Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
1
Лектор
Basak Kurtoglu
Название лекции
Creating a Worldwide
Unconventional Revolution
Through a Technically Driven
Strategy
Lessons Learned, How NOT to
Do Drilling Automation
Evaluating Completion Options
to Maximize Value
2
Bill Koederitz
3
Dan Gibson
4
Daniel McKinney
Operational Geochemistry at
Work: Integrate or Perish!
5
Daniel Yang
The Value and the Danger of
Complex Reservoir Simulations
6
Dean Rietz
7
Ed Grave
8
Frank Blaskovich
Incorporating Numerical
Simulation Into Your Reserves
Estimation Process: A Practical
Perspective
Verifying Performance and
Capability of New Technology
for Surface and Subsurface
Facilities
Energy Policy: Is it Effective? Is
it Fair?
9
Frans VandenBerg
10
Graham Mensa-Wilmot
11
Ian Walton
12
Isabela Falk
13
Jim Gouveia
14
Johan van Dorp
15
John Macpherson
16
Julmar Shaun Sadicon
Toralde
17
Jürgen Grötsch
Integrated Reservoir Modelling
in Carbonates - Quo Vadis?
18
Kevin Fisher
Integration from Multiple
Disciplines in Horizontal Well
Evaluations to Increase
Production in Organic Rich
Shales
The Digital Oilfield Collaborative Working at
Global Scale
Performance Drilling
Expectations, Perceptions, and
Path Forward – Turning
Challenges Into Opportunities
The Role of Natural Fractures
in Shale Gas Production: What
Does Production Data Tell Us?
Improving Reservoir Simulation
Modeling with Seismic
Attributes
“Fooled by Randomness”
Improving Decision Making
With Limited Data
Does Heavy Oil Recovery
Need Steam?
Automation of the Drilling
System: What has been done,
what is being done, and why it
is important
Deepwater Managed Pressure
Drilling and Well Drillability,
Efficiency and Process Safety
Перевод
Рождение мировой революции
нетрадиционных коллекторов
путем технически
ориентированной стратегии
Работа над ошибками: как не
надо автоматизировать бурение
Оценка параметров
заканчивания для увеличения
прибыли
Геохимия в работе: интегрируй
или проиграешь!
Польза и опасность сложных
гидродинамических
симуляторов
Включение численного
моделирования в процесс
подсчета запасов:
практические аспекты
Проверка производительности и
возможностей новых
технологий в подземном и
наземном обустройстве
Энергетическая политика:
Эффективна ли она?
Справедливо ли это?
Цифровое месторождение:
совместная работа на мировом
уровне
Бурение с забойным
двигателем: ожидания,
представления, пути развития;
превращаем проблемы в
возможности
Роль естественных трещин в
добыче сланцевого газа: о чем
нам говорят данные добычи?
Улучшение гидродинамического
моделирования с помощью
сейсмических атрибутов
"Одураченные случайностью":
оптимизация принятия решений
в условиях недостатка данных
Нужна ли обработка паром
месторождениям с вязкой
нефтью?
Автоматизация систем бурения:
что уже сделано, что делается и
почему это важно
Глубоководное бурение с
управляемым давлением:
применимость, эффективность
и безопасность
Интегрированное
моделирование карбонатов: что
дальше?
Интеграция нескольких
дисциплин в оценке
горизонтальных скважин для
увеличения добычи в сланцах,
богатых органикой
Дисциплина
Reservoir
Description and
Dynamics
Drilling and
Completions
Drilling and
Completions
Reservoir
Description and
Dynamics
Reservoir
Description and
Dynamics
Reservoir
Description and
Dynamics
Projects, Facilities
and Construction
Management and
Information
Management and
Information
Drilling and
Completions
Production and
Operations
Reservoir
Description and
Dynamics
Management and
Information
Reservoir
Description and
Dynamics
Drilling and
Completions
Drilling and
Completions
Reservoir
Description and
Dynamics
Drilling and
Completions
Drilling Dynamics – Five
Fundamental Questions
Answered
The Science and Economics of
Multiphase Flow
How can Microfracturing
Improve Reservoir
Management ?
Applications and Advantages of
Logging-While-Drilling in High
Angle and Horizontal Wells
19
Liam Lines
20
Mack Shippen
21
Mayank Malik
22
Michael Gillen
23
Neal Nagel
24
Pavel Bedrikovetsky
25
Randy Freeborn
Two Vital Secrets for Building
Better Type Wells
26
Reidar B Bratvold
27
Ronald McLeod
Creating Value from
Uncertainty and Flexibility
Human Factors in Barrier
Thinking
28
Segun Jebutu
In-situ Wettability Utilizing Low
Gradient Magnetic Resonance
29
Shrikant Tiwari
Salt Behavior and Drilling
Strategies to Overcome
Challenges in Pre-Salt
Exploratory Wells
30
Steve Mackie
31
Steve Morice
32
Surej Kumar Subbiah
Dry Hole Analysis: What I Have
Learnt About the Upstream Oil
and Gas Industry from My
Failures
Borehole Seismic Solutions for
Integrated Reservoir
Characterization and
Monitoring
Minimize Operational Risk
Using Shared Geomechanical
Earth Model
33
Wally Georgie
Stress Shadows: How and Why
They Can Affect Hydraulic
Fracturing in Both Conventional
and Unconventional Shale
Plays
Prediction and Management of
Fines Migration for Enhanced
Oil & Gas Production
Your Field is Getting Older: Is
your Process Engineering Still
Cost Effective?
Динамика бурения - ответы на
пять фундаментальных
вопросов
Наука и экономика
многофазных потоков
Как микроГРП улучшает
разработку месторождения?
Применение и преимущества
каротажа во время бурения в
наклонно-направленных и
горизонтальных скважинах
Зоны ослабления напряжений:
как и почему они могут повлиять
на ГРП в обычных и
нетрадиционных сланцевых
пластах
Прогноз и управление
миграцией твердой фазы для
интенсификации добычи нефти
и газа
Два важнейших секрета
повышения качества
строительства скважин
Создание стоимости из
неопределенности и гибкости
Барьерное мышление и
человеческий фактор
Определение смачиваемости в
пластовых условиях с
использованием метода
низкоградиентного магнитного
резонанса
Поведение соленосных
пластов и стратегии бурения
для преодоления
трудностей в подсолевых
разведочных скважинах
Анализ сухих скважин: что я
узнал из своих ошибок
Применение скважинной
сейсмики при комплексном
изучении и мониторинге
залежей
Использование
геомеханической модели Земли
для минимизации
операционных рисков
Оценка рентабельности
производственных процессов на
поздних стадиях разработки
Drilling and
Completions
Production and
Operations
Reservoir
Description and
Dynamics
Reservoir
Description and
Dynamics
Drilling and
Completions
Production and
Operations
Management and
Information
Management and
Information
Health, Safety,
Security,
Environment and
Social Responsibility
Reservoir
Description and
Dynamics
Drilling and
Completions
Management and
Information
Reservoir
Description and
Dynamics
Drilling and
Completions
Projects, Facilities
and Construction
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Creating a Worldwide Unconventional Revolution
Through a Technically Driven Strategy
Basak Kurtoglu
Citigroup Investment Bank
Abstract:
Unconventional development propelled the United States to produce more oil than it imports
for the first time in 20 years. Increased production of domestic oil and gas profoundly impacted
economic growth and job creation for the U.S. During this evolution, there was a need to
address environmental regulations and infrastructure requirements in order to access the
sheer volume of resources. Combined with today’s horizontal drilling and hydraulic fracturing
technology, a strategic development plan can be constructed for any country to create an
unconventional energy opportunity. In this lecture, the experience from U.S development is
utilized to provide a fully-integrated workflow for developing shale oil and gas reservoirs from
exploitation to production.
Starting at the nano-scale, we will zoom into the pore structure to understand the storage and
flow paths. Transitioning to the reservoir-scale, well testing and microseismic are utilized to
define the flow capacity and estimate the stimulated volume. Learnings from this subsurface
characterization is used to guide well completion, flowback, and production operations. The
diagnostic methodology specific to each operation can be applied to identify geologically
favorable areas and the best completion practice. As development progresses, opportunities to
improve recovery can be magnified through optimum well spacing and refracturing. As a final
step in the development, determining an appropriate enhanced recovery method is essential to
access the remaining resources. Finally, example development scenarios are provided to
demonstrate how a technically driven strategy is more effective to maximize value and make
the unconventional revolution a global one.
Biography:
Basak Kurtoglu is Vice President in the Global Energy Group of Citigroup Investment Bank.
Prior to Citi, she was Integrated Project Team Manager at Marathon Oil. She has been
instrumental in assimilating multiple disciplines to evaluate and develop unconventional
reservoirs. Kurtoglu earned her BS from Middle East Technical University, and her MS and
PhD in petroleum engineering from Colorado School of Mines. Her numerous publications
range from pore to reservoir scale analyses of unconventional reservoirs with an emphasis on
enhancing oil recovery. She serves on the SPE Forum Series Coordinating Committee and the
SPE Reservoir Description and Dynamics Advisory Committee.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Lessons Learned,
How NOT to Do Drilling Automation
William L. Koederitz
GK Plus Innovations LLC
Abstract:
The uses of automation in the drilling process are expanding and are typically resulting in
improved drilling performance. However, many of these projects struggle in the initial stages,
often trying to overcome a common set of hurdles. Many of these hurdles are not technical
challenges, but instead are related to people issues and the methods for implementing the
solutions. This presentation covers the basics of drilling automation and describes the
problems and solutions that have been found to improve the startup success for drilling
automation.
IDEA TO TAKE AWAY - For automation to be successful, the key users, especially the driller,
must be involved in every step of design and implementation.
Biography:
Bill Koederitz is Chief Technology Officer at GK Plus Innovations. Previously, Bill spent 20
years building real-time applications and drilling automation systems at National Oilwell Varco.
Prior to that, Bill worked as a drilling engineer and as a university researcher. He holds BS, MS
and PhD degrees in Petroleum Engineering from Louisiana State University and is a
Registered Petroleum Engineer in Texas. He has authored or coauthored 25 technical papers
and holds 15 patents.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Evaluating Completion Options to Maximize Value
Dan Gibson
Add Energy - Consulting Services
Abstract:
The Completion Engineer integrates the requirements of a number of other disciplines
(Reservoir, Drilling, Production, etc) to maximize the value of a hydrocarbon resource. This
almost always requires evaluating competing and conflicting factors to determine the 'best'
option for a particular problem. This talk will demonstrate a decision making process that
allows the stakeholders to compare various options in a fair and roboust way. Two real
onshore or offshore examples will be reviewed depending on SPE chapter interest.
Members will take away a new methodology on how to compare competing factors that
influence a completion or well design.
Biography:
Mr. Dan Gibson is a Senior Completions & Well Integrity engineer with over 35 years of
experience. He has worked his way through the oil and gas production stream from Facilities
and Production engineering to Completions in assignments across the USA and around the
world (Gabon, Congo, Egypt, Scotland, Russia, and Australia). This breadth of expereince
comes across in the presentation and his ability to deal with different audiences with a wide
range of challenges.
He has authored or co-authored a number of papers ranging from polymer flood management
to ice mechanics and most recently an innovative ICD system. He is one of the most active
members of SPE Connect where members can readily contact him with questions.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Operational Geochemistry at Work: Integrate or Perish!
Daniel McKinney
Sarawak Shell Berhad
Abstract:
Fluid properties have a profound impact on the exploration and production business;
everything from acreage positioning, subsurface evaluation, reservoir performance, top sides
design, flow assurance, metallurgy, etc. relies heavily on fluid properties. Yet many times,
projects go through decision gates with a general lack of appreciation or awareness of the
intricacies and interdependencies that exist within the petroleum system. In addition, one may
not even have the proper datasets to realize missed opportunities that could impact
significantly on CAPEX and OPEX. Operational Geochemistry is uniquely positioned to bridge
the gap between the various disciplines, both subsurface and surface, to make sure that during
exploration and appraisal campaigns reliable, complete and consistent datasets are obtained,
quality assured and integrated right from the start. It is not a spectator sport where plans are
designed only to be handed off to someone else to execute. Involvement from beginning to
end is crucial. To do this, the objectives need to be clear and an action plan formulated with
sufficient flexibility to react to surprises; and buy-in needs to be sought from all parties far in
advance of well delivery. All the while, technologies should be identified and earmarked for
deployment where warranted. Last but not least, once data gathering commences, the
Operations Geochemist needs to reflect upon the fluid data and properties and identify
outliers. In this presentation, a number of case studies are presented illustrating the workflow
and describing both the prize and the potential lost opportunities.
Biography:
I graduated in 1992 and 1998 with a B.S. in Chemistry and a Ph.D. in Material Science and
Engineering from The Pennsylvania State University. I joined Shell shortly thereafter and have
spent 17 years in Houston, New Orleans, and, now, Malaysia providing Geochemistry and
formation testing solutions. I am Shell’s Subject Matter Expert (SME) for Operations
Geochemistry, and I was one of the founding members of Shell’s Fluid Evaluation and
Sampling Technologies (FEAST) team. I have contributed to a number of manuscripts, oral
presentations, Special Interest Groups (SIGs), as well as posters at SPE, SPWLA, and
Organic Geochemistry Conferences.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
The Value and the Danger of Complex Reservoir Simulations
Daniel Yang
Shell Canada Ltd.
Abstract:
The weakness of reservoir simulations is the lack of quantity and quality of the required input;
their strength is the ability to vary one parameter at a time. Therefore, reservoir simulations are
an appropriate tool to evaluate relative uncertainty but absolute forecasts can be misleading,
leading to poor business decisions. As recovery processes increase in complexity, the impact
of such decisions may have a major impact on the project viability. A responsible use of
reservoir simulations is discussed, addressing both technical users and decision makers. The
danger of creating a false confidence in forecasts and the value of simulating complex
processes are demonstrated with examples. This is a call for the return of the reservoir
engineer who is in control of the simulations and not controlled by them, and the decision
maker who appreciates a black & white graph of a forecast with realistic uncertainties over a 3D hologram in colour.
Biography:
Daniel Yang is Petroleum Advisor at Shell Canada. Holding a PhD in Geophysics from the
Technical University of Berlin, Germany, he dedicated 15 years of his oil-industry career to
Enhanced Oil Recovery methods, focussing on thermal recovery and originating from 10 years
of research in geothermal energy. Daniel worked at Shell International, Canadian Natural
Resources Ltd. and Laricina Energy Ltd. He holds two patents, was recognized as Subject
Matter Expert in Shell, has over 20 publications, recently received a SPE Best Paper Award,
and was a guest lecturer at universities in Germany, U.S.A. and Canada.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Incorporating Numerical Simulation Into Your
Reserves Estimation Process: A Practical Perspective
Dean Rietz
Ryder Scott Company Petroleum Consultants
Abstract:
Reservoir simulation is a sophisticated technique of forecasting future recoverable
volumes and production rates that is becoming commonplace in the management
and development of oil and gas reservoirs, small and large. Calculation and
estimation of reserves continues to be a necessary process to properly assess the
value and manage the development of an oil and gas producer’s assets. These
methods of analysis, while generally done for different purposes, require knowledge
and expertise by the analyst (typically a reservoir engineer) to arrive at meaningful
and reliable results. Increasingly, the simulation tool is being incorporated into the
reserves process. However, as with any reservoir engineering technique, certain
precautions must be taken when relying on reservoir simulation as the means for
estimating reserves. This discussion highlights some of the important facets one
should consider when applying numerical simulation methods to use for, or
augment, reserves estimates. The main take away will be an appreciation for the
areas to focus on to arrive at meaningful and defendable estimates of reserves that
are based on reservoir models.
Biography:
Dean C. Rietz, P.E., President and member of the board of directors at Ryder Scott
Company, has over 30 years of diverse experience in evaluating oil and gas
properties, including more than 25 years applying numerical modeling approaches to
these evaluations. Prior to his current position, he managed the Ryder Scott
Reservoir Simulation Group for approximately 15 years. Before joining Ryder Scott
in 1995, Rietz worked at Chevron, Gruy, and Intera. He received a B.S.P.E. degree
from the University of Oklahoma and an M.S.P.E. degree from the University of
Houston. His past teaching experience includes in-house material balance schools
at Chevron and Eclipse user courses at Intera. Currently, Rietz teaches a two-day
SPE simulation course and is an adjunct professor of reservoir simulation at the
University of Houston. Rietz has published various papers related to reservoir
modeling, including its application to reserves reporting. Rietz is a registered
professional engineer in Texas and serves on the Petroleum Engineering Advisory
Board for the University of Houston.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Verifying Performance and Capability of New Technology for
Surface and Subsurface Facilities
Ed Grave
ExxonMobil Upstream Research Company
Abstract:
As we have seen with the advent of the shale oil revolution in the United States, the development of new technology
plays an important role in the oil and gas industry. It’s an enabler in reducing capital costs, simplifying production and
increasing capacity of new or existing facilities. It can make a marginal project into a profitable development.
Progressing technology, while dealing with significant risk, is a challenge that can be overcome through a technology
qualification process. A Technology Qualification Program (TQP) provides a means to identifying the risks and taking
the correct steps to mitigate it; not avoid it.
This lecture summarizes the required steps involved in qualifying technology and how to keep track of technology
development through the Technology Readiness Level (TRL) ranking system. In addition, some of the pitfalls in
executing a TQP program are identified and discussed with emphasis on both component and system testing.
Examples are given to illustrate the danger in taking shortcuts when executing the qualification plan.
Data from a recent subsea separation qualification program is presented comparing test results between CFDs, model
fluid and actual crude testing at operating conditions. Knowing the limitations of the tools and testing system selected
is an important step in closing the gaps identified in the TQP program.
The TRL has evolved at a faster pace and has become more acceptable in the oil and gas industry then the TQP.
Nonetheless, continued standardization of both the TQL and TRL is still necessary in order to reduce overall cost of
developing technology and allow faster implementation.
Biography:
Ed Grave graduated from New Jersey Institute of Technology with a Master of Science in 1982. Ed started his career
at Lummus working on a number of petrochemical projects, in which in gravitated towards mass transfer and
separations. He later joined Mobil Research & Development Company in 1990 as a mass transfer specialist. Today
Ed is ExxonMobil’s Upstream Senior Technical Advisor for Fractionation & Separation at ExxonMobil Upstream
Research Company in Spring, TX. His team is responsible for research, design, and troubleshooting, for all
fractionating & separation systems for the entire ExxonMobil Upstream organization.
Ed is recognized for his expertise and as a leader within ExxonMobil in advancing new technology. He also led the
effort in designing and qualifying separation system for ultra-deep water, making ExxonMobil ready to meet their future
needs.
He initiated and is presently guiding the joint industry Separations Technology Research (STAR) Program on
qualifying separation equipment as technical chairman. He also served as vice-chair at SPE’s Separation Technology
Technical Section (STTS).
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Energy Policy: Is it Effective? Is it Fair?
Frank Blaskovich
Blaskovich Services, Inc.
Abstract:
Developing sound energy policies is difficult under the best circumstances. There is a delicate
balance between government's need for revenue, modern society's need for energy and the
producer's need for profitability to exploit resources. Many factors can affect the results for all
interested parties. Good policies require an appreciation for the interactions among oilfield
development and operations, costs and prices, government taxes and regulations and many
other factors that are often difficult to define accurately.
We live in a complex world that acts like a system with many interconnected components.
Humans are ill equipped to understand its behavior. We instinctively focus on short term, local
issues and simple cause and effect rather than the bigger picture. This reduces the likelihood
that we can design effective policies that will work well over the long term for all stakeholders.
There are no easy solutions in complex systems. We developed an approach using system
models and regret analysis to find flexible and resilient tax policies, in spite of uncertainties,
that would provide all parties with fair, profitable solutions – even though none might achieve
their maximum goals. It can also measure the relative benefits of existing energy policies and,
potentially, help to improve them.
These challenges will only become harder in the future and more important for the energy
industry. Now is the time to pursue new ways of thinking to solve these problems.
Biography:
Frank Blaskovich is Vice-President of Blaskovich Services, Inc. in Northern California. He
received his B.S. in aerospace engineering from the University of Notre Dame. He has more
than 40 years of experience in reservoir engineering and simulation, software development,
environmental modeling, and policy analysis. He has worked on energy issues around the
world for the largest multi-national energy companies, government agencies and major
consulting firms. He has published numerous papers on reservoir simulation and energy
policy analysis available in the SPE literature and elsewhere. His work and research activities
over the last decade have focused on developing improved energy policies that can benefit all
stakeholders fairly.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
The Digital Oilfield - Collaborative Working at Global Scale
Frans van den Berg
Shell
Abstract:
Collaborative Working helps assets to operate more efficiently and as one team, resulting in
higher production, less cost, lower HSE exposure and higher morale.
Shell has pursued the Digital Oilfield for the last ten years, under the heading of Smart Fields.
Collaborative Work Environments (CWEs) were implemented in the majority of assets, live
environments now cover over 50% of Shell’s production.
The presentation will provide an overview of current Collaborative Work Environments. It will
show examples of CWEs in different types of assets, and of the business value achieved. The
large scale implementation was achieved through a structured deployment programme, taking
assets and projects through a standard design, implementation and embedding approach.
To embed and sustain the new ways of working, a focus on the people aspects and change
management has been critical. Each project included mapping workflows, awareness and
training sessions and establishing coaches, support and continuous improvement.
Biography:
Frans van den Berg currently works in the global Smart Fields programme in Shell’s Projects
and Technology organisation in the Netherlands. He leads the global implementation of
Collaborative Work Environments in Shell.
Frans joined Shell after graduation in Physics at Leiden University in The Netherlands. He has
held various positions as a petroleum engineer and asset development leader in operational
roles and in global technology deployment. He worked ten years in Malaysia and Thailand.
He has been involved in the organisation of the SPE Intelligent Energy and Digital Energy
Conferences since 2008.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Performance Drilling Expectations, Perceptions, and Path Forward –
Turning Challenges Into Opportunities
Graham Mensa-Wilmot
Chevron Energy Technology Company
Abstract:
Drilling activities continue to be extended into harsher and more challenging environments. In addition,
directional drilling, with its increased activity level, has also become more complex. These conditions have
escalating effects on operational costs. Performance drilling is universally accepted as an enabler in
operational costs reductions, through improvements in drilling efficiency. However, achievement of these
expectations continues to fall short, while also lacking consistency in most instances. These conditions are
primarily due to the industry’s different positions on what constitutes performance drilling. In most situations,
the use of new technology, sophisticated tools, or expensive drive systems, is classified as performance
drilling. Primarily, this lecture will challenge and move away from such positions. Most importantly, it will
present new definitions, concepts, and processes that facilitate consistent achievement of performance
drilling’s intended objectives and benefits.
In addition to establishing how performance drilling should be executed, a new benchmarking process which
focuses on how and why events occur will be discussed. Additionally, clear distinctions between project
success and efficiency as they relate to operational costs will also be established. The challenges posed by
specific applications, which need performance drilling focus, will be identified and discussed.
Global projects in different applications, where challenges continue to be turned into opportunities, will be
presented and supported with the appropriate data and discussions.
Biography:
Graham Mensa-Wilmot is a Sr. Advisor, Drilling Engineer in Chevron's Energy Technology Company.
Graham is the MAXDRILL (Performance Drilling) project leader. He has more than 28yrs experience in
drilling applications research, downhole tool development, drilling vibrations identification and remediation,
drilling mechanics, drilling system design and analysis, and drilling performance improvement. He has
authored 42 technical papers and also holds 34 patents on same disciplines.
Graham is a recognized industry leader on performance drilling. He serves on the SPE/IADC Drilling
Conference Program Committee, and the SPE Drilling and Completions technical review committee. He
previously served for 6 years, on the JPT Editorial committee, as technical editor for the Bits/BHAs and
Performance Drilling. Graham also served as a distinguished lecturer on the Petroleum Network Educational
Courses series. Graham holds an MS degree in Drilling Engineering from Romanian's University of
Petroleum and Gas in Ploiesti.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
The Role of Natural Fractures in Shale Gas Production: What Does
Production Data Tell Us?
Ian C. Walton
Energy & Geoscience Institute, University of Utah
Abstract:
Natural fractures are very common in shale gas plays. It is often presumed that because the
formations are so tight gas can be produced economically only when extensive networks of
natural fractures exist. The creation of large fracture surface area in contact with the reservoir
is regarded as essential to commercial success. This is facilitated by multi-stage hydraulic
fracturing of long horizontal wells using large volumes of low-viscosity (low-cost) fracturing
fluid. The fracture systems that are created by this process are indeed large and often
complex, due essentially to intersection of the hydraulic fractures with the natural fracture
network. However, the efficiency of this process in terms of water usage is now coming under
close scrutiny, not least because of growing environmental concerns.
The success of these operations is beyond doubt, but what can be inferred about the accuracy
of this conceptual picture in light of many years’ accumulated production data? What does
production data tell us about the role of natural fractures, whether initially closed (mineralized)
or open, in the production process? This presentation addresses these issues by using a
semi-analytic shale gas production model to analyze and interpret production data from many
shale gas wells across several different plays. Among the many inferences that can be drawn
from the results of this investigation is a fresh appraisal of the role of natural and hydraulic
fractures in the production process.
Take-away message: natural fractures may not, after all, be essential for economic shale gas
production and may even be detrimental.
Biography:
Ian Walton is a Senior Research Scientist in the Energy & Geoscience Institute at the
University of Utah and an Adjunct Professor in the Department of Chemical Engineering. He
holds a Ph.D. in Applied Mathematics from the University of Manchester. Dr. Walton has more
than 25 years of petroleum industry experience, most recently as a Scientific Advisor for
Schlumberger and more than 15 year’s university teaching experience. He has published
many technical reports and papers and has been awarded eight patents. He has made many
technical presentations at industry conferences, forums and workshops. Current research
centers on modeling and forecasting gas and oil production from shales.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Improving Reservoir Simulation Modeling with
Seismic Attributes
Isabela Falk
Schlumberger
Abstract:
Seismic attributes are being used more and more often in the reservoir
characterization and interpretation processes. The new software and computer’s
development allows today to generate a large number of surface and volume
attributes. They proved to be very useful for the facies and reservoir properties
distribution in the geological models, helping to improve their quality in the areas
between the wells and areas without wells.
The seismic attributes can help to better understand the stratigraphic and
structural features, the sedimentation processes, lithology variations, etc. By
improving the static geological models, the dynamic models are also improved,
helping to better understand the reservoirs’ behavior during exploitation.
As a result, the estimation of the recoverable hydrocarbon volumes becomes
more reliable and the development strategies will become more successful.
Biography:
Isabela Falk is a Senior Geologist, currently the Subsurface Team Leader in a
Schlumberger P&AM project in Romania. Previously she worked as a Project
Geoscientist for Fugro-Jason in Germany and Holland. Prior to that, she worked
as a Researcher Geologist in the Romanian National Gas Company: Romgaz.
Isabela holds a PhD in Geology from the University Babes-Bolyai from ClujNapoca, Romania, since 2008. She has 20 years of experience in the Oil& Gas
industry, specialized mostly in geological modeling, but is experienced also in
seismic inversion.
She made several scientific presentations in internal and international
conferences and is a member of SPE, SEG and EAGE.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
“Fooled by Randomness”
- Improving Decision Making With Limited Data
James Gouveia
Rose & Associates LLP
Abstract:
Professionals routinely face the challenge of making informed decisions with limited data sets.
Our exploitation of Unconventional resource plays has exacerbated this issue. We commonly
refer to these resource plays as “statistical plays”, as large programs have provided repeatable
year over year results. Competitive pressures and the desire to get to the right answer as
soon as possible has driven the observed decision-making based on limited data sets. In an
environment where horizontal well costs can exceed $10 MM and programs hundreds of
millions of dollars, decisions based on limited wells have become our industry’s “money pits”.
Development decisions are often made without due consideration for the representativeness of
the data. Similarly, we frequently test new technologies with limited samples with the
expectation that a simple arithmetic comparison of the average results can validate or refute
their further application.
This talk presents the theory and utilization of aggregation curves as a pragmatic graphical
approach to determining the uncertainty in the sampled mean relative to the desired average
program outcome. The presentation will conclude with a discussion on the use of sequential
aggregation plots as a graphical approach to validating the representativeness of our
forecasted results versus based on limited actual results.
Biography:
James Gouveia is a Professional Engineer with a diverse technical, business and operations
background. He has worked in a variety of technical and managerial assignments in
exploration, reservoir engineering, strategic and business process planning, portfolio and risk
management. From 1996 to 1999, Mr. Gouveia was Director of Risk Management for the
Amoco Energy Group of North America. In this role he was accountable for assurance of
consistent project evaluation of major capital projects. With BP, he was an Assurance
champion and Asset manager. Jim has co-authored and presented papers, most recently as a
contributing author to the SPEE’s 2011 Monograph 3, and SPE 175527 & 175888 & 121525.
Mr. Gouveia is a member of APEGA, SPE, SPEE and AAPG. Mr. Gouveia is a partner in Rose
& Associates LLP.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Does Heavy Oil Recovery Need Steam?
Johan van Dorp
Shell
Abstract:
Heavy Oil recovery traditionally starts with depletion drive and (natural) waterdrive with very
low recoveries as a result. As EOR technique, steam injection has been matured since the
1950s using CSS (cyclic steam stimulation), steam drive or steam flooding, and SAGD (steam
assisted gravity drainage). The high energy cost of heating up the oil bearing formation to
steam temperature and the associated high CO2 footprint make steam based technology less
attractive today and many companies in the industry have been actively trying to find
alternatives or improvements. As a result there are now many more energy efficient recovery
technologies that can unlock heavy oil resources compared with only a decade ago. This
presentation will discuss breakthrough alternatives to steam based recovery as well as
incremental improvement options to steam injection techniques. The key message is the
importance to consider these techniques because steam injection is costly and has a high CO2
footprint.
Biography:
Johan van Dorp holds an MSc in Experimental Physics from Utrecht University and joined
Shell in 1981. He has served on several international assignments, mainly in petroleum and
reservoir engineering roles. He recently led the extra heavy-oil research team at the Shell
Technology Centre in Calgary, focusing on improved in-situ heavy-oil recovery technologies.
Currently, he is senior consultant in the "Nederlandse Aardolie Maatschappij", a JV operated
by Shell. Van Dorp is also Shell Group Principal Technical Expert in Thermal EOR and has
been involved with most thermal projects in Shell throughout the world, including California,
Oman, the Netherlands, and Canada. He (co-)authored 13 SPE papers on diverse subjects.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Automation of the Drilling System:
What has been done, what is being done, and why it is important
John Macpherson
Baker Hughes
Abstract:
Drilling systems automation is the real-time reliance on digital technology in creating a
wellbore. It encompasses downhole tools and systems, surface drilling equipment, remote
monitoring and the use of models and simulations while drilling. While its scope is large, its
potential benefits are impressive, among them: fewer workers exposed to rig-floor hazards, the
ability to realize repeatable performance drilling, and lower drilling risk. While drilling systems
automation includes new drilling technology, it is most importantly a collaborative infrastructure
for performance drilling.
In 2008, a small group of engineers and scientists attending an SPE conference noted that
automation was becoming a key topic in drilling and they formed a technical section to
investigate it further. By 2015, the group reached a membership of sixteen hundred as the
technology rapidly gaining acceptance. Why so much interest? The benefits and promises of
an automated approach to drilling address the safety and fundamental economics of drilling.
What will it take? Among the answers are an open collaborative digital environment at the
wellsite, an openness of mind to digital technologies, and modified or new business practices.
What are the barriers? The primary barrier is a lack of understanding and a fear of automation.
When will it happen? It is happening now.
Digital technologies are transforming the infrastructure of the drilling industry. Drilling systems
automation uses this infrastructure to deliver safety and performance, and address cost.
Biography:
John Macpherson is a Senior Technical Advisor for Baker Hughes. He holds a BSc (Hons) in
Geology from the University of Glasgow. During his 40 years in the oil industry, he has
participated in exploratory drilling operations -- primarily in remote areas of South America -and in various positions in drilling research and development. His focus has been on
exploration and drilling: starting with geology, through geomechanics, drilling modeling, to
drilling dynamics and drilling systems automation. He has published about 40 papers, and has
more than 25 granted patents. He is the Chairman of the SPE Drilling Systems Automation
Technical Section (2014 and 2015), and a member of the Drilling Systems Automation
Roadmap initiative. He is a member of the JPT editorial committee.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
"Deepwater Managed Pressure Drilling and Well Drillability,
Efficiency and Process Safety"
Julmar Shaun Sadicon Toralde
Weatherford
Abstract:
Adoption of managed pressure drilling (MPD) technologies of the applied surface
backpressure type in deepwater environments have mainly involved a rotating control device
(RCD) to create a closed drilling system where flow out of the well is diverted towards and
backpressure regulated using an automated MPD choke manifold with a high-resolution mass
flow meter that increases sensitivity and reaction time to kicks, losses and other unwanted
drilling events.
This integration of MPD equipment into floating drilling rigs to provide it with MPD capabilities,
including the capacity to perform pressurized mud cap drilling (PMCD) and riser gas mitigation
(RGM), has not only produced improvements in terms of drillability and efficiency, but most
importantly, in terms of process safety.
Case histories on how MPD has performed will be presented on the following:
• allowed drilling to reach target depth in rank wildcat deepwater wells that have formations
prone to severe circulation losses and narrow mud weight windows;
• increased drilling efficiency by minimizing non-productive time associated with downhole
pressure-related problems and by allowing for the setting of deeper casing seats;
• enhanced operational and process safety by allowing for immediate detection of kicks, losses
and other critical downhole events.
• provided riser gas mitigation capabilities that can detect a gas influx once it enters the drilling
fluid stream, and not after it has already broken out above the rig blow-out preventers (BOPs).
Biography:
Julmar Shaun Sadicon Toralde is the Global Champion for Deepwater Managed Pressure
Drilling (MPD), Downhole Deployment Valve (DDV) and SteadyState Continuous Flow System
technologies, based in Houston, Texas, USA. He helped pioneer deepwater MPD deployment
on a dynamically positioned drillship in 2010 and is actively involved in major deepwater MPD
rig integration projects globally. Shaun is from the Philippines and holds a Geothermal
Engineering degree from Negros Oriental State University, where he taught and conducted
research on energy engineering. He previously held various field and office management
positions with Weatherford in the Asia Pacific region. He has 50 technical papers / trade
articles and various MPD training courses to his name.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Integrated Reservoir Modelling in Carbonates - Quo Vadis?
Jürgen Grötsch
Shell Global Solutions International B.V.
Abstract:
Integrated reservoir modelling (IRM) is a best practice in the Upstream industry applied
throughout all life cycles stages of oil and gas projects aiming at characterisation of subsurface
reservoirs and optimisation of field development phases. In this respect, carbonate and clastic
reservoirs are different in a range of aspects which will be highlighted.
During the past 25 years, major steps in technology development have proven the importance
of IRM as a key subsurface contributor to Upstream projects. A brief history of IRM through
time will be provided using carbonate examples from exploration, development up to recent
learnings around unconventional hydrocarbon trapping. More importantly, these industry
showcases will be used to introduce present-day challenges around IRM in the Upstream
business. Despite the significant progress in modelling technologies, root causes for
disappointing results of such studies are limitations in software tools and workflows together
with the lack of integration. This often causes poor project delivery. Such pitfalls within existing
practices in the Upstream industry will be discussed highlighting that tools only are not able to
assure success in subsurface reservoir characterisation projects.
Finally, an outlook into the future of hydrocarbon development planning and IRM will be
provided. Ultimately, end-to-end integration in Upstream project workflows requires focus on
associated business decisions, scaling of models and scenario management supported by
content and context based data management as well as capabilities around fast iterative
feedback loops. Only the combined improvements around tools, processes and people will
maximise value for Upstream project delivery.
Biography:
Jürgen is currently Global Learning Advisor Geology at Shell responsible for design and
deployment of advanced training programs. In this position, his focus areas are integration and
building capabilities around decision based subsurface modelling for muilti-disciplinary teams
which he was involved with for the past 25 years in various assignments within Shell
Production and Exploration ventures around the world.
Jürgen holds a Ph.D. in carbonate sedimentology and has authored and co-authored
numerous publications and books. He is known as keynote lecturer from international
geoscience conferences and, since 2009, as visiting lecturer at the GeoZentrum of the
Universität Erlangen-Nürnberg in Germany. Currently, he is Vice-President of the German
Geological Society (DGGV).
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Integration from Multiple Disciplines in Horizontal Well Evaluations to
Increase Production in Organic Rich Shales
Kevin Fisher
Schlumberger
Abstract:
Drilling horizontal wells is the common mode of operation for field development in permeabilitychallenged unconventional reservoirs such as an organic shale. Assumptions are made
regarding the homogeneity of the reservoir as wells are drilled away from the vertical pilot well.
It is assumed that the reservoir characteristics remain uniform and also that the structure is
known to remain in a constant orientation based on the dip information at the pilot wellbore.
Experience tells us that these assumptions can lead to wells placed out of zone and in rocks
with much different reservoir quality and stress magnitude, which can adversely affect the
production potential of the well. With the high cost of drilling and completing these wells, it is
generally economically beneficial to do some evaluation of the lateral to ensure proper
placement of the well and also the optimal placement of completion zones along the lateral.
Lateral measurements and petrophysical interpretations can be used to define variations in
reservoir quality (RQ) and completion quality (CQ), which can then be used to optimally place
perforation clusters in similar rock to increase production when compared to peer geometric
wells. The integration and interpretation of pilot and lateral wellbores with a geological
structure component is defined as geology quality (GQ). A methodology to integrate data from
many sources enables a better understanding of the variability and structural challenges of
these complex reservoirs. This integrated methodology has been refined using lessons
learned from various case studies showing increased production when compared to geometric
completions.
Biography:
Kevin is a Senior Petrophysicist for Schlumberger based in Houston, TX with 25 years of
experience in petrophysics and rock physics, after graduating from the University of Tulsa with
a degree in Petroleum Engineering. He is currently working in the South Texas Production
Technology Integration Center focusing on unconventional resource plays, mainly in the Eagle
Ford basin. Additional areas of expertise have been deep water and shelf sturctures in the
Gulf of Mexico, tight gas sands in South TX and Rockies, Alaska, Permian Basin,
Unconventional Gas & Oil shales, Coal Bed Methane and international (Australia, Brazil,
Argentina, United Kingdom, France, Nigeria, Angola, Turkey and Saudi Arabia).
Kevin is guest lecturer since 2012 at Rice University for a graduate level petroleum geology
class entitled “Economic Geology – Petroleum”.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Drilling Dynamics - Five Fundamental Questions Answered
Liam Lines
Weatherford
Abstract:
Understanding downhole dynamics is key to reducing downhole failure and non
productive time.
Damage resulting from drilling dynamics costs the industry in excess of $750
million per year in repair and maintenance alone not to mention the additional
costs due to reduced drilling efficiency and trips for failure. This presentation
answers five fundamental questions relating to drilling dynamics; 1) What it is; 2)
How we know it is happening, 3) What the consequences are, 4) How it can be
predicted and 5) What can be done to prevent it.
Biography:
Liam Lines is the Global SME for Drilling Mechanics and Vibration for Weatherford
Drilling Services. He is charged with advancing the companies understanding of
the drilling environment, developing and evaluating new downhole logging-whiledrilling and rotary steerable technlogies and defining best practice guidelines for
drilling optimization and hazard mitigation. He has a number of patents pending
and has presented a series of technical papers at international conferences. Liam
has a Masters Degree in Mechanical Engineering from the University of Bristol and
a PgCE in Petroleum Engineering from Harriot Watt University.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
The Science and Economics of Multiphase Flow
Mack Shippen
Schlumberger
Abstract:
We are all familiar with the production systems through which reservoir fluids flow to
reach our processing facilities. This is a journey characterized by complex multiphase
flow phenomena that govern pressure and temperature changes along the way. A
monumental amount of research and development work has been invested towards
better understanding multiphase flow behavior over the past fifty years. Yet, many
challenges remain as we strive to optimize ever more complex production systems
fraught with difficult flow assurance issues.
Just how good is the science? And more importantly, how does this impact our bottom
line?
This lecture will discuss key concepts of multiphase flow leading to the current “state-ofthe-art” models used today. Looking towards the future, the science must be advanced
to address areas of greatest uncertainty and align with trends in field development
strategies. Recommendations will be presented covering the top 5 areas of research
necessary for these purposes. The economic impact of multiphase operations will be
illustrated using two examples that provide insight towards maximizing asset value.
Biography:
Mack Shippen is a Principal Engineer with Schlumberger in Houston, where he is
responsible for the global business of the PIPESIM multiphase flow simulation software.
He has extensive experience in well and network simulation studies, ranging from flow
assurance to dynamic coupling of reservoir and surface simulation models. He has
served on a number of SPE committees and chaired the SPE Reprint Series on
Offshore Multiphase Production Operations. He holds BS and MS degrees in Petroleum
Engineering from Texas A&M University, where his research focused on multiphase
flow modelling.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
How can Microfracturing Improve Reservoir Management ?
Mayank Malik
Chevron
Abstract:
Microfracturing is an excellent method of obtaining direct stress measurements, not only in
shales, but in conventional reservoirs as well. Recent advances have shown that
microfracturing can help improve reservoir management by guiding well placement, completion
design, and perforation strategy.
Microfracturing consists of isolating small test intervals in a well between inflatable packers,
increasing the pressure until a small fracture forms and then by conducting a few injection and
shut-in cycles, extend the fracture beyond the influence of the wellbore. Results show that
direct stress measurements can be successfully acquired at multiple intervals in a few hours
and the vertical scale nearly corresponds to electric log resolution. Therefore, microfracture
testing (generally performed in a pilot / vertical well) is an appropriate choice for calibrating log
derived geomechanical models and obtaining a complete, accurate, and precise vertical stress
profile.
This talk describes the microfracturing process and presents several examples that led to
increased hydrocarbon recovery by efficient stimulation and/or completion design. Case
studies presented range from optimizing hydraulic fracturing in unconventionals, determining
safe waterflood injection rates in brownfields, and improving perforation placement in ultra
deepwater reservoirs.
Biography:
Mayank Malik is the Global Formation Testing Expert in Chevron's Energy Technology
Company and is a champion for advancing research on microfracturing. He holds a B.S. in
Mechanical Engineering from Delhi College of Engineering (India), MS in Mechanical
Engineering from University of Toronto (Canada), and Ph.D. in Petroleum Engineering from
The University of Texas at Austin (USA). Malik has authored numerous papers on
petrophysics, formation testing, and microfracturing. He is currently serving on the SPE ATCE
Formation Evaluation committee and is also the Chairman for SPWLA Formation Testing
Special Interest Group.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Applications and Advantages of Logging-While-Drilling in
High-Angle and Horizontal Wells
Michael Gillen
Baker Hughes
Abstract:
The drilling industry has undergone a revolution in the past decade, with horizontal drilling
becoming the norm for the development of many unconventional and conventional reservoirs.
For example, rig count statistics for the US show that since 2004 the percentage of rigs drilling
horizontal wells has steadily risen to almost 80% of today’s active drilling rigs. Horizontal
drilling, which has enabled the economic development of many reservoirs, will continue to be
the prevalent method for drilling in the future.
Horizontal wells pose unique challenges for log interpretation and formation evaluation. Most
of the logging technology in use was developed for evaluating vertical wells. The
measurement responses observed in horizontal wells are often different from vertical wells in
the same reservoir. It is important to understand how standard logging “quad-combo”
measurements are affected by the orientation change from vertical to horizontal. Sometimes
these changes are misinterpreted or assumed to be tool malfunctions. By understanding the
changes in the measurement responses we can take full advantage of the information they
provide to understand the formations surrounding the borehole. This talk will address some of
these issues and discuss the various applications for real-time LWD measurement to improve
drilling efficiency and safety. Case histories are presented to support these points.
The attendees at this talk will leave with an increased understanding of how logging
measurements are affected differently in horizontal wells and how to take full advantage of the
differences.
Biography:
Michael Gillen is the Global Director for Formation Evaluation Services at Baker Hughes.
With 34 years of logging and formation evaluation experience, Mike began his career as a
Field Engineer with Dresser Atlas in 1981. He later joined NUMAR Corp. where modern NMR
technology was first developed for well logging. He joined Baker Hughes in 2000 and was
responsible for several new wireline technology introductions before moving to the Drilling
Services group to lead the LWD team. Mike holds a BS in Engineering from the University of
Colorado and an MBA from Penn State University. He has published several papers on new
wireline and LWD technologies and interpretation techniques and holds two patents in this
field.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Stress Shadows: How and Why They Can Affect Hydraulic Fracturing in
Both Conventional and Unconventional Plays
Neal B. Nagel
OilField Geomechanics LLC
Abstract:
Much is now made about “Stress Shadows” and their impact on hydraulic fracturing particularly in multi-stage horizontal laterals commonly used in Unconventionals. Unfortunately,
there is no standard definition of Stress Shadows and, as a result, there is much confusion
over what they are and aren’t, and, most importantly, why they can have a significant impact
on hydraulic fracturing operations. The goal of this presentation will be to address this
confusion and more fully explain Stress Shadows and their impact.
The creation of hydraulic fracture width during a stimulation generates a change in the stress
field, which alters all three principal stresses as well as tip shear stresses. These stress
changes are the Stress Shadows.
As hydraulic fracture propagation is often controlled by the stress field, Stress Shadows may
change the propagation path for subsequent hydraulic fractures or, as seen in cluster
fracturing, propagation may be impeded completely. The presence of natural fractures and
weakness planes can also affect, and be affected by, Stress Shadows. At the hydraulic
fracture tip, shear stresses are generated that offer the potential to shear and open closed
natural fractures and weak planes – and if opened, it may be possible to stimulate them.
Equally important, behind the hydraulic fracture tip Stress Shadows increase the magnitude of
all three principal stresses, which tends to close weakness planes making them more difficult
to stimulate. Because of these effects and others, understanding and designing for the impact
of Stress Shadows is often critical for stimulation optimization.
Biography:
Dr. Neal Nagel is currently Chief Engineer for OilField Geomechanics and has nearly 30 years
of industry experience. He is a well-known expert in the geomechanics of Unconventionals and
has given many invited SPE, AAPG, HGS, SEG, and SPWLA presentations. Nagel has also
authored or coauthored more than 50 technical papers, with 20+ related to Unconventionals,
including a keynote presentation at the 2014 SPE HFTC. He is a past SPE Distinguished
Lecturer, was chief editor of the 2010 SPE Monograph on Solids Injection, has served on the
SPE Drilling and Completions Committee, and also been a local SPE section officer.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Prediction and Management of Fines Migration for
Enhanced Oil & Gas Production
Pavel Bedrikovetsky
University of Adelaide
Abstract:
Fines migration is the most common formation damage mechanism that challenges the economic viability of
petroleum development projects. The phenomenon has been widely reported for production and injection
wells, drilling, completion, waterflooding and pressure depletion with water support. It is explained by the lifting
of reservoir fines, their migration and pore plugging with consequent permeability decline.
We introduce a maximum retention function for fines that models fines mobilization and allows coreflood
interpretation, well impairment history analysis and well behavior prediction. The laboratory and field case
studies presented validate the approach. The reservoir study presented shows how to use the coreflood- and
well-history data for reliable prediction of productivity decline, its prevention, and mitigation.
The traditional view of fines migration is that it should be avoided because of its detrimental effect on reservoir
permeability and hence well productivity. However, the permeability decline effect provides a relatively simple
method for water mobility control. We show laboratory and field cases where, compared with “normal”
waterflooding, the fines-assisted low salinity waterflood results in a significant increase in reservoir sweep due
to fines lifting and permeability decline in the swept zone.
Additionally, in oil and gas reservoirs, the injection of a small fresh water bank into watered out wells, or above
the hydrocarbon-water contact, decelerates the invaded water and significantly decreases water production.
Huf-n-puf by low-salinity water significantly decreases water production in oil- and gas wells.
Reliable prediction of productivity decline due to fines migration and its effective management to enhance oil
and gas production is the key message of this lecture.
This lecture stimulates the petroleum engineer’s thinking into productivity enhancement options and, in
particular, that natural or deliberately induced fines migration may often assist in oil and gas production.
Biography:
Pavel is Professor of Petroleum Engineering at the University of Adelaide. He authors a seminal book on
reservoir engineering and over 200 papers in international journals and SPE. His research covers formation
damage, waterflood and EOR.
Pavel holds an MSc in Applied Mathematics, a PhD in Fluid Mechanics and a DSc in Petroleum Engineering
from the Russian Gubkin Oil and Gas University. He was a Visiting Professor at Delft University of Technology
and at Imperial College of Science and Technology in London. He boasts 35 years of industrial experience in
Russia, Europe, Brazil and Australia.
Pavel serves as a short course instructor and a Program Committee member at numerous SPE Conferences.
He was a 2008-2009 SPE Distinguished Lecturer.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Two Vital Secrets for Building Better Type Wells
Randy Freeborn
Energy Navigator
Abstract:
Each year, companies use averaged well production (type wells) to support billion dollar
expenditures to buy and develop oil and gas resources. These type wells often have
unrepresentative rate-time profiles and recoveries over-stated by as much as 50%. These
intolerable errors result from common, but incorrect, assumptions in constructing type well
production profiles, and the selection and weighting of analog wells.
Literature related to constructing type wells is sparse and incomplete. This lecture will fill that
gap and lead participants to informed decisions for best practices in type well construction.
Hind casting examples show that only small errors in recovery result when the type well
construction combines historical and predicted production rates. This improvement results from
using educated estimates (not intrinsic values) for months with no data to average, and from
individual well forecast errors that offset one another. A Monte Carlo method incorporates risk
and leads to better well selection and weighting factors, achieving more representative ratetime profiles. The recommended methodology incorporates aggregation and choosing different
uncertain parameters. Parameter choice is important because it makes little sense to risk
recovery (e.g., P90 for proved reserves) when the application demands a different parameter
such as present value.
Type well construction methods are common, but they have errors that are difficult to detect.
Evaluators are likely using type wells for financial analysis, facility design, cash flow prediction,
reserve estimation and debt financing without knowledge of the inaccuracies and options to
improve accuracy.
Biography:
Randy Freeborn is a subject matter expert in the field of empirical forecasting, type wells and
related technology. Currently, he is Chief Research Engineer at Energy Navigator where he is
responsible for identifying and inventing engineering technology for inclusion in the company’s
reserve management software. He has been a professional engineer for 44 years and is a
member of SPEE and SPE. Freeborn has prepared numerous technical papers for
presentation at conferences, workshops and industry meetings. He has given guest lectures at
the University of Houston and Texas A&M, and has been called as an expert witness.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Creating Value from Uncertainty and Flexibility
Reidar B. Bratvold
University of Stavanger
Abstract:
An increasing number of oil & gas companies use decision analytic methods to deal
with complex and uncertain decisions, but still they get consistent under-performance in
typical business metrics (cost, production rates, time to start, … ) leading to less value
than expected, or, more perniciously, than possible. Uncertainty per se is not the culprit,
rather a failure to make the best decisions under uncertainty – which are often nonintuitive. The real value-destroyers are bias and failing to plan for, and exploit, the
different ways reality might evolve - if you under-estimate the real uncertainty, you are
likely to under-invest in managing its consequences. Making the best decisions requires
an accurate assessment of uncertainty (unbiased, neither optimistic nor pessimistic) –
and an unbiased approach to managing its consequences – putting as much effort on
capturing upside opportunities as mitigating risks.
We often make decisions to live up to expectations rather than to live up to possibilities.
Despite the ubiquity of options in the oil & gas industry, in practice these embedded
options are often overlooked in the formulation and evaluation of investment
opportunities, even when uncertainties are explicitly modeled.
This talk will illustrate and discuss how to create value from uncertainty and flexibility by
applying an option pricing methodology that explicitly focuses on upside possibilities. To
properly value flexibility, we must model not only the possible future decisions, but also
the information available at the time these decisions are made.
Biography:
Reidar B. Bratvold is Professor of Petroleum Investment and Decision Analysis at the
University of Stavanger. His research interests include decision analysis, project
valuation, portfolio analysis, real-option valuation, and behavioral challenges in
decision-making. Prior to academia, he spent 15 years in the industry in various
technical and management roles. He is a co-author of the SPE book Making Good
Decisions. Professor Bratvold has previously twice served as an SPE Distinguished
Lecturer. He is the 2015 recipient of the North Sea Region SPE Management &
Information Award and currently serves as the executive editor for the SPE Economics
& Management journal. He is a Fellow of the Society of Decision Professionals and a
member of the Norwegian Academy of Technological Sciences. He holds a PhD in
petroleum engineering and an MSc in mathematics, both from Stanford University and
has studied business and management science at INSEAD and Stanford University.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Human Factors in Barrier Thinking
Ron McLeod
Ron McLeod Ltd.
Abstract:
The oil and gas industry places great reliance on layers-of-defenses, or barrier thinking, to
protect against process safety incidents. Human performance continues to be the single most
widely relied on barrier: whether as a defense in its own right, or in implementing, inspecting,
maintaining and supporting engineered defenses. Human error, in its many forms, also
continues to be a significant threat to the reliability of engineered and organizational defenses.
While approaches to developing and assuring layers of defenses strategies have become
increasingly formalized and rigorous in recent years, many organizations struggle to know how
to ensure the human defenses they rely on are as robust as they reasonably can be when
those strategies are developed and implemented. Drawing on the 2005 explosion and fire at
the Buncefield fuel storage site as a case study, the presentation considers issues associated
with the independence and effectiveness of human defenses. The key idea SPE members
should take away from the lecture is that organizations can improve the strength of their
human defenses by being clearer about exactly what it is they expect and intend of human
performance to protect against threats. The presentation sets out challenges organizations can
use to ensure the human defenses they rely on are as robust and reliable as they reasonably
can be.
Biography:
Ron McLeod holds a BSc in Psychology, an MSc in Ergonomics and a Ph.D. in Engineering
and Applied Science and is Honorary Professor of Engineering Psychology at Heriot-Watt
University. He has more than 30 years experience as a Human Factors specialists and was
Shell’s Global Discipline Lead for Human Factors until March 2014. He has been active in
organisations including the UK National Advisory Committee on Human Factors, the Process
Safety Leadership Group, as well as the IOGP, SPE and CIEHF. He has published in
scientific journals and has authored or contributed to numerous technical standards and bestpractice guides. His first book, “Designing for Human Reliability: Human Factors Engineering
in the Oil, Gas and Process Industries” was published by Elsevier in 2015.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
In-situ Wettability Utilizing Low Gradient Magnetic Resonance
Oluwasegun Jebutu
Baker Hughes Inc
Abstract:
Main idea: Evidence has shown that mixed-oil wet reservoirs do exist. How mixed wettability
occur is complex, water wet systems can transition to mixed wet, but if we can identify where
they occur and know the distribution in the reservoir, we can produce more efficiently.
Hydrocarbon recovery, production mechanisms and field development economics strongly rely
on understanding the wetting characteristics of the in-situ reservoir fluids. This paper presents
a new approach to estimate wettability, utilizing low-gradient magnetic resonance technology.
Wettability is difficult to measure in-situ, however the interaction of the fluid and rock mineral
surfaces have an apparent relaxation time that is influenced by the surface relaxation
mechanism of magnetic resonance. Wettability can be measured in the laboratory through
contact angle, atomic forces microscope imaging and Ammot index measurements. These are
scale-constrained and difficult to replicate original down-hole conditions for these
measurements. The new approach enables direct wettability estimation at in-situ reservoir
conditions
A spin-lattice function is derived, which is directly related to the interfacial tension and surface
wetting fluid properties. A wettability index is then computed from the function using a
reference zone below the free water level. The results indicate mixed wetting characteristics in
asphaltenes and heavy-to-solid hydrocarbon bearing sections. Several other factors evaluated
that may account for the wettability distribution include, asphaltene content of oil, acid number
of the oil, rock surface roughness and paleo-diagenetic thermal and pressure history of the
reservoir. The early insitu knowledge of the presence of mixed wet systems allows for optimal
sweep efficiency planning of future recovery methods.
Biography:
Oluwasegun Jebutu has over 28 years' experience in reservoir characterization supporting
Wireline and Logging While Drilling operations. Roles include Strategic Senior Manager,
Global integration manager, Reservoir development services, Regional geoscience manager
North America, District Petrophysicist, Petrophysical and project consultant, Operations
Manager Integrated field studies, worked in USA,United Kingdom, Angola, Nigeria; Baker
Hughes, Halliburton, Gearhart. He has a B.SC. Physics and M.SC in Petroleum Engineering,
MBA Texas A&M. He has authored patents on NMR technology and co-authored over 40
publications. An SPE Distinguished lecturer in 2011-2012, A member of the SPE and SPWLA,
SPE Conference Chairman, SPE Section chairman.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Salt Behavior and Drilling Strategies to Overcome Challenges in
Pre-Salt Exploratory Wells
Shrikant Tiwari
Saudi Aramco
Abstract:
Swathes of salt in various geometries exist at varying depths in several salt basins in the
world with significant accumulation of hydrocarbon beneath. These pre-salt accumulations
require drilling through different types of salt structures. The geological uncertainty due to
seismic anisotropy and inherently poor imaging below salt layers require sound drilling
engineering and solutions-driven drilling practices.
Initial salt drilling posed several challenges, for salt behaves very different from other clastic
sediments. The challenges vary with the geological conditions and composition of salt
body. Several experiments conducted over the years and experience of drilling salt in
different basins helped enriching Industry knowledge base to comprehend the salt drilling
situation better.
Exploratory drilling brings another dimension of challenges with uncertainty of geological
conditions. The drilling plan needs to be robust enough to handle these uncertainties and
flexible enough to amend drilling strategies based on actual conditions. Devising
appropriate well construction and drilling strategy require a sound understanding of salt
behavior and its variability with geological conditions. Successful drilling requires aligning
drilling solutions with salt behavior under anticipated geological conditions and adopting
scenario based approach to handle unexpected situations. This lecture establishes a link
between salt characteristics and drilling techniques, enabling technology options and
workflows that have been instrumental in successful well construction in frontier areas for
pre-salt exploration.
Biography:
Shrikant Tiwari is General Supervisor heading an Offshore Exploration Drilling Engineering
Division in Saudi Aramco and is leading exploratory drilling projects in Red Sea and
Arabian Gulf. He holds Bachelor of Engineering and MBA degrees. He has over 28 years of
experience in the field of drilling and completions for offshore and onshore operations.
Shrikant has worked in several International locations in different positions and has
authored and co-authored several papers in leading Industry journals. He has successfully
led many drilling and completion projects in his career. Drilling project planning and
devising drilling strategies for critical well situations are his strengths.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Dry Hole Analysis: What I have Learnt about
the Upstream Petroleum Industry from My Failures
Steve Mackie
Santos Ltd
Abstract:
Finding and producing oil and gas are the major objectives of any upstream oil and gas
company. Both, however, can be highly elusive. Dry hole analysis is an exploration
methodology to determine what can be learnt from drilling failures. Using a series of
case studies from my own career I look at what we can learn from "failures" - not just
those that occur during exploration, appraisal and development but also those that relate
to the business as a whole. Having worked for all types of companies - multinationals
(both Euopean and USA), local Australian companies and even my own consulting I
have been exposed to many and varied management and organisational models. In
each case the distilled learnings are universal and applicable at any stage of a carreer.
Originally prepared as a Young Petroleum Professionals lecture, the concepts have been
expanded to help all professionals see the upstream petroleum industry as a business.
As well as uncovering technical findings from failures we can also find out a great deal
about the industry that will help working in it become more rewarding and exciting!
Biography:
Steve Mackie has a BSc (geophysics and sedimentology), MBA (strategy) and PhD
(decision-making) together with 35+ years’ experience in the upstream petroleum
industry functioning in both regional and field specific geoscience and engineering. As
well as running his own successful consultancy he has worked with multinationals and
local explorers in both technical and managerial roles. He has been forming, managing
and developing asset teams, including virtual teams, associated with exploration and
development geoscience and engineering for the last 20 years. He currently is Manager
– Geophysics at Santos Ltd. He is also an adjunct at the Australian School of
Petroleum, University of Adelaide; a member of the Advisory Board to the Australian
School of Petroleum; chairman of the Australian Petroleum Production and Exploration
Association (APPEA) Technical Program Committee and editor of the APPEA Journal
(2009 – 2015). Steve is the Federal President of the Petroleum Exploration Society of
Australia (PESA). He is an honorary life member of APPEA and an active member of
SPE, AAPG and EAGE.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Borehole Seismic Solutions
for Integrated Reservoir Characterization and Monitoring
Steve Morice
Shell Todd Oil Services Ltd
Abstract:
Modern oil and gas field management is increasingly reliant on detailed and precise 3D
reservoir characterisation, and timely areal monitoring. Borehole seismic techniques bridge the
gap between remote surface-seismic observations and downhole reservoir evaluation:
Borehole seismic data provide intrinsically higher-resolution, higher-fidelity images than
surface-seismic data in the vicinity of the wellbore, and unique access to properties of seismic
wavefields to enhance surface-seismic imaging.
With the advent of new, operationally-efficient very large wireline receiver arrays; fiber-optic
recording using Distributed Acoustic Sensing (DAS); the crosswell seismic reflection
technique, and advanced seismic imaging algorithms such as Reverse Time Migration, a new
wave of borehole seismic technologies is revolutionizing 3D seismic reservoir characterization
and on-demand reservoir surveillance. New borehole seismic technologies are providing
deeper insights into static reservoir architecture and properties, and into dynamic reservoir
performance for conventional water-flood production, EOR, and CO2 sequestration – in
deepwater, unconventional, full-field, and low-footprint environments.
This lecture will begin by illustrating the wide range of borehole seismic solutions for reservoir
characterization and monitoring, using a diverse set of current- and recent case study
examples – through which the audience will gain an understanding of the appropriate use of
borehole seismic techniques for field development and management. The lecture will then
focus on DAS, explaining how the technique works; its capability to deliver conventional
borehole seismic solutions (with key advantages over geophones); then describing DAS’s
dramatic impact on field monitoring applications and business-critical decisions.
New and enhanced borehole seismic techniques – especially with DAS time-lapse monitoring
– are ready to deliver critical reservoir management solutions for your fields.
Biography:
Steve Morice holds a PhD in Geophysics from Cambridge University, and is a Lead
Geophysicist and Shell's global focal-point for well-to-seismic interpretation. With 20 years of
experience in the international oil and gas industry, Steve has contributed to the fields of
surface- and borehole-seismic survey design, acquisition technologies, processing/imaging
techniques, and geophysical interpretation - with particular emphasis on the integration of
surface- and borehole data for field development and production optimization. Steve is an
author and co-author of numerous technical publications and two patents.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Minimize Operational Risk
Using Shared Geomechanical Earth Model
Surej Kumar Subbiah
Schlumberger
Abstract:
Stuck drill pipe, lost hole, severe mud losses, unable to hydraulically fracture the formation,
well shut down due to sand production, early water breakthrough. Sound familiar? These
incidents can cost E&P companies millions of dollars.
Geomechanics combines geology, geophysics, petrophysics and rock mechanics in order to
describe state of earth stresses and rock mechanical properties. This can be done along a
single wellbore, or in 3D field scale, and the results are presented in what is known as the
Shared Geomechanical Earth Model. This model helps in the understanding and managing
of the risks associated with rock deformation, which in turn helps minimize operational risks
for the life of the field from exploration to abandonment. Examples include wellbore
instability, sand production, hydraulic fracturing, injectivity, subsidence, compaction, fractures
reactivation, and thermal effects.
This presentation aims to increase awareness as to how one and the same Shared
Geomechanical Model can be used by different departments in an E&P company for their
operational planning, with focus on drilling and completion activities.
Biography:
Based in Abu Dhabi, Surej Kumar Subbiah is currently the Principal Geomechanics Lead for
Schlumberger Middle East. Surej holds BS and MS degrees in petroleum engineering from
the University of Technology Malaysia, with specialization in geomechanics. He spent the first
five years of his career in an academic environment as a Research Associate and a Lecturer
before he joined Schlumberger. With 20 years of experience, Surej has been involved in
many applied geomechanics projects from well centric to 3D field scale, and conducted
training courses in geomechanics for NeXT as well as SPE Netherlands and SPWLA Abu
Dhabi.
Society of Petroleum Engineers
Distinguished Lecturer 2016-17 Lecture Season
Your Field is Getting Older: Is your Process Engineering Still Cost
Effective?
Wally John Georgie
Maxoil Solutions
Abstract:
The lifecycle of developed fields, onshore and offshore will go through different stages of production
up to the decline into late field life. Effective reservoir engineering management will lead to prolonging
the life of field if a cost effective processing surface facilities strategy is put in place. Factors that lead
to the decline in oil production or increase in OPEX may include increased water production, solids
handling and the need for relatively higher compression requirements for gas lift. In order to maintain
productivity and profitability, an effective holistic engineering approach to optimizing the process
surface facilities must be utilized. The challenges of Optimizing Mature Field Production are:
1. Reservoir understanding with potential definition of additional reserves
2. Complete re-appraisal of the operability issues in the production facilities
3. Develop confidence to invest to optimize the process handling capabilities and capacity
4. Low CAPEX simplification of the surface facilities infrastructure to meet challenges
5. An implementation plan that recognizes the ‘Brownfield’ complexities
6. Selection of suitable optimum technology, configuration and training
7. Optimum upgrade plan of the facilities with minimum production losses
Successful operation of mature fields and their surface facilities requires successful change
management to the new operating strategy. Using a holistic approach can maximize the full potential
of mature processing facilities at a manageable CAPEX and OPEX.
Biography:
Dr. Wally Georgie has a B.Sc degree in Chemistry, M.Sc in Polymer Technology, M.Sc in Safety
Engineering and PhD in Applied Chemistry with training courses in oil and gas process engineering,
production, reservoir and corrosion engineering. He has worked for over 37 years in different areas of
oil and gas production facilities, including corrosion control, flow assurance, fluid separation,
separator design, gas handling and produced water. He started his career in oil and gas services
sector in 1978 based in the UK and working globally with different production issues then joined
Statoil as senior staff engineer and later as technical advisor in the Norwegian sector of the North
Sea. Working as part of operation team on oil and gas production facilities key focus areas included
optimization, operation trouble-shooting, de-bottlenecking, oil water separation, slug handling,
process verification, and myriad other fluid and gas handling issues. He then started working in March
1999 as a consultant globally both offshore and onshore, conventional and unconventional in the area
of separation trouble shooting, operation assurance, produced water management, gas handling
problems, flow assurance, system integrities and production chemistry, with emphasis in dealing with
mature facilities worldwide.