
pipeline solutions.
6 | TECHNOLOGY FOCUS
Locked In: Offshore isolations
for smaller diameter lines.
8 | SAFETY MATTERS
Seeing all the pieces when it
matters most.
10 | FUTURE THINKING
Playing catch-up when
product demand outpaces
service capability.
12 | MARKET REPORT
Working in Isolation: From
valve repair to construction
zones.
20 | TOUCHPOINTS
Pipeline events, papers and
conferences.
28 | BY THE NUMBERS
Offshore pigging in 4 phases.
14 | Cover Story: Raising Lima
With a sinking platform and more than 5 million
customers at stake, global mobilization and new
technology save the day.
22 | The Power of Unity
Whether working in the Gulf of Mexico or the North
Sea, at shallow depths or great, operators must partner
to overcome common issues.
D E P A R T M E N T S
EDITOR-IN-CHIEF Jim Myers Morgan
MANAGING EDITOR Waylon Summers
ART DIRECTOR Joe Antonacci
DESIGN PRODUCTION Kat Eaton, Mullerhaus.net
DIGITAL PRODUCTION Jim Greenway, Ward Mankin
PHOTOGRAPHY Douglas Barnes, Adam Murphy, Ezequiel Scagnetti
COVER STORY ILLUSTRATIONS Patrick Gnan, represented by
Deborah Wolfe, LTD.
T.D. Williamson
North and South America +1 918 447 5000
Europe/Africa/Middle East +32 67 28 3611
Asia Pacific +65 6364 8520
Offshore Services +47 5144 3240
info@tdwilliamson.com | www.tdwilliamson.com
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V O L . V I , N O . 2 | A P R I L - J U N E 2 0 1 4
Innovations™ is a quarterly publication produced by T.D. Williamson.
®Registered trademark of T.D. Williamson, Inc. in the United States and other countries. ™ Trademark of T.D. Williamson, Inc. in the United States and other countries.
© Copyright 2014. All rights reserved by T.D. Williamson, Inc. Reproduction in whole or in part without permission is prohibited. Printed in the United States of America.
14
10 22

2
Look around at one of the technologies you interact
with – your cellphone, tablet, touchscreen monitor. Now
ask yourself where it came from – not guessing which country
in which it was manufactured, but how it actually came into
being. Who dreamt it up? Or what drove its creation? Chances
are, the origin of several of your gadgets, or at least their respective
components, can be traced back to one world altering event – the
global military conflict of the early 1940s.
Although many of the technological advancements of that time
were directly related to combat efforts, such as developments in
heavy weaponry, aircraft and naval vessels, there were many less
overtly celebrated breakthroughs in supporting fields like electronics,
communications and industrial technology – including … momentous
advancements in the transportation of hydrocarbons.
Consider the first subsea pipeline, constructed in the UK in 1942.
This engineering feat was a test of the Allied ability to run pipelines in
the English Channel, which ultimately supported troops following the
Normandy landing in 1944. Although the energy industry didn’t take
immediate advantage of this technology, the inevitable advance toward
commercial subsea development had begun.
Around this same time, T.D. Williamson was recruited into the
pipeline business – via what became a pigging project – to support
the war effort. As a result of the immediate and intense international
need for more oil and gas, TDW experienced its first era of accelerated
onshore research and development growth.
For the next 60 years, TDW focused on solving the increasingly
complex challenges of onshore operators, developing a portfolio that
covers nearly every aspect of pipeline service. But near the turn of the
millennium, increasing offshore demand for equivalent expertise and
services compelled TDW to look to the sea.
Already a global company, with manufacturing facilities and service
centers throughout the world, TDW was well positioned to meet
offshore operators where they were. Of particular value were its strategic
hubs in the Gulf of Mexico and North Sea. From these hubs TDW
began engineering a new wave of offshore pipeline solutions, helping
operators manage risk, optimize throughput and extend asset life.
So, the next time you pore over a platform’s Piping and
BY MIKE BENJAMIN
SENIOR VICE PRESIDENT –
MARKETING & TECHNOLOGY,
T.D. WILLIAMSON
E X E C U T I V E O U T L O O K
From the Land, to the Sea

3
Instrumentation Diagram (PID), isolate a dropped
object zone during construction, or plan the
replacement of an emergency shutdown valve, you’ll
know where that technology was born, and what
drove its existence. You’ll also know that TDW
will be right there with you, continuing to invest
in processes and technologies to help manage and
reduce risk in offshore operations, effectively helping
you reach farther, wider and progressively deeper.
And that’s what this issue of Innovations™
magazine is about. We hope you find great value in
it and enjoy the experience.

4
Automation is Key
To increase the efficient control of both the volume and flow of natural gas
liquids into its processing plant, a provider in Ohio invested in its second 24” x
30” SmartTrap® Automated Combo Pigging System, replete with accompanying
infield service. In addition to significantly reducing the manpower requirements
associated with the daily pigging of its 24” trunk line, the automated launcher
will lessen wear and tear on its 24” valves, minimize employee exposure to
hazardous environments, and reduce the escape of “unaccounted for natural
gas” from closure openings.
Increase in Eagle Ford
One of the top 10 producers in the Eagle Ford shale play has recently maximized
the throughput of its extensive small diameter gathering system by adopting
a progressive pigging and integrity management program provided by TDW.
Following thorough cleaning of its 6", 8", 10" and 12" lines with progressively
more aggressive pigs, the operator is now reaping the benefits of maximized flow
and more acccurate data from its DEF and MFL integrity inspection runs.
INDIA USA
Forces of Nature
A submerged 30" gas pipeline
ruptured due to strong floodwater
currents following heavy rains and
was forced through 5 to 8 meters
of river bottom, shooting nearly 30
meters above the water level.The
operator was forced to shut down
the line. However,TDW was able to
mitigate the loss by quickly creating
a bypass to allow product to flow
within just 5 weeks.
GlobalPerspective

5
CANADA COLOMBIA
A Better Understanding
Several of Canada’s pipeline operators recently
convened in Toronto for a three-day integrity conference
hosted by TDW. In addition to a keynote address by
Gonzalo Juarez, Senior Manager – Integrity Strategy
& Risk, Enbridge Gas Distribution, operators received
training on the Multiple Dataset Platform, EMAT
Crack Detection, Data Analysis and Nondestructive
Examination – including an in-depth look at Positive
Material Identification (PMI).The training concluded
with a tour of the Enbridge Gas Distribution,Training &
Operations Center.
NORWAY
Isolate and Accomplish A liquefied
natural gas (LNG) producer in Sarawak is planning to
replace several valves on its 36" offshore trunk line.
To accomplish the safe isolations needed to perform
this maintenance, TDW has been retained to provide
the operator with its non-intrusive SmartPlug® isolation
tool technology. In 2009, the operator successfully
performed an almost identical scope of work on
another of its trunk lines.
Pressurized Pipeline Solutions From Around the World
MALAYSIA
>>
Emergency Response
One of the country’s largest producers is securing its
safe operating future by filling in the remaining gaps of
its Emergency Pipeline Repair System (EPRS).To round
out preparedness on its class-900 liquid pipeline
network, the company recently acquired additional hot
tapping equipment and attended advanced operator
training at the TDW Colombia facility.
Well Prepared
Many offshore operators have been investing in greater
safety through Emergency Pipeline Repair Systems
(EPRS). In essence, EPRS means pre-investment in
emergency repair solutions and associated hardware
BEFORE a failure occurs – to increase response
capability, lessen environmental impact, and reduce
downtime.As part of a Master Service Agreement with
TDW, a major US based E&P company has recently
secured storage and maintenance for two 34" clamps
and access to TDW’s remote controlled subsea hot
tapping machine, the Subsea 1200RC.

6
T E C H N O L O G Y F O C U S
Locked In:
Offshore Isolations
Companies that create technology are always working on
the next big idea.
Often, innovation originates from breakthrough, whiz-bang,
lightning-strikes thinking.
But sometimes, instead of a revolution, an evolution will do just fine.
And sometimes, that evolution begins with a little prompting from
the marketplace.
Such is the case with the hydraulic locking capabilities of the
tetherless, remote-controlled SmartPlug® isolation system. Evolving
versions of this non-invasive plugging technology have been isolating
offshore pipelines for more than 20 years. SmartPlug tools, designed
by pipeline service provider T.D. Williamson (TDW), remotely
isolate and stop product flow to a designated area of the pipeline
so that maintenance, repair or tie-ins can be performed in a safe,
inert environment.
A key component of the system is its ability to hydraulically lock into
place during isolation in a lower pressure line. This locking mechanism
supplements, or can even replace, pipeline pressure differential to more
securely hold the isolation tool in place.
Without hydraulic lock capabilities, and in the case of a substantial
drop in pipeline pressure, the differential pressure across the plug could
diminish to a point that the tool could naturally begin unsetting. This
would cause both the pipeline operator and service provider to take
immediate corrective action, resulting in delays and wasted time and
money, potentially jeopardizing the whole operation. But hydraulic
locking capabilities provide an additional level of safety and security,
allowing the tool to maintain the isolation regardless of pressure changes
within the pipeline.
“Hydraulic lock capability greatly increases safety during pipeline
isolation,” Gary Anderson, Director of SmartPlug Technology, explains.
“By continuing to expand the locking function across all sizes of the
tool, operators will ultimately benefit from the same safeguards and risk
mitigation, regardless of the diameter of their line.”
Hydraulic Locking a Necessity
SmartPlug tools come in a variety of sizes – for every pipeline diameter
from 8 inches to 48 inches, there’s a unique, specific isolation tool with a
proprietary intelligent control system to match. Offshore operators who
had experience using the SmartPlug tool in larger diameter pipelines

asked TDW to add hydraulics to the control system
for use in their smaller diameter lines. According to
Anderson, not only do operators see the technology
as desirable, some believe it’s a necessity.
Anderson cites an example of an operator
working in the Gulf of Mexico who sees hydraulic
locking capabilities as a requisite part of its
plugging operation.
“For this operator, the hydraulic locking
capability is a ‘must-have’ safety feature,”
Anderson says. “The client needs to isolate a
smaller diameter pipeline, but the previous
control system for this particular size of
SmartPlug tool didn’t yet have the ability to
hydraulically lock the tool in place.”
This need expedited the introduction of the
next generation of control module that will bring
the tool within the client’s operating guidelines and
provide the requisite level of safety and redundancy.
All SmartPlug control systems are operated
topside by laptop computer. The system uses
extremely low frequency technology to enable
communication so the operator can send commands
and receive real-time, two-way, through-wall data
about plug, pipeline and other key conditions.
The newest control module continues to expand
the locking options for operators of smaller diameter
lines. But, regardless of diameter, operators continue
to rely on the DNV-certified, double block safety of
the SmartPlug® isolation system.
Risk is defined by Det Norske Veritas (DNV) as, “the
qualitative or quantitative likelihood of an accidental or
unplanned event occurring, considered in conjunction with
the potential consequences of such a failure. In quantitative
terms, risk is the quantified probability of a defined failure
mode times its quantified consequence.”
The SmartPlug isolation system provides operators with
options for self-locking technology in high pressure lines
and hydraulic locking for use in low pressure. Both choices
provide a double-block method to greatly reduce risk, as
every SmartPlug tool receives a Type Approval Certificate from
DNV, confirming compliance with DNV-OS-F101 standards.
Certification includes a detailed Failure Mode, Effects, and
Criticality Analysis study based on a Fault Tree Analysis.
Doubling Risk Reduction
SmartPlug® isolation technology featuring
hydraulic locking in low pressure lines

S A F E T Y M AT T E R S
In the summer of 2013, an offshore oil and gas operator
needed to isolate a large diameter subsea pipeline. Although
the company had performed basically the same operation on the same
line just a few years earlier – utilizing SmartPlug® isolation technology
to double block and seal the line – this was not a simple case of
procedural “copy and paste.”
Following recent catastrophic events, operators have become even
more conscious of process safety risk, gaining a heightened sensitivity to
low-frequency, high-potential consequence operations. And as a tribute
to an industry in constant search of safer operations, the mindset has
shifted toward a more customized and comprehensive approach, even for
routine maintenance.
It’s not just operators that have changed their outlook in recent years.
Pipeline service companies are taking a new approach to how they do
business, as well. Service companies have been traditionally very tool or
singular service-centric. They know hot tapping or pigging, Magnetic
Flux Leakage (MFL) or hydrostatic testing. Ask them about inline
inspection or cutter repair, and they could write a white paper. But ask
them to leverage their expertise to create a well-rounded risk-mitigation
plan, and they’d likely tell you that wasn’t in their wheelhouse.
This operation was going to break tradition. This time, hazard
identification, risk assessment, and Hazard and Operability review
(HAZOP) meetings were no longer the other guy’s job. This time,
big-picture risk was everyone’s job.
T.D. Williamson (TDW), the service company that provides
Seeing All the PIECES
“The P&ID diagrams are
highly technical, so learning
how to read them is like
learning a different language.
Without that understanding,
we can’t effectively engage
in high-level risk discussions.
We’d be too tool-centric and
not environment-centric.”
8

9
SmartPlug technology, was involved in planning
meetings from the start. For the project, they
worked through various scenarios and emergencies:
How will communication work? How will the
diving control center on the vessel get information
on the status of the isolation? What’s considered
a sound isolation, and what should be done if
something does not meet the criteria?
The collaborative planning proved to be worth it.
After the technicians deployed and activated the
SmartPlug tools on each side of the target area, one
of the seals wasn’t keeping the pressure consistent
enough. While the pressure was in normal range, it
did not seal to the operator’s unique requirements.
These project-specific limits were specifically
designed to provide additional diver safety during
the operation.
Now, the teams had the ability to follow the
established contingency plan. They quickly pulled
the plug and replaced it with a backup plug at
another location in the pipeline, which worked.
Due to the pre-planning, the teams didn’t need to
stop and develop a response to the setback.
A New Mode of Operation
Some service companies are taking their
involvement in risk assessment and planning one
step farther. For example, at TDW, technicians
receive specific training aimed at getting them to
see things from the operator’s perspective. In the
training, engineers teach technicians how to read the
P&ID (called either a Piping and Instrumentation
Diagram or a Process and Instrumentation Diagram,
depending on the company) and to analyze and
understand the full environment surrounding
the isolation operation, not just in relation to the
particular tool.
By thinking beyond how the tool operates, to
how it impacts and is impacted by what’s happening
on the platform or facility where the isolation is
taking place, the technicians are better prepared to
consult operators in the project planning phases.
Larry Ryan, Director of SmartPlug Operations
for TDW, says this new way of doing business isn’t
always easy, but it’s certainly worth it. “The P&ID
diagrams are highly technical, so learning how to
read them is like learning a different language. But
with this added knowledge, our technicians can sit
in the HAZOPs and discuss what would happen
if things don’t go exactly as planned. They can’t
do that unless they can understand the diagrams.
Without that understanding, we can’t effectively
engage in high-level risk discussions. We’d be too
tool-centric and not environment-centric.”
Cool-headed Decisions
When service company personnel and operator
staff share knowledge from day one, the team as
a whole is better equipped to handle situations
that arise and keep a cool head when things don’t
go correctly.
“When you’re offshore, and you’ve got your
whole field shut down on a huge pipeline and
infrastructure, time is not your friend,” Ryan said.
“So the last thing you want to do is make decisions
in the heat of the moment. You want to make them
in the cold light of day when everyone is sitting
around onshore, before anything happens.”

10
F U T U R E T H I N K I N G
Deepwater,
Black Gold Rush
Today’s gold rush is a “black” one, but in California, circa 1848, when gold was
discovered at Sutter’s Mill, on the banks of the South Fork American River, it was the
color of the sun. Word of riches, ripe for the taking, spread like wildfire. Within a year,
a mass pilgrimage of would-be prospectors fueled by million-dollar dreams braved the
journey west to make their fortunes.
But even as the Forty-niners staked their claims, the voracious appetite for gold
quickly outstripped the original miners’ modest means for recovering it. By the 1850s,
mining technology had evolved from “placer” mining with simple pans, to diverting
entire rivers into elaborate sluices, and finally, to surface methods that utilized high-
pressure hydraulic blasting hoses, and “hard-rock” or quartz mining underground.
While these new methods were vastly more efficient than previous ones, at the
Playing Catch-Up When Product Demand
Outpaces Service Capability

11
CONTINUED ON PAGE 26
time, little thought was given to either short-term
safety issues, or the long-term consequences on
the health of the people or the land they impacted.
History marks this era of rapacious growth as a
cautionary tale for others attempting to harvest
resources from deep beneath the surface of the Earth.
As operators probe further and further to find
resources, the frontier they must now
contend with lies deep beneath the
ocean floor. Until not long ago, the
challenges that faced them in this hostile
environment made viable oil production
next to impossible. However, advances in
deepwater oil and gas technologies have
allowed production to shift into high gear.
But the process is not without caveats.
“THE GAP”
The nature of deepwater production requires
multiple systems, including flow-lines, to withstand
the extreme pressures of the external environment
and that of the reservoir. Various flow-line
architectures exist which contend with these
pressures and the potential shifts in temperature
due to production. Steel pipe covered with external
insulation, pipe-in-pipe (PIP), and other “layered”
pipeline systems have emerged which accommodate
these pressure and thermal demands.
The architectures which make these deepwater
pipes effective in maintaining product flow –
combined with the effects of the high-pressure,
high-temperature (HPHT) environments into which
the “next generation” pipe is often deployed – have
created a unique set of obstacles for inspection, repair,
maintenance, and expansion.
The industry has made laudable advances. For
example, to help prevent hydrates and wax buildup
from blocking deepwater lines, engineers have
introduced new forms of insulation and heated flow
lines, while swaged end connections can shut down
production in the event of an outer pipe breach. But
as the industry steers toward deepwater production,
the technology to service these applications has a way
to go to catch up.
What happens, for example, should a hydrate
or paraffin blockage occur in one of these remote
deepwater lines? If the operator is not able to remove
the blockage by non-intrusive means, intrusive
methodologies provide the only chance to resume
flow within the line. This scenario requires remote
installation of a fitting, remote tapping of the line,
and remote insertion of technologies to remove the
hydrate or paraffin blockage.
“Service providers are tasked with matching
their solutions to the needs of the operator
throughout the lifecycle of the pipeline,” notes
Jeff Wilson, Chief Technology Officer for T.D.
Williamson (TDW). “They must also ensure
that both the specific tasks of the intervention
go according to plan, and that the long-term
reliability for any systems remaining on the line
following the intervention is considered and
accounted for.”
Finally, aside from general maintenance
and servicing needs, the technology to monitor
integrity and, hopefully, prevent deepwater
calamity before it becomes catastrophic, must also
be brought up to speed.
PIONEERS ON THE NEW FRONTIER
Joint industry projects (JIPs) are one way that oil
and gas companies, pipeline service providers, and
technology experts from outside the industry are
coming together to help fill the technological gaps
associated with servicing pipelines in deepwater
environments. Through combined expertise,
efforts and financial resources, JIP participants can
more quickly address and overcome the myriad
As operators probe further and
further to find resources, the frontier
they must now contend with lies
deep beneath the ocean floor.

12
M A R K E T R E P O R T
Working in Isolation
How Isolations Can Help Solve Pipeline Challenges –
From Valve Repair To Extending Reservoir Life
The Malampaya Shallow Water Platform in the Philippines
provides 40 percent of the gas to Luzon, one of the most populated
islands in the world. So shutting it down for any length of time could
result in gas shortages and serious damage to Luzon’s economy.
But that’s exactly the proposition that Shell Philippines Exploration and
Production (SPEX) was faced with in 2010, when they learned that a shallow
water platform’s main emergency shutdown valve (ESDV) and neighboring
manual block valve were defective. If the platform needed to be isolated in
case of emergency such as a fire, the valve could leak and fuel the flames.
The consequences could be disastrous – major hydrocarbon spills into the
environment, potential loss of the platform, and large-scale disruption of an
integral part of Luzon’s supply of energy.
Due to the dangers inherent to a leaky valve, most operating
companies diligently monitor internal leakage in critical valves and
replace them if the leakage rate is above a certain threshold.
That threshold had been crossed.
SPEX, the line’s owner-operators, knew the valves had to be replaced.
But what solution would cause the least disruption to the island’s
energy supply?
One option would be to bleed down the line, blow
down 504 km (313 miles) of pipeline, purge the entire
length of the pipeline using nitrogen, replace the valves,
then carry out additional purging steps prior to the
reintroduction of natural gas. Blowing down the line

13
would cause the loss of a significant amount of
product, massive gas flares, and lengthy shutdown of
the gas supply from the line to the island.
Since that option was clearly unattractive, SPEX
chose to explore isolation. During an isolation
exercise, a short portion of the pipeline housing the
valves is shut off from the rest of the pipeline and
depressurized. Once the isolation is secured, the
valves can be replaced.
A proven method of isolation involves the
SmartPlug® tool. SmartPlug technology has been
used for more than 20 years to isolate portions of
pipelines, while withstanding maximum allowable
operating pressure. The process involves pigging the
SmartPlug tool to the isolation point and setting the
plug. While the plug is navigating the line, a wireless
communication system – called the SmartTrack™
System – allows engineers to track its movement.
Once the plug is in the proper location, the engineers
use SmartTrack technology to remotely set the plug.
As it was critical that the shutdown time be kept
to a minimum, SPEX opted to use the SmartPlug
tool to isolate their line.
“SPEX appreciates that bleeding down an entire
gas export pipeline is time-consuming and costly,
so we chose instead to deploy pressure isolation
of the line downstream,” said Sarawak Shell Sdn
Berhad/Sabah Shell Petroleum Project Manager
Nathan Stephenson.
SPEX’s decision to use SmartPlug technology was
a resounding success. The operation was completed
without incident, and the island’s energy supply
remained intact.
Beyond Maintenance: What Operators
Don’t Know About Isolations
Valve maintenance – maintenance similar to that
undertaken by the operator for the aforementioned
Philippines project – is the most common SmartPlug
operation. However, according to Rolf Gunnar Lie,
TDW Regional Manager of Business Development
in the Far East Asia Pacific, SmartPlug technology
can be used for much more.
One growing SmartPlug application is the
isolation of subsea pipelines during massive
construction projects. During construction, heavy
equipment is lifted and carried over the underwater
pipes. It goes without saying that dropping a multi-
ton object on a pipe could result in a catastrophic
spill. By isolating a short portion of the pipe,
construction work can continue with significantly
reduced risk and the contents of the rest of the
pipeline can remain in place.
Other perhaps lesser known SmartPlug
applications in use today are isolations for
hydrotesting, midline repair and tie-ins.
Gary Anderson, Director of SmartPlug
Technology, cites the ability to extend the life of
subsea reservoirs as a cutting-edge SmartPlug tool use.
“We want to extend the life of subsea reservoirs by
planning a bypass location and booster station during
pipe lay. The booster station would lie dormant until
the pressure from the reservoir no longer produced a
strong flow of product. At that point, we would pig
down the SmartPlug tool, isolate the pipeline, and
reroute the flow through the bypass and booster.”
TDW has already achieved a record 299 day
isolation, but these reservoir-extending isolations
would be in place much longer, perhaps three to five
years. Anderson projects it will be available soon.
Until then, operators will likely continue to
use SmartPlug isolations in their most well-known
capacity: as a low-risk, cost-saving alternative to
blowing down lines for planned maintenance.
SmartPlug technology uses two independent
plug modules – each of which is capable
of isolating the full pipeline pressure. This
independence provides a true double-barrier in
the unlikely event that one of the systems fails.
It’s because of this redundancy that
SmartPlug technology meets the Norwegian
Det Norske Veritas (DNV OS – F101) and other
stringent standards & requirements for pipeline
pressure isolation.
A Positive Redundancy

14
RaisingA New

COVERSTORY
15
he phone rang one morning in the spring
of 2013. After Syamsu Alam, Pertamina EP’s
President Director, hung up the phone, he
knew he would have to make a quick and difficult
decision that could affect employee safety, the
citizens of West Java, and energy supply.
The Lima Flow Station, located off the coast of Jakarta
in the Northwest Java Sea, was at risk of structural failure.
The flow station, acquired by Pertamina EP in 2009 when
they purchased BP West Java, was starting to sink into
the seabed.
Seabed subsidence in a fixed offshore platform isn’t
uncommon – especially in a flow station like Lima, which
has been around since 1973. The sinking is caused by a
release in pressure in the reservoir’s porous rock after years
of oil production. This pressure reduction causes the rock
T
Technology Helps Fix a Flow Station in Double Time

THAILAND
CAMBODIA
LAOS
VIETNAM
MAYANMAR
MALAYSIA
MALAYSIA
PHILLIPPINES
SINGAPORE
SOUTH CHINA OCEAN
INDIAN OCEAN
INDONESIA
APPROXIMATELY 50% OF
JAKARTA’S RESIDENTS WERE
FACING THREE MONTHS
WITHOUT ACCESS TO
GAS FOR COOKING
AND HEATING.
50%
Jakarta
to compact, which lowers the seabed, taking the
platform along with it.
Now, the Lima Flow Station wasn’t going to
disappear overnight, but the seabed subsidence
was beginning to bring the platform too close
to the water. Offshore platforms are built
to stand high above the ocean, protecting
the structure, equipment, and workers from
potentially destructive wave force. The space
between the average wave height and the
platform – called an air gap – must allow a
sufficient separation between the water and the
station. Allowing Lima’s air gap to fall below
that distance could seriously compromise the
safety of the flow station’s production platform,
compression platform, living quarters platform
and bridges – especially if a strong storm caused
significant waves.
Lima will be retired in 2026, but Alam
knew that Pertamina EP couldn’t wait that long
to fix the problem. He consulted with Jamsaton
Nababan, Vice President of Surface Facilities.
After some deliberation, Alam and Nababan
came up with a solution to the problem: Raise
Lima Flow Station by four meters.
Pertamina EP hired its main contractor
and a project management firm to carry out
what became known as the Lima Subsidence
Remediation Project. The two companies got
started right away and, for a moment, it seemed
that the sinking station problem would be fixed
without issue.
Shortly after the project got underway,
Alam was presented
with an even more difficult challenge:
To safely lift the flow station’s most critical
platforms and facilities, they would have to
shut down several pipelines connected
to it, severely limiting the gas supply for
approximately three months.
This was the last thing that Alam wanted to
hear. Pertamina EP is the main supplier of gas
to West Java, including the big city of Jakarta.
It supplies gas to Kujang’s fertilizer plant,
a refinery in Balongan, and several power
stations. The Lima field also supplies natural
gas to millions of residential consumers, with
many depending on it for their electricity.
Disrupting the gas supply for a mere three
days would be a problem. Three months
would be a disaster.
To further complicate matters, Pertamina
EP is a government-owned company. Any
accidents or disruption in gas supply would
have political implications. And, of course,
shutting down the flow of product would cause
them to lose profit.
In other words, the pipelines had to keep
running no matter what.
FORMING A SOLUTION
Rakhmat Sani, a sales engineer at T.D.
Williamson (TDW), got the call from
Pertamina EP. They explained that the project
needed TDW’s expertise in a pipeline isolation
project, specifically the installation of several
16

lines to bypass the 14-inch and 20-inch main
gasline pipelines (MGL) that extend from
the TLA and TLD platforms to the L-PRO
platform, as well as the 24-inch MGL pipeline
that extends between the L-PRO and a port
onshore. Pertamina EP wanted to isolate the
affected lines while the bypass lines were
installed – keeping gas flowing to Jakarta.
TDW specializes in isolating pipelines
using hot tapping and plugging. Hot tapping
involves connecting a piece of equipment to
the pipeline, then making an opening in the
pipeline so that the plug can be inserted.
The company’s STOPPLE® plugging system
is used for hot tapping and plugging. It helps
isolate sections of pipeline, then allows the
rerouting of the product through a temporary
bypass so that the isolated section of pipeline
can undergo maintenance. This procedure
allows the operator to keep the oil or natural
gas supply flowing while repairs are made.
After the pipeline is repaired, a diving team
comes in and plugs the openings created
for bypass.
Sani assured Pertamina EP that the line
intervention and temporary isolation project
wouldn’t be an issue – but then Pertamina EP
revealed that TDW needed to get their part
of the project done in just four months to
avoid the gas shutdown – an unprecedentedly
short timeline.
PLANNING FOR SUCCESS
TDW Project Manager, Mohamad Ameen, came
on board to manage Pertamina EP’s isolation
and rerouting project. Ameen knew he would
have to go to extreme lengths to meet the client’s
tight deadline.
“Typically, a subsea hot tap and STOPPLE
isolation takes several months – but TDW was
asked to plan, research, and execute in less than
four,” explains Ameen. “We had never completed
a project of this type so quickly. In fact, I don’t
think anyone in the industry has completed such
a big project in such a short time.”
Ameen and Edmund Ang, a TDW Operations
Manager, didn’t waste a second. They, along with
others at TDW, came up with a unique plan: To
safely bypass the pipelines and keep gas flowing,
they would need to perform nine hot taps, then
execute STOPPLE isolations in six different
locations. In order to complete the project in the
four month timeline, the team would have to
execute all nine hot taps simultaneously, followed
by performing, concurrently, all six STOPPLE
plugging operations.
Not only did TDW need to get the project
done quickly, they needed a lot of equipment and
personnel to complete it. Usually, the company
uses equipment from its nearest location and
builds more if necessary. “Because our timeframe
was so short, we opted to mobilize equipment
from other locations around the world,” says
INNOVATIONS•APRIL-JUNE2014COVERSTORY
17
In order to complete the project in the four month
timeline, the team would have to execute all nine
hot taps simultaneously, followed by performing,
concurrently, all six STOPPLE®
plugging operations.

Ameen. “That way we were able to get it all to
Singapore to do a final assessment test before
going offshore.”
“Such complex operations typically take
several months to plan,” explains Ang.
ALL HANDS ON DECK
TDW, Pertamina EP and the contractors all met
to plan every detail of execution. First, various
pieces of hot tap and plugging equipment from
North America, Europe, and Asia Pacific were
gathered in Singapore, along with a team of
expert technicians. Once they completed system
integration testing and a mock-up simulation
of 14-, 20- and 24-inch hot tap and STOPPLE
plugging, the team was ready to mobilize to the
offshore jobsite.
In hot tapping and plugging, the entire
execution is performed by subsea divers. The
underwater operation takes a great deal of skill
to avoid human error. For example, if the plug
setting is not completed, the pipe contents can
escape, causing a potential safety hazard and
wasting valuable product.
A diving contractor was brought on to
support the project with their divers and dive
support vessels (DSVs). Working in five-
member teams at depths of 131 feet below the
surface, the divers deployed a 1200 XL and a
SubSea 1000 XL Hydraulic Operated Tapping
machine. They took field measurements on
the subsea mechanical clamps to calculate the
cutting distance, then mounted the tapping
equipment and completed the hot taps to cut
into the pipeline.
SAVING TIME WITH
SIMULTANEOUS ISOLATIONS
With all nine hot taps completed, it was time
to carry out the task of installing six STOPPLE
“SUCH COMPLEX OPERATIONS TYPICALLY
TAKE SEVERAL MONTHS TO PLAN
”– EDMUND ANG
TESTING &
MOCK-UP
SIMULATION
FOR HOT TAP
& ISOLATION
24in.PIPE
DIAMETER
14in.PIPE
DIAMETER
20in.PIPE
DIAMETER
MAKING THE IMPOSSIBLE POSSIBLE
18
63DAYS EXECUTED
SIMULTANEOUSLY
9 HOT TAPS
6 ISOLATIONS

plugging heads onto the mechanical fittings
and setting them into position, so that gas
could continue flowing through the bypass
lines while maintenance was performed on
the main pipelines. In order to get this done
within Pertamina EP’s timeline, the STOPPLE
plugging operation had to be performed in six
locations at once.
At this critical juncture, the offshore
technicians ran into a problem that almost
delayed them. “We discovered that a piece of
equipment had been damaged during execution,”
recalls Ameen. “We had actually never had a
piece of equipment damaged like that before,
and we didn’t anticipate it.” The project manager
quickly procured a replacement and the project
was able to move forward.
“When subsea, just one hot tap can take
several weeks, including planning,” Ameen
explains. In just 23 days, the team completed all
hot tapping, plugging and isolation of all lines –
a feat that kept Pertamina EP’s project perfectly
on schedule.
With STOPPLE plugging equipment in place,
the pipelines remained safely isolated while the
bypass lines were commissioned and the L-PRO
platform was raised. The entire operation took
only 63 days, keeping safely within Pertamina
EP’s timeline.
How was the team able to pull off the tapping
and plugging operation in such an unprecedented
amount of time? Edmund Ang credits use of the
latest plugging technology.
A SEAL THAT SNAPS INTO PLACE
Plugging the openings where the bypass occurred is
the last phase in a hot tap and plugging operation.
Murky waters, such as those at the Lima flow
station, can complicate an operation, because it’s
difficult for divers to determine exactly when the
INNOVATIONS•APRIL-JUNE2014COVERSTORY
19
1
3
1
FEET
BELOW
SURFACE
5-MEMBER
DIVING
TEAMS
EQUIPMENT
Shipped in from:
NORTH AMERICA
EUROPE
ASIA PACIFIC
Normal Planning
& Completion
8+months
SUBSEA
HOT TAP LIMA Planning
& Completion 4months
CONTINUED ON PAGE 27

DUG Bakken and Niobrara
2-4APRIL | Denver,CO | USA
ASME Plant Engineering & Maintenance
10APRIL | Pasadena,TX | USA
Kinder Morgan Supplier Showcase
20-22 MAY | Houston,TX | USA
AGA Operations Conference
20-23 MAY | Pittsburgh,PA | USA
MANGO - Missouri Association
of Natural Gas Operators
25-27 JUNE | Lake Ozark,MO | USA
CGA Measurement and Regulation School
2-5 JUNE | Edmonton, AB | Canada
OWWA/OMWA Joint Annual
Conference & Trade Show
4-7 MAY | London,ON | Canada
9th Pipeline
Technology Conference
12-14 MAY | Berlin | Germany
EXPO FORO PEMEX 2014
22-24APRIL | Mexico City | Mexico
ACPS - Atlantic Canadian
Petroleum Show
18-19 JUNE | St.John’s,NFLD | Canada
20
APRIL 2014
2-4 DUG Bakken and Niobrara
Denver, CO, USA
10 ASME Plant Engineering &
Maintenance
Pasadena,TX, USA
21-23 Moscow International Energy Forum
Moscow, Russia
Booth A6
22-24 EXPO FORO PEMEX 2014
Mexico City, Mexico
Booth 313
TDW Events, Papers & Conferences
TouchPoints

ESDA 2014 (ASME 12th Biennial Conference
on Engineering Systems Design and Analysis)
25-27 JUNE | Copenhagen | Denmark
Moscow International Energy Forum
21-23APRIL | Moscow | Russia
Indicates TDW will present a
white paper at this event
21
TDW experts deliver – providing technical presentations and hands-on
demonstrations throughout the world. To learn more:
tdwontour@tdwilliamson.com.
4-7 OWWA/OMWA Joint Annual
Conference & Trade Show
London, ON, Canada
12-14 9th Pipeline Technology Conference
Berlin, Germany

20-22 Kinder Morgan Supplier Showcase
Houston,TX, USA
Booth 73
20-23 AGA Operations Conference
Pittsburgh, PA, USA
2-5 CGA Measurement and Regulation School
Edmonton,AB, Canada
18-19 ACPS - Atlantic Canadian Petroleum Show
St. John’s, NFLD, Canada
25-27 ESDA 2014 (ASME 12th Biennial Conference
on Engineering Systems Design and Analysis)
Copenhagen, Denmark
25-27 MANGO - Missouri Association of Natural
Gas Operators
Lake Ozark, MO, USA
JUNE 2014MAY 2014 INNOVATIONS•APRIL-JUNE2014

• Answers to
Complex Questions
• Developed at
Operator Request
• Preparing Operators
for What’s Next
22
hether they’re working in the moderate
Gulf of Mexico or the more treacherous
North Sea, at shallow depths or levels where
divers can’t reach, offshore operators face certain common
issues. Like the best way to increase throughput. And how
to mitigate risk associated with construction, flow assurance,
integrity management and repair.
W
OF
THE

FEATURESTORYINNOVATIONS•APRIL-JUNE2014
23
Pooling industry expertise guides offshore
operators to technical solutions.
Participating in Joint Industry Projects (JIPs)
is one way operators can collaborate to solve the
problems they share. JIPs are focused on advancing
technologies to meet operators’ business needs,
particularly in the realm of increasing production
and extending reserves. By leveraging the resources
of its members – which include operators, service
providers and various vendors – the JIP can often
come to a solution faster and with more likelihood
of commercial success than any single participant
toiling on its own.
The Engineering Services department at T.D.
Williamson (TDW) has a lot in common with
JIPs. Both build upon collaborative relationships
to generate innovations. In fact, the Engineering
Services department was created with the sole

24
purpose of developing strategic solutions for offshore
operators by leveraging portals for success, like
integrating knowledge from intra-industry sources,
as well as from TDW’s internal experts. In addition,
both JIPs and Engineering Services are the result of
market demand. Operators have often requested that
TDW partner with them in developing conceptual
solutions to complex operational challenges, but
until now, the company had not institutionalized
a process for generating cross-functional solutions
spanning multiple departments.
Answers To Complex Questions
As the manager of Engineering Services,
George Lim is, perhaps, a bit of a guru. Or,
in today’s business parlance, a thought leader.
Instead of spiritual seekers, though,
he’s sought out by operators looking to manage
their businesses with greater certainty and
less risk.
Oh, and rather than being perched
on a mountaintop, he’s easily accessible by
phone or email. No pitons, boots or climbing
expertise required. And one more thing,
unlike the crest-dwelling guides of old, Lim
doesn’t work in seclusion to solve the issues
that operators bring to him, challenges that
lately have ranged from how to detect and
plug leaks in an Arctic subsea line using
fiber optic cable, to the remote control of
subsea hot tapping in water 1500 meters
(4921 feet) deep.
Instead, Lim assembles subject matter
experts from the company’s regions and Centers
of Excellence, teams them with subcontractors
and other partners when necessary, and leads
them through a process that includes:
• Evaluating the operator’s technical issue
and objectives,
• Reviewing operational, economic and
environmental considerations, and
• Developing an engineered solution drawing
from multiple areas of expertise.
If this sounds like the stuff of engineering
and feasibility studies, well, it is. Engineering
and feasibility studies are among the types of
integrated work Engineering Services produces,
along with method statements, narratives and
calculations for opportunity scoping.
Developed At Operator Request
With more than 30 years of offshore experience on
his resume, there’s no question that Lim understands
the unique demands of offshore operations. (In
fact, he was recently also named the company’s
interim Director of Offshore Market Development,
a position he’ll hold concurrently with his
Engineering Services role.)
But how did he know that operators would
welcome the kind of comprehensive problem-solving
that Engineering Services furnishes?
The short answer is, because they repeatedly
request it through TDW’s regional sales teams.
Like the time the UK E&P division of a global
energy giant asked TDW for help removing a stuck
pig and wax plug from a 16-inch pipeline. Lim’s
team provided a method statement and remediation
STUDIES PROCEDURE INDUSTRY KNOWLEDGE BASE

proposal that integrated products, services and
multiple skill sets.
Or when an operator in the North Sea,
unfamiliar with subsea hot
tapping, desired to tie-in a
new, piggable oil line into
an existing export line. The
Engineering Services response
included everything from
a hot tap market study,
business and technical risk,
and piggability assessment,
to the subsea hot tap
procedure and evaluation of
the isolation valve and fitting
options. The study results
were incorporated by TDW’s
regional sales and operations
teams into a proposal for
the actual tie-in services,
including the supply of valves
and fittings through subcontracted vendors.
“The offshore industry is extremely cautious,”
Lim explains. “There are a lot of steps they do in
advance to make sure their operations are done
correctly. Studies are a typical tool of offshore
operators. Any time they need to do something
and they’re not sure what the risk looks like, they
initiate an engineering study.”
Lim goes on to state that it is not the intention
of Engineering Services to
compete with the established
industry of independent
engineering companies who
traditionally provide Front
End Engineering Design
(FEED) work for operators.
Instead, the department is a
response to customer requests
for the specific knowledge
that TDW can bring, given
its experience and expertise
in intervention, isolation and
pigging technologies. “TDW
adds value to the operator’s
evaluation process where the
solution involves a wide range
of its solutions.”
According to Chief Technology Officer Jeff
Wilson, who oversees Engineering Services, the
department not only enables TDW to participate
INNOVATIONS•APRIL-JUNE2014FEATURESTORY
25
Developing Viable Solutions
GEORGE LIM – Manager of Engineering Services,
T.D. Williamson
>>
George Lim, who heads Engineering Services, thinks the new department
could also become the formal gateway for TDW to participate in more Joint
Industry Projects (JIPs). JIPs are formal, highly structured collaborations
formed by operators, service companies, vendors, and academia to
investigate technical challenges and develop viable solutions.
Lim cites the DeepStar Global Deepwater Technology Program,
which is based in Houston, TX, and has 70 members, and Aberdeen,
U.K.’s ITF, which bills itself as ‘the internationally recognized champion
for facilitating collaborative development of innovative
technologies within oil and gas and related
industries’ as two of the best-know JIPs.
“JIPs are a common practice in the offshore
industry in particular,” Lim says. “They’re a way
for service providers to partner with operators
to better understand the market challenges and
contribute to more comprehensive solutions.”
“Instead of channeling
a request to one
department, we’re
identifying what the
operator’s greater
needs are and
bringing distinctly
different technologies
together to meet them,”
Wilson says.

deepwater challenges, such as remote operations in
extreme environments.
TDW has already developed technology that can
connect to deepwater lines and install a wide variety
of remote-controlled, third-party-client solutions, as
well as perform remote hot tapping. But operator
need is outpacing development.
VOYAGE TO THE BOTTOM LINE
Although the upfront cost to E & P companies
operating in extreme environments can be immense,
the potential value of these high pressure, high
temperature deepwater opportunities simply
outweighs the existing challenges. As a result, the
development, adoption and implementation of
advanced deepwater pipe materials will only increase
going forward, so having the technology to sustain
and expand these systems, while simultaneously
addressing issues of safety and securing the
environment, is more than common sense, it’s
good business.
“Due to overall economics, operators realize
they’re going to need these new pipe materials,”
says Wilson, “so industry starts with pipe, and
from there, other technologies to inspect, to repair,
and maintain must follow.”
The California Gold Rush suffered many
challenges, but today, we have the opportunity
to forge a destiny for the new Gold Rush with
careful planning, commitment to best practices,
and cooperation between operators, the service
industry, and the community they serve. When
future generations look back at “The Black Gold
Rush,” if the challenges of deepwater oil are met
thoughtfully, and with due diligence, the legacy
will be a bright one.
Deepwater, Black Gold Rush CONTINUED FROM PAGE 11
26
in operators’ studies, it also allows TDW to create
solutions that are more comprehensive in scope.
“Instead of channeling a request to one
department, we’re identifying what the operator’s
greater needs are and bringing distinctly different
technologies together to meet them,” Wilson says.
“We’re accelerating our progress as an integrated
concepts solution provider.”
Preparing Operators For What’s Next
So far, Lim and the teams he’s pulled together have
guided offshore operators toward sound decisions of
how to deal with pipeline flooding, pipeline blockage,
diverless subsea tie-ins, corrosion and related threats,
deepwater wax and hydrate remediation, and the
impact of dents, ruptures and repairs.
They’ve also been involved in emergency
preparedness work. This is an area where Lim and
Wilson see tremendous opportunity for the industry,
particularly in planning ahead to minimize the effects
of unexpected events ranging from infrastructure
damage to weather disasters. The Emergency Pipeline
Repair System (EPRS) studies that TDW offers not
only calculate the probability of failure, they also
demonstrate the potential risks of various emergency
situations and outline different repair scenarios.
And with aging pipelines (30 percent of the
world’s 250,000 km [155,343 miles] of offshore
pipelines are at least two decades old); unpiggable
lines (about 50 percent of offshore pipelines can’t be
pigged); and pipelines simply too deep to be reached
safely by divers, offshore companies have
a lot of risk to avert.
Which means George Lim, the guru of
TDW’s Engineering Services department, has
a lot to contemplate.

27
Raising Lima CONTINUED FROM PAGE 19
INCREASED SAFETY
»» No potential leak path
through flange
»» No plug drop
»» Interlock system
»» Operator can retrieve set,
pressurized plug without being
positioned over it
EFFICIENCY
»» Easier, quicker setting process
»» Plug can only be set correctly
»» Correct coupon alignment
eliminates piggability problems
MAINTENANCE
»» Flange and plug have fewer
parts compared to standard
LOCK-O-RING design
SIMPLICITY EQUALS SAFETY
Once the leaves are fully extended, the LOCK-O-RING®
Plus
completion plug provides operators increased safety and simplicity.
LOCK-O-RING®
Plus Plug
Features & Benefits
plug has been set. With divers struggling with
traditional, unwieldy equipment, each plug
setting can take several hours.
To save time, the team decided to try something
previously performed only onshore: Installation of
LOCK-O-RING® Plus completion plugs.
This completion plug technology was patented
in early 2011, and has been successfully used to
complete multiple onshore STOPPLE isolation
jobs. The technology had been thoroughly
tested for subsea, but had not yet been used
on a subsea job.
Each STOPPLE fitting has a flange with no
side openings, which reduces any potential leak
paths. This flange helps with the attachment of
the bypass system. Once the bypass is removed,
the flange can also assist with the attachment of
the LOCK-O-RING Plus completion plug.
A feature of the completion plug that made it
the right tool for Pertamina EP’s project is that
its interlock system indicates when the leaves
are fully extended, which lets divers know, with
certainty, when it is positively set in the flange.
Plus, the plug setting machine used to set the
plug transfers pressure from the pipeline to the
inside of the plug setter, balancing the pressure
by counteracting the force pushing against the
machine. Altogether, this system provided divers
and engineers with a quicker and safer way to
complete their work underwater.
PERTAMINA EP’S CUSTOMERS
CONTINUE TO COOK
The Lima project was a distinguished introduction
of the LOCK-O-RING Plus completion plug to its
new subsea application. Now that the technology
has proven to be effective underwater, the door has
been opened to using the technology in similar
projects following the shared experiences and
lessons learned by Pertamina EP, the contractors
and TDW’s project managers.
Most importantly, Pertamina EP was able to
raise their Lima Flow Station without any incidents
or disruptions to the gas supply. Jakarta and the rest
of West Java had gas for cooking and power, and
Pertamina EP didn’t lose profits from a shutdown.
“We asked our team to make the impossible possible,
and they did it,” says Nababan.
COVERSTORY

28
As part of the pre-commissioning process
operators rely heavily on flooding, cleaning
and gauging pigs, almost always opting for bi-directional discs (easier to reverse if
needed). Commissioning largely depends on batching and specialty dewatering pigs.
The decommissioning process utilizes both batching and cleaning pigs.
Flooding, Gauging,
Batching, Dewatering
BY THE
NUMBERS
Chemical, Discs,
Cups, Brushes,
Scrapers
Magnetic Flux Leakage
(MFL), Ultrasonic (UT),
Circumferential MFL,
Geometry
Tetherless, Double
Block, Remote-
controlled
Pigging to clean
and displace
liquids is essential to maximize throughput and extend offshore asset life. Clear
communication and planning is key to eliminate waxy buildup, clear debris from
internal pitting, effectively apply corrosion inhibitor and remove water.
Primarily divided between
Ultrasonic (UT) and Magnetic
Flux Leakage (MFL) technology, accurate and timely integrity data are critical to
the safe operation of offshore lines, particularly as these lines are in an often
harsh, high-consequence environment that can be entirely inaccessible to divers.
The purpose of a non-invasive isolation system
is to pressure isolate a section of pipeline during
maintenance, emergency repair or construction, while the rest of the pipeline
remains at operating pressure. The primary advantage of such systems is the
ability to minimize pipeline downtime and reduce lost transmission revenue.
1
2
3
4
COMMISSIONING
CLEANING & DISPLACEMENT
INLINE INSPECTION
ISOLATION
OFFSHORE

29
THINGS CAN GET CONFUSING JUST BELOW
THE OCEAN’S SURFACE, but keeping your lines clean and
safe is a clear proposition. Pipeline service providers assist operators
in developing and executing customized pigging programs aimed at
maximizing throughput and increasing operational safety. Although
possibly overwhelming at first glance, these complex programs can be
simplified into just four phases.
PIGGINGin 4phases

North & South America
Europe / Africa / Middle East
Asia Pacific
Offshore Services
+1 918 447 5000
+32 67 28 3611
+65 6364 8520
+1 832 448 7200
TDWilliamson.com
® Registered trademark of T.D. Williamson, Inc. in the United States and in other countries. ™ Trademark of T.D. Williamson, Inc. in the United States and in other countries. ©Copyright 2014 All rights reserved. T.D. Williamson, Inc.
Trusted Partnership
For four generations, companies around the world have trusted
TDW’s unwavering commitment to pipeline performance.
So can you.
North & South America
Europe/Africa/Middle East
Asia Pacific
Offshore Services
+1 918 447 5000
+32 672 836 11
+65 6364 8520
+1 832 448 7200
TDWilliamson.com
® Registered trademark of T.D. Williamson, Inc. in the United States and in other countries. ™ Trademark of T.D. Williamson, Inc. in the United States and in other countries. © Copyright 2014 All rights reserved. T.D. Williamson, Inc.
Trusted Partnership
For four generations, companies around the world have trusted
TDW’s unwavering commitment to pipeline performance.
So can you.
Inline Inspection • Non-destructive Evaluation • Interactive Reporting

Innovations™ Magazine April - June 2014

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