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Transcript of DNV cutting edge projects 2012
CUTTING EDGE VIEW
DNV 27 Cutting Edge projects 2012
02 CUTTING EDGE
CONTENTS
MARITIME & CLASS p 32–51
34 Bunkering LNG as fuel for ships 36 LNG bunkering in Australian ports feasible 38 LNG case study in Baltic container market39 Gas carrier research & development40 Arctic shipping: Updating ice load tools42 Nauticus Hull – capturing engineering knowledge43 Nauticus Air – and environmental benchmarking44 Particulate matter – getting the whole picture 46 A closer look at sulphur scrubbers 48 Propulsion machinery performance investigated50 Powering ships with DC power51 Making hybrid ship design easier
SERVICE DIRECTORS p 6–7
FURTHER ON p 52–53
OIL & GAS FRONTIERS p 8–31
10 The remaining life of offshore assets12 Pipeline Recommended Practices get updated14 MARV proves itself to the pipeline industry16 Submarine pipeline systems17 The life of a well18 Measuring risk in real time20 Blow-Out Prevention (BOP) meets automation22 Major accident risk revisited23 Safe operations in the Arctic frontier24 Onshore pipeline verification arrives25 Recommendations for risk management of shale gas26 An offshore oil rig for the future28 Offshore wind turbine vessels Improving29 Jack-ups: Rewriting users’ rule experience30 When hot repairs should go cold
CUTTING EDGE 03
CUTTING EDGE VIEW 2012
That is because we believe that colleagues working closely with our customers all over the world have the keenest appreciation for our customers’ needs. As a consequence, we can and do address important industry issues as they arise.
In 2012, 166 of these project ideas got realized. We think that sharing knowledge is a key driver to success. This Cutting Edge View is meant to be a sample of how we are focusing that knowledge. We have selected 27 projects within the categories, Maritime & Class and Oil & Gas, to present in this publication.
We welcome your responses, and invite you to contact us, whether it is to provide input, get more information, or join us in our efforts. Together, we will continue to solve industry challenges and lead the way.
Contact [email protected] for more information or for an overview of ongoing Joint Industry Project initiatives.
EVERY YEAR WE INVITE OUR STAFF TO PROPOSE NEW IDEAS FOR TECHNOLOGY AND SERVICE DEVELOPMENT.
04 CUTTING EDGE
INTRODUCTIONMANAGING RISK HAS MANY FACETS
Henrik O. Madsen, CEO
Managing risk has many facets. While most of our customer projects focus on managing the risks of building a new ship or safeguarding an existing offshore structure, our Cutting Edge projects are different. They are established on the premise that managing today’s risks is not enough – we also have to manage tomorrow’s risks. Since our customers are constantly moving into new territories with more complex technologies operat-ing in more challenging environments, they are facing an uncertain risk picture. Our Cutting Edge projects are designed to keep us in the forefront of technology development and qualification, enabling us to help our customers identify and manage their risk frontiers.
Growing demand for energy, combined with an increased focus on environmentally friendly technologies, drives a constant need for innovation. At DNV, we invest heavily in research and innovation to enhance and develop services, technologies, software, rules and industry standards in the energy and maritime sectors. Many of the technology solutions developed by DNV have helped define internationally recognized standards.
Our efforts are implemented worldwide. As a knowledge-based company, our prime assets are the creativity, knowledge, and expertise of more than 10,000 employees from more than 85 nations. A selection of recent projects is presented in the following pages, illustrating the depth and extent of our work. They are based on ideas from creative individuals in our worldwide organization, generated by interaction with, and the involvement of, a number of our key customers. We are excited and proud of the results, and look forward to continuing our work with the industry to lead the way.
Happy reading!
CUTTING EDGE: 05
6%n The long term perspective DNV Research and Innovation looks into the future, focusing on long term strategic research programs to acquire new knowledge and competence.
n Challenging the industry DNV conducts short-term, intense projects where project teams are taken out of production to work full-time to answer specific challenges. These “extraordinary innovation projects” are deep-dives into real industry challenges, addressed by innovatively combining existing technologies with concepts that can be further matured by the industry.
n Increased efficiency DNV’s Platform initiatives are large development programs initiated by DNV management. These initiatives aim to improve our competitive edge through process and efficiency enhancements and through development of our IT and production systems.
n Responding to expressed customer needs DNV’s Cutting Edge portfolio is a “bottom-up” innovation initia-tive in which ideas for development projects are collected from creative DNV employees from around the world. The projects in the resulting portfolio aim at developing services that add value to our clients by collaborating with them, and focusing on solving their real-life challenges.
n Technology development DNV’s Technology Leadership is centred on its core technical disciplines, and is driven by our subject matter experts. The objective of the initiative is to maintain and further develop state-of-the-art technology.
This publication showcases a selection from DNV’s 2012 Cutting Edge and Technology Leadership projects. Our goal is to give you a taste of the range of exciting development initiatives carried out by DNV around the world, just in the last year.
Fo r almo s t 150 yea r s , DNV ha s been mee ting cu s tome r s’ and so cie t y ’s need s, g rowing th rough it s s t rong
vision, pu rpo s e and value s. Ou r s e r vice s a re to iden tif y, a s s e s s and manage ris k s to c r ea t e and p ro te c t
value fo r ou r cu s tome r s and so cie t y a t la rge. We build the s e s e r vice s on ou r s t rong ba s e o f te chnologie s,
ou r compe ten cie s, and ou r independen ce and third pa r t y role. DNV ha s e s t ablished thou s and s o f initia -
tive s fo r innova tion and te chnology developmen t, fulfilling sp e cific and alway s fo rwa rd -looking pu rpo s e s.
INNOVATION IN DNV
Research and innovation
Challenging concepts
Increased efficiency
We invest 6% of our revenue in research and development
In 2012 we ran 29 Joint Industry Projects within the Cutting Edge portfolio
Service development
Technology development
29 JIPNumber of projects within the categories
06 CUTTING EDGE
We focused in 2012 on assisting the industry in complying
with an increasing number of environmental regulatory
requirements. By the end of January, 2015, the permitted
levels of sulphur in marine fuels, or emissions from ships’
engines, will fall in emission-control areas. To comply with
these changes, ship owners need to make some key business
decisions: should they opt for vessels that use low-sulphur
fuels, should they install exhaust scrubber systems on their
ships or should they invest in gas-powered tonnage?
The Ballast Water Management Convention is expected to
enter into force within the next two years and require all
ships and offshore structures to clean their ballast water.
This will have a major effect on operations and involve
major investments in technology. DNV has become the
industry’s preferred technical and advisory partner in
ballast water management.
It is not only in the area of environmental protection that
we see new regulations coming into effect; in August,
2013, the Maritime Labour Convention (MLC) will enter
into force. DNV Development trained MLC inspectors in
2012, in preparation for this new Convention, which aims
at providing decent working and living conditions for
seafarers onboard ships.
DNV has developed a Port State Control App for smart-
phones. The Port State APP enables customers to under-
take pre-PSC checks, using standard checklists. This service
will reduce down time, create hassle-free operation without
detentions, reduce the cost of delays and minimize unin-
tentional disturbances in daily operations. Our focus on
port state has shown results, as our customer are amongst
those with the fewest detentions in both the Paris and
Tokyo MOUs.
We bring our expertise in class services to a global clientele
to help them manage their compliance needs and prepare
for a bright future, for our customers, the broader industry
community, and the world.
IN A WORLD OF INCREASING ENERGY DEMAND, BALANCED BY STRICTER ENVIRONMENTAL CONTROLS AND HIGHER COST, DNV PROVIDES KNOWLEDGE, EXPERIENCE AND SERVICES TO ITS CUSTOMERS.
CLASSIFICATION SERVICES
Geir Dugstad Service Director
“We assist our customers to ensure compliance with conventions and regulations.
DNV delivers verification services in all phases of a
project: concept, design, operation and de-commis-
sioning. We make our verification services transparent
in the DNV Service Specifications, framework and
activity.
DNV has developed a range of Offshore Standards and
Recommended Practices, together with the industry,
to set requirements and offer guidelines based on new
technology and the state of knowledge. One example
is our Offshore Standard for Submarine Pipeline which
is the leading international technical standard for pipe-
lines. This offshore standard is supported by a number
of Recommended Practices. The DNV Offshore Service
Specification for Certification and Verification of Pipe-
lines has been adopted as the industry standard.
Lately, DNV has successfully developed service docu-
ments also for onshore applications and, in 2012,
developed a DNV Service specification for Verification
of Onshore Pipelines. Historically, onshore pipeline
systems are normally not subject to independent veri-
fication. However, there is an increasing need to
involve independent verifiers to provide operators
VERIFICATIONSERVICES
IN AN EVOLVING MARKET, THE OIL & GAS INDUSTRY FACES MANY RISKS DURING DESIGN AND OPERATIONS OF THEIR FACILITIES. BY OFFERING HIGHLY TECHNICAL COMPETENCE AND DELIVERING RISK BASED VERIFICA-TION SERVICES, DNV HELPS OUR CUSTOMERS MANAGE THESE RISKS.
“Customers are drawing on the extensive experience and technical expertise of our employees.
CUTTING EDGE 07
Close collaboration with the industries has been key to the results we have created.
Astri GaardeService Director
“
The maritime industry is rapidly embracing new and
more environmentally friendly technology. The risks
associated with these opportunities need to be managed,
and last year DNV engaged in a number of technology
projects focusing on more environmentally friendly fuel,
propulsion and ship design. One good example is the
project we did on SOx abatement technologies, to use
scrubbers to remove sulphur from fuel oil exhaust. We
also did several projects focusing on LNG, including on
LNG bunkering and on the design of innovative ship
concepts using LNG-fuelled engines.
When we look further north, sustainable operations
become more important, and we engaged together with
other industry partners in Joint Industry Projects focusing
on Safe Arctic Operations.
Our risk management and technology qualification
services for the oil & gas industry are continuously
working to make the industry safer, as the industry’s focus
is still to regain confidence after the Macondo accident.
One project we delivered last year focused on establishing
safety indicators giving early warnings when things are
not in place. And, as existing installations and pipelines
grow older, managing the risk of degradation was another
key focus area of our studies last year.
We will bring our knowledge from all these development
projects into our advisory services, managing the risks of
today and tomorrow for our customers and the broader
industry community.
SAFEGUARDING OUR INDUSTRIES AND MANAGING THEIR RISKS AS THEY MOVE INTO NEW FRONTIERS IS THE GOAL OF ALL THE UNIQUE DEVELOPMENT PROJECTS DNV ACCOMPLISHED THIS PAST YEAR, THE BEST OF WHICH ARE PRESENTED HERE.
ADVISORY SERVICES
Sverre Alvik Service Director
with the required level of confidence that their facili-
ties are compliant.
In 2012, DNV also set the standard for Shale Gas Risk
management by launching a Recommended Practice
for the entire life cycle of shale gas extraction based
on risk management principles.
This addresses public concern about the consequences
of shale gas operations. We believe our Recommended
Practice will contribute to increasing trust and confi-
dence among all stakeholders. These efforts demonstrate
how we bring knowledge forward to address the needs
of our customers and the broader industry community.
image size: 540x210mm
08 CUTTING EDGE > OIL & GAS FRONTIERS
OIL & GAS FRONTIERS > CUTTING EDGE 09
OIL & GAS FRONTIERSChanges in the oil & gas industry are taking place at increasingly rapid pace, and projects today will need to be robust against the changing requirements of tomorrow.
Within only a few years, the shale revolution has changed and will continue to change the world energy supply and demand profiles. However, environmental risk in addition to trust from authorities and local communities are major issues that must be handled. Another example is projects targeted in the Arctic, seen as the last frontier for the industry. Here, new technologies need to be developed to meet the additional risks.
At the same time, global oil & gas infrastructure continues to expand, often around existing hubs, thereby further extending field life often well beyond the initial design life of assets. Therefore, continued safe operation of mature assets against a verified level of integrity is going to be critical, particularly for offshore assets and for wells where life-cycle integrity is more difficult to measure.
Reducing the risk of major accidents is intrinsic to the license to operate.
Remaining Life, Remaining life assessment, Offshore assets, Fixed offshore platforms, Ageing units, Life extension
AGE ING OFFSHORE TODAY
Ageing assets form a substantial world market,
as more offshore assets – in all geographic areas
– reach or surpasstheir design life-span. Life
extension is a top priority. For example, hun-
dreds of Fixed Offshore Platforms (FOUs) in
the Middle East are approaching or have
exceeded their design life. North Sea offshore
production facilities, built in the ‘70s and ‘80s,
had a design life of 25 years and are over 20
years old. The average age of Norway’s offshore
installations is near 25 years, past the intended
productive lifespan. Similar situations exist
in the U.S., Brazil, and in South East Asia.
PROJECT WORK
This project took ongoing life extension assess-
ment techniques and created a comprehensive
Remaining Life Assessment (RLA), unified
across the various facilities and elements of
offshore assets. The DNV Abu Dhabi office
took the lead, coordinating, analyzing and
compiling the methodology. The methodology
is derived from DNV best practices and other
relevance references from outside DNV. Subject
matter experts contributed from DNV offices
around the globe.
REPORT RESULTS
The report captures the methodology for the
assessment of remaining life for the structure,
pipeline, topside and wells of an ageing FOU.
The methodology provides the basis for techno-
economical assessments upon which decisions
can now be made for the safe extension of FOUs
beyond their original design life. The compre-
hensive RLA also analyzes the status of the instal-
lation, its associated facilities and the investment
needed to ensure that the extension period is
economically efficient.
The report proposes that at the start of a life
extension assessment, a high level risk assess-
ment of all major components be undertaken
to identify critical and focus areas for further
detailed assessment. Future cost analysis forms
a part of evaluation. A Regulation Gap Analysis
is then carried out to identify current regula-
tory gaps and assess the risks taken when oper-
ating with gaps. The critical equipment and
facilities identified through as-is condition
assessment may need detailed evaluation to
Ageing assets pose challenges to oil & gas when operated past their design life. With the
high level of oil & gas prices on the world market, buoyed by the lack of any viable alter-
native source to satiate growing energy demand, operators are seeking to maintain pro-
duction from existing facilities for longer than their intended design periods. While they
endeavour to do so, the risk to safety, reliability, and the environment need careful
consideration.
DNV has various services tailored to this ever growing market. However, few docunents
addressed the requirements of a fixed offshore asset comprehensively. Driven by the need
to capture life extension requirements of all important facilities under one umbrella, DNV
has now created a comprehensive methodology for life extension of fixed offshore units.
In his present role, Anupam drives the DNV Verification, Certification and Asset Integrity Management work in the Middle East – India market. He is responsible for the commercial and technical delivery of oil & gas projects.
Anupam has more than 21 years’ experience in core energy engineer-ing industries including oil & gas, as well as in business and engineering management, the last three years located at Abu Dhabi for DNV.
Before joining DNV, he was respon-sible for the development of the oil & gas business in the Middle East and Africa regions for Lloyds Regis-ter EMEA, where he was involved in several oil & gas and maritime projects. Anupam has technical expertise encompassing safety case verification, design of structure, pressure equipment, lifting equip-ment, marine equipment and Asset Integrity Management, among other areas.
PROJECT MANAGERANUPAM GHOSAL
THE REMAINING LIFE OF OFFSHORE ASSETS
Illustration of the life extension process
Degradationmodel 1
Installation
Life extensionevaluation
Originalservice life
Extendedservice life
Newdesign life
Originaldesign life
Degradationmodel 2
Acceptancelevel
Integrityassessment
10 CUTTING EDGE > OIL & GAS FRONTIERS
arrive at actions and recommendations for life
extension. For topside facilities of fixed off-
shore structures, the methodology suggests
appropriate analysis for life extension of static
equipment, rotating equipment, electrical and
instrumentation components.
The structures of fixed offshore platforms are
constantly exposed to a hostile environment.
The approach detailed in the RLA identifies
the structural asset reliability, integrity, vulner-
ability and risks associated with safe operations
that need to be managed before it is approved
for operating beyond its design life.
The methodology also addresses pipelines,
addressing potential problems by using a variety
of engineering methods to predict the remain-
ing safe lifespan. These methods include both
simple and complex fitness for purpose analyses
as well as other care and maintenance
elements.
Following the Macondo accident, a greater
focus on safe drilling and well operations is
present in the industry. Traditionally, well
integrity management has been conducted
independently from integrity management of
other assets. Only in recent years have operators
started to use systematic integrity management
principles. The RLA developed by DNV pre-
sents a recommended approach to integrated
well integrity management and risk based
inspection. The methodology presented cap-
tures the practices that DNV has adopted to
help global operators maintain production
from existing facilities for longer periods,
safely and efficiently.
RESOURCES RESOURCES
LEADERSHIP
RESULTS
People and organisation
Materials
Information and IT systems
People and organisation
Materials
Information and IT systems
ContinualImprovement
Act
Plan
Do
Check
Overall framework for an Asset Integrity Management System.
ASSET INTEGRITY MANAGEMENT
MANAGEMENT SYSTEM, ORGANIZATION, REPORTING
SAFETY BARRIERS
Technical integrity:
Understanding of POF for Critical Equipment and implement appropriate Measure
Operational integrity:
Monitoring andRecording of process parameters in order to maintain the designed operating envelope
Design integrity:
Identification of operational risk early in the design phase in order to implement suitable measures in future
Integrity Management
OIL & GAS FRONTIERS > CUTTING EDGE 1 1
Felix is currently involved in the implementation and development of DNV’s Pipeline Integrity Management services at the Operations Technology unit at DNV Høvik. His work includes the development of Recommended Practices for integrity management of submarine pipeline systems, the development of risk based inspection programmes, and integrity assessments.
Felix is a Principal Engineer with a specific work interest in asset integrity services including Risk Based Inspec-tion (RBI) of offshore topsides static mechanical equipment and Pipeline Integrity Management. Before joining DNV in 1998, he worked for two years in the Norwegian Army Mate-rial Command in projects aimed at assisting them in evaluating opera-tional and maintenance concerns while developing and acquiring complex military systems. Felix is a System Engineer with his Master’s degree from Kungliga Tekniska Högskolan, Sweden (1996).
Corrosion, Corrosion monitoring systems, Submarine pipeline corrosion, Key performance indicators, Integrity management, DNV-RP-F101 “Corroded Pipelines”, DNV-RP-F116 “Integrity Management of Submarine Pipeline Systems”, DNV-OS-F101 “Submarine Pipeline Systems”, Joint Industry Project, JIP, Recommended Practice
IT’S CALLED INTEGRITY MANAGEMENT
For decades, key performance indicators (KPIs)
have been used to ensure the integrity of oil &
gas installations. KPIs include such things as
the number of failures, violations, and inspec-
tions, and are usually expressed in diagrams
– trends and ‘traffic lights’. Yet, KPIs have not
been applied to submarine pipelines as often
as to processing facilities.
Potential KPIs related to managing corrosion
threats have been one of the subjects of a DNV
Joint Industry Project (JIP), with a revision to
DNV-RP-F116 “Integrity Management of Sub-
marine Pipeline Systems”.
LEADERSHIP PROJECT THINKING
Potential KPIs have been identified based on
a combined integrity management and barrier
concept. In this context, barriers include any
kind of measure put in place to prevent a haz-
ardous event, as well as any measure that breaks
the chain of events to prevent or minimize
consequence escalation should the hazardous
event take place. Such measures can be physi-
cal and/or non-physical (e.g. organisational).
The resulting set of potential KPIs can be used
as input when choosing indicators to be
included in existing or planned company KPI
systems, and tracked to actual pipeline systems
for follow-up.
CORROSION IN FOCUS
A second element of the work in this area
involved revisions to DNV-RP-F101 “Corroded
Pipelines”. Another DNV JIP has been contrib-
uting with significant input since 2011. The
revisions improve guidance on how to account
for system effects, how to perform probabilistic
assessments, and include a new assessment
methodology for long axial corrosion. The new
RP will reduce conservatism in current methods
for assessing interacting defects, while permit-
ting pipelines to achieve full compliance with
the broader DNV Standard, DNV-OS-F101
‘Submarine Pipeline Systems’.
SHARING FORWARD
DNV and its partners will now go forward to
craft the final RPs – following numerous work-
shops held in connection with their develop-
ment. With further cooperation, constructive
discussions and key experts, the last phase will
include an external hearing process for all
interested parties before new revisions are
issued later in 2013. This effort addresses key
industry concerns, and is a welcome addition to
DNV’s leadership in the continuous improve-
ment of quality, safety and efficient operations.
Corrosion of submarine pipelines in the North Sea is the most common threat for loss of
pressure containment in oil pipeline operations. The industry’s experience shows that pipe-
line failures are often due to a lack of sound corrosion monitoring systems. Such systems
are an important part of an integrity management system, a system that must support
management oversight. Two DNV Recommended Practices (RPs) were revised in 2012 in
order to do a better job of assisting the industry in integrity management and corrosion
assessments, with publication expected in 2013.
PIPELINE RECOMMENDED PRACTICES GET UPDATED
PROJECT MANAGERF E L I X SAINT-VICTOR
C A U S E
3
C A U S E
2
C A U S E
1
CONSE-QUENCE
3
CONSE-QUENCE
2
CONSE-QUENCE
1
LOSS OF CONTAINMENT
PRESSURECONTAINMENTAND PRIMARYPROTECTION
PIPELINEINTEGRITYCONTROL
OPERATIO-NAL/PROCESSCONTROL
PIPELINEINTEGRITYIMPROVE-MENT
Barriers to prevent hazardous event
LEAKDETECTIONANDEMERGENCYSHUTDOWN
OPERATIONAL/PROCESS CONTROL
COMMUNI-CATION, COMBAT, DIVERSION AND RESCUE
PIPELINEREPAIRSYSTEMS
Barriers to control consequences and effects
12 CUTTING EDGE > OIL & GAS FRONTIERS
OIL & GAS FRONTIERS > CUTTING EDGE 13
“To be a surrealist… means barring from your mind
all remembrance of what you have seen, and being always on the lookout
for what has never been.”
RENÉ MAGRITTE, QUOTED IN TIME, APRIL 21, 1947
Gerry is a Senior Principal Engineer in the Materials and Corrosion Technology Center, and works with DNV R&I to develop MARVTM into a commercially viable risk manage-ment tool and to create superusers in the DNV operating units globally.
Gerry started as a Senior Metallurgist at Fokker Aircraft working on the development of hybrid aircraft com-ponents. In 1980, he began work at Battelle Memorial Institute on materi-als and corrosion in coal-fired power plants, before he moved to CC Technologies in 1990. He became part of a core team that grew CC Technologies from a small testing laboratory to a company that com-manded a significant portion of the North American onshore pipeline research and engineering market. Following their acquisition by DNV in 2005, where Gerry was active in the integration process, he has worked on structural integrity of oil & gas pipelines and upstream equipment.
MARV, Pipelines, Bayes theorem analysis, Risk modelling, Risk assessment, Pipelines, Joint Industry Project, JIP
MARV PROVES ITSELF TO THE PIPELINE INDUSTRY
PROJECT MANAGERG ERRY KOCH
PIPELINE RISKS
Pipelines continue to be the safest way to trans-
port liquids and gas. However, pipeline acci-
dents do occur and pose considerable risk,
threatening the public and the environment.
With the ageing of both onshore and offshore
pipelines, the likelihood of pipeline failure is
increasing, and pipelines that were once remote
are now often encroached upon by other oper-
ations. As a result of the increasing likelihood
of pipeline incidents and the potentially severe
consequences of these to safety, health and the
environment, operating pipelines must be
better understood, and risks managed in a
more comprehensive and sophisticated manner.
MARV™ stands for Multi-Analytic Risk
Visualization, and gives pipeline operators the
ability to predict and visualize significant cur-
rent and future risks to pipelines. The tool uses
the Bayes theorem in its network model – ena-
bling this prediction, drawing from theoretical
models and empirical learning – and provides
a robust probabilistic method of assessing risk
in conditions of uncertainty.
DEALING WITH DATA
In order to develop a truly comprehensive risk
assessment method, it is critical to use ‘all’
available information about a pipeline. Many
types and sources of information exist and not
all information is readily available. The types
of information regarding a pipeline can be
grouped into three (3) main categories: inci-
dent databases, time-based data, and geographi-
cally based information. The MARV™ tool
box can interface with a wide variety of data
sources, including unreliable data sources or
data that is changing over time.
Risk on a pipeline is location dependent.
Therefore any risk assessment tool must be
able to manage risk by location. Past failure
data alone is not sufficient as the environment
around pipelines and the operating conditions
change with time. Predicting future risk of
pipeline failure requires connecting potential
causative factors in a quantitative manner to
failure processes. Once such data is analyzed, it
is integrated into different data sets as input to
risk assessment. Risks are then presented in a
visually comprehensible manner.
In 2012, the MARV™ tool was presented to the
global pipeline industry through workshops
organized by local DNV units in Houston,
Columbus, Tulsa, Abu Dhabi, Rio de Janeiro,
London, Aberdeen, Groningen, and Oslo.
Industry feedback was very favourable, and
their participation in validation work has made
it possible to now offer MARV modules on
current and future risks resulting from:
■n internal corrosion
■n external corrosion
■n stress-corrosion cracking, and
■n third-party damage.
GOOD VISUALIZATION
A good visualization tool is essential in a risk
management program. The MARV™ tool is
location and time specific, and shows the
results of the risk assessment in terms of both
risk probability and risk consequences. Further,
the tool makes it possible to drill down and
discover more detailed information. All num-
bers and calculations used to assess the risk can
be made available, if so desired. From a practical
standpoint, technological developments will
enable us to receive the information electroni-
cally via touch screen interfaces anywhere we go.
EXPANSION POTENTIAL
Now that the MARV™ pipeline risk tool has
been developed to the point that we can offer
the tool as a service to pipeline operators, the
global market outlook is very promising. The
risk tool will continuously be upgraded as the
Bayesian network continues to learn from the
various inputs. The tool will further take full
advantage of continuously improving informa-
tion and visualization technology. Further plans
are to combine advanced sensor technology
with MARV™, which will allow for real time
risk assessment and data management. And
while the MARV™ development has been
MARVTM is a DNV tool used to predict future risk to pipelines. Developed by DNV in 2011,
this risk information and management tool was introduced to the global pipeline industry
in 2012. Industry feedback was favourable and several pipeline operators agreed to work
with DNV to validate the tool using their actual pipeline data. Based on the successful
outcome of this validation work, DNV is ready to offer several MARV modules to pipeline
operators that will significantly improve their assessment of current and future risks.
14 CUTTING EDGE > OIL & GAS FRONTIERS
focused on pipelines, the concept has a much
broader application potential. As was con-
cluded through a Business Model Canvas,
MARV™ can have a future application any-
where risk management is used, from pipe-
lines, offshore structures, wind farms, utilities,
and grid systems to healthcare, bio risk and
climate change. Hence, once MARV™ for
pipelines is fully ready for the pipeline market,
it will be transferred to DNV’s operating units,
and the MARV™ team will move on to the
next phase of MARV™ application, where risk
management and risk prediction is crucial.
WOR LD CLASS
This is an example of what happens when
DNV’s Research and Innovation Materials
Group works with stakeholders and DNV’s
operating units across the globe.
Results of a Bayesian calculation
Tempera-ture
pH
CO2 O2
ID
Lowestpoint
Pig Run
Sand
Flange or Valve
DiameterChange
Bend
T-Piece
SulfidesTempera-
tureHydro-carbon
Oxygen
Pipe inclanation
OilDensity Oil
Viscosity
OilVelocity
Water Cut
Fe2+
CorrosionRate
Acidic/alkiline...
PassiveFilm
CorrosionUnde...
Wall Lossin...
FlawDepth
BurstingPress...
Pipe Section
Fa...
+
......
...
S...
Pr...
Deposits
WaxDeposit
Asphalat.D...
OD SigmaPipewallThick...
OperatingPres...
FlawLength
Last FlawDepth
Galvanic Cell
LocalizedInhibi...
Oil type
Water Wetting
Water Layer Prob...
Sand Deposits
Total Velocity
GeometryCha...
GAB
Protection from...
Shelter Source ofEnergy
SRBpresence
GAnB
SRBConditions
SRBMIC
Microbio-logical...
FavourableEnvi...
Protection from...
Erosion
InhibitedCorros...
Wall Lossfrom...
LocalizedCorr...
...
CorrosionInhibi...
Chlorides
Slug Flow
H2S
OIL & GAS FRONTIERS > CUTTING EDGE 15
Steinar is a Principal Specialist and lead within fracture mechanics including brittle and ductile fracture analyses and fatigue crack growth analyses. He has worked in the Mate-rials Laboratory since beginning at DNV in 2001. Steinar’s work also involves FE analyses, materials testing and probabilistic analyses. Work has focused on pipelines, but fracture evaluations are also undertaken for various components in pressure vessels, ship structures, jack-ups, valves, shackles, mooring sockets, processing plants and wind turbines. Additional work has focused on projects related to technology qualifi-cation and component testing. Steinar has worked on several suc-cessful and significant Joint Industry Projects.
Before joining DNV, Steinar worked at ABB Offshore Systems AS with mechanical design. He holds a Mechanical Engineering degree from the Norwegian University of Science and Technology (NTNU).
Submarine pipeline systems, Fracture mechanics analysis, ECA, DNV-OS-F101, JIP, Joint industry project, Oil & gas industry pipelines, Pipeline weld analysis, Pipeline structural reliability-based methodology, Recommended Practice, Verification
A BIT OF BACKGROUND
The need for this work arose from what some
considered unnecessarily conservative weld
defect acceptance criteria, but also because
some of the assessment procedures used are
not in full accordance with DNV-OS-F101. In
most cases, it is believed that the current DNV-
OS-F101 assessment procedure is unnecessarily
conservative and that a reliability-based
approach would reduce costs due to fewer
repairs of weld defects, less intervention work
and easier verification of ECAs by third parties.
In order to develop a reliability-based fracture
mechanics assessment approach, the accuracy
of fracture mechanics analyses itself had to be
significantly improved, in particular for strain-
based loading. A reliability based fracture
mechanics approach will ensure more consistent
results from different ECA providers and make
it easier to verify the safety and reliability of
other assessment procedures on an ongoing
basis.
ABOUT THE PROJECT
DNV staff in fracture mechanics and structural
expertise worked on the idea of improving the
current simplified fracture limit state specified
in DNV-OS-F101, which is a “worst case” deter-
ministic approach, for several years. In 2012,
the background work, a detailed description
for a Joint Industry Project was prepared. The
JIP will result in continued evaluations in the
field, using the methodology developed for
performing reliability-based fracture mechan-
ics analyses. “The goal now is to get the word
out to potential sponsors about DNV’s inten-
tion to update the deterministic fracture limit
state with a reliability-based methodology,”
states Steinar Bjerke, Project Manager.
INDUSTRY IMPORTANCE
Fracture mechanics analyses are increasingly
important in monitoring and assessing the
integrity of submarine pipeline systems due to
more complex and challenging pipeline pro-
jects. The intention is to develop a separate
DNV Recommended Practice which may be
revised more frequently than the DNV pipeline
standard. Several research programs related to
fracture mechanics analyses are ongoing in the
industry, and this JIP will also use these results
in developing future standards.
Submarine pipeline systems in the oil & gas industry are designed and constructed to
withstand remarkable natural conditions. Their safety and reliability are assured in part
by meeting standards for pipeline girth welds that include fracture mechanics analysis
(ECA). Current standards are based on calculations of the crack driving force using ‘worst
case’ inputs. In this project, DNV has started to develop a reliability-based, probabilistic
approach – one that will enable operators to determine a correct and uniform safety
level for the fracture limit state, considering the design life of pipeline girth welds.
SUBMARINE PIPELINE SYSTEMS
PROJECT MANAGERS TEINAR LINDBERG BJERKE
16 CUTTING EDGE > OIL & GAS FRONTIERS
© D
NV
/Nin
a E.
Ran
gøy
Life of a Well, Well integrity, Well lifecycle, Well information management, Ontology Based Data Access, Linked Data
BACKGROUND
Operators are required to ensure the integrity
of their oil & gas (O&G) wells for authorities,
shareholders and the society at large. Yet, direct
inspection of most aspects of an O&G well is
not feasible. Well integrity is managed with a
host of data sources, including design basis,
manufacturing records, and the operational
history of safety barriers. Excellent information
management is thus vital to securing sufficient
lifetime integrity.
BETTER INFORMATION FOR BETTER
CONTROL
Life of a Well was one of three tightly integrated
projects aimed at creating a Next Generation
Well Integrity solution. The approach was to
pull together a suite of information models and
technologies into a single system, and apply it to
the problem.
DNV is developing the Life of a Well (LoW)
system for cradle-to-grave O&G well informa-
tion management, with initial application to
well safety barriers and offshore incidents. The
system utilizes a vendor agnostic Linked Data
architecture, enabling stakeholders to achieve a
new level of collaboration. LoW combines three
services: storage of well information in non-
proprietary form to ensure the information can
live as long as the O&G facilities themselves; a
knowledge base and encyclopedia of the O&G
domain; and data search and retrieval.
SUPPORTS INTEGRATION
LoW is designed to complement, not replace,
existing well information systems. The data
store is structured using an open and extend-
able information model – an ontology. This
brings an integrated view to the enterprise
portfolio of well IT applications and databases,
and facilitates stepwise incorporation of data
from external sources, across the full range
required for well management. The LoW
knowledge base function builds on the Sky-
brary™ aviation incident system, developed
and operated by DNV for EUROCONTROL,
to provide a user-friendly portal tailored to
domain expert tasks and workflows.
INTERFACE FOR THE FUTURE
DNV is continuing the work on information
management for safer and more efficient O&G
wells. The approach demonstrated in the LoW
prototype is relevant to O&G stakeholders inter-
nationally: operators, service providers, and
public bodies. The potential reach of LoW is
also substantial. One evident opportunity lies
in integrating international well registries with
incident databases, making the information
available in a non-proprietary interface. The
enterprise also stands to benefit from synchro-
nizing core business objects among well appli-
cations and work processes.
The overall challenge here was oil well integrity. How could we improve the safety and
efficiency of a well, across its long lifecycle, from planning to abandonment? Reliable
information is crucial to well integrity management, but the industry faces problems in
lack of data consistency, lack of standardization and high complexity. It was time to take
a hard look at the life of a well, and to find a better way to handle the many different
kinds of information about oil wells. DNV is now in the process of solving the information
management problem.
Johan is a Dr. Philos. and a Principal Specialist in the Information Risk Management unit. He is part of a team dedicated to bringing ontolo-gies and Linked Data to the energy industry, primarily oil & gas.
Johan works at the interface between research and industry, drawing on his background in applied philosophical logic as well as hands-on experience with enterprise databases. His current engagements include master data integration and governance for major Engineering, Procurement, and Construction (EPC) clients; and introducing cutting-edge ontology based data access (OBDA) methods to oil & gas exploration. Johan has contributed to several Joint Industry Projects, including Integrated Opera-
tions in the High North (IOHN, 2008–2012) and the on-going Optique JIP, Scalable End-user Access to Big Data (EU FP7 program, 2012–2016).
THE LIFE OF A WELL
PROJECT MANAGERJ OHAN WILHELM KLÜWER
Ignition
Corrosion
Fatigue
Barriers
Reservoir
TIMETopics addressed over a lifecycle
OIL & GAS FRONTIERS > CUTTING EDGE 17
Peter is the Region UK Business Development leader for Advisory Services. He has broad experience in the application of hazard identifica-tion, as well as risk analysis, technical and business risk assessment, safety engineering and regulatory compli-ance assurance services. These are provided primarily in the upstream and allied marine sector globally.
Peter has managed significant multi-disciplinary and long term projects covering various DNV services, includ-ing SHE, ARM, ERM and TQ services.
Peter is routinely involved in new technology, the application of new techniques and the export of such techniques to new market sectors, including aviation, rail, downstream, and marine sectors. His work has extended to all geographical areas, with paper presentations highlighting the application of new services to different sectors and regions.
Peter has been with DNV for over 18 years.
Quantitative risk assessment, Real-time risk assessment, Offshore oil installations, Upstream industry risk management, Safer Operations Upstream Landscaping (SOUL), Demonstration project, Joint Industry Project, JIP
THE SOUL PROJECT
Everyday, operators of offshore oil installations
collect data associated with risk, data difficult
for them to use quickly and readily. The indus-
try relies on static Quantitative Risk Assessments
(QRAs) and models that remain uninfluenced
by daily risk changes. Furthermore, the time-
frame needed to build and run conventional
QRA prevents its use in real time decision-
making. Wouldn’t it be useful to provide actual
risk information in real time that could be used
to address operational risk-based
decisionmaking?
This was the aim of the SOUL Project, a dem-
onstration project to show how diverse risk-
related data can be used to yield live risk infor-
mation. SOUL represents not just an evolution
in operational risk management thinking but
clears a completely new road. That is Land-
scaping, Safer Operations Upstream Land-
scaping (SOUL). It also aims to be something
that is ‘virtual’ – it works subtly in the back-
ground without the need for costly integration
or interference with operator running demands.
It also interfaces with existing industry data
management systems.
HELPING ONE TODAY
As a demonstration project, DNV aimed to
develop a prototype model, learning from the
leadership and innovation work. Project scope
was limited to an exploration drilling case,
suitable for the upstream oil & gas exploration
and production market. Using a Bayesian
model, it allows the illustration of many factors,
including primary and secondary well control
systems, developments leading to blowout,
human competence, risk modeling, safety
culture, and trends.
AND MANY TOMORROW
The upstream market is already extremely
keen on this type of application, with both
academia and leading operators wanting to
move toward real-time risk assessments. That’s
‘facing facts’ in the daily life of this industry,
which remains under constant operational
change in a post-blowout era. DNV is planning
to expand on SOUL, with a full range of major
accident hazard scenarios and a future Joint
Industry Project.
Offshore oil installations generally rely on static risk models and assessments. While these
may help identify general risk-trend areas and responses, they are not operating in real
time to reduce the operational potential for hazards and accidents as an outgrowth of
current data. Yet, offshore installations are collecting data associated with actual risk
position, often difficult to interpret and use in-place, in real time. This demonstration
project did just that, interfacing with existing industry data management systems to
create real-time risk assessment information key to industry operators.
MEASURING RISK IN REAL TIME
PROJECT MANAGERP ETER BOYLE
PRIMARY
WELL
CONTROL
FAILURE
DRILL
FLOOR
BLOWOUT
SECONDARY
WELL
CONTROL
FAILURE
FACTORS AFFECTING
PRIMARY WELL
CONTROL FAILURE –
PHYSICAL, PEOPLE, PROCESS
FACTORS AFFECTING
SECONDARY WELL
CONTROL FAILURE –
PHYSICAL, PEOPLE, PROCESS
MANAGEMENT
SYSTEM
FACTORS
SAFETY CRITICAL
ELEMENT STATUS
ACHIEVEMENT
AGAINST
PERFORMANCE
STANDARDS
ACCIDENT AND
INCIDENT
HISTORY
MAINTENANCE
STATUS
ETC...
18 CUTTING EDGE > OIL & GAS FRONTIERS
ANDRÉ BRETON
“The imaginary is what tends to become real.”
OIL & GAS FRONTIERS > CUTTING EDGE 19
Peder Andreas works as Approval Engineer and Offshore Surveyor in the section for Drilling and Well Intervention. He is working with approval of drilling systems and advanced drilling technologies in addition to component certification of drilling equipment. He also over-sees various floating rigs for compli-ance with DNV Class. He is Project Manager for a novel modular drilling system for compliance to NORSOK. Peder Andreas started at DNV in 2009, and worked for a time as a NB Surveyor at Hyundai Heavy Industries in Ulsan, South Korea, and as a UiO/SiO Surveyor in Rio de Janeiro, Brazil.
Peder Andreas holds a Mechanical Engineer degree from the Norwegian University of Science and Technology (NTNU).
BOP, Oil drilling industry, Blow-out prevention systems, Offshore oil drilling, Deep water oil drilling, Automated drilling operations, JIP, Joint industry project, Well control
THE HUMAN FACTOR
BOP systems have received substantial negative
publicity, partly due to the general misconcep-
tion that the BOP is an emergency solution: if
all else fails, the BOP will shut in the well. The
truth is that current design criteria for BOPs
do not address ‘blowout stoppage’ scenarios.
We cannot assume that a BOP designed accord-
ing to current standards is, in fact, able to stop
a blowout. Like all systems, the BOP is doing
its job when used in accordance with its opera-
tional limitations and specifications. This means
that the BOP must be activated before a blow-
out occurs – in order to prevent it.
This DNV project evaluated how human inter-
vention can best be supported by automation
in a well control event, in order to ensure that
correct actions are taken in time.
MAN VS. MACHINE
BOP functions have remained unaltered for
decades; designs are extrapolated to compen-
sate for more extreme conditions. In deep
waters, well ‘kicks’ can be difficult to detect.
A highly compressed undetected gas kick that
enters the marine drilling riser can expand
and replace large volumes of mud as it moves
up in the marine riser, causing considerable
problems.
Automated drilling operations are expected to
increase dramatically in coming years, in part,
to allow for entering reservoirs with narrower
pressure margins, thus setting a higher bar for
responsible well shut-in.
Automated BOP functions are considered pos-
sible and believed to increase safety. However,
the efficiency and reliability of such a system
will depend upon early and accurate kick
detection.
SMART AUTOMATION
In this project, a fully automated BOP system
was contemplated, one monitoring the drilling
process and coming into play when needed.
Ideally, the BOP control system should auto-
matically close off the wellbore when manual
activation fails or is ignored after kick detec-
tion. If correct actions are taken manually, the
system remains in a monitoring/advising state
and activates no functions.
The overall goal is to close off the wellbore
before the well is flowing at considerable rates,
when rams are moving towards closed position.
To ensure this system works as planned, among
the factors that must be identified for each
operational scenario are which parameters
shall be governing for identifying a kick, defin-
ing a kick quantitatively and knowing which
actions are correct in any given situation. To
do this, the various operational scenarios must
be analysed to identify correct well control
actions from the governing well control proce-
dure. Based on the above, the system will iden-
tify a well control incident and inform the
driller as to what has been detected, what is the
recommended action and when the system will
automatically execute this action.
The time limit for response will depend on kick
magnitude and development rate, based on
real-time feedback from the well. The person
responsible for well control remains responsi-
ble and obliged to manually activate the BOP
as before if a kick is detected. However, in
addition, the system can activate functions if
manual activation is not performed for any
reason, in this way, becoming a backup resource.
The driller would have the opportunity to
bypass the automated action if it were consid-
ered a low risk situation.
The quality and reliability of the information
flow is imperative. The automated system will
depend on real-time data from both topside
and from the well, including bottom-hole
pressure, temperature and flow rates.
TIME FOR TEAMWORK
This project was run by DNV Offshore
Classification in close cooperation with the
Subsea consultancy environment. Team mem-
bers considered all BOP operational factors,
presenting the results as an overall philosophy
for automated BOP activation. The results will
In the offshore oil drilling industry, the shutting in of a well can only be initiated by human
action. This project asked, is this an adequate and robust approach for the future? As drilling
operations become more complex, and well control becomes more challenging, DNV decided
to take a closer look at current well control systems and philosophies. This project analyzed
BOP automation potential, creating a framework for moving forward.
PROJECT MANAGERPEDER ANDREAS VASSET
BLOW-OUT PREVENTION (BOP) MEETS AUTOMATION
20 CUTTING EDGE > OIL & GAS FRONTIERS
now be presented to key industry players with
the intention to take this work further, through
a Joint Industry Project.
This work demonstrates DNV’s leadership role
– with foresight, customer focus and a results
orientation.
© S
canpix
Macondo showed the importance of the BOP. The project seeks to give a direction to the industry by initiating the developments of a system that is believed to increase the overall safety of drilling operations.
OIL & GAS FRONTIERS > CUTTING EDGE 21
Solveig has worked in DNV Risk Management Solutions since 2010. Her work has focused on safety barrier management, management systems and emergency prepared-ness analysis for customers in the offshore oil & gas industry.
Solveig joined DNV Maritime Solu-tions in 2009, working on projects related to safety culture, risk man-agement, strategy development and business performance management for customers in the maritime industry.
Solveig has a Master of Science degree in Marine Technology from the Norwegian University of Science and Technology (NTNU) in Trond-heim, taken in 2009. She specializes in marine systems, focusing on risk analysis and safety management, and wrote her thesis in cooperation with DNV.
MARInd, Major accident risk indicators, Performance indicators, Human Reliability Analysis, Safety barrier management, Barrier management, Bow-tie analysis
THE WAY THINGS WERE
What is it that reduces the risk of major acci-
dents in the oil & gas industry? When the
Macondo field accident occurred in the Gulf
of Mexico, plenty of understanding existed as
to ‘occupational accident’ risk. Systems and
procedures were in place. Yet, there was little
comprehensive understanding in the industry
of the organizational and operational factors
that could play a part in a major accident. DNV
was already strong on the technical aspects, so
getting organizational and operational factors
in place was an extension of prior research
tools and techniques. DNV decided to act.
For major accident indicators to be applicable
for risk-informed decisionmaking, it was
important that their effects on major accident
risk be thoroughly analyzed.
PROJECT ACTIVITY
A multi-disciplinary team of DNV experts have
been working alongside industry representa-
tives to take major accident risk indicators to
the next level.
The objective of this project was to specify a
DNV point of view on established indicators
for major accident risk, and to develop a frame-
work for identifying such indicators. The frame-
work has been developed using barrier man-
agement and human reliability analysis. The
results were presented internally and exter-
nally in 2012, and have already had a positive
impact on ongoing barrier management
projects.
THE RIGHT RISK RECIPE
“Our goal was to find key performance indica-
tors linked to the actual risk, which are verifi-
able and actionable,” states Project Manager,
Solveig Walsøe Pettersen. “That is the reason
for using the barrier/bow-tie model as a basis
for the indicator framework. As Solveig states,
“The industry is going to learn that it is not just
‘defining indicators’ that reduce the risk of a
major accident, but – of primary importance
– the risk-informed decisions made by staff.”
An oil drilling rig in the Gulf of Mexico blows up. Why did this have to happen? In this
project, DNV staff dissected the elements at play in a major accident risk scenario – in
order to better understand how to effectively reduce the risk of major accidents in oil & gas
industry field operations. Safety barrier management and human reliability analysis were
used to go that one step further, identifying key performance indicators in complex risk
scenarios. The framework developed may help the industry reduce risk and prevent a repeat
scenario.
PROJECT MANAGERSOLVEIG PETTERSEN
MAJOR ACCIDENT RISK REVISITED
In the Gulf of Mexico more than 50 miles southeast of Venice on Louisiana’s tip shows the Deepwater Horizon oil rig burning in April 21, 2010.
22 CUTTING EDGE > OIL & GAS FRONTIERS
© A
P/ G
eral
d H
erber
t
Arctic operations, Propulsion systems, Marine propulsion, Environmental footprint, Ice loads, Joint Industry Project, JIP
ARCTIC LIMITS
DNV and others are “setting the Arctic stand-
ard”. Arctic operations are an emerging market,
and limited knowledge, data and experience are
shaping much of the current situation.
Identifying gaps in knowledge, practice and
regulatory regimes is essential for all. Shaping
marine Arctic development at an early stage
will assure risk levels within acceptable limits,
and contribute to safeguarding life, property
and the environment.
PROJECT ACTIVITY
DNV’s ‘SafeArc’ project is a cross-disciplinary
project that is developing and documenting
improved knowledge. Ice loads acting on pod-
ded propulsion systems that operate in Arctic
waters are in focus. In addition, the project is
assessing solutions for efficiency in Arctic opera-
tions and studying precisely how to reduce the
‘environmental footprint’ generated by marine
activities there.
The project team consists of Rolls Royce Marine
Propulsion and DNV, and is financed by the
Norwegian Research Council with a budget of
12 million NOK. Work is involving the world’s
leading ice navigators and vessel operators.
Top class knowledge is being generated within
this field and, as a result of this project, knowl-
edge closely linked to national and interna-
tional regulatory regimes applicable to Arctic
operations will be pushed into the future.
State of the art reports were developed to bring
the project up to speed on the latest develop-
ments in the field. This was followed by full-
scale testing of ice loads on rimtruster, con-
ducted at production facilities in Ulsteinvik,
Norway. Several outreach initiatives have also
been carried out, from the Norwegian University
of Science and Technology (NTNU) to industry
symposiums.
CROSS-DISCIPLINARY SUCCESS
Already, it is clear that safe and efficient Arctic
operations result from a cross disciplinary
approach, with sustainability objectives. This
includes not compromising on environmental,
human or economic issues, and identifying
linkages and key risk drivers. The outcomes
of the project already go beyond immediate
improvements to Arctic ops, although they will
do that also: creating knowledge that will be
utilized to develop better designs for podded
propulsion systems, and that will feed into the
calibration of class requirements, and new
offerings in advisory services to clients.
It seems like a ‘last frontier’: Arctic operations hold a promise of great potential for devel-
opment while also challenging everything we think we know about competence, technol-
ogy and cooperating with nature. We and others are getting “ready for the cold rush”
with a safe path forward in all related operations. This DNV project is studying ice loads
on propulsion systems operating in Arctic waters. The team’s cross-disciplinary approach
is helping to secure acceptable levels of risk and safety knowledge within this high-risk
environment, pushing knowledge into the future, the Arctic.
Knut Espen has, since 2009, worked as a Project Manager in DNV Techni-cal Advisory on issues related to shipping, the Arctic and climate change. Knut Espen started his career at DNV in 1999 when writing his master’s thesis on the environ-mental aspects of ship demolition, continuing as a Superintendent for several Norwegian shipowners.
Knut Espen has vast experience from the Arctic, having conducted several expeditions to the area, including wintering with a sailboat in the Northwest Passage and in north Greenland from 2003 to 2005.
Besides working for DNV, Knut Espen runs Fotspor AS, a company that facilitates scientific fieldwork related to climate change and economic development in the Arctic. Knut Espen has published two books on the Arctic.
Knut Espen has an MSc degree in Naval Architecture and Marine Engineering.
PROJECT MANAGERK NUT ESPEN SOLBERG
SAFE OPERATIONS IN THE ARCTIC FRONTIER
© S
afeA
rc/K
nut
Espen
Solb
erg
OIL & GAS FRONTIERS > CUTTING EDGE 23
Ali is the Head of the Pipeline and Subsea section in the London Approval Centre, and also leads pipeline activities in the DNV region UK. Before joining the Approval Centre, Ali led the Pipeline and Integrity Assurance section at London Solutions.
Ali is a Principal Integrity Engineer with a specific interest in pipeline design verification, engineering critical assessment, Fitness for services and residual stress. He has published and presented more than 30 technical papers in international conferences and is a member of the British Standards BS7910 and R6 sub-committees on residual stress.
Before joining DNV, Ali worked at The Welding Institute (TWI) Ltd. in Structural Integrity Technology. He has also worked with British Energy Ltd. as a part-time research contrac-tor. Ali is a Charted Mechanical Engineer with a Ph.D. in Fracture Mechanics.
Onshore pipes, Pipelines, Specifications, Verification, Pipeline support, Recommended Practice
ONSHORE HAZARDS
Onshore pipeline systems present a wide spec-
trum of hazards, often adjacent to public areas.
The industry has recognized an increasing need
to involve an independent verifier to provide
the required level of confidence that their facili-
ties are in compliance with regulatory require-
ments and recognized codes and standards.
RESPONDING TO NEED
DNV responded with a global team of experts
and the new service specification, DNV-DSS-
316. Participation included senior engineers
and stakeholders in Norway, the UK, Singapore,
Australia, Canada and the Netherlands.
The new service specification outlines DNV
recommendations on the scope and depth of
involvement by a verification body for onshore
pipeline systems. This service specification
provides criteria for, and guidance on, verifica-
tion of complete onshore pipeline systems and
the integrity of parts and phases of a pipeline
system. DNV-DSS-316 follows a risk based
approach. The level of verification activity is
differentiated according to the risk. Where the
risk associated with the pipeline element or
process is higher, the level of verification
involvement is greater. Conversely, where the
risk associated with the aspect is lower, the level
of verification activity can be reduced without a
consequent reduction in effectiveness.
TAILORED BENEFITS
DNV-DSS-316 outlines different levels of verifi-
cation involvement, to be selected by the client.
This ensures that the verification body’s scope
is well defined and transparent. Third party
verification of onshore pipelines has the benefit
of providing stakeholders with confidence that
the system’s integrity is assured, and that risks
to personnel and the environment are
reduced.
Additionally, it is good business practice to
subject such critical work to a third-party check
as this minimises the possibility of undetected
error. A Statement of Compliance will be avail-
able, to be issued by DNV, on completion of
each particular project phase, and will be
based on a dedicated verification report.
The production of this service specification is
very welcome in the industry and complements
offshore pipeline Recommended Practices and
specifications produced by DNV earlier, now in
use by operators and pipeline support compa-
nies worldwide. “With close collaboration of
different DNV offices, today we reached
another milestone in providing our unique
verification services to our clients,” states Ali
Sisan, Project Manager.
Historically, onshore pipeline systems have not been subject to independent verification.
However, with changing regulatory environments and industry norms requiring greater
scrutiny, an increased need for pipeline oversight was identified. DNV responded with a
new service specification. This service specification provides criteria and guidance on the
verification of complete onshore pipeline systems, their parts and the phases of their
development and completion.
ONSHORE PIPELINE VERIFICATION ARRIVES
PROJECT MANAGERALI SISAN
© iS
tock
Imag
es
24 CUTTING EDGE > OIL & GAS FRONTIERS
Shale gas, Natural gas, Recommended Practice, Verification, Joint Industry Project, JIP
TOPIC UNDER PRESSURE
Extracting natural gas from shale rock forma-
tions became more feasible as technological
advances occurred in drilling and fracturing.
Fracturing fluids are injected at high pressure
to create fissures in the rock, providing a path
to the well for extraction. Resulting wastewater
and chemical releases present substantial issues
and must be managed properly. Already, shale
gas extraction represents 15 percent of natural
gas production in the U.S. alone, a figure expec-
ted to triple in the next 25 years. Yet, no single
recommended practice has existed. Until now.
FOUNDATIONAL WORK
DNV’s Recommended Practice is based on risk
management principles and industry best prac-
tices and standards. The objective was to form
the foundation for future development of a
globally recognized standard for safe and sus-
tainable shale gas extraction.
The framework was developed over an 18-month
period, and included collaboration with stake-
holders as well as review of existing practices
and guidelines. Many organisations have already
developed recommendations and guidelines.
Yet a complete risk management framework
had not existed.
THE NEW RP
The RP recommends a risk-based approach to
shale operations, including monitoring and
reporting guidelines. Proper points of refer-
ence are established for all stages of extraction
operations. The RP also advises on extensive
baseline surveys prior to the commencement
of shale gas activities, as well as open discussion
with all stakeholders, including the general
public.
Thon explains, “One of the key elements of
the RP is about encouraging transparency – for
example in what chemicals are used, disclosing
accidents or near misses and uncontrolled
emissions. Operators should report to authori-
ties not just from a regulatory point of view but
also to stakeholders from a corporate social
responsibility point of view.”
The RP, DNV-RP-U301 ‘Risk Management of
Shale Gas Developments and Operations,’ is
intended not only as a reference document for
independent assessment or verification; it is
also hoped that it will influence overall aware-
ness of the risks of shale gas activities, and pro-
vide a basis for identifying risk management
interventions throughout – in the application
of processes, tools and methods. It also com-
piles the references to existing standards
impacting the shale gas extraction operation,
identifies management principles which should
be in place, and analyzes the nature of related
risk identification and mitigation activities.
RECOMMENDATIONS FOR RISK MANAGEMENT OF SHALE GAS
Steinar is currently Project Director at DNV Risk Management Solutions. Since late 2011, he worked as Pro-ject Manager on the development of the Recommended Practice for Risk Management of Shale Gas Activities. Steinar joined DNV in 1974 and has had an extensive career, including several years as a manager and direc-tor, with eleven years of international experience. His technical competence areas are within offshore classification and verification, structural strength analysis and the evaluation of offshore structures. Steinar recently led a three-year project for the European Commission on knowledge manage-ment in the field of Carbon Capture and Storage (CCS).
Steinar holds a Master of Science degree from the Norwegian Univer-sity of Science and Technology (NTNU) in Trondheim.
The foundation for the future development of a globally recognized standard for safe
and sustainable shale gas extraction has been built using risk management principles.
DNV launched its Recommended Practice (RP) for the entire life cycle of shale gas extraction
in 2012.
PROJECT MANAGERSTEINAR THON
DNV’S SHALE GAS RECOMMENDED PRACTICE FOCUSES ON:
■n Management systems
■n Safety, health, and the environment
■n Well integrity
■n Management of water and energy
■n Infrastructure and logistics
■n Public engagement
■n Stakeholder communication
■n Permitting
OIL & GAS FRONTIERS > CUTTING EDGE 25
Jingyue is currently a Senior Researcher on IT programs in DNV R&I with a specific interest in soft-ware verification and validation. Jingyue joined DNV in 2011 and, since 2002, has been conducting research on empirical software engineering and studying software process improvement and software quality assurance, in particular.
Jingyue has vast experience as a researcher from the Norwegian University of Science and Technology (NTNU), the University College of London, and the University of Washing ton. He also worked as an Associate Professor at NTNU in 2008–2009. He has more than 40 scientific publications in software engineering journals and at inter-national conferences, and received the “Best Paper Award” from the 4th ACM/IEEE International Sympo-sium on Empirical Software Engineer-ing and Measure ment in 2010.
Jingyue holds a Doctor of Philosophy degree from NTNU (2006).
CatDrill, Oil drilling, Offshore oil rigs, Integrated software systems, ISDS, Cat D oil rigs, Semi-submersible rigs, Operational scenarios, Software system rules, Offshore rules, Joint Industry Project, JIP
CAT D TERRITORY
On the Norwegian continental shelf (NCS), a
new oil rig was needed, the kind that could
manoeuvre about, inspecting mature oil fields
for untapped resources, working in well drill-
ing and well completion processes – under-
water.
The Cat D is a semi-submersible rig that can
operate at water depths up to 1,300 metres and
drill wells down to 8,500 metres. It is tailor-
made for mid-water depth segments on the
NCS, and is planned for eventual use in deep
water, in high pressure, high temperature
(HPHT) environments, and in the Arctic. As
many software intensive control systems from
different suppliers will be installed and inte-
grated on the rig, one of the key challenges is to
verify software quality, system integration and
commissioning.
DNV’S APPROACH
A new offshore rule, OS-D203, Integrated
Software Dependent Systems (ISDS), is geared
to the Cat D to help ensure the delivery and
integration of the systems with high opera-
tional reliability. Documented operational
scenarios contribute to reducing integration
costs and time during the new building phase,
and increase safety during operations.
PUSHING THE PROJECT ENVELOPE
Creating realistic operational scenarios is tech-
nically difficult and complex work. DNV’s
Research and Innovation staff worked in close
coordination with the ISDS software team,
creating a “handle drift off operational sce-
nario” example based on the technical specifi-
cations and expected operations of the“Cat D”
drilling rig. The ‘OpS’ example and template
have been presented to and reviewed by engi-
neers of rig owner, Songa Offshore, and yard
owner, Daewoo Shipbuilding & Marine
Engineering Co., Ltd., DSME.
As a result of this work, owners, operations,
engineers, integrators and suppliers working
on the Cat D are getting a better understand-
ing of the OpS concept. Additional critical
OpS scenarios are now being developed, fol-
lowing DNV’s example and template, and a
new rig by Fred. Olsen Energy will use the new
rule to class a new build. The knowledge and
expertise developed by DNV is also going
beyond the Cat D, to assist other customers
with advisory service contracts.
As oil becomes more scarce and offshore exploration pushes forward, innovative new
equipment and the systems to protect it are coming into place. In the case of the ‘Cat D’
oil rig, operational scenarios were to be a part of this. However, operational scenarios
are difficult to develop and assess. DNV has now created examples to assist our clients.
This work helps ensure that integrated software dependent systems (ISDS) deliver high
operational reliability in remarkable new circumstances.
PROJECT MANAGERJINGYUE LI
AN OFFSHORE OIL RIG FOR THE FUTURE
© S
tato
il.co
m
26 CUTTING EDGE > OIL & GAS FRONTIERS
OIL & GAS FRONTIERS > CUTTING EDGE 2 7
“We may brave human laws, but we cannot resist natural ones.”
JULES VERNE,
20,000 LEAGUES UNDER THE SEA
Wind turbines, Offshore wind turbines, MOUs, Mobile Offshore Units, WTI vessels, Wind turbine installation vessel, Hybrid vessels, Fatigue analysis, Strength analysis
A LITTLE HISTORY
By the end of the year 2000, DNV had fielded
its first request to provide a proposal for classifi-
cation of a vessel that would be dedicated to the
installation of wind turbines offshore. Previously,
small self-elevating units or converted, small
feeder containers could only be partially jacked
up for this task. The new concept was to create a
wind turbine installation vessel, one that would
perform the work done by several units, and
faster. This idea resulted in a hybrid vessel that
included the characteristics of a self-elevating
unit – for operating in the water depth range of
the future wind farms, along with the mobility
of a Dynamic Positioning unit.
This new unit, now named MPI Resolution,
would change the way the Wind industry
worked, along with a pioneering Class
Notation developed by DNV.
FAST FORWARD
As new Wind Turbine Installation Units (WTIs)
came into operation, some typical issues began
to emerge, reoccurring particularly at the design
and manufacturing stages, but also as the result
of years of experience in the field. The WTI
vessel operates in a multitude of conditions,
ranging from harbour loading, either floating
or jacked up, to transit, to operations in jacked
up mode. WTI vessels are exposed to substan-
tial loading. In addition, weather, seabed and
cargo conditions all impact operating limits.
CUTTING EDGE RESULTS
DNV initiated this project to improve the class
requirements for the WTI vessel’s materials,
strength and fatigue, and address the frequent
movement of the vessels. The project unified
the different approval groups with experience
in the design and fabrication of WTI: London,
Høvik and Poland.
The team defined a simplified assessment
approach sufficiently flexible to assess the
vessel during all operational phases. The pro-
posed fatigue assessment methodology pro-
vides a simple way to check the evolution of
fatigue damage considering the actual param-
eters of operation of the unit during the in-
service life. So far, this project’s results have
been incorporated into updates to related
DNV Offshore Standards (OS-J301, OS-C101
and OS-C104). Some tests are ongoing, and
once final results are available, either a
Guidance note or Appendix to OS-J301
will be issued.
Offshore wind turbine installations appear surreal, floating on the surface of the blue
waves. Yet, nothing about their installation or maintenance can be taken for granted.
The vessels that build and maintain them are, equally, design wonders. Wonders that
DNV helped to build from the start.
In this DNV project, staff revisited the design specifications and tolerances for offshore
wind turbine vessels. The in-depth work performed in 2012 has resulted in new, and at
the same time, streamlined classification requirements on materials, fabrication inspection
and structural integrity.
Claudio is a Senior Principal Engineer and Surveyor at the Section for Pipelines, Subsea, Wave and Tidal at DNV UK. He is responsible for the development of the certification process for certification of wave and tidal energy converters. He has also been responsible for approval of the MPI Resolution, the first vessel designed for wind turbine installation, and the MPI Adventure and MPI Discovery, recently delivered.
Before joining DNV UK in 1993, he worked for five years at DNV Brazil with structural analysis, marine warranty and certification of offshore installations.
Claudio is a Structural Engineer (1984) and took an MSc in Dynamic of Structures in 1990. He has exten-sive knowledge of Sesam modeling of jacket structures and FE modeling of fixed and floating structures, and is specialized in certification and classification of fixed and floating structures.
PROJECT MANAGERC LAUDIO BITTENCOURTFERREIRA
OFFSHORE WIND TURBINE VESSELS IMPROVING
MPI Discovery
© D
NV
28 CUTTING EDGE > OIL & GAS FRONTIERS
MOUs, Mobile offshore units, Rule book revision, Jack-ups, Self-elevating ships
DNV’S APPROACH
Providing a service means more than just estab-
lishing rules, correct procedures, clear guid-
ance and information for the service providers
in the field, and an exchange of knowledge
– all are essential elements. Fortunately for the
project, in this case, expertise was not in short
supply, taking advantage of DNV segment
specialists with deep experience in the jack-up
segment.
NEW RULE BOOK, NEW FORMAT
Many technical standards ensure safety and
reliability of results while working at the edge
of the operational and design envelope. This,
however, has a price in the complexity of the
resulting standards. In other words, rules do
not always give the sort of clear guidance that
designers, yards and owners are looking for.
This clear guidance is especially important in
the self-elevating market.
DNV prioritized this area in 2012. To answer the
market’s challenge, the project team decided to
create a new rule book format. The new book
has seven sections which cover the entire class
service concept, from newbuilding design
requirements, component certification and the
survey on the newbuilding site, to the survey in
the operational phase after delivery. Each sec-
tion is based on the renowned DNV offshore
standards, but also explains in detail specific
challenges faced in the jack-up high risk area.
GOING BEYOND THE RULES
“Looking back, the team has had so much
agility – remarkable in the often traditional
and bureaucratic world of classification
societies,” says Michiel van der Geest. “A new
rule book with an innovative format and a
revamped focus service delivery approach –
from scratch, and in a timeframe usually associ-
ated with defining a first business concept.”
It all makes this project a good example of
DNV’s strengths, effective and efficient net-
works bringing people together all over the
world to meet market needs.
Almost 50 percent of the world’s Mobile Offshore Units (MOUs) are self-elevating units or
jack-ups. They deserve attention and focus. For example, when their fixed platforms are in
elevated mode, not all regulations and rules for MOUs apply to them. Then there is the
naturally developed complexity of myriad rules and standards, not all applicable for jack-ups.
This created a clear drive for DNV to define a new jack-up rule book. The new and unique
concept and format chosen meet the need for a balance between detail and overview,
covering each phase of a jack-up’s lifecycle.
Michiel is an Offshore Class Product Manager with a broad background in management of operations and technical and strategical projects. Before joining DNV, he concluded a 13-year career as Lieutenant Com-mander in the Dutch Navy. Beside his operational skills, he achieved Master’s degrees in Electrical Engi-neering, Business Administration and Project Management. In his latest role, he managed a technol-ogy development program in state-of-the-art radar technology.
Since 2006, Michiel has built up Classification experience as a nauti-cal safety approval engineer/sur-veyor with assignments in Norway and Korea. Later, he took this experi-ence further as a Classification Product Manager, from 2010, with a primary focus on the Offshore Segment. In this role, he combines his background and project approach to develop the DNV Offshore Class Service further to cover business needs and technical developments.
JACK-UPS: REWRITING USERS’ RULE EXPERIENCE
PROJECT MANAGERM ICHIEL VAN DER GEEST
© D
NV
OIL & GAS FRONTIERS > CUTTING EDGE 29
Not Hot, Cold repair, FPSOs, Floating structures, Oil & gas industry service vessels, Corrosion, Corrosion repair, Recommended Practice
Jan is a Principal Engineer in the Materials Laboratory at Høvik, Norway. He is the coordinator of DNV’s global Materials Technology Leadership initiative, whose aim is to develop Cutting Edge competence within materials technology.
He also has responsibility for the development of cold repair methods, in particular bonded patch methods. He has edited two books on adhesive bonding and published more than 25 articles. He is a member of the Techni-cal Committee ISO/TC 67, Petroleum, petrochemical and natural gas indus-tries, Subcommittee SC 6.
Jan worked previously with non-metallic materials and coatings, NDT and repair of composites. He was Project Manager for two major projects on adhesive bonding in shipbuilding, and was Research Programme Director for strategic materials research at DNV. Jan holds a Doctor of Philosophy in Materials from the University of Southampton, UK (1997).
PROJECT MANAGERJAN WEITZENBÖCK
WHEN HOT REPAIRS SHOULD GO COLD
THE INDUSTRY PICTURE
An FPSO is a floating production, storage and
offloading unit used by the offshore oil & gas
industry to process hydrocarbons and store oil.
FPSOs are being utilised beyond their initial
design life, resulting in increased corrosion and
degradation. When repairs are needed, the
traditional tools involve burning, welding and
grinding, all potential fire or explosion sources.
This requires safety measures including degas-
sing of tanks and shutting down of oil opera-
tions during repair work. Associated industry
losses in revenue are estimated to be in the
millions of U.S. dollars per day. Cold repair has
become a go-to strategy, but one which required
substantial testing and detailed examination.
A PROJECT WITH PURPOSE
To address repair of FPSO and tanker structures,
DNV initiated, as early as 2001, a series of Joint
Industry Projects. Cold repair in situ of struc-
tures that are difficult to access or remove was
the goal. Cold repair would be economically
efficient, and could be used, in some cases, to
postpone emergency repairs until planned
maintenance or refitting.
Cold repair thus became a new structural
repair method that could change maintenance
strategies, allowing some repairs to be delayed
until planned maintenance events. While not a
‘silver bullet,’ it has proven effective, in particu-
lar, for repair of corrosion damage, and for
specified timeframes.
PLANNING TO PERFECTION
The project’s primary deliverable is the
Recommended Practice, DNV-RP-C301 –
Design, Fabrication, Operation and Qualification
of Bonded Repair of Steel Structures, published in
April, 2012. The bulk of the development work
was carried out by staff at the DNV Material Lab
in Høvik, Norway. Key results were presented
at industry meetings in Houston and
Stavanger, Norway.
The past decade has been used to develop this
repair method for structural applications. We
are now starting to see commercial applications,
and expect steady growth of its use in the future. © D
NV
Corrosion pits or cracks
(I)
(II)
Bounded patch
30 CUTTING EDGE > OIL & GAS FRONTIERS
“Cold repairs” improve the reliability of operations for floating structures and vessels as
repairs can be carried out without disrupting operations. In 2012, DNV released a new
guideline on cold repairs, the primary result of a multi-year series of projects which exam-
ined the potential for making cold repairs to floating structures.
OIL & GAS FRONTIERS > CUTTING EDGE 31
SALVADOR DALÍ
“Intelligence without ambition
is a bird without wings.”
Although marine transportation is considered energy efficient compared to other transportation alternatives, shipping is now facing a new reality. Media, politicians and the public at large are increasingly focusing on environmental issues. Carbon emissions that contribute to global warming are particularly in the spotlight.
Vessels ordered today may still be in operation beyond 2040.
MARITIME & CLASS
image size: 540x210mm
32 CUTTING EDGE > MARITIME & CLASS
MARITIME & CLASSPredicting the future is a challenging task, and prioritizing which competence to focus on is equally difficult. That said, a few topics will certainly continue to dominate the shipping agenda in the coming years, including a continuous cost focus, energy efficient ship operations, and environmental performance. The industry has already come a long way within these areas, well assisted by existing and upcoming regulations, but the pace of innovation towards a cost efficient shipping operation will continue at high speed. Alternative fuels – LNG, biofuel, fuel cells – are of particular interest. At the same time, we will not remove our focus from our longstanding goal: safer shipping.
MARITIME & CLASS > CUTTING EDGE 3 3
Bungas, LNG, LNG bunkering, Bunkering systems, Bunkering barges, Bunker stations, Bunkering risk assessment, LNG risk assessment, Joint Industry Project, JIP
HISTORICAL NOTES
According to the IGC-Code, only LNG carriers
can utilize LNG boil-off gas in the machinery
space as fuel. Since 2000, a few LNG-fuelled
vessels not covered by the Code have come
into service, with national administration
permission and in compliance with DNV class
rules. Due to missing safety requirements, the
IGF-Code (Gas as Ship Fuel) was proposed to
the IMO in 2004. The goal is an international
standard for natural gas-fuelled engine installa-
tions. Interim guidelines adopted in 2009 give
criteria for arranging and installing LNG fueled
machinery to achieve a level of integrity equiv-
alent in safety, reliability and dependability to
conventional oil-fuelled machinery. The IMO
is currently developing the IGF Code, with a
first revision planned for 2014. DNV and oth-
ers are working to contribute their expertise
and developed knowledge in that effort.
WANTED: STANDARDS
When the BUNGAS Joint Industry Project (JIP)
was begun, there was no common industry
standard for equipment and procedures for
the use of LNG as fuel. Even now, there are
still a limited number of bunkering infrastruc-
ture arrangements available worldwide. The
development of standards was therefore seen
as both timely and important. The work was
started with the aim to develop sound equip-
ment, ship designs and to develop accurate
risk assessments to evaluate design alternatives.
A number of projects for LNG refuelling sys-
tem development are planned or ongoing in
Europe. Nevertheless, a general approach cov-
ering the technical, legislative, organizational
challenges in a way so as to be able to transfer
the results within the EU in general is missing.
This project is developing an overall technical
basis for the design and operation of safe bun-
ker stations onboard gas fuelled commercial
vessels, and is addressing the related bunker
supply vessels. It is developing the baseline for
safe and competitive gas refuelling in European
ports in a way that the results can be applied to
all types of gas fuelled ships, and it includes the
requirements for a basic design of a bunker
vessel with a suitable transfer system.
PROJECT DETAILS
Work has focused on five main areas:
1.■ Bunkering requirements: setting the base-
line requirements for an LNG bunker sys-
tem and identifying how these differ from
more traditional marine bunkering
arrangements;
2.■ The design of a bunker ship: developing a
concept for a bunker vessel which can be
used to bunker a range of different ship
types and sizes, with a focus on safety and
bunkering equipment;
3.■■The design of a bunker station: designing
a bunker station including best suitable
placement of control and safety systems
on the receiving ship;
4.■■Risk assessment of the bunkering operations,
including estimating leak probabilities and
modelling the consequences; and
5.■■Training needs for bunkering: requirements
for crews on both vessels.
DNV’S ROLE
DNV’s role, to date, has been in developing
state of the art bunkering procedures based
on current experience gathered from existing
ships in operation in Norway. DNV has also
modelled leak probabilities from LNG bunker-
ing as well as their potential consequences, by
use of the DNV softwares, LEAK and PHAST.
In addition, the consortium members have
developed a concept for a bunker barge and
a bunker station on a passenger vessel.
RESULTS IN 2012
“The main accomplishment from our side was
the modeling of gas dispersion and potential
fire scenarios given a leakage of LNG or gas
during bunkering operations,” stated project
staff. “We modeled the receiving vessel and
bunker barge in KFX software and modeled
This project’s acronym, BUNGAS, stems from its objective, to address issues related to bun-
kering of liquefied natural gas (LNG) when used as fuel on ships. Answering some of the
related challenges of LNG as fuel were part of the challenge, as LNG becomes a more
common alternative to traditional petroleum fuels. DNV contributed critical LNG bunker-
ing data and risk assessment materials to this wide-ranging project effort during 2012.
Peter is currently the Discipline Leader Operational Safety and Risk in Maritime Advisory. His position includes extensive quantitative and qualitative risk assessments related to maritime operations and ship-ping, including the Formal Safety Assessment (FSA) approach devel-oped by IMO. The group is responsi-ble for the development of compe-tence and methodology in the field, as well as building a local market and supporting the global organisation. Peter has been with DNV for more than ten years and has extensive experience from work with risk assessment for worldwide maritime customers. In addition, he has con-ducted energy efficiency studies for various European customers and has spent years studying how to reduce emissions-to-air from ships including the related barriers to implementa-tion. Peter holds an MSc degree in Naval Architecture, received in 2000.
BUNKERING LNG AS FUEL FOR SHIPS
PROJECT MANAGERPETER NYEGAARD HOFFMANN
34 CUTTING EDGE > MARITIME & CLASS
different leak rates, gas/LNG pressures and
weather conditions in order to see what the
potential consequences would be.”
The results of this JIP will now be used as input
to the ongoing development of industry stand-
ards and best practices for LNG bunkering.
There are very many initiatives ongoing in the
industry to develop rules and standards for
bunkering of gas and the use of LNG as fuel
for ships, and the aim is to contribute to overall
knowledge in the industry. DNV’s role includes
continuation of a full risk assessment, which
will include further study of the probability
for leaks occurring and gas igniting, the aim
for work continuing in 2013.
Ecore bunker ship, a very large ore carrier (VLOC) concept designed to lower fuel costs and improve loading efficiency.
© D
NV
/Eco
re d
esig
n c
once
ot
FACTS REGARDING THE BUNGAS PROJECT:
■n A three-year JIP with the main objective to develop a bunkering system for
refueling of commercial vessels with LNG including the development of
technical and organizational solutions with focus on ship to ship bunkering.
■n The main partners are: Germanischer Lloyd (Lead), AIDA Cruises, Meyer Werft,
MAN and DNV
■n Partly funded by German and Norwegian governments
■n Total budget: 1.9 million Euro
■n DNV budget: 200,000 Euro with main focus on risk assessment
MARITIME & CLASS > CUTTING EDGE 35
Liquefied natural gas, LNG, Natural gas, Bunkering, JIP, Joint industry project, LNG feasibility study
PA R TNERS FOR PROGRESS
DNV led this Joint Industry Project on the
feasibility of LNG bunkering in Australian
ports. The partners on the JIP included the
Australian Maritime Safety Authority (AMSA),
BOC Limited (Linde Group), Farstad Shipping
Pty. Ltd., Ports Australia, Rolls-Royce Marine
AS, SVITZER Australia, Swire Pacific Offshore
Operations (Pte) Ltd., Teekay Shipping
(Australia) Pty. Ltd. and Woodside Energy Ltd.
Together, they conducted a detailed study
designed to produce practical results. DNV
and all parties are now optimistic about the
future of LNG as maritime fuel in Australia
after having screened the possibilities to estab-
lish LNG bunkering in ten Australian ports.
STUDY RESULTS
This study recommends that additional techni-
cal guidelines be established, and encourages a
clearer regulatory framework, along with finan-
cial incentives to kick-start development. When
establishing LNG bunkering, the critical busi-
ness phase occurs in the first 2–4 years of oper-
ation, when the LNG suppliers rely on a few
foresightful ship owners willing to be industry
forerunners. After some years of successful
operation, a second wave of ships is expected
to enter the market, which will reduce suppli-
ers’ uncertainty and reinforce the business
case. The JIP focused specifically on the initial
phase, and created roadmaps for necessary
action for the most rapid establishment of
LNG bunkering in shortlisted ports. An acceler-
ated approach could open up LNG bunkering
in Australia by 2016.
Key conclusions of the JIP were (1) that there
is an attractive payback period, from the addi-
tional investments required for LNG fuelled
shipping to the reality, and (2) that there were
no significant legal restrictions hindering
development of LNG bunkering in Australia.
POSITIVE POTENTIAL
DNV Maritime Country Manager, Tim Holt,
states “We have been impressed with the inter-
est and commitment shown by the Australian
shipping industry in investigating LNG as a
cleaner and locally available marine fuel.”
JIP Project Manager, Henning Mohn adds,
“Increasing LNG production along with new
international regulations boosts interest in
LNG fuelled shipping; this could actually, to
some extent, cause ships to switch from fuel-
ling with imported fuel to using domestically
produced LNG.”
The use of Liquefied Natural Gas (LNG) as a fuel for ships is seen as one of an array of
options to address the future environmental and commercial challenges in the shipping
industry. With a proper combination of LNG storage and bunkering solutions, including
tank trucks, permanent tanks and barges in selected and destination ports, efficient LNG
bunkering can be established. In this 2012 project, DNV experts and DNV’s partners deter-
mined that LNG bunkering in Australian ports is feasible. The study presents details and
timeframes for development.
Henning now heads the Green Shipping Advisory group in Singa-pore following the merger of Tech-nical Advisory with the maritime portion of DNV Clean Technology, where he was Head of Section.
Henning has been with DNV since 2008 and is knowledgable in ser-vices related energy efficiency, LNG as fuel, emissions, ballast water purification and maritime technology. He has experience from running large LNG bunkering studies in Europe, Asia and Australia, with more than 17 years of experience from environmental engineering, and has until recently been the main advisor to a dominant green shipping funding scheme in Norway.
Before DNV, Henning worked at Scanship Environmental AS as Chief Marketing Officer, the Norwegian Institute for Water Research as a Research Manager, and at Miljø-Kjemi as Project Manager. Henning has MSc degrees in Environmental Engineering (1995) and Civil Engi-neering (1993).
LNG BUNKERING IN AUSTRALIAN PORTS FEASIBLE
PROJECT MANAGERHENNING MOHN
ECA
ECA
SOx – ECA
ECA
ECA
NOx and SOx – ECA
Existing ECA areas. Source: IMO.
36 CUTTING EDGE > MARITIME & CLASS
MARITIME & CLASS > CUTTING EDGE 37
“Our lives begin to end the day we become silent about things that matter.”
MARTIN LUTHER KING, JR.
LNG TEU, LNG, Liquefied natural gas, LNG feasibility study, JIP, Joint industry project, Container vessel market, Baltic Sea feeder market, Emission control area, ECA, Pollution control requirements
POLLUTION CONTROL MEETS
THE MARKET
Reducing pollution is the subject of new ship-
ping regulations. Emission targets adopted by
the International Maritime Organization are
affecting the maritime industry in a series of
stages, requiring reductions in the emission of
nitrogen oxides and sulphur oxides, unburnt
hydrocarbons, and particulate matter as well
as greenhouse gases.
Emission Control Areas (ECAs), such as the
Baltic Sea market area, already have stricter
requirements regarding emission targets than
global standards. Starting in 2015, the maxi-
mum sulphur content of fuel oil is limited to
0.1% SOx for vessels operating in ECAs.
LNG is being explored as one possible approach
to meeting these needs. In 2011, container ship
owners and operators were asked about the
future of Baltic feeders. The feedback showed
the majority believed that the container feeder
size would increase compared to the fleet today,
‘newbuildings’ would have to replace existing
fleet and LNG as fuel would become an impor-
tant fuel type for the Baltic trade.
THE FUTURE IN FOCUS
DNV worked with partners, Shanghai Merchant
Ship Design & Research Institute, CSSC (SDARI)
and MAN Diesel & Turbo SE to develop a
1,900TEU gas fuelled Baltic feeder. The result
is a feasibility study evaluating 2-stroke versus
4-stroke dual fuel engine options, integration
with MAN dual fuel engines, and design evalu-
ation of the LNG tank and safety layout of the
fuel gas supply system.
The resulting model LNG-as-fuel design mini-
mizes hazardous areas and potential risks to
the safety of the ship, personnel and equipment,
while the economic analysis demonstrates the
feasibility of LNG as fuel in the Baltic container
feeder market area.
This JIP demonstrates a promising path ahead
for the realization of much-needed shipping
innovation in the search for efficient and effec-
tive pollution control responses, while also
illustrating LNG’s particular applicability to
the Baltic Sea market area.
We know that shipping transportation is polluting. New standards are impacting the industry,
challenging them to respond with innovative solutions. The use of liquefied natural gas
(LNG) as fuel is being studied for use. This Joint Industry Project (JIP) examined the feasibility
of using LNG fuel on container vessels, and involved a case study of the Baltic Sea market
area. A limited cost-benefit analysis was also performed. The results show the viability of
LNG as a potential solution particularly suited to this short sea shipping container market.
Pål has since 2012 been working as DNV’s Business Development Man-ager in Shanghai for the pre-contract and marketing department. He started working for DNV in 1998 in the Hull Approval section as Hull Responsible Approval Engineer, where he was PMA for the world’s largest cruise ship, Oasis of the Seas.
In 2009, he joined the Container Lift program. He worked for Seaspan, a major container ship owner, in Vancouver, Canada, focusing on operational challenges with a focus on fuel-saving initiatives. Returning to DNV, he became Project Manager for implementation of the Container Lift program. Further, he has been part of various development projects for container ships, including the Quantum 6000 and 9000, in addi-tion to being Project Manager for “Ecore,” an large, eco-friendly ore carrier.
Pål is a Principal Engineer in DNV Maritime Advisory, and holds a Master of Science degree from the University of Glasgow, with a focus on Naval Architecture, from 1998.
PROJECT MANAGERPÅL WOLD
LNG CASE STUDY IN BALTIC CONTAINER MARKET
Annual fuel and exhaust cleaning cost [MUSD] (reference oil price + oil linked gas price)
Vessels in the Baltic 2011
Mi
ff2-stroke diesel 2-stroke diesel + scrubber 2-stroke Dual Fuel 4-stroke Dual Fuel
10
8
6
4
2
0
HFO MDO LNG Scrubber
ff
Dry cargo
Miscellaneous
Pass/Ferry
Tanker
Container
Bulker
Roro
Offshore
Reefer
Combination
38 CUTTING EDGE > MARITIME & CLASS
Gas carriers, Offshore oil & gas industry, Gas tank structural requirements, Gas carrier requirements, Independent tank types, Classification notes, Structural integrity of tanks, Strength analysis of LNG carriers, Joint Industry Project, JIP
NEW CLASSIFICATION NOTES
The structural reliability of LNG tanks is of
primary importance for the safety of gas carri-
ers and vessels using gas as fuel. In 2012, DNV
finalized a set of new Classification Notes for
Strength Analysis of independent tanks Types
A, B and C. Independent tanks are defined in
the IGC-Code as self supporting structures
which do not form part of the ship’s hull. The
documents are expected to be officially intro-
duced in June, 2013.
SLOSHING MEASUREMENTS
This JIP project continues to measure sloshing
onboard an LNG IMO. It is measuring the
structural response in the load carrying insula-
tion of the membrane type LNG containment
system to improve our understanding of the
nature and effect of sloshing impacts in LNG
tanks. The sloshing impact measurement sys-
tem has been fully operational since 2010.
However, collection of suitably large measure-
ment samples to enable evaluation of statistical
parameters and meaningful comparison of
statistical parameters between application and
experiment is a time consuming task. The main
activities in 2012 included tests to better under-
stand the relationship between measured struc-
tural response and impact pressure in the tank,
which is complicated by the need to replicate
the cryogenic temperature conditions in the
tank.
NEW NEEDS MET
DNV has classed vessels carrying LNG tank
types for decades, but the acceptable strength
analyses procedures have, so far, not been
described in detail in official documents. This
market segment has been relatively small, with
a few competent designers and with a close
group of DNV engineers handling approvals.
However, with the growth of the gas carrier
segment, new designers entering the field, the
introduction of new tank designs and the need
to distribute approval work globally, it has
become increasingly important to formalize
this to ensure uniform handling of class
approval.
■n 2013-082 Classification Notes no 30.12
(new) Strength analysis of LNG carriers
with independent Type A prismatic tanks
■n 2013-083 Classification Notes no 30.13
(new) Strength analysis of LNG carriers
with independent Type B prismatic tanks
■n 2013-084 Classification Notes no. 30.14
(new) Strength analysis of independent
Type C Tanks.
Increasing interest in using liquefied natural gas (LNG) has led to a boom in the market for
ships carrying LNG, and a significant drive for development of new containment systems for
carriage and storage. DNV has, for decades, developed competence, standards and guide-
lines to support and facilitate industry development in this segment. In 2012, efforts included
a continuation of a JIP for measurements of sloshing impacts in the cargo tanks of a mem-
brane type LNG carrier, and the completion of Classification Notes for strength analyses of
independent type cargo tanks for carriage and storage of liquefied gases at sea.
Tom currently works for Maritime Advisory as a Project Manager for internal R&D projects, Joint Industry Projects (JIPs) and consultancy projects related to the LNG trans-portation and delivery chain. He is also frequently involved in projects involving ultimate strength/progres-sive collapse assessment and colli-sion resistance assessment by non-linear finite element analysis.
Tom has more than 14 years of working experience with a focus on R&D activities and classification of LNG carriers. His major areas of competence are safety of contain-ment systems for transportation of liquefied gas, development of structural design rules, classification procedures and guidelines, ultimate strength and progressive collapse of structures, linear and non-linear finite element analyses of structures, as well as software development. He has also published and presented several technical papers at interna-tional conferences.
Tom holds an MSc degree in Structural Engineering (1998).
PROJECT MANAGERTOM KLUNGSETH ØSTVOLD
GAS CARRIER RESEARCH & DEVELOPMENT
© D
NV
/Nin
a E.
Ran
gøy
MARITIME & CLASS > CUTTING EDGE 39
Arctic shipping, Ice loads, Ice impact assessment, Ice classification rules
Håvard is currently working as a Senior Engineer in the Ship Struc-tures and Concepts section within the DNV Maritime Advisory Unit. His core competence is within buckling and ultimate strength of vessels and offshore structures, ranging from hull approval, rule development and maintenance to R&D, design verifica-tion and technical advisory projects. His main disciplines include Gas Carriers, especially focusing on the design of different types of contain-ment systems, and the design and operational aspects related to ships operating in ice-covered waters.
Håvard holds a Master of Science in Marine Technology from the Norwe-gian University of Science and Tech-nology (NTNU).
UP THERE
Changes in climate and technology are facili-
tating access to the Arctic. This is fuelling great
expectations in the shipping and energy sec-
tors. The ability to safely and securely exploit
oil & gas resources in the Arctic requires ves-
sels and offshore units fit for the conditions.
Ships are increasingly entering ice-bordered
waters.
New developments in the Arctic attract both
experienced and new operators, and vessels
without ice class strengthening. Ships operat-
ing in the Arctic already experience extreme
loads and impacts from heavy ice floes as well
as floating and drifting icebergs/growlers.
These unintentional, accidental impacts are
not explicitly accounted for by the standard ice
classification of ships. Additional hull dimen-
sioning methods may be necessary to provide
the level of structural integrity needed.
BEYOND ‘ICE CLASS’
Ice classes issued by classification societies are
used by the operator to document and stand-
ardize the capability of the vessel for regulatory
and insurance purposes, but are not linked to
the actual operational profile. Both customers
and designers are seeking greater confidence.
Evaluating accident scenarios involving
impacts with heavy ice floes and growlers
means studying the complicated non-linear
structural and material behaviour of both the
hull, the ice growler and their interactions,
considered beyond the scope of standard ice
classification. However, such evaluations will
ensure that structural integrity is maintained.
THE CUTTING EDGE ON ICE
The Cutting Edge on ice is the ice impact
assessment design now developed by this pro-
ject team. While no single defining ice load
modelling approach exists, this project team
has created a guideline that will lead the way.
It provides customers with the latest tools and
procedures to help them document the suit-
ability of their ships consistent with a variety of
potential ice impacts and loads. The guideline
also suggests applicable modelling and analysis
techniques to ensure that all mechanical aspects
of ship-ice collision scenarios are covered. For
more challenging areas, such as ice material
modelling and ice growler/ship hull interac-
tions, directions for beneficial and in-depth
study are suggested.
This work demonstrates DNV’s commitment
to reducing risk while expanding capability –
where and when it matters.
It’s not that ice rules don’t exist. It’s just that they don’t necessarily forecast accidental
impacts with ice. DNV has stepped in. Classification rules addressing hull strength for ice
conditions needed to be linked to actual trade experience. With the work of this project
team, a guideline has been established for the evaluation of such “off-design” ice load
inquiries. The opening of the Arctic continues. DNV is there.
PROJECT MANAGERH Å V A R D NYSETH
ARCTIC SHIPPING: UPDATING ICE LOAD TOOLS
Ice growler impacting a double hull ship side. Computer simula-tions using a non-linear FE model.
40 CUTTING EDGE > MARITIME & CLASS
MARITIME & CLASS > CUTTING EDGE 41
“I believe in the future resolution of these two states, dream and reality, which are seemingly so contradictory,
into a kind of absolute reality, a surreality, if one may so speak.”
ANDRÉ BRETON, MANIFESTOES OF SURREALISM
RULES COME ALIVE
The class rules constitute one of DNV’s major
bodies of knowledge. The new DNV Rule
Framework can revolutionize the way rules are
formulated in the future, as the framework is
capable of expressing rules (read formulas) in
a context making the application and interpre-
tation of the rules transparent to the end user.
When combined with the ease of automatic
execution, this body of knowledge becomes a
living asset.
PROJECT ACTIVITY
DNV worked with specialists with long experi-
ence and deep knowledge of hull structures
and wave loads. The goal was to achieve both
rule transparency and efficient execution of
the rules. The rules are implemented in the
DNV Rule Framework, comprised of a state-
of-the-art rule engine with interface toward
the applications using the rules.
A fundamental component of the DNV Rule
Framework is the ability to represent knowl-
edge in the form of rules and use them to infer
results. The DNV Rule Framework provides a
means for putting rules into a context repre-
sented by a task model. Task models and flow-
charting provide a valuable way of representing
procedural knowledge that naturally comple-
ments rules. Together, these form a framework
for expressing knowledge in a very transparent
way.
The DNV Rule Editor offers a long list of fea-
tures not easily available through traditional
programming:
■n Dynamic changes of the rules are possible
without requiring a new release of
Nauticus™ Hull.
■n Parallel rule computing is made possible.
■n There is a clear interface between applica-
tion and rules.
■n Many applications can use the same
rule-base.
■n Domain experts can implement rules without
having detailed programming skills.
■n Multiple rule sets and rule revisions
are supported.
■n Transparency of implemented rules
is provided.
■n Distributed computing – in the cloud –
is supported.
■n Rules can be managed independent
of programming language.
The work puts DNV in the forefront on
rule development.
IACS (International Association of Classification Societies) is presently harmonizing the
Common Structural Rules for tankers and bulk carriers into one common rule set. DNV
is heavily involved in the development, testing and calibration of the harmonized rules.
The Nauticus™ Hull program is a DNV software application for verifying the strength of
ship structures according DNV and IACS Common Structure Rules. The tool is used by DNV
and external shipyards and designers to verify the design of ships. As ship rules become
more and more computerized, the applied rules also become less transparent to the end
user. In this project, DNV has ‘lifted the veil’ on this dilemma – by creating a new rules
service software, DNV Rule Framework. This comprehensive software development has
been carried out in parallel with the harmonized rule development.
Ove is the Head of the Rule Tech-nology section in DNV Software located at Høvik, Norway. He joined DNV in 1993 as a Software Devel-oper and Software Architect. During the last ten years, he has also been Group Leader and Head of Section with Nauticus Hull as his main responsibility.
Before joining DNV, Ove worked at the software company, Coastdesign Norway, selling hull design and fairing, and stability calculation software, mainly in the Nordic countries. He has also worked on an offshore project at the Sterkoder shipyard in Kristiansund, Norway, where he was responsible for strength calculation and participated in making production drawings.
Ove has a Master of Science degree in Marine Technology from the Norwegian University of Science and Technology (NTNU) (1988).
PROJECT MANAGEROVE AAE
NAUTICUS HULL – CAPTURING ENGINEERING KNOWLEDGE
Start
End
End?
Calculated Bilgeplate requirement
Calculatedplate requirement
Calculated plate requirement
Rounded Sheer
End?
Add results object
Add results object
End?
FalseTrue
True False
BilgePlate
if sloshing
True False
Add results object
Nauticus Hull, Nauticus™ Hull, Rules promulgation, Ship design software, Rule Editor, IACS Harmonized Common Structure Rules (HCSR)
Figure 1: DNV Rule Framework
42 CUTTING EDGE > MARITIME & CLASS
Benchmark, Nauticus Air, Environmental efficiency, MARPOL Annex VI requirements, Emissions, ships, Energy efficiency, ships
EMISSION LIMITS
While the shipping industry is facing increased
international pressure to reduce emissions of
CO2, NOx and SOx, regulatory bodies includ-
ing the EU and International Maritime
Organisation (IMO) will begin enforcing
newer and stricter emission limits.
NAUTICUS AIR™
With the Nauticus AirTM tool, ship operators
and owners register and monitor the environ-
mental and energy efficiency performance of
their ships. Nauticus Air has been adopted by
a number of shipping companies world-wide,
resulting in thousands of reports submitted to
the DNV database, capturing and processing
structured and useful information. Daily report-
ing from ships, common for decades, is now
feedback that gives users of the Nauticus AirTM
tool an effective overview of the vessels’ and
fleet’s energy performance, and a useful meas-
ure for ‘active benchmarking’.
BENCHMARK OF ENVIRONMENTAL
PERFORMANCE
Nauticus AirTM provides a simple user interface
where the ship’s crew enters the daily fuel
consumption, distance travelled and cargo
carried onboard. Additional operational indi-
cators can be recorded. Aggregated data in the
form of trend reports are created, available to
the ship operator through a web access solution,
giving the vessel’s crew as well as onshore staff
an accurate picture of the vessel’s actual emis-
sions to air and operational efficiency. As a
result, captured data can be used to compare
the operational performance of different vessels
in a fleet, or other vessels of similar size and
trading pattern.
BENCHMARKING IMPROVEMENT
As a flexible, low-cost solution for reporting of
air emissions according to defined indicators,
Nauticus AirTM conforms with and supports
international (IMO) standards and guidelines.
The Energy Efficiency Operational Indicator
(EEOI) is calculated from the reported data as
an indicator of the specific vessel’s operational
efficiency. This ensures compliance with the
requirements of IMO’s Ship Energy Efficiency
Management Plan (SEEMP), which became a
MARPOL Annex VI requirement for all ships
as of January, 2013. By continuously monitoring
the EEOI over time, and actively applying the
results for trending purposes, shipping compa-
nies can readily identify improvement targets
and set key performance indicators. That is
called looking into the future.
Per is currently the DNV Maritime Environmental Program Director covering technical and business development projects serving ship-ping community needs with respect to environmental challenges and performance monitoring. Per has worked with environmental issues at DNV since 2007 and, prior to his current position, his work focused on environmental performance, benchmarking and energy management.
From 1985 to 2007, Per worked in DNV Petroleum Services, the last three years as the Managing Director located in Singapore, with global responsibility for business operations including five fuel laboratories. Prior to his career at DNV, he worked 5 years as a Research Scientist at the Centre for Industrial Research (SINTEF) in Norway.
Per holds an MSc degree in Physical Chemistry from NTNU, Norway (1979).
Active monitoring of environmental and fuel efficiency performance in shipping is becom-
ing a requirement in our time. Simple, reliable and verifiable reporting is necessary. The
Nauticus AirTM tool has proved to be a viable solution to fulfill this need, and is a contribu-
tion to the emerging demand for environmental rating schemes, supporting ship opera-
tors in their efforts to reduce fuel bills and optimize operations. In 2012, this DNV project
further developed methods to establish performance baselines for individual ships and to
facilitate benchmarking when comparing performance between ships in a fleet.
PROJECT MANAGERPER HOLMVANG
NAUTICUS AIR – AND ENVIRONMENTAL BENCHMARKING
IN P U T : DAILYNOON REPORTS
DATA CATUREDIN DNV ‘DATA WAREHOUSE’
ANALYZE REPORT
CALCULATEBENCH-
MARKING
CORRECTIMPROVETROUBLE-SHOOTING
DNV ‘Nauticus Air’: Reporting & Monitoring Tool
MARITIME & CLASS > CUTTING EDGE 43
Dag Harald is working in the Machinery – Newbuilding Section at the DNV Approval Center at Høvik, with responsibility for diesel & gas engines. He has worked in this section since 1999, and has been involved in type approval of all kind of engines. He is also responsible for NOx certifi-cation of diesel engines.
Dag Harald has also been the DNV representative in two external projects related to particulate matter (PM), one being the PM-NOx project headed up by Marintek, Trondheim, and the second being the EU-financed Hercules-B project with MAN Diesel and Turbo and Wärtsilä as the main project partners.
Before joining DNV, Dag Harald worked as a Development Engineer for the engine manufacturer, Rolls-Royce, in Bergen, Norway.
PartMatt, Particulate matter, PM pollution, PM emissions, Maritime industry pollution, JIP, Joint Industry Project, Verification
THE SITUATION
Particulate matter is not simply innocuous
pollution; the scope of its danger to health and
the environment is only now being fully recog-
nized. Particulate matter, also known as particle
pollution or PM, is “a complex mixture of
extremely small particles and liquid droplets,”
including a wide number of components, acids
such as nitrates and sulphates, organic chemi-
cals, metals, and soil or dust. These are emitted
directly from many sources – including vehicles,
smokestacks and fires. They also form when
gases are emitted from power plants, industrial
processes and gasoline and diesel engines.
MARITIME’S ROLE
The maritime transport sector is known to
contribute significantly to PM pollution, espe-
cially in coastal areas. While there is not yet
direct regulation of PM emissions from ship-
ping, it is widely recognized that the maritime
sector is one of the biggest contributors to PM
pollution of the atmosphere. Ocean-going ships
are estimated to emit approximately 1.2–1.6
million metric tons of particulate matter with
aerodynamic diameters of 10 µm or less annu-
ally, and this number is expected to increase
in the future as shipping activity increases
worldwide.
THE OBJECTIVE
Particulate matter emission from ships’ diesel
engines is likely to become the next hot environ-
mental topic. By participation in this project,
DNV stays in the forefront of understanding the
principles and mechanisms for formation of
particulates during the combustion phase. It is
vital for the maritime sector to have such com-
petence at its disposal, and DNV will profile this
knowledge externally.
RESEARCH LEADS THE WAY
PM emission data from ships is based on meas-
urements done in accordance with ISO stand-
ards which focus on total particulate mass and
do not differentiate particles by size and number.
A relatively high level of PM leads to a demand
for diluting, while methods used do not specify
an upper limit for the dilution ratio. This can
result in variability in measurement results for
high sulphur marine fuels.
Particulate matter is now being subjected to a
wide array of tests in order to identify not only
the effects of PM, but to find practical measur-
ing equipment, documentation and verification
procedures that demonstrate repeatability.
A wide array of conditions have been tested,
including the effects of PM from various fuel
types, and at different stages of the ignition
and fuel-burning process. PM sampling meth-
ods are also being compared.
Further understanding of PM emission forma-
tion in diesel engines is under study. Fuel char-
acteristics influence the formation of PM emis-
sions. DNV research is working to provide
information needed to advise on fuel blends,
as well as to guide developers and producers
of NOx reduction technology equipment.
RESULTS THAT MATTER
Experience from these tests has demonstrated
the complexity related to these kind of meas-
urements and the potential challenges related
to future, on-board documentation and verifica-
tion of PM/NOx emissions. The Joint Industry
Project work, based at Marintek, Trondheim,
Norway, has been supported by the Norwegian
Research Association and several commercial
companies in combination. DNV has also
funded the project at 900,000 NOK to date.
The results of this research, in the form of
scientific papers and global discussion, are
paving the way to a healthier future for the
marine industry and all living things. The
knowledge gathered will be used by DNV in
providing advisory services to its clients.
Particulate matter, or PM, is one of the consequences of traditional industrial and marine
operations, and has been the subject of inquiry and study in recent times. Research is
resulting in new knowledge about the risks PM presents within the maritime industry,
resulting in further investigative efforts, and regulatory discussion.
DNV is active in this work with original research geared toward assisting the shipping
industry in understanding the effects of PM, and in addressing the maritime industry’s
role in reducing PM.
PROJECT MANAGERDAG HARALD WILLIKSEN
PARTICULATE MATTER – GETTING THE WHOLE PICTURE
44 CUTTING EDGE > MARITIME & CLASS
Nasal Airway
Pharynx
Trachea
Bronchi
Bronchioles
Alveolar ducts
Alveoli
Larynx
Lymph nodes
Vasculature
Alveolus
Blood vessels
0.0
0.2
0.4
0.6
0.8
1.0
0.0001 0.001 0.01 0.1 1 10 100
0.0
0.2
0.4
0.6
0.8
1.0
0.0001 0.001 0.01 0.1 1 10 100
0.0
0.2
0.4
0.6
0.8
1.0
0.0001 0.001 0.01 0.1 1 10 100
NASAL, PHARYNGEAL, LARYNGEAL
TRACHEOBRONCHIAL
ALVEOLAR
Diameter (um)
Diameter (um)
Diameter (um)
Percentage of particle deposition in certain segments of human respiratory system (Oberdörster et al., 2005)
MARITIME & CLASS > CUTTING EDGE 4 5
ABOUT PM
The main components of PM are black carbon (soot), sulfates, nitrates, organic carbon and ash. Additionally, PM can be also divided into primary particles and secondary particles depend-ing on their formation mechanism. In case of diesel engine combustion, primary particles are ones produced in the engine and directly emitted into the ambient air, while secondary particles are formed already in the air mainly by interac-tion among gaseous species in the atmosphere via certain chemical reactions. They are mainly the products of atmospheric transformation of nitrogen oxides and sulfur dioxide produced during diesel fuel combustion. Most of such particles can be found in the fine and ultrafine particle size range.
DNV’S PARTICULATE MATTER RESEARCHERS ARE STUDYING:
■n the nature and type of PM effects on
human health,
■n the methods and means of PM formation,
■n the development of evaluative measurement
techniques, and
■n identification of influences on PM formation
in combination with various systems for NOx
abatement.
Tomas has been with DNV since 1991 and currently works in the DNV Maritime Advisory section on issues concerning machinery energy effi-ciency, exhaust gas cleaning technolo-gies and innovation and technology qualification. Before joining DNV Advisory, Tomas was the Head of Section for Machinery Newbuilding Approval.
Within DNV Research and Innovation, Tomas was the initiator and manager of the Joint Industry Project, “Fellow-SHIP,” which developed and demon-strated fuel cells for maritime appli-cations. This project was selected a top sustainable solution at the United Nations Rio+20 conference in 2012.
Tomas has a Master of Science degree in Marine Technology (1990) from the Norwegian Institute of Technology, Trondheim, and a Master’s degree in Energy Management (2007) from ESCP (Paris) and the Norwegian Business School (BI-Oslo).
SOXAT, SOx, Sulphur dioxide, Pollution control equipment, Scrubbers, Emission control, Exhaust gas cleaning, Qualification of New Technology, DNV-RP-A-203, “Qualification of New Technology”, Fitness for purpose, Confidence review, Recommended Practice
PROJECT MANAGERTOMAS TRONSTAD
A CLOSER LOOK AT SULPHUR SCRUBBERS
FITNESS FOR PURPOSE
Exhaust gas cleaning systems involve new tech-
nology unfamiliar to many in the shipping
industry. That technology should also meet
fitness-for-purpose criteria in a multi-dimen-
sional and multi-party environment. Factors
include novel technology, operational issues,
compliance regimes and local and international
enforcement strategies. The challenge DNV
was given in this project was to respond com-
prehensively to the question, “How can we be
assured that new SOx abatement technology
and systems will work as intended, and with no
surprises?”
PROJECT DESIGN
DNV utilised Recommended Practice A-203,
“Qualification of New Technology,” as a frame-
work for supporting this task. Qualification is
the process of providing evidence that the
technology will function within specified limits
with an acceptable level of confidence. This also
helped establish the right balance between deep
investigations and effective result oriented pro-
cesses. Project scope included three steps:
1.■Define functional requirements, including
criteria such as ‘no downtime’, ‘lifetime
according to specification’, ‘no unacceptable
safety issues’, ‘meeting international require-
ments’, and ‘energy efficiency’;
2.■Identify hazards and develop a plan for
mitigating risks and hazards at all stages
and levels; and
3.■Execute activities considered part of a com-
prehensive technology qualification plan.
Upon completion of step 1, DNV issued a
“Statement of Feasibility”, documenting that
the technology is considered technically feasi-
ble and suited for further development and
qualification. After step 2, DNV issued a “State-
ment of Endorsement”, documenting that the
technology can be proven fit for service,
through the remaining qualification activities.
Following the third step, a Technology
Qualification Report is issued by DNV. Based
on successful execution of the technology
qualification plan, a “Statement of Fitness for
Service” can be issued, affirming that the new
technology is considered fit for service.
MANAGEMENT FOLLOW-UP
The evaluation process used provides several
stage gates at which upper management in the
client’s organisation can readily and easily
follow the project status. A high level system of
traffic light signals was created and applied to
indicate the degree of compliance with the
functional requirements. As a result, manage-
ment can follow-up and have expressed appre-
ciation for this project’s structure, the approach
used, and the usability of the results, going
forward.
The choice of strategy for compliance with upcoming sulphur dioxide (SOx) emission
requirements is causing frustration as owners weigh up the pros and cons of exhaust
cleaning solutions against low sulphur fuels. The SOx cleaning technology is paradoxical.
On the one hand, it is a favourable economic solution. On the other hand, there are
unknown risks that accompany the introduction of new technology. In this project, DNV
was asked to address this conundrum, and created a thorough plan for responding.
Closing the gap: qualification of new technology provides confidence
IMO environmental requirements, MEPC 184(59)
Core Class 1A1 – Safety for personnel and vessel
“Fit for purpose” = No surprises
LEVEL OF ASSURANCE/DETAILS OF REQUIREMENTS
How do you assure new technology’s fitness for purpose?
Requirements from Specification
46 CUTTING EDGE > MARITIME & CLASS
MARITIME & CLASS > CUTTING EDGE 47
“Everything tends to make us believe that there exists a certain point of the mind
at which life and death, the real and the imagined, past and future, the communicable and
the incommunicable, high and low, cease to be perceived as contradictions.”
ANDRÉ BRETON, MANIFESTOES OF SURREALISM
Geir is the current Head of Section of Rotating Machinery, as well as a technical consultant on propulsion and auxiliary machinery.
Geir has had a long career at DNV, starting in 1992, including more than ten years in management positions. His technical experience is within the following areas: machinery drive-train components, power generator-drives and marine propulsion sys-tems; diesel engines and power machinery; shaft dynamics and design; control engineering; proba-bilistic analyses and measurement technology.
Before joining the machinery section in 1997, Geir worked in DNV apply-ing probabilistic methods for mechanical component designs, and developing models for calculating transient dynamics responses in non-linear machinery systems.
Geir holds a Master of Science degree from the Norwegian Univer-sity of Science and Technology (NTNU), taken in 1991.
PROPULSION MACHINERY PERFORMANCE INVESTIGATED
PROJECT MANAGERGEIR DAHLER
Propulsion machinery systems, Propulsion machinery design, Propulsion machinery dynamics, Propeller design, Ship propulsion
BACKGROUND – THE GAP
There is a gap between expected machinery
system performance of new designs and what
is experienced on-board, learned from real
measurements. The gap between theory and
practice is obvious with propulsion machinery.
The reasons are varied: vibrations, uncertainty
in diesel-engine damping and propeller damp-
ing, inertia and excitations, and propeller
forces.
DNV has a substantial amount of data based
on related measurements, made onboard
modern ships during the past decade. This
project aimed to fill in some of those gaps, by
systematically reviewing selected measurements,
comparing the data with design calculations,
and recalculating in selected cases, to identify
how established theory and practices should
be improved.
DATA UNDER REVIEW
Project team members went back, tested the
models, the conventions and past understand-
ings, and re-evaluated the correctness of the
margins of the technology. That revaluation
focused on risk management. “The innovation
element for this project, addressing design
models and reliable operations, was a conse-
quence of the request to save fuel and costs,
and get more efficiency,” states Geir Dahler,
“also thus we are talking about the critical zone
with physical loads, and about problems which
are related to fatigue – they don’t appear sud-
denly but over some years. They may occur
over 20–25 years.”
RESULTS
This project helped identify propulsion failure
boundaries by design element, reducing the
gap between designed performance and actual
performance. Overall, it highlights and devel-
ops DNV’s knowledge of propulsion machinery
performance, and is helping DNV remain in
the technological forefront in this critical area.
This project involved the task of reviewing ship propulsion machinery systems. DNV and
others started to see that modern propulsion systems were not behaving as expected.
Certain propulsion designs were at issue. First, the shaft dynamics were not as expected,
and, second, from a safety perspective, risk of damage and hazard needed reassessment.
DNV took the substantial data at their disposal and reviewed it with an eye towards
assessing new goals: gaining fuel savings, cost reductions, and more efficiency and less
fatigue in the design. The result is a re-evaluation of the state of the technology, and
an updated capacity to assess new designs being developed.
MEGA-TRENDS IN FUEL-SAVING PROPELLER DESIGN
■n Slower speed
■n Larger diameter
■n Less power per diameter
(de-rated engines)
■n Less blade area
■n Shorter blade profile
48 CUTTING EDGE > MARITIME & CLASS
MARITIME & CLASS > CUTTING EDGE 49
“Mistakes are almost always of a sacred nature. Never try to correct them. On the contrary:
rationalize them, understand them thoroughly. After that, it will be possible for you
to sublimate them.”
SALVADOR DALÍ
Arne works as a Principal Engineer in Electrical Systems. He joined DNV in 1996 and has experience as an Approval Engineer for electrical systems and equipment, inspection and testing. Besides being stationed at Høvik, he has been working for two years at DNV’s Shanghai Maritime Service Centre, the last year as the Head of the Section on system/statutory approvals.
Today, Arne is primarily involved in the development of new rules for electrical installations, helpdesk cases, clarifications of requirements and the evaluation of new technology in marine electrical systems.
Before joining DNV, Arne worked for large companies, with five years experience as manager of an electri-cal engineering department. Further, he has experience as a service engi-neer for electrical installations on ships, offshore units, and industrial installations, and as a project engineer for industrial frequency converter drives.
B ENEFITS OF DC POWER
Greener
■n Can combine energy sources to meet new
requirements for fuel efficiency and CO2
reductions and take advantage of new and
renewable energy sources such as fuel cells
and solar
■n More energy efficient and up to 20% more
fuel efficient
Smarter
■n Better dynamic response
■n Reduced maintenance
■n Possibly a quicker fault recovery potential
■n Would optimize fuel consumption at a low
investment cost while increasing engine
lifespan
■n Would reduce the power equipment
weight and ‘footprint’ onboard
Electric, Electric power distribution, ships, DC power distribution systems, Fuel efficiency measures, Pollution control technology
AC VS . D C P O W E R
Traditional power distribution systems on ships
have historically used AC electric current
(alternating current) with a frequency of 50
or 60 Hz. This means that the combustion
engines running the generators must be kept
at a constant speed in order to provide the elec-
trical power system with this fixed frequency.
Not surprisingly, engines operating on con-
stant speed with a low load have low fuel effi-
ciency. Developers have tried to address the
technical hurdles to using DC (direct current),
where diesel engines drive electric generators
with variable speed. Using DC for power distri-
bution enables diesel engines to operate with
variable speed, and can result in reduced fuel
consumption, increased engine efficiency and
provide important pollution control benefits.
PROGRESS BEING MADE
DC power generation system developers are
making headway, and two owners are building
new vessels to DNV class, Myklebusthaug at
Kleven yard, with an ABB-designed DC distri-
bution system, and Østensjø at Astilleros
Gondan yard, with a Siemens-designed system.
Before detailed engineering was begun, DNV
was commissioned to create a Design Verifica-
tion and an Approval In Principle. The pro-
ject objective was to evaluate feasibility and
functional requirements in order for the new
systems to comply with rules and requirements
made for traditional AC power distribution
systems. During the newbuilding phase, DNV
is following development and equipment man-
ufacture as a standard class contract.
SPARRING FOR SOLUTIONS & STANDARDS
While relevant rules and technical requirements
today are based on AC technology, relevant
and comparable functional requirements for
DC systems are being developed. One of the
main challenges has been determining how to
evaluate electric protection functions in DC
power distribution systems. The projects DNV
evaluated have also followed certification and
testing routines, and DNV
has been a good ‘sparring
partner’ for the designers
with respect to safety criti-
cal points.
What if you could reduce ship emissions of pollutants while simultaneously reducing fuel
consumption, increasing engine lifespan, reducing the installation’s space and weight, get
rid of transformers, and lower your investment cost? Sound too good to be true? We are
just talking about the difference between using a traditional AC electric power distribution
system or switching to a DC power distribution system. DNV has worked with two differ-
ent projects to evaluate use of DC power distribution system on ships. The projects have
examined the technical challenges and functional requirements of this emerging technology,
with a view towards developing certification and testing standards.
PROJECT MANAGERARNE FÆREVAAG
POWERING SHIPS WITH DC POWER
Onboard DC Grid: A significant step forward in electric propulsion increasing vessel efficiency up to 20%
50 CUTTING EDGE > MARITIME & CLASS
HybridComp, Hybrid ship design, Dual power ship design, LNG fuel, Liquefied natural gas, Electric battery powered ships, Ferry ship design innovation, Fuel efficient ship design competition, Innovative design, impact on rules, Concept ship, design reviews
DESIGNING THE FUTURE
Ship design is constantly in a state of develop-
ment and improvement, both for fuel efficiency
and pollution emission purposes. Using lique-
fied natural gas (LNG) and electric power bat-
teries offer possible solutions. While a design
approval process looks at the equivalency of
valid related rules, new designs introduce con-
ditions not covered by existing rules, resulting
in a time-consuming and unpredictable process
that increases costs. To the degree that DNV is
able to assist in evaluating new design solutions,
it is doing its customers and the industry a valu-
able service. That is what they did in this project.
APPLYING EXPERTISE
Norway’s Transportation Department held a
competition in 2011 for an energy efficient
ferry, proposed for potential development at
the highway E 39 crossing, Lavik-Oppedal, on
the western coast. DNV initiated a request to
review and analyze two of the concepts
submitted.
One design was for a hybrid solution using an
electric battery pack and LNG-driven generator.
The second concept proposed a pure battery
driven vessel. Project staff included experts in
the System section of DNV Maritime, and DNV
experts in electrical, control, piping and
machinery systems.
The team asked how each design would meet
current requirements for safety and reliable
propulsion, steering and power supply. Project
analysis also revealed what systems and functions
were likely to be questioned, and what explana-
tions and documentation would be sought, in
addition to that required to meet current rules
and requirements.
WIN-WIN RESULTS
The resulting report creates a win-win situation.
The ships’ designers were given the reports for
their information, as would be done in a more
formal Design Review, while DNV experts have
identified potential rule improvements, modi-
fications that can make innovative design both
more predictable and a more attractive option.
Looking forward, new projects to analyze
potential requirement improvements are
already underway.
There are many paths in the forest of innovation. Some cross while others converge.
In the case of this project, both occurred, as DNV reviewed the results of a competition
to improve energy efficiency and reduce emissions from a particular Norwegian auto
ferry crossing’s ships. DNV staff got access to two of the design submissions and created
an analysis of their feasibility, as well as a review of the rules that would be impacted.
Improvements in the designs as well as in the rules were identified. The results also
increase DNV readiness for review of more innovative ship designs.
Svein-Olav is currently Approval Engineer for machinery components, and Deputy Head of Section, work-ing with plan approval for machinery components, covering propeller, shafting, reduction gear, thrusters, compressors and diesel engines, pressure vessels and boilers. His earlier work at DNV included approval work of jacking gear for the offshore sector, and work on two projects as project manager, for revisions of steering gear and thruster require-ments. Earlier work also included quality assessment work for SEATRANS.
Svein-Olav holds a Master of Science degree in Marine Engineering from the Norwegian University of Science and Technology (NTNU), taken in 1994, in addition to having sustantial post-degree technical training.
MAKING HYBRID SHIP DESIGN EASIER
PROJECT MANAGERSVEIN-OLAV HANNEVIK
Fjord1 concept
MARITIME & CLASS > CUTTING EDGE 51
52 CUTTING EDGE
FURTHER ON PMO – OPTIMIZING SYNERGIES IN THE INNOVATION PORTFOLIO
The PMO drives the innovation process
across DNV’s geographic divisions. This
ensures a consistent and transparent
approach for project development through
the entire innovation life cycle, from idea
collection through implementation of pro-
ject results into operational units. Further,
a centrally located PMO optimises the
synergies across various development port-
folios, supporting project managers and
project sponsors, enabling them to focus
on the subject matter, and minimising
their administrative work.
The PMO manages various development
portfolios, ranging from large, centrally
driven, efficiency and work process devel-
opment initiatives, to short term “bottom
up” service and technology development
initiatives like this “Cutting Edge” publica-
tion. Colleagues all over the world contrib-
ute with good project ideas, and projects
are carried out in teams consisting of sub-
ject matter experts assembled from our
global organisation.
CUTTING EDGE – SERVICE AND
TECHNOLOGY DEVELOPMENT
Cutting Edge projects are typically carried
out within one year. The scope should ful-
fill expressed customer needs. Strategic fit
is ensured through an annual development
plan that links DNV strategy to focus areas
for development. Technology Directors
in our geo divisions, as well as the global
Service Directors, are involved in assess-
ment and selection of the best ideas. A
wide range of services and service docu-
ments (rules and standards, guidelines,
recommended practices etc.) is developed
in close cooperation with customers and
other external stakeholders, and run as
Joint Industry Projects focusing on key
industry challenges. Oil and Gas Frontiers
and Maritime and Class were our main
portfolios in 2012.
SEVEN FOCUS AREAS WITHIN
TECHNOLOGY LEADERSHIP
Seven core technical disciplines have been
identified as focus areas for development
of state-of-the-art technology within our
“Technology Leadership” initiative. Project
ideas originate from global networks of
subject matter experts within DNV,
working closely with our clients within
the following fields:
■n Environmental impact and risk
■n Hydrodynamics and advanced
simulations
■n Structural integrity and fatigue
■n Materials, welding technology and
fracture mechanics
■n Risk, reliability and human factors
■n Integrated systems and software
■n Integrated machinery systems
We welcome your feedback, whether it
is to get to know the projects more, or
suggestions for working together to
solve challenges and lead the way for
the industry.
DNV’s ambition is to maintain its role as technology leader within defined technical
disciplines, as well as to provide Cutting Edge services and technologies to clients in
selected markets. That is why we invest heavily in innovation and technology
through a central Project Management Office (PMO) in Governance and Global
Development.
CUTTING EDGE 53
For further information, please contact
■n Tore Torvbråten (Director of operations,
Technology and Services)
■n Evelin Garnaas
(Processes and Communication)
■n Linn Cathrine Sundby
(Technology Leadership)
■n Christina Høysæter
(Cutting Edge)
54 CUTTING EDGE
INDEX
AAgeing units ............................................... 10Arctic operations .................................... 23,40Arctic shipping ............................................ 40Automated drilling operations ..................... 20
BBaltic Sea feeder market .............................. 38Barrier management .................................... 22Bayes theorem analysis ................................ 14Blow-out prevention systems ....................... 20BOP ............................................................ 20Bow-tie analysis .......................................... 22Bunker stations ........................................... 34Bunkering ................................................... 36Bunkering barges ........................................ 34Bunkering risk assessment ........................... 34Bunkering systems ....................................... 34
CCat D oil rigs ............................................... 26Classification notes ..................................... 39Cold repair .................................................. 30Concept ship, design reviews ....................... 51Confidence review ...................................... 46Container vessel market .............................. 38Corrosion .............................................. 12, 30Corrosion monitoring systems ..................... 12Corrosion repair .......................................... 30
DDC power distribution systems .................... 50Deep water oil drilling ................................. 20Demonstration project ................................. 18DNV-OS-F101 “Submarine Pipeline Systems” .................................. 12, 16DNV-RP-A203 “Qualification of New Technology” .................................... 46DNV-RP-F101 “Corroded Pipelines” ............. 12DNV-RP-F116 “Integrity Management of Submarine Pipeline Systems” ................... 12Dual power ship design ............................... 51
EECA ...................................................... 16, 38Electric battery powered ships ..................... 51Electric power distribution, ships.................. 50Emission control .......................................... 46Emission control area .................................. 38Emissions, ships ........................................... 43Energy efficiency, ships ................................ 43Environmental efficiency .............................. 43Environmental footprint............................... 23Exhaust gas cleaning ................................... 46
FFatigue analysis ........................................... 28Ferry ship design innovation ........................ 51Fitness for purpose ...................................... 46Fixed offshore platforms .............................. 10Floating structures ....................................... 30FPSOs ......................................................... 30Fracture mechanics analysis ......................... 16Fuel efficiency measures .............................. 50Fuel efficient ship design competition .......... 51
GGas carrier requirements .............................. 39Gas carriers ................................................. 39Gas tank structural requirements ................. 39
HHuman Reliability Analysis ........................... 22Hybrid ship design ....................................... 51Hybrid vessels .............................................. 28
IIACS Harmonized Common Structure Rules (HCSR) ............................................... 42Ice classification rules .................................. 40Ice impact assessment ................................. 40Ice loads ............................................... 23, 40Independent tank types ............................... 39Innovative design, impact on rules ............... 51Integrated software systems ........................ 26Integrity management ................................. 12ISDS ............................................................ 26
JJack-ups ...................................................... 29JIP ............................................. 16, 20, 36, 38Joint industry project .... 12, 14, 16, 18, 20, 23, 25, 26, 34, 36, 38, 39, 44
KKey performance indicators ......................... 12
L Life extension .............................................. 10Life of a Well (LoW) ..................................... 17Liquefied natural gas ....................... 36, 38, 51LNG ................................................ 34, 36, 38LNG bunkering ............................................ 34LNG feasibility study .............................. 36, 38LNG fuel ..................................................... 51LNG risk assessment .................................... 34
MMajor accident risk indicators ...................... 22Marine propulsion ....................................... 23Maritime industry pollution ......................... 44MARPOL Annex VI requirements .................. 43Mobile Offshore Units ........................... 28, 29MOUs ................................................... 28, 29
CUTTING EDGE 55
NNatural gas ........................................... 25, 36Nauticus™ Air ............................................. 43Nauticus™ Hull ........................................... 42
OOffshore assets ............................................ 10Offshore oil & gas industry .......................... 39Offshore oil drilling ...................................... 20Offshore oil installations .............................. 18Offshore oil rigs ........................................... 26Offshore rules ............................................ 26Offshore wind turbines ................................ 28Oil & gas industry pipelines .......................... 16Oil & gas industry service vessels .................. 30Oil & gas well information management ...... 17Oil & gas well lifecycle ................................. 17Oil drilling ................................................... 26Oil drilling industry ...................................... 20Oil well integrity .......................................... 17Onshore pipes ............................................. 24Ontology-based methods ............................ 17Operational scenarios .................................. 26
PParticulate matter ........................................ 44Performance indicators ................................ 22Pipeline structural reliability-based methodology .............................................. 16Pipeline support .......................................... 24Pipeline weld analysis .................................. 16Pipelines ......................................... 14, 24, 44PM emissions .............................................. 44PM pollution ............................................... 44Pollution control equipment ........................ 46Pollution control requirements ..................... 38Pollution control technology ........................ 50Propeller design........................................... 48Propulsion machinery design ....................... 48Propulsion machinery dynamics ................... 48Propulsion machinery systems ...................... 48Propulsion systems ...................................... 23
QQualification of New Technology ................. 46Quantitative risk assessment ........................ 18
RReal-time risk assessment ............................ 18Recommended Practice . 12, 16, 24, 25, 30, 46Remaining life assessment ........................... 10Risk assessment ........................................... 14Risk modelling ............................................. 14Rule book revision ....................................... 29Rule Editor .................................................. 42Rules promulgation ..................................... 42
SSafer Operations Upstream Landscaping (SOUL) ..................................... 18Safety barrier management ......................... 22Scrubbers .................................................... 46Self-elevating ships ...................................... 29Semantic web technology ............................ 17Semi-submersible rigs .................................. 26Shale gas .................................................... 25Ship design software ................................... 42Ship propulsion ........................................... 48Software system rules .................................. 26SOx ............................................................. 46Specifications .............................................. 24Strength analysis ......................................... 28Strength analysis of LNG carriers .................. 39Structural integrity of tanks ......................... 39Submarine pipeline corrosion ....................... 12Submarine pipeline systems ......................... 16Sulphur dioxide ........................................... 46
UUpstream industry risk management ............ 18
VVerification................................ 16, 24, 25, 44
WWell control ................................................ 20Well information management .................... 17Wind turbine installation vessel ................... 28Wind turbines ............................................. 28WTI vessels .................................................. 28
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