bluuebunny/crossref_metadata_2025_split huggingface dataset:
SS-FA - Flow Assurance Challenges in the Papa-Terra Project
Authors: Santos Junior Jesulino , Paternost Guilherme , Condessa Diego 
Published: July 2009

Abstract
The Papa-Terra project is among the most complex subsea developments executed in Brazil. Flow assurance strategies were a key driver because of the extreme water depth, the high viscosity and low API (&lt;15 API) of the produced fluids. Petrobras has been considering the first TLWP, which will be installed 350 m away from a FPSO, with multiphase flow between units.
This project demanded a new approach on fluid behavior model and the adoption of some technologies not applied in the Campos Basin yet due mainly to emulsion impact in fluid viscosity. For example of these technologies are a dry completion unit with high power ESP's installed in deep water (4000 ft) and electrical heated flexible pipes. As another example the studies resulted in a new fluid model to be used in flow simulator that considers viscosity data measured in laboratory.
This paper gives an overview of the main flow assurance challenges faced on the basic project development, that include heavy oil modeling applied to an offshore deepwater field, multiphase flow transport between two production units (DCU and FPU) and dry completion unit using high power ESP as lift method.

Introduction
The Papa-Terra field is located offshore on south of Campos Basin, approximately 110 km from the coast of Cabo Frio, at Rio de Janeiro State, under 400 to 1400 meters of water depth (Figure 01). The field is at the Exploratory Block BC-20, 100 km south west from Petrobras Pampo's platform. It's a joint venture between Petrobras - responsible for the operation- and Chevron.
Subsurface Safety Valve Control System for Ultradeepwater Applications
Authors: Bane Darren , Peoples Brock 
Published: July 2009

Abstract
The typical subsurface safety valve for deepwater high-pressure/high-temperature (HP/HT) subsea applications employs many operational techniques including pressure-balanced pistons using gas energy for assisted closure, hydraulic balance lines, or a heavy spring to ensure failsafe closure in the event of an emergency shutdown. Each of these techniques has an impact on the valve's characteristics, which can raise concerns about valve operation or reliability.
A solution is desired that minimizes valve opening pressures by balancing tubing pressure, yet allowing extreme valve setting depth capability without compromising operational characteristics such as high opening pressures or pressure-balanced pistons using long term valve gas charge storage.
This paper discusses a new surface-controlled subsurface safety valve (SCSSV) control system that uses the low opening pressures of a tubing-pressure-insensitive safety valve, without gas-charged assisted closure or dual control lines for balanced line applications. This system eliminates the need for pressure reversals across the valve's critical actuating piston seals, which increases valve reliability and sealing performance while maintaining tubing pressure insensitivity. This control system allows for deeper valve depth capabilities compared to the methods previously discussed, allowing the safety valve to overcome annulus pressure buildup scenarios not possible in current SCSSVs for the applications described.
This paper presents design considerations using an SCSSV control system allowing technological accomplishments not previously possible with existing SCSSV technology. Test results demonstrate the suitability of the new control system design for previously unattainable valve operating depths in aggressive well designs or annulus pressure buildup situations while enhancing valve reliability.

Introduction
Deepwater production and operations in the outer continental shelf (OCS) is defined by the United States Minerals and Management Service (MMS) as operations taking place in OCS water depths in excess of 1,000 feet or 305 meters1. Given that deepwater discoveries are considered higher-risk ventures with unique operational, environmental, health, and safety concerns, it is no surprise that the visibility and criticality of subsurface safety valve designs for these applications are taking center stage in critical field completions.
Many projects in the Gulf of Mexico are taking place in excess of 7,000 feet of water depth and new discoveries support the future of deepwater development as technically feasible and financially justifiable. Existing technologies for subsurface safety valves each pose unfavorable features or risk when exceeding the earlier noted depths. Recognizing the high costs associated for a deepwater well workover, every precaution must be taken to ensure optimum valve performance and reliability.
Henning Devices: A New Class of VIV Suppression Apparatus for Offshore Tubulars
Authors: Allen Donald Wayne , Lee Li , Henning Dean L. 
Published: July 2009

Abstract
This paper introduces a new class of vortex-induced vibration (VIV) suppression apparatus, Henning devices. Test results for a number of such devices are presented and discussed. One of the main advantages of these novel devices over helical strakes and streamlined fairings is that the coverage density required to be effective is reduced from about 70 to 80% or more to approximately 20 to 25%. The drag on the tubulars with the light coverage density is therefore significantly reduced, compared to that of helical strakes. An additional advantage of Henning devices over fairings is that they are not required to rotate to be effective at reducing VIV, as evidenced by the tests. With the application of this new type of hardware, great cost savings can be expected.

Introduction
Offshore tubulars used in oil and gas exploration and production are often protected from vortex-induced vibration (VIV) with add-on hardware. Among the various types of suppression devices, helical strakes and streamlined fairings are the most common. These apparatus are effective at reducing VIV, though each has its own advantages and disadvantages [1,2]. One common feature to strakes and fairings is that a coverage density of greater than 70 to 80% is normally required to effectively mitigate VIV [3]. For example, if a suppression coverage length of 1,000 ft of the tubular is determined necessary, the required amount of suppression, in linear feet, should be at least 700 to 800 ft spaced evenly along the 1000 ft length.
Extensive VIV testing has been performed at Shell Westhollow Technology Center current tank, to explore more efficient suppression devices. As a result, a new class of VIV suppression hardware was discovered in 2006. In early 2007, a general methodology for VIV suppression was developed based upon the understanding of the test results. Additional tests, at higher Reynolds number, were subsequently conducted to further validate these novel concepts.
This paper presents and discusses some of the test results for this new class of suppression devices. First, the test facility and setup are described, followed by an introduction of various types of Henning devices. Test results for three examples (tribladed, square, and fixed 4-bladed devices in a range of applications) are presented next to illustrate various features. Conclusions are drawn thereafter.
The information presented in this paper should be of interest to offshore engineers and project managers involved in platform, mooring and riser design as well as project execution, as it discusses some of the latest developments in VIV suppression.
SS - Ocean Mining "Extending Deepwater Technology to Seafloor Mining"
Authors: Yu Chenten Alan , Espinasse Philippe 
Published: July 2009

ABSTRACT
This paper builds on the experience of designing, and building production and drilling risers for oil and gas fields and extends into deepwater mining. With the recent discovery of high grade seafloor massive sulphides (SMS) in Papua New Guinea, New Zealand and elsewhere, there is a resurgence of interest in deep ocean mining. This renewal of interest has been spearheaded by Nautilus Minerals through its Solwara 1 project; in 1,700 m of water, with a production rate of 2.0 million tons per annum. Neptune Minerals Plc also endeavors to produce SMS with a similar production rate. This paper describes the two different deepsea SMS lifting concepts being developed by the two projects and the design challenges encountered during the course of the project executions for the two mining companies.
Nautilus plans to explore other adjacent fields with water depths reaching and surpassing 2500 m. It will use a riser and a lift system that utilizes a steel vertical riser combined with a bottom-suspended displacement pump for lifting the mined ore slurry. Waste water is separated from the slurry and then discharged at the seafloor. Many technical challenges have to be overcome to achieve the required performance, especially in the areas of lifting solids in a two-phase flow. Among these challenges are erosion and corrosion issues, two-phase flow assurance technology, methods of defining the system operational windows, and the overall integration of the equipment packages for the brand new industry.
Separately from Nautilus, Neptune Minerals Plc commissioned an engineering scoping study for technologies for the commercial development of SMS deposits offshore New Zealand. The scope of the conceptual study was to screen options regarding subsea mining tools and strategy, alternative SMS lifting methods, and SMS processing.
The SMS mining options integrated existing marine equipment and technologies, and the recommended lifting system incorporates a flexible production riser with an airlift system connected at the seafloor to an ore crusher and seafloor miner.
The objective of this paper is to describe the two deepsea SMS lifting concepts and approaches to help pave the way for the future development of systems of other potential miners. Both authors have been involved extensively in the development of deep ocean production and drilling systems for the last two to three decades. Various parts of their experiences were used for the overall deepsea mining system configuration and for the evaluation of the airlift and displacement pumps for lifting SMS from the seabed to the surface. The results depicted here draw heavily upon those experiences.
SS Ocean Mining: Development of Environmental Research related to future Deep Sea Mining - Are Concerns justified and what should be done?
Authors: Schriever G. 
Published: July 2009

Abstract
During the past fifty years, the deep sea has moved more and more into the realm of societal interest. Waste dumping into and ore mining in the deep-sea were discussed and the international community agrees that environmental considerations and further research on potential impacts on the largest environment of our earth (about 60%) are obligatory before such industrial intrusions start. Even during the initial exploration phase on polymetallic nodules at the beginning of the 1970s, environmental studies were being conducted: Deep Ocean Mining Environmental Study (DOMES) and Metalliferous Sediments Atlantis II Deep (MESEDA) both launched about 30 years ago. The second phase with large-scale in-situ experiments called Disturbance and Re-colonization Experiment in a Manganese Nodule Area of the Deep South Pacific Ocean (DISCOL) (Germany) and Benthic Impact Experiment (BIE) (USA, Soviet Union, Japan, the international consortium Interocean Metall, and India), commenced their studies between 1988 and 1997. Results of these experiments and accompanying initiatives such as those of the German interdisciplinary advisory TUSCHgroup (from German Tiefsee-Umwelt-Schutz), are reported and discussed. In 2001 the International Marine Minerals Society published its " Code for Environmental Management of Marine Mining?? and during the Deep-Sea Minerals and Mining Conference in Aachen/Germany representatives of the mining companies Nautilus and Neptune reported collecting initial environmental baseline data in areas of future marine massive sulphide mining. Based on recent knowledge and experiences, recommendations for responsible environmental care related to deep-sea mining are described.
The United Nations Convention on the Law of the Sea (UNCLOS) places the responsibility for the environment on States for mining in exclusive economic zones (EEZs) and on the International Seabed Authority (ISA) for the exploitation of the resources in the Area, all regions beyond EEZs. Therefore, environmental regulations may develop independently and somewhat controversially. Harmonized directives should be strived for. From 1998 to 2007 the ISA has held several workshops in which different aspects of future mining of mineral resources were discussed. An overview is given here.
Evaluating the Loading and Structural Response of an Offshore Platform Using Integrated Large and Small Scale Testing Combined With Diffraction and Finite Element Analysis and Offshore Measurements
Authors: Buchner Bas , Heerink Robert , de Wilde Jaap , Witz Joel , la Cour Hjelholt Karen 
Published: July 2009

Abstract
After discussing the specific roles of model tests, simulations and offshore (full scale) measurements for the evaluation of offshore structures in general, the paper applies this integrated methodology to the investigation of the loading and structural response of the South Arne platform with the aim of extending the platform's capabilities. The South Arne platform deck is supported by a combination of a large volume concrete Gravity Based Structure (GBS) and a slender steel lattice structure. This resulted in a unique project, including the novel combination of small scale tests of the complete structure (GBS and lattice tower) with large scale component testing of parts of the lattice tower to limit and quantify scale effects on these slender members. The paper discusses the different phases (and scales) of model testing and also highlights the related Finite Element (FE) and diffraction calculations and offshore (full scale) measurements.

INTRODUCTION
In the process of evaluating an offshore structure during its design or while in operation, model tests, simulations and offshore (full scale) measurements all clearly complement one another (Figure 1). All three have their specific roles, strengths and limitations [1] which are summarised below.
SS: Exploration Prospect Interpretation and Risking Using Modern Geophysical Technology - Marine Applications of Highest Possible Resolution Imaging
Authors: Neidell Norman S. , Cuttell Andy 
Published: July 2009

Abstract
The classical CDP imaging method approximates a zero source-receiver offset view under each surface symmetry position for the sources and receivers used. Marine seismic surveys are inherently two-dimensional in nature. Nevertheless, there is bone fide diffractive information content. Imaging between different traverses relies solely on this diffractive component. Many migration methods treat such contributions in approximation..
A final CDP-based image can deliver good to excellent data quality. We investigate here the effect of parameters such as the number of data planes, separation of the planes, and other such factors on the resulting imaging character.
One particular imaging method is called the Highest Possible Resolution Seismic Image. In order to most effectively use the resulting extended spatial and reflection time resolution, a trace inversion is used to display seismic datat. Color presentations which significantly extend the visual dynamic range are also used. This allows better access to the full information content of the images. Examples will show these results and further enlighten geoscientists about basic seismic imaging considerations, with emphasis on resolution which have particular relevance to important applications such as 4D surveys.

Introduction
Classical CDP imaging approximates a zero source-receiver offset view under each surface symmetry position for the paired sources and receivers used. Marine seismic surveys however, are inherently two-dimensional in nature even when multiple streamers and sources are deployed. This character results from combining data acquired using parallel passes of the vessel.
There is bone fide diffractive information in marine data which is derived laterally, but away from the basic survey plane of each traverse. When we image subsurface locations between different traverses, we rely primarily on this diffractive content. If we formulate a travel-time relationship as a function of lateral offset, we can see how the image relates to those parameters about which we have some information - source position, receiver location, velocity, etc. In fact, most current migration methods do approximately correct for such contributions.
CDP Imaging methods can be effective despite using only reflective returns plus very limited diffractive components. The marine 3D final image can deliver good to excellent data that approaches the quality of full 3D imaging as on land for example, which has more diffractive contributions as well having a greater diversity of azimuths. We investigate here the effect of parameters such as the number of planes, separation of the planes, and other factors on the resulting imaging information content.
Future Vision: The Next Revolution in Production Operations
Authors: Bartram Mark A. , Wood Tony 
Published: July 2009

Abstract
In recent years there has been a proliferation of onshore control centres and advanced collaborative environments supporting the digitization of offshore oil and gas production. Information and communications technologies have facilitated this ‘digital’ evolution. To-date the results have been impressive, improved productivity and economics, together with health, safety and environmental benefits have been demonstrated. New advances in digital technologies are now poised to revolutionize how engineers and oil and gas professionals collate, visualize and interact with complex information, from real-time sensor data through to ‘fuzzy, asynchronous chat’ from instant messaging and other internet based communications tools.
This paper presents a review of how the next generation information and communication technologies are impacting complex, virtualized operations in industries such as the military. Case studies and lessons learned are presented together with insights and experience on how these findings can be applied to offshore production operations.
3D Petroleum Visualization: Workflows and Collaborative Solutions to Identify New Exploration Plays, Enhanced Reservoir Characterization and Improved Drilling and Wellbore Placement.
Authors: Love Frank , Purday Nicholas 
Published: July 2009

Abstract
Emerging plays, deeper zone exploration, along with complex reservoir development require the best possible workflows and collaborative solutions in today's competitive environment. The seismic amplitude play has been exhausted, today's E&P Companies must focus on the classic prospect and field elements of reservoir, trap, and charge. Deepwater field appraisal, development, and production operations increasingly require collaboration of multiple disciplines. This paper will evaluate how visualization workflows are used to de-risk reservoir presence and complexity. We will show how enhanced imaging tools and structural evaluation technology can further the understanding of trap risk and fault compartmentalization. How using 3D Petroleum Basin Modeling technology we can better predict charge potential, gas verses oil, and the presence of over-pressure. Enhanced geologic risk analysis through the use of 3D-Visualization workflows is essential to make commercial decisions in high cost deepwater and international settings. Reducing well count through better understanding of reservoir complexity and early prediction of reservoir performance can be enhanced through visualization technology. Of paramount importance to E&P Companies is safe drilling and risk reduction through the integration of geologic models with drill technology and pre-drill planning in a fully 3D environment. An integrated collaborative approach using visualization is increasingly needed to bring the basin wide knowledge into a single frame.3D-Visualization is no longer a game changer technology, but a necessary tool used by petroleum professionals. Companies which fail to fully adopt visualization technology are now at a disadvantage.
SS: Testing in the Offshore: Philosophies for dynamic positioning in ice-covered waters
Authors: Kuehnlein Walter L. 
Published: July 2009

Abstract
Approximately one third of the world's known and not yet exploited reserves of hydro carbons are in Arctic and Subarctic areas. Consequently, the offshore technology is going towards Arctic. New developments for operation in ice are generating new exiting challenges for offshore and ship building industries all over the world.
The paper describes the major challenges of dynamic positioned vessels in ice-covered waters. As the forces acting on vessels in ice and also their response are substantial different from the behavior in open waters, new philosophies and strategies have to be developed: How to keep vessels or offshore structures at a given position.
Based on model test results from HSVA the paper explains the main challenges of dynamic station keeping in ice and describes the consequences on station keeping philosophies and strategies for ships and offshore structures in ice. As up to now no dynamic positioning system exists for ice covered waters the paper illustrates a new approach in order to reach this goal.
The paper gives by far not a complete description of dynamic positioning of vessels in ice. But it summarizes where we are and what needs still to be done.

Introduction
It is estimated that the Arctic contains more than one third of the world's undiscovered oil and gas reserves. Although some development has already been undertaken, the region remains one of the last energy frontiers. At the same time, the region is also one of the most difficult areas in the world to work in, due to its remoteness, the extreme cold, dangerous sea ice, and its fragile environment. Major energy companies are already getting prepared to get into the Arctic, taking precautions to operate safely and responsibly.
This is not the first run to the Arctic. Petroleum companies entered into the Arctic already half a century ago. Experiences from past Arctic developments show the potential hazards of further exploration in the area. A key challenge will be developing and deploying solutions, which are currently at the cutting edge of technology. The Arctic Ocean is the only major sub-basin of the world's oceans that has only occasionally been sampled by deep sea drilling. Today the properties of the Arctic Ocean are being focused upon by both researchers and commercial oil and gas drilling companies. Research core drilling is of great importance for the researchers because it allows them to increase their knowledge about that large ice covered area. And, of course, high energy prices in the future, similar to the ones we have already seen during last summer, make it profitable to explore for reserves and to produce energy even in the ice covered waters of the " High North??.