bluuebunny/crossref_metadata_2025 huggingface dataset:
SS: Subsalt imaging using wide azimuth data
Authors: Kapoor S. Jerry , Moldoveanu Nick , Vigh Denes
Published: July 2010

Prestack depth migration and wide-azimuth towed-marine acquisition provided step-change improvements in subsalt imaging during the last decade. Incremental enhancements in image quality were also provided by the development of processing algorithms like one-way wave equation (WEM), two-way wave equation (RTM) and true-azimuth 3D surface multiple attenuation (GSMP) (Dragoset et al., 2008). These compute intensive technologies are now routinely available due to cost effective compute capacity and fast algorithms.

Introduction

In general the industry has made tremendous improvements in the quality of subsalt images, however there are challenging areas where the imaging is still quite poor and needs further advances in technology.

Progress has also been made in building better velocity models with azimuthal tomography, introduction of TTI anisotropy combined with other seismic and non seismic measurements such as VSP's, Well logs, MMT, Gravity, geomechanical stress fields and basin modeling. However interpreting and incorporating salt geometry into the velocity model is the weakest link in our ability to consistently image subsalt sediments.

Although the current wide azimuth data sets provide better illumination of complex salt geometry and subsalt data they still fail to illuminate in many challenging areas especially at steep dips.

The Next Chapter

The industry needs another step change in improving illumination by acquiring data at all azimuths and longer offsets instead of just wide azimuth at current offset configurations of 8 × 4 km. Current datasets are also lacking in low frequencies where the subsalt signal is strongest.

So, the next step is to raise the WAZ technology to a new level by implementing a dual-coil acquisition design. This can enable the recording of full-azimuth data with a 14 × 14-km offset range. Indeed, such a program has been identified for the Gulf of Mexico. In that program, the sources and receivers will be towed at depths appropriate to optimize low-frequency content (Moldoveanu and Kapoor, 2009).

3D finite-difference (FD) modeling of the SEG advanced modeling (SEAM) model shows the illumination improvements obtained by full-azimuth 14 × 14-km data vs. wide-azimuth 8 × 4-km data.
AKPO: Early Completion of a Giant Nigerian Deep Offshore Development
Authors: Rafin Francois
Published: July 2010

Akpo field was discovered in January 2000 and production started ahead of schedule in March 2009 in block OML 130, 200 km offshore Nigeria in 1400 m water depth.

Akpo reservoirs exist in a 620 million recoverable barrels accumulation of a critical fluid made of very light oils up to 53° API and classified as condensate, with well head shut-in pressures up to 430 bars, fluid temperature up to 116 °C at the wellhead and very high GLR. AKPO is not only a giant condensate field, but also a gas field with 1Tcf planned gas export. Plateau production is 175,000 bbls/day of condensate for offshore loading to tankers and 320 mmscfd of gas exported by pipeline to Bonny NLNG plant, onshore Nigeria.

The AKPO field development scheme was described in the SPE document OTC-18816-PP " AKPO: A Giant Deep Offshore Development??, presented at OTC 2007.

The AKPO project faced the challenges of combining gigantism, new technological frontiers, world scale industrial execution, scarcity of resources in booming years for the offshore industry and setting new records of local content in an unstable Niger Delta.

This paper provides an insight into how TOTAL as Operator responded to these many challenges, in association with the contractors and vendors.Gigantism and new technological frontiersDevelopment of metallurgy solutionsQualification programsRisk managementSharing the risk with contractorsLocal content and Niger Delta threatsNew players in the global marketSimultaneous operations rescue late project

TOTAL, with 24% interest, is the operator on OML 130 on behalf of PETROBRAS of Brazil, SAPETRO of Nigeria, CNOOC of China and NNPC of Nigeria.
AKPO: The Subsea Production System
Authors: Nelson Stuart Graham
Published: July 2010

It has been said " All deep water offshore projects are challenging??. Nowhere in the world do projects have such high commercial pressures as those which take on the challenge of Deep Water. Rarely if ever can it be said that any one field is a repeat of another. Each therefore raises its own issues which each development must solve anew. Some lessons are the same, and we forget them at our peril. Some are new challenges, and we then call on our experience of the past to rise to meet them, and hence all our experience is necessary. In the case of Akpo, many of the issues were totally new and we called on all of our experience of Deep Water fields in the Gulf of Mexico and West Africa.

The Akpo field in block OML 130, 200 km offshore Nigeria is in 1400 m water depth. It is a gas/condensate field with high pressures and high temperatures. One of the greatest challenges is to ensure that condensate and gas in multiphase flow reach the production facilities without being stopped by hydrates and wax and scale deposition. The technical challenges alone are significant, but when set against the background of increasing oil prices and high commercial pressure on the suppliers from more than one operator and more than one field, the challenges take on a new dimension. Added to that for Akpo were the issues of resources of personnel and manufacturing capacity in a very buoyant market as well as the new challenge of manufacturing in Nigeria.

This paper also addresses the challenges of the Subsea Production System of the AKPO development. It shows how the conceptual design principles are encapsulated in the simple acronym - RAM and how these lead to some key issues.

The second most important issue facing all Subsea decisions is the fact that the cost of installation - whether by Drilling Rig or by Installation Vessel - FAR exceeds (in most cases) the cost of the equipment itself. Added to that is the cost of the lost production. This cost is effectively tripled if equipment has to be retrieved and then re-installed. No Subsea Engineer ever wants to see their equipment return to the surface. Nevertheless - things do go wrong even on a single well - and in a system as large as Akpo, the opportunities for something to go wrong increase. Such is the inevitable nature of large Systems. The ability to recover and install was seen as vital. Design for installation was a vital strategy in the design process. This lead to design in order to minimize installation - and retrieval - costs.

The overall Field Layout, showing the full subsea network and its connection to the FPSO is shown in Figure 1.
Material Assessment for Souring Subsea Systems
Authors: Ramirez Felipe A. , Hill Rick , martinez Soifa
Published: July 2010

Material selection for subsea pipelines and equipments for the cases where the well fluid analysis shows elevated levels of H2S (sour service) has been extensively studied and documented during the past years. However, several cases have been reported where the fluid analysis at the start up stage does not show evidence of H2S but the risk of sour production is still present. There are two main causes for this to occur:typically, the resolution of the gas composition measurement is only valid down to 0.01 mole% (100 ppm) leaving the possibility of H2S being present in amounts between 0-99 ppm presenting potential sour conditions for high pressure systems.The H2S contents can increase during production when water injection systems are used to pressure-support the production reservoir. Seawater injection increases the H2S levels on the fluid due to microbial activity.

This paper addresses the risk associated with sour systems which were not designed for such service. The paper presents a project specific study where the presence of H2S was determined after the system was built. A material risk assessment was performed to determine the suitability of the system. The purpose is to share the lessons learned and to provide guidelines for the material assessment of souring production systems.

Introduction

Corrosion produced by hydrogen sulfide (H2S) in oil and gas production, referred to as sour corrosion, has been recognized and extensively studied for several years. The presence of H2S in the produced fluids not only generates general corrosion but also can lead to hydrogen embrittlement and cracking making the material prone to catastrophic failure. When the produced fluid is regarded as sour, the risk of hydrogen embrittlement failures due to sulfide stress cracking (SSC) or hydrogen induced cracking (HIC) may support the selection of highly priced materials reflected in abundant cost penalty on the initial capital expenditure (CAPEX) [1,2].

Several systems on the North Sea and Gulf of Mexico have been designed for sweet service (i.e. H2S is not present) since the fluid analysis at the start up stage did not show evidence of H2S. However, it has been reported that several of these systems have experienced the presence of H2S afterwards [2-5]. There are two main reasons for this to occur:Usually, the gas composition measurement resolution is only valid down to 0.01 mole% (100 ppm) and, therefore, there is the possibility of H2S being present in amounts between 0-99 ppm presenting potential sour conditions for high pressure systems.
AKPO Project Start-Up and Operation
Authors: Fournie Francois
Published: July 2010

Akpo field is located in block OML 130, 200 km offshore Nigeria in 1400 m water depth. At plateau production, Akpo produces 175,000 bbls/day of condensate and exports 320 mmscfd of gas to Bonny NLNG plant. It is the first Deep Offshore development for TOTAL in Nigeria, soon to be followed by Usan (currently in Construction phase) and Egina (currently in Basic Engineering phase).

Akpo reservoirs contain 620 million barrels recoverable reserves of a critical fluid made of very light oil up to 53° API and classified as condensate, with wellhead shut-in pressures up to 400 bars, wellhead temperatures up to 116 °C and very high GLR (Gas Liquid Ratio). AKPO is not only a giant condensate field, but also a gas field with 1Tcf planned gas export.

The Akpo Operations team has contributed to all the field development phases, from Pre-Project, Basic Engineering, Project execution (sanctioned on 25th April, 2005) to the Start-Up and Operation in a truly integrated manner with the Reservoir, Drilling and all the Project package teams.

Akpo achieved first production on 4th March, 2009, ahead of schedule, and completed the ramp-up of all the subsea and topsides facilities within only 3.5 months from the initial start-up date.

This paper presents the strategy and organization put in place by Akpo Operations to meet in a timely manner the challenges encountered for the preparation and actual start-up / ramp-up of the field, together with the actual operational performance achieved. It addresses in particular the key aspects of:The Operations organization and its evolution to adapt to the various Project locations during all phases and to match the progress pace in order to ensure full readiness for the production start-up target dateThe Operations technical preparation activities, focusing on project engineering input and validation, together with dedicated operations engineering deliverablesThe human resources mobilization and the associated training effort for the Nigerian operatorsThe management of the Site Operations during the offshore installation and hook-up / commissioning phases in Nigeria and the performance achieved in terms of coordination efficiencyThe actual production Start-Up and Ramp-Up performance and the associated lessons learned.

AKPO DEVELOPMENT

TOTAL is the Operator on OML 130 with a 24% interest. The partners are Petrobras of Brazil, Sapetro of Nigeria, CNOOC of China and NNPC of Nigeria.

Akpo is a standalone development based on a spread moored Floating Production Storage and Offloading (FPSO) moored in 1314m water depth with a storage capacity of 2 million barrels of condensate. The stabilized condensate is exported via offloading lines and a deep water buoy located 2 km away from the FPSO.
Mirage Field Multi-Column Deep Draft Floating Platform: Graving Dock Construction and Hull Fabrication
Authors: Ocker Colin , Bordlee Corey
Published: July 2010

In the fourth quarter of 2006 the first prototype multi-column deep draft floating platform (DDFP) was contracted for fabrication. The hull is a patented deep-draft floating production system with three vertical columns arranged in a triangular shape. The hull looks like a semisubmersible but behaves like a spar in terms of stability and dynamic response to waves.

With the development on the " fast track??, construction began while the details of the hull were still being designed. This presented numerous opportunities for the project team to overcome. One of the initial problems that needed to be solved was how to launch hull into the water. The project team decided to construct a graving dock, the largest of its kind on the U.S. Gulf Coast. The graving dock construction began in April 2007 and was complete in February 2008.

In January 2007 hull fabrication began. The hull was fabricated in smaller subassemblies that included the upper column, lower column, pontoons, lower raft, and the access trunks. These sections were fabricated in various locations using jigs and panel lines. The smaller subassemblies were then joined to form larger subsections.

As the subsections were completed, they were assembled in the graving dock. Each section lift weighed between 450 and 3,000 short tons and were lifted using various combinations of spreader bars, crawler cranes, lifting towers and strand jacks.

After fabrication was completed, the graving dock was flooded, the front wall of the dock was removed and the hull was ready for tow.
Well Design Requirements For Deepwater And Arctic Onshore Gas Hydrate Production Wells
Authors: Hancock Steven H. , Moridis George J. , Robertson Alexandra , Wilson Scott
Published: July 2010

Gas hydrate wells will have a number of production challenges, including maintaining commercial gas flows with high water production rates; operating with low temperatures and low pressures in the wellbore; flow assurance issues including hydrates and freezing in the wellbore; controlling formation sand production into the wellbore; and ensuring well structural integrity with reservoir subsidence and/or changes in geo-mechanical properties along the wellbore. This paper addresses these production issues and outlines the design requirements for typical deepwater and arctic onshore gas hydrate production wells.

Background

Methane gas hydrates are solid crystalline compounds of water and methane gas, in which the molecules of methane occupy the lattices of ice-like crystal structures. Methane hydrates can form and accumulate in sandstones, shales, or silts, where methane and water is present under the necessary conditions of low temperature and high pressure, as illustrated in the following figure. Hydrates can occupy the pore spaces of sands and silts, and can also be found in fractures or lenses, and in some cases can act as the matrix supporting sediments. In North America, onshore gas hydrates can be found under permafrost in the US and Canadian Arctic regions, and offshore gas hydrates can be found in the deepwater margins around the continent. Internationally, offshore methane hydrates have been discovered in deepwater margins in many locations around the world. There has been no consistent effort to map and evaluate this resource on a global scale; therefore, current estimates of gas in place volumes vary widely, possibly up to many thousands of TCF (Moridis 2010). Given the sheer magnitude of the resource, ever increasing global energy demand, and the finite volume of conventional fossil fuel reserves, gas hydrates are emerging as a potential energy source for a growing number of nations, even if only a small portion of gas hydrates can be economically recovered. The attractiveness of gas hydrates is further enhanced by the environmental desirability of natural gas as opposed to solid or liquid fuels. Thus, the appeal of gas hydrates accumulations as future hydrocarbon gas sources is rapidly increasing and their production potential clearly demands technical and economic evaluation. The past decade has seen a marked acceleration in gas hydrate research and development.
Development Of Mirage & Telemark Fields - Classification And Regulatory Considerations Applied To An Innovative Concept
Authors: Feijo Luiz Paulo , Frazer George Ross , Parker Wanda June
Published: July 2010

To meet the challenges imposed by the production of oil and gas from deepwater fields in increasingly harsher environments, new concepts of floating production facilities have been developed in recent years. These facility concepts have the ultimate goal of providing more cost effective solution through simplified construction processes, coupled with more efficient operational characteristics. They may present new technologies for which no directly applicable classification or regulatory requirements exist. To overcome the regulatory constraints, classification societies have to adapt existing requirements to the new designs to allow their development and not dampen the innovation process.

The development of the ATP Titan floating production installation for the Mirage and Telemark deepwater fields in the U.S. Gulf of Mexico using the MinDOC3 concept illustrates the process of defining the appropriate regulatory framework to be applied throughout the project. The MinDOC3 is a new concept developed for deepwater applications intended for fabrication in Gulf of Mexico yards. The early engagement of the classification and regulatory bodies proved to be instrumental in the success of the project by providing a clear explanation of the applicable standards and promoting a more thorough understanding of the concept. The cooperation between the owner, designer, classification society and regulators presented itself as a key factor in the determination of the appropriate rules and regulations to be applied.

This paper describes the process of determining the regulatory framework successfully applied throughout the development of the MinDOC3 installation for application on the Mirage field. It also describes the cooperative approach that helped the parties involved to more fully understand the concept, and to identify how innovative technology and functionalities could be harmonized with the existing classification and regulatory requirements while maintaining the feasibility of the project.

Introduction

Worldwide energy demand has been growing over the last decade and is expected to continue growing. Over the last 20 years consumption increased at an average rate of 1.92 percent annually and a steady growth is projected until 2030 (U.S. Energy Information Administration, 2009). The vast majority of the energy produced in the world comes from fossil fuels, having petroleum as the primary source. Therefore, continued growth of energy demand is heavily dependent on finding and developing new oil and gas sources.
Five Dangerous Trends in Hazardous Operations
Authors: Ebot Lambert
Published: July 2010

Description

The 5 Dangerous Trends in Hazardous Operations is a study that identifies and analyzes the major factors that lead to the continued rise in major accidents. Past accidents in various facilities; both on-shore and off; show that trends related to operation cost, knowledge drain, and asset decay are all on the rise. The study discusses the key differences between occupational safety and inherent safety, and the importance of design in hazard management.

Application

The 5 Dangerous Trends study is used to educate organizations that operate covered and hazardous facilities about the current and ever-present dangers that exist. Furthermore, the study demonstrates the difference between the focus on occupational safety and that of inherent safety. Organizations learn more about the tools and techniques; such as QRAs and HAZIDs; so as to drive initiatives in process (inherent) safety practices.

Results, Observations, and Conclusions

The study identifies 5 dangerous trends in terms of direct and indirect costs as they relate to the operations of hazardous facilities. The data is obtained from sources such as the Centre for Research of the Epidemiology of Disasters (CRED) and the Baker Panel Report. The study concludes that most major accidents still occur due to the same fire and explosions that have always affected hazardous operations. Additionally, change needs to occur soon before the experienced operators and engineers are gone.

Significance of Subject Matter

Some organizations have changed design practices in order to reduce the occurrence of major disasters; many have not. Major disasters have escalated, leading to larger financial and human losses. Instead of changing design, companies have tried to implement more complex and rigid procedures and safeguards. The study uses examples of the industrial disasters to include: the Bhopal Catastrophe, the Piper Alpha disaster, and the Texas City Refinery explosion. The study delivers the message that it is the responsibility of each individual to champion inherent safety. Companies operating within hazardous industries may develop new ways of designing process systems and effectively put an end to multi-million dollar disasters.
API RP2EQ - Seismic Design Procedures and Criteria for Offshore Structures
Authors: Younan Adel , Puskar Frank
Published: July 2010

This paper describes the updates of the API recommended practice for seismic design procedures and criteria for offshore structures. The updates are divided into two parts. The first part is a new API Recommended Practice (RP) called API RP 2EQ which contains the overall seismic design procedures and selection of seismic design criteria, applicable to all types of offshore structures. This is a modified version of ISO 19901-2 adjusted as necessary for the USA. The second part is an update to API RP 2A (RP2A) or seismic design practices for steel jackets, that follows a combination of prior RP2A practices as well as the guidance contained in ISO 19902 (steel jackets). This paper describes these updates and in particular discusses how the changes differ from prior API practice. The updated seismic documents are part of an overall API effort to update RP2A as well as merge and align with the worldwide ISO documents.

Background

The original API RP 2A seismic design procedures were developed in the 1970's and early 1980's for fixed steel structures offshore California and Alaska. There have been few updates to these design procedures since then. However, during this time, there was considerable effort by the onshore building industry and the International Standard Organization (ISO) to develop new seismic design procedures and guidance. Much of the onshore industry work was an outcome of lessons learned from large seismic events like the 1985 Michoacan earthquakes that affected the Mexico City area, the 1989 Loma Prieta earthquake in the San Francisco Bay area, the 1994 Northridge earthquake in the Los Angeles area and the 1995 Hyokogen- Nanbu earthquake in the Kobe area. These earthquakes resulted in damage and destruction of various types of structures, some of which had been designed to what was thought at the time to be adequate seismic design standards.
Platform Waste Gas Combustion: Efficiently, Safely, Reliably and Economically
Authors: Mascarenhas Audrey
Published: July 2010

The combustion of waste gas, or gas that cannot be processed economically, has attracted considerable global attention. Recently, the World Bank has been focused on viable alternatives to the practice of flaring and venting. And, since 24 billion cubic feet are flared and vented daily from oil and gas operations, the reasons are clear. Over 9,000 trillion BTU of energy and 1.4 billion tonnes of carbon dioxide are released into the atmosphere each year. These are significant contributors to global climate change, potentially harmful emissions and energy waste. But waste gas combustion is conducted in a responsible manner as there have been significant technological improvements over flaring or less efficient technologies.

Safety is of paramount importance with respect to the design and operation of offshore platforms and here the combustion of waste gases must be carried out with the highest consideration for the protection of human health and safety. The most environmentally and conservation conscious option is to capture these gases for further processing, should that be practical. The recovery and transportation of waste and fugitive gases from offshore operations, however, is both challenging and costly which has resulted in the traditional flaring of these streams. If combustion is deemed most appropriate, the selection of the combustion process can result in very diverse emissions.

An example of this is the incineration of tail gas. This yielded an annual fuel savings of over $2MM. The annual reduction of over 73,000 tonnes of carbon dioxide equivalent creates a value stream of over $1.1 MM. This is due to the more efficient combustion and the 60% in fuel utilization.

Maximizing safety and minimizing GHG and other pollutants and harmful emissions is attributable to high combustion efficiency. While combustion efficiency is a vital part of the overall performance the other critical parameter is reliability. High efficiency and reliability is a result of controlling the environment in which combustion occurs, within the proper operating range and design conditions, while ensuring that all process components have been designed to function prolifically in the marine environment.
New 9-7/8-in. HPHT Permanent Packer With New Back-Up System Provides North Sea Operator With an Effective Solution for Worn Casing
Authors: Innes Richard , Eddy Michael , Ligertwood John , Robb Thomas Ellis , Valentine Ernest
Published: July 2010

A major operator in the North Sea had experienced a problem with worn casing at the packer setting depth of an existing HPHT well, causing a leak into the production annulus. This problem required a workover, and a calliper survey was conducted after retrieving the tubing. Two large grooves along the longitudinal axis of the casing at 120° to each other were found.

Since the worn casing was the problem, a new permanent packer was required, and this paper will discuss the process required to successfully qualify and install an HPHT permanent packer that would satisfactorily address the needs for worn casing.

Permanent packers are qualified by ISO 14310 V0 in a test fixture to meet the API 5CT internal casing dimensions; however, they do not account for any wear or damage in the casing. A test program was developed to test the packer for both HPHT well conditions and worn casing. The test program consisted of the following:Install the packer in 9-7/8-in casing and flow test to 3 bpm at 180°F to verify that the circulation around the packer would not damage the Aflas® element.Perform an application test using synthetic oil to mimic packer loading until failure, including setting, production, and hot/cold shut in.; apply 9,000 psi annulus pressure to support the casing during testing. In this case, the maximum temperature was 343°F or above for over 200 hours.Perform a modified ISO 14310 V0 test at 450°F with 15,000 psi differential pressure and 400,000 lbf tension and compression.

The packer passed all tests with no extrusion of the three-piece multi-durometer Aflas® element, and no leaks were detected at any of the load points in the application (liquid) test or modified ISO V0 gas test.

The discussion will include information on the packer design, HPHT tests in worn casing, and casing acceptance criteria. This test was the first packer test performed in worn casing that demonstrated the capability of a compliant back-up system to support the entire element in worn casing and at the HPHT conditions.
Risk Mitigation in International Oil & Gas Developments
Authors: Otillar Steven P.
Published: July 2010

Preface

This manuscript sets the stage for a panel discussion, " Risk Mitigation in International Oil & Gas Developments??, scheduled for Tuesday, May 4, 2010. The panel participants include:

Panelist

Guy Dayvault - Director, Gazprom Marketing & Trading USA, Inc. Mick Jarvis - BD Manager Commercial Negotiations, ConocoPhillips Pietro A. Milazzo - Manager, Latin America Region, Weatherford International, Ltd. Christopher P. Moyes - President, Moyes & Co., Inc. and AIPN President Claudi Santiago - President & CEO, GE Oil & Gas Dee Simpson - Senior BD Advisor, Noble Energy (Invited)

Moderator

Steven P. Otillar - Partner, Baker & McKenzie LLP and AIPN US Region Director

Organizers

Christopher P. Moyes - President, Moyes & Co., Inc. and AIPN President Sandeep Khurana - Advisor, Devon Energy Corporation and OTC Program Chair

Oil and gas exploration is a technology driven industry, with the most substantial new deepwater discoveries pushing the outward limits and capabilities of existing methods. Exploration and production companies are having to explore previously untapped emerging markets, overcome barriers to maximize existing fields, and exploit previously uneconomic projects. Major exploration and production projects are extremely capital intensive and require multi-year corporate commitments at a time when access to capital on a global basis is somewhat limited. While the economy appears to have turned the corner and commodity prices are stabilizing in many markets, overall uncertainty remains.

In this regard, it is of paramount importance for companies to be able to protect their international investments through legal, financial, technical and other means. This panel will seek to identify the primary risks involved in an international upstream oil and gas exploration and development project, and identify tools and methodologies to mitigate such risks. After a brief introduction from each panelist, this unique group of panelists will examine upstream risks and mitigation techniques from their own point of view as representatives of a major integrated International Oil Company (" IOC??), an independent IOC, a National Oil Company (" NOC??), a Service Company, and a International Financial Advisor. Active audience participation will be encouraged to vote on how a certain project risk should be approached, such as host country security, protection of intellectual property, or securing declarations of commerciality to satisfy terms of a production sharing contract. Then our panelists will address the situation and how they would recommend that their company should handle such project risk.
Changing the Game Bit by Bit
Authors: Fryklund Bob
Published: July 2010

Background

Exploration is one of the pillars of supply and is perhaps the most storied of them due to the risks, with images of remote harsh areas, fortunes won and lost and geoscientists scouring across the globe in search of the next big play. Yet due to these same risks, when commodity prices drop, it is the first to suffer budget cuts.

A historical review of discoveries shows the peak of oil discoveries was in the mid 60's and gas the mid 70's. Since then exploration has yielded an average of almost 13 Bbo per year, with a recent uptip in 2008 to 15 Bbo thanks mostly to deepwater. Giants, those fields greater than 1 Billion barrels equivalent and the holy grail of the exploration hunt, have until recently averaged only around 12 per decade or a little more than one per year. The last two years has seen at least 4 per year. Much of this can be attributed to the opening of several new huge hydrocarbon provinces- Brazil's subsalt, West Africa's Ivorian Basin Maghony trend, the US GOM Lower Tertiary and Kurdistan Iraq's Zagros Foldbelt. Surprisingly around 40 % of the giants are still coming from onshore.

A recent IHS CERA report shows that exploration will have to contribute some 20 mmb/d of production in 2030 to meet growing demand. This panel will look at the future of exploration and what obstacles we face towards meeting the future targets for exploration.

Key Topics

Amongst the topics to be discussed will be:Where are the next new petroleum provinces or plays that will change the game ?Has the unconventional revolution changed conventional exploration thinking ?Are we investing enough to meet the goal ?Access to opportunities has changed so how do you play the new game ?Have we reached a technology plateau ?What area would benefit the most from a technology break through?What tools do we need ?Are we making progress in solving the great crew change ?Will government policy and legislation make it impossible ?
What is the Right Global Energy Mix? Desired Transition Pathways to an Affordable and Secure Energy Future
Authors: Hassan Gamal A.
Published: July 2010

The recent global financial crisis has brought about a significant deterioration in near-term energy demand and a consequential reduction in supply which has possible longer-term implications. Secondly, climate change considerations and greater regulation of the energy mix are also on the horizon. The combination of these - one being a mega event and the other a mega trend - already had significant near-term impact on the oil and gas sector and could also lead to a fundamental transformation in the long-term.

Even with the projected reduction of carbon in the energy mix, it is expected that the level of energy demand in 2050 will be such that it will require similar levels of oil and gas production as today. Since oil and gas production declines naturally, sustaining it to 2050 effectively requires re-building the equivalent of today's oil and gas business over the next 40 years - and doing so from more technically challenging deposits.

At the same time, the world increasingly desires lower carbon energy. Governments and industry are responding. A rapid transition to green energy will likely prompt the introduction of more green incentives and increased regulation of fossil fuels. This in turn could lead to an increase in the total cost of energy, since most renewable energy options are inherently more expensive to scale up than energy derived from fossil fuels.

All of this raises key questions. What are the desirable energy mix and transition pathways which will provide the world with affordable, secure and increasingly lower-carbon energy?
Deep Ocean Seafloor Resource Exploration - Technique Enhancements for a Rapidly Growing Industry
Authors: Stevenson Ian
Published: July 2010

Nautilus Minerals', the world's leader in exploration and development of deep ocean seafloor resources, is today focusing its exploration effort on its high grade polymetallic Seafloor Massive Sulphide (SMS) resource pipeline expansion in the Western Pacific. These high grade copper, gold and zinc deposits are typically located near deep seafloor tectonic plate boundaries in back arc basins.

Exploration for seafloor massive sulphides has until recently relied on exploration techniques developed by Marine Scientific Research groups. It has involved the use of;" Plume hunting?? techniquesVarious geophysical techniques to help image prospective zones (e.g. deep tow side scan sonar, magnetics, electrical methods, etc)ROV based sampling

Nautilus' entry into this industry has seen it focus on exploration technique development and improvement that has realised;Improved plume hunting/water sampling techniques.Electro-magnetic imaging of near-surface, copper-rich mineralisation.Improved core recovery through the development of ROV based drill platforms.

The development of these new techniques culminated in the world's first NI 43 101 compliant seafloor resource statement, and the rapid discovery of numerous new seafloor massive sulphide mineralised deposits in the Western Pacific.

An opportunity exists for the seafloor resource and offshore exploration industries to further develop or adapt offshore exploration / survey techniques and accelerate the establishment of this new and predominantly untapped industry. Well-established existing techniques and technologies that can be adapted for SMS exploration include:Fully Autonomous AUV's, with ultra-high resolution sonar mapping capabilities.AUV based magnetic and gravity systemsDeep sea shallow geophysical techniques (electrical, acoustic, and other) for 3D ore body imaging and characterisationImproved drilling technology including down-hole logging.
Walking with Music Is a Safe and Viable Tool for Gait Training in Parkinson's Disease: The Effect of a 13-Week Feasibility Study on Single and Dual Task Walking
Authors: de Bruin Natalie , Doan Jon B. , Turnbull George , Suchowersky Oksana , Bonfield Stephan , Hu Bin , Brown Lesley A.
Published: July 2010

This study explored the viability and efficacy of integrating cadence-matched, salient music into a walking intervention for patients with Parkinson's disease (PD). Twenty-two people with PD were randomised to a control (CTRL,n=11) or experimental (MUSIC,n=11) group. MUSIC subjects walked with an individualised music playlist three times a week for the intervention period. Playlists were designed to meet subject's musical preferences. In addition, the tempo of the music closely matched (±10–15 bpm) the subject's preferred cadence. CTRL subjects continued with their regular activities during the intervention. The effects of training accompanied by “walking songs” were evaluated using objective measures of gait score. The MUSIC group improved gait velocity, stride time, cadence, and motor symptom severity following the intervention. This is the first study to demonstrate that music listening can be safely implemented amongst PD patients during home exercise.
Hierarchical Formation of Fibrillar and Lamellar Self‐Assemblies from Guanosine‐Based Motifs
Authors: Neviani Paolo , Sarazin Dominique , Schmutz Marc , Blanck Christian , Giuseppone Nicolas , Spada Gian Piero
Published: July 2010

Here we investigate the supramolecular polymerizations of two lipophilic guanosine derivatives in chloroform by light scattering technique and TEM experiments. The obtained data reveal the presence of several levels of organization due to the hierarchical self‐assembly of the guanosine units in ribbons that in turn aggregate in fibrillar or lamellar soft structures. The elucidation of these structures furnishes an explanation to the physical behaviour of guanosine units which display organogelator properties.
Speaking the language of the kingdom of God in the context of a society in transition
Authors: De Wet Friedrich W.
Published: July 2010

Venturing to speak the biblical language of the kingdom of God, with its distinct covenantal intensity, in the context of a South African society in transition from paternalistic power structures to liberal democratic structures is not easy. How should the language of the kingdom of God be spoken in a society that demands ‘non-intrusive’ and ‘politically correct’ speech without – in the process – rendering the intense intentionality of its covenantal roots to that of a speech without zeal? Having to face the daunting task of ‘translating’ kingdom language into a type of language that suits the present-day context without sacrificing or diminishing its powerful intentionality demands the development of a new sensitivity. Such a sensitivity is required to incentivise the accommodation of the dimensions of truthful, authoritative and authentic communication in spoken language. In this research article, the implications of the speech act theory, as pioneered by scholars such as J.L. Austin and J. Searle, are utilised to identify possible markers for such a venture. Insight into the locutionary, illocutionary and perlocutionary dimensions present in speech acts is indicated as a relevant starting point for attempting to obtain a more comprehensive and perspective-rich understanding into speaking the language of the kingdom of God in a way that fits the present South African context.
Transformational leadership in merging higher education institutions: A case study
Authors: Chipunza Crispen , Gwarinda Shungu A.
Published: July 2010

Orientation: The use of transformational leadership in the implementation of merger and incorporation policy in the higher education sector is well documented in other parts of the world and not in countries in transition like South Africa.Research purpose: The objectives of this study were to establish an understanding of ‘transformational leadership’ and to determine the extent to which it was employed by leaders in an institution of higher education which had incorporated another institution.Motivations for the study: The study provides a starting point, not only for the successful implementation of higher education changes in the future but also the building of leadership commitment and alignment to the proposed changes in the sector as well as the development of institutional leadership teams to take responsibility for any other transformation processes.Research design, approach and method: The population of the study consisted of 350 full-time employees of the institution who had experienced the incorporation process. Two samples – one consisting of six executive management leaders and the other consisting of 153 employees – were used. Both qualitative and quantitative research approaches were employed using the case study method.Main findings: Results showed that transformational principles of idealised influence, intellectual stimulation, and inspirational motivation principles were used more than others and that employees were generally not satisfied with how the incorporation process had taken place.Practical/managerial implications: The results of the study affected the attitude and satisfaction of the employees in this study.Contribution/value-add: The study reveals that leaders in the institution played key roles such as shared vision, team work and the creation of an enabling environment. An important point that has emanated from this study is the evidence that during transformation, a lack of strategic direction and empowering of followers and capacitating them leads to dissatisfaction with the whole process, despite the transformation process being declared a success.
HR competencies at a merged Higher Education Institution
Authors: Schultz Cecile M.
Published: July 2010

Orientation: Certain human resource (HR) competencies are essential to assist with the dynamics of change in the higher education landscape.Research purposes: The aim of this study was to determine the HR competencies at a merged higher education institution. Other objectives were to establish the satisfaction of academics, administrative staff and management regarding the HR competencies and the importance thereof.Motivation for the study: Human resource professionals require assistance by providing HR competencies necessary to add value at a merged higher education institution.Research designs, approaches and methods: A quantitative research design was employed as the research strategy. The questionnaire was based on the literature, the business plan and the HR balanced scorecard report. The target population was 1363 permanent staff on one campus and the response rate was 28%. A principal factor analysis, spider charts and box plots were utilised for data analysis. The results indicated business knowledge, HR practices, personal skills and management skills as the vital HR competencies.Practical implications: Staff were not satisfied with the current HR competencies and consequently this necessitated attention to improve the deficient areas.Contribution: This study shows that limited research was done with regard to HR competencies in the South African higher education backdrop.
Job insecurity, leadership empowerment behaviour, employee engagement and intention to leave in a petrochemical laboratory
Authors: Van Schalkwyk Sonet , Du Toit Danie H. , Bothma Adriaan S. , Rothmann Sebastiaan
Published: July 2010

Orientation: Engaging individuals at work plays an important role in retaining them. Job security and leadership empowerment behaviour are antecedents of employee engagement.Research purpose: The objective of this study was to investigate the relationship between job insecurity, leadership empowerment behaviour (as perceived by the employees who report to leaders), employee engagement and intention to leave their jobs in a petrochemical laboratory.Motivation for the study: Knowledge of the effects of job insecurity and leadership on employee engagement and turnover intention will contribute to improved talent management.Research design, approach and method: A correlational design was used. A total of 169 employees in a petrochemical laboratory were studied. The measuring instruments included the Job Insecurity Index, the Leadership Empowerment Behaviour Questionnaire, and the Utrecht Work Engagement Scale. Two questions were used to measure intention to leave.Main findings: The results showed that job insecurity was not statistically significantly related to employee engagement and turnover intention. Leadership empowerment behaviour contributed statistically significantly to employee engagement and low turnover intention. Employee engagement partially mediated the relationship between leadership empowerment behaviour and turnover intention.Practical implications: Leaders should be developed to show empowerment behaviour, because it affects employee engagement, which in turn affects their turnover intentionContribution: This was the first study that demonstrated the effect of empowerment behaviour of leaders on the engagement and turnover intention of employees.
Financial health and sense of coherence
Authors: Barnard Antoni , Peters Dorè , Muller Helene
Published: July 2010

Orientation: This article reports on a quantitative-relational study addressing the impact of sense of coherence (SOC), which is a psychological-wellness construct, on the financial-health profile of employees in an insurance company.Research purpose: The objective of the study was to explore the relationship between psychological wellness as operationalised in the SOC construct and in financial health.Motivation for the study: Financial pressure can be a major stressor in the workplace, affecting employees’ ability to function optimally. The debt crisis in South Africa is therefore necessitating employers to invest in the financial health of their employees. In light of the National Credit Act 34 of 2005, employers should, in fact, provide debt counselling to employees struggling with financial problems. In the South African context, however, studies investigating the potential influence of psychological-wellness constructs on financial health are lacking.Research design, approach and method: A cross-sectional survey design was applied and a quantitative-relational approach followed. From the 1 100 employees in a financial insurance company, 435 completed questionnaires were received.Main findings: The empirical results indicated a significant relationship between the variables, confirming that a stronger SOC impacts positively on employees’ financial health. A stronger SOC therefore relates positively to more effective debt management and retirement planning.Practical/managerial implications: The findings emphasised the importance of debt management and retirement planning being addressed and integrated into employee-assistance strategies and programmes.Contribution/value-add: This study is a significant step in addressing financial health from a psychological perspective.