bluuebunny/crossref_metadata_2025_split huggingface dataset:
Viscoelastic Properties of Marine Sediments
Authors: Carpenter Samuel H. , Thompson Louis J. , Bryant William R. 
Published: October 2008

ABSTRACT
Because of their high moisture content, marine sediments have characteristics of both solids and liquids. Being neither liquid nor solid it is difficult to evaluate material 'constants using conventional soil-testing equipment .or conventional liquid viscometers. However, these properties must be evaluated if problems such as anchor resistance to motion, submarine bearing capacity, and slope instability problems are ever to be solved.
Before properties can be evaluated, a theory must exist. Nonlinear viscoelastic theory was used and a simple shear device called the shear viscometer was developed. From cores taken in the Gulf of Mexico it was found that the shear resistance of marine sediment was the sum of an exponential function of shear deformation and a function of the one third power of the rate of shear deformation.
The shear resistance can also be empirically related to more conventional tests such as vane shear, moisture content, liquid limit, specific gravity, and the depth from which the sample was taken.

INTRODUCTION
Investigations into the, engineering properties of marine sediments have slowly been increasing. The bulk of published literature has been written from the geological point of view with fragments of information on the engineering properties being available. The recent increase of interest in the marine floor as a construction area has brought about an increase in the amount of study being devoted to the engineering aspect of marine sediments.
One area of rapid expansion has been the field of projectile penetration into marine sediments. Thompson has derived the theoretical expressions for the penetration phenomena. 15 There are several reports and conferences that detail the scope of study being conducted in this field.8,6,,17
The ability of projectile penetrometers to study the nature of soil deposits in inaccessible regions has been shown by Caudle et al.5 The proper use and interpretation of penetrometer data coupled with the knowledge available from laboratory testing will yield much information that could aid in conducting wide area soil surveys very cheaply.
The application of penetration theory to marine sediments has resulted in a need to understand the dynamic properties of these sediments. Of all the properties, it is apparent that viscosity is the term most often discussed when using marine sediments. Dynamic shear studies will lead to improvement in the areas ofdesign of sample devices to take long undisturbed samples of marine sediment,design of penetration anchors and buoy anchoring systems,obtaining soil information in the deep water environment to great depths anda better understanding of the mechanics of marine sediment.
It is apparent that a study of the dynamic properties, with the viscosity term being stressed, will aid in understanding the penetration phenomenon as well as other engineering problems that occur on the sea floor.
Golfinho Project-Well Construction
Authors: Buchner Bas , Bunnik Tim 
Published: October 2008

Abstract
The Golfinho Field is located in the Southeastern coast of Brazil, at water depths between 1,300 and 1,640m and is the first offshore deepwater development in the Espirito Santo Basin. The field has two main oil reservoirs - Campanian, with 40° API oil, and Maastrichtian, with 28° API. The field has been developed through horizontal wells. This paper describes some drilling and completion operations, the equipment used, as well as some lessons learned during the course of the work.
Two kinds of completion systems - conventional and one-trip completion - have been used. Open Hole Gravel Packing was also installed in all the wells to control sand production. The wells which at first flow naturally are also equipped with continuous gas lift and electrical submersible pumps to be used later when artificial lift becomes necessary.

Introduction
The Golfinho Field was discovered in July 2003 by the wildcat well 1-ESS-123. Located at water depths between 1,300 and 1,640 m, it is 80 km away from Vitoria, the capital city of the state of Espirito Santo (see Figure 1). The field was declared commercially feasible in January 2004, after which the Brazilian Regulatory Agency granted PETROBRAS with a license for exploitation. This would be the first deepwater oilfield development project in the Espirito Santo Basin. Two Floating Production Storage and Offloading (FPSO) units were then leased by PETROBRAS to develop the Golfinho Field. The first one, FPSO Capixaba, was leased from the Swiss SBM to develop Module 1 of the Golfinho Field; and the second, FPSO Cidade de Vitoria, was leased from the Italian Saipem to develop Module 2. Both have a maximum throughput of 100,000 barrels of liquid per day.
Module 1 comprises five production wells and three injection wells, all of which have already been drilled and completed. Three of these producers as well as the three injectors were drilled into the Campanian reservoir, with the two other producers being drilled into the Maastrichtian reservoir. Module 2 comprises four producers in the Maastrichtian reservoir, all of which have already been drilled and completed, and four injectors also in the Maastrichtian reservoir, which should be drilled and completed by June 2007. The project also includes the completion of well 1-ESS- 132, in October 2007, to produce gas from the Santonian reservoir to FPSO Cidade de Vitoria (see Figure 2).
Figure 1 - The Golfinho Field (available in full paper)
After connecting well 7-GLF-1HA-ESS to FPSO Seillean, production started, in February 2006, to collect data to allow a better development plan for Module 2. This was the first deepwater light crude to be produced in the Espirito Santo Basin. In May 2006, Module 1 started producing with FPSO Capixaba, to which three producers and three injectors are presently connected in the Campanian reservoir. The two producers in the Maastrichtian reservoir are yet to be connected. Module 2 should start producing with FPSO Cidade de Vitoria by June 2007, then consolidating Espirito Santo as the second largest crude-producing state in Brazil.
Storm Warning
Authors: Brown Alan S. , Bomba John G. 
Published: October 2008

Abstract
STORM WARNING, A Panel In 2005, Hurricanes Katrina and Rita acted like brooms to sweep away 115 production platforms, damage more than 50 others, and capsize, damage, or carry away numerous drilling rigs. While most of the platforms were old, perhaps as many as 20 percent of the platforms and most of the rigs were new and built to the most modern specifications. In addition, the hurricanes devastated the underwater pipeline system that ties platforms to shore. Ten months after the 2005 hurricane season began, 12 percent of Gulf oil production and 9 percent of its gas production remained out of commission.
By April 2006, industry and government organizations had rushed new benchmarks for offshore construction through standards-setting organizations. Although the 2006 hurricane season did not challenge these new standards, severe hurricanes are a certainty in the future.
Our panel includes key members of standard-setting committees, who will provide a high-level review of Gulf Coast readiness to weather another severe hurricane season. They will assess data from the latest hurricane season, project the effectiveness of the new rules, discuss how the industry has used the time bought by the weak '06 hurricane season, and talk about the next wave of proposals.

Introduction
In June 2006, Mechanical Engineering magazine ran an article titled "Storm Warning". This article consisted of a series of interviews with recognized industry engineers and Governmental Agencies to assess the impacts of Huricanes Katrina and Rita on the offshore industry and what the industry did to improve design codes and methods. Why? In the summer of 2005, Hurricanes Katrina and Rita swept away 115 production platforms, damaged more than 50 others, and capsized, damaged, or carried away numerous drilling rigs. While most of the affected platforms were old, perhaps as many as 20 percent of the platforms and most of the rigs were new and built to the most modern specifications. In addition, the hurricanes devastated the underwater pipeline system that ties platforms to shore. Seven months after Rita, 23 percent of Gulf oil production and 14 percent of its gas production remained out of commission.
Industry and Government trade and standards-setting bodies responded faster than ever before. By April 2006, they had promulgated new standards. Although the 2006 hurricane season did not challenge these new standards, severe hurricanes are a certainty in the future.

The Panel's Purpose
By the time OTC '07 convenes in April, it will be time to assess the minimal data from the latest hurricane season, discuss the potential effectiveness of the new rules, and look at how our experience evaluating the past hurricane seasons is shaping the next wave of proposals for changes to the applicable rules and standards.
Our panel includes several of the original interviewees, key members of standard-setting committees and Government agencies, who will provide a high-level review of Gulf Coast readiness to weather another severe hurricane season.
Fatigue Comparison Of Two High Strength Heat Treated Structural Steels For Low Temperature Service
Authors: Graff W.J. , Pinyopusarerk Chao J. 
Published: October 2008

ABSTRACT
Quenched and tempered carbon steels are used in the construction of offshore platforms, refrigerated gas cargo tanks, storage tanks, pipelines, pressure vessels, container ships, ice breaker ships, and other structures which require a high degree of notch toughness at low temperatures or where the increased strength with minimized weight is the dominant factor in design. This paper summarizes the results of 40 plate specimen fatigue tests on two quenched and tempered carbon steels:U. S. Coast Guard specification CG-A-537M, andASTM specification A-537B.
Bending stress and axial stress test results are reported for stress ratios of 0, ½ and -1, representing zero-totension, half-tension-to-tension, and fully reversed loading, respectively. Conventional S-N curves are presented for both steels The A-537B bending S-N curve at a stress ratio of zero corresponds with that for axial loading taken from the literature. For lives up to about 3 × 105 cycles at any positive stress ratio the fatigue strength of non-welded CG-A-53'7M exceeds the yield strength. The fatigue strength of CG-A-537M' is higher than that of A-537B when comparing ratios of fatigue strength to tensile strength. At a stress ratio of the fatigue strength of CG-A-537M exceeds the yield strength for lives of two million cycles. Data for both steels with the tensile strengths are plotted as modified Goodman Diagrams.

INTRODUCTION
In recent years hurricanes have caused great damage to offshore operations in the Gulf of Mexico. In other parts of the world platforms have been extended into deep water and into severe cold regions, such as Alaska and the North Sea. It has become necessary to study the problems of brittle fracture at low temperatures (1). The failures of offshore drilling platforms under severe weather conditions emphasize the need for increased reliability in these structures to protect the large capital investments and human lives.
To solve the problems of brittle fracture at low temperature and to meet the need for stronger offshore platforms with minimum structural weight, designers are now choosing heat-treated carbon steels. These steels not only provide high static strength, good weldability and excellent notch toughness at low temperatures (2), but also have high fatigue strength as reported in this paper.
The purpose of this paper is to summarize the results of fatigue tests on two kinds of quenched and tempered structural steel:a relatively new grade tailored for artic ice breaker and tanker service which is currently designated U. S. Coast Guard specification CG-A-537M, andan older grade ASTM specification A-537B which has been used successfully for the past ten years in offshore platforms as well as in storage tanks for low temperature refrigerated gases.
Toward Low Costs for High Cost Resources
Authors: Bairrington P.D. , Bodwell Bradley , Farnsworth James , Parker Timothy , Pierce Charles , Ross Chris 
Published: October 2008

Abstract
Oil and gas companies are being driven to find and develop resources that are intrinsically higher cost than those that were accessible a decade ago. They must face the challenge of lowering full cycle costs so that they can provide their shareholders with the returns that they have become accustomed to in an environment of volatile and unpredictable commodity prices. In this paper, we draw on the experience of practitioners in US and international deep water exploration and development and unconventional resource plays as well as consultants active in developing strategies and performance improvement programs for high cost resources, to uncover common themes in moving toward low costs for high cost resources.
In the view of the authors, three key themes emerge in the effort to lower costs: scale, excellence in execution and controlled experimentation. Scale is a prerequisite for lowering unit costs and leveraging lessons learned; excellence in execution extracts the full value embodied in scarce skilled employees; controlled experimentation is by definition necessary to continuously rewrite the rules of the game in producing high cost resources and progressively drive costs down. This system, once created, can be deployed in new fields and basins to build profitable growth from high cost resources (See Figure).
Flow Assurance in 30" BUT Subsea Pipeline Without the Usage of PPD
Authors: Prasad Jitendra , Philip P. Cherian , Sharma Vinod , Verma Prem Kumar 
Published: October 2008

ABSTRACT
203 km long, 30?? dia sub sea pipeline transports Mumbai High crude oil to Uran onshore terminus (BUT oil line). In order to ensure that there is no congealing of crude and restartability is easy after prolonged shutdown, Pour Point Depressant (PPD) was being dosed. The average cost of treatment for flow assurance was very high (to the tune of 10 million USD per annum). Expanding database, infrastructure development has led to the present studies to explore the possibility of flow assurance without PPD usage. Extensive rheological studies have been carried out at BHS platform on live Mumbai High crude to analyze the effect of temperature, pressure, shear history, water cut, ageing etc. Results of field and laboratory studies were integrated with the observations made during rupture/ repair of BUT oil line in since1992. Case studies of BUT pipeline rupture in recent past have given authentic information about heat losses and gel strength of the aged crude. Concept of estimation of pour point of live crude (with pressure and lighter cuts) was used for the first time on PPD treated and untreated crude to understand the crude behavior under pipeline conditions. Field experiments in 18 km long BHN-SA sub sea well fluid line were also carried out to understand heat losses and restartability behavior. Bathymetry data from IPSHEM, Goa and software modeling has also been used.
It was observed that cooling of crude oil in the sub sea pipeline is less pronounced than estimated earlier. Restartability of crude oil after prolong shutdown (˜30 days) would not pose any problems. Rheological behavior of crude under pipeline conditions is much better than observed in laboratory. Flow assurance with out PPD usage can be attained. PPD usage has been completely stopped and pipeline is functioning smoothly without any increase of pressure drop / wax deposition.

INTRODUCTION:
Mumbai High- Uran sub sea trunk crude oil pipeline (BUT oil line) is 30?? dia, 203 km long pipeline carrying Mumbai High crude oil to Uran onshore terminus. The pipeline is buried and insulated. The pipeline was commissioned in 1979 and adequate data and information is now available to have relook into the salient aspects of its operation.
A CFD-Based Model to Locate Flow-Restriction Induced Hydrate Deposition in Pipelines
Authors: Jassim Esam I. , Abdi Majid Abedinzadegan , Muzychka Yuri 
Published: October 2008

Abstract
Hydrate is a major risk in all high pressure natural gas transport lines including the connecting lines and manifold systems in all offshore production facilities. Marine transportation of compressed natural gas is one example where prediction of hydrate formation in loading and unloading lines and manifold systems is a requirement for the safe transport of gas to and from ocean going ships. Production facility components such as chokes, velocity-controlled subsurface safety valves, and conventional valves and fittings can all act as restrictions to the flowing fluids, resulting in changes in flow conditions, which could lead to the formation of hydrate in the pipeline.
The principal objectives of our research can be summarized as:to identify the location where hydrate blockage would most likely develop,to study the effect of parameters such as orifice geometry, gas composition, real gas behaviour, and surrounding conditions on the agglomeration spot, andto validate the numerical results with available experimental data.
Numerical simulation using computational fluid dynamics (CFD) techniques is underway to model the mechanism of the deposition based on the most recent theories of the deposition phenomenon. The model uses CFD algorithm for assisting to configure the flow field using real gas models and predicting the actual fluid properties. The nucleation theory and driving force models and their relationships to hydrate formation are also used to predict the incipient hydrate particle size and growth rate.
In this paper, the theory of the deposition mechanism is briefly discussed. The application of the theory in turbulent regime for different hydrate particle sizes is then presented. Finally the approach used for deposition process is discussed.
The study concludes that two phenomenon control the deposition mechanism, namely: the Brownian diffusion mechanism by which the movement of small particles (&lt;1µm) can be explained and the inertia mechanism which controls the dynamics of the relatively large particles. The collection efficiency, the indicator of the deposited particles, decreases as the size of the particles increases in the diffusion region whereas in the impaction region, the collection efficiency increases with particle size.

Introduction
Particle deposition is a process that plays a key role in many fields ranging from atmospheric applications to material sciences. In the oil and gas field, the accumulation of hydrate is one of the most challenging aspects in flow assurance studies. It could partially plug and eventually completely block the natural gas pipeline, causing serious risk to the safety of operating personnel and equipment as well.
ACG Offshore Platforms Temporary Pin-Pile Foundations
Authors: Kitney Neil , Penman Allan David 
Published: October 2008

Abstract
Seabed uncertainties, limitations of marine construction vessels in the Caspian Sea and the size of the two Phase-3 platforms for the ACG development offshore Azerbaijan, led to temporary foundations being needed to support the jackets on the seabed prior to installing the main foundation piles. Pin-piles were selected, requiring development of a sophisticated and innovative scheme for their extremely accurate seabed positioning. A modular space-frame system was designed to position eight individual pin-piles in a single and continuous subsea operation. The system had to be capable of numerous subsea relocations and accurate attitude adjustment to counter a sloping seabed, potential subsidence and have sufficient structural integrity against damage from pile driving loads. Exceptionally tight pin-pile installation tolerances were essential to ensure tieback of pre-drilled wells, bridge linking of the two platforms and accommodation of the piles within the geometry of the jacket legs.
This paper describes the development of the engineering solution from analysis, laboratory testing, fabrication and field trials through to offshore installation.

Introduction
The ACG field is located in the Azerbaijan sector of the Caspian Sea approximately 130 km east of Baku, in water depths varying between 118m and 175m.
Each of the three project phases included the installation of two fixed jacket structures. In order to optimize project delivery a standardized design approach was employed; this included the temporary foundations. For Phase 1 and 2, temporary jacket seabed support was provided by glass fibre reinforced mudmats in each corner of the jacket base, each mudmat having an area in the order of 700m2 (see Figure 1). These foundations were to provide OBS in 10-year return period environments prior to the installation of permanent foundation piles.
Risk Management in the Offshore Energy Industry
Authors: Pollett Buford 
Published: October 2008

Abstract
Based on the earlier work of pioneers in risk management in the offshore industry, the panel will discuss various types of risk associated with the new opportunities and challenges that now face the offshore industry. The various risks include geological and engineering evaluations, commercial concerns, weather risks, and setting contract terms between culturally diverse people. The panel will speak to identifying the risks, setting risk base-lines, and addressing uncertainty. Having a reasonable assessment of risk allows decision-makers to assess the true value and potential return of projects in the offshore industry and provides clear windows of opportunity for investors.

INTRODUCTION
The decision to go forward with new energy opportunities, and pursue an associated offshore project is clearly premised on an expectation of a return on investment. The return, however, is affected by the amount of risk a project bears whether such risk is an operational risk including the use of new technologies or a commercial risk. It is important that each investor have a clear understanding of the known and potential risks. Different parties will be comfortable with different degree of risk. Each party must understand the degree of risk the other party is willing to accept and what type of return is expected. So, it is not only preferable, but imperative, that individuals, teams and entities adopt and use reliable methodologies in order to make informed decisions.
This paper is designed to provide a general outline of the different risks to be considered in an offshore industry project and offers examples of each type of risk. The paper has been written to facilitate discussion and questions for attendees to ask the panel at the conference, and may further serve as an outline or checklist when analyzing and determining various risks in any offshore industry project.

Discussion

I. Operational Risks

A. Geological
Common geological concerns often center on structure, reservoir, hydrocarbon charge and seal.1 Other geological factors can be of a geohazard nature including:Slope instabilityShallow gasNatural gas hydrates and their climate-controlled dissociationShallow water flowsMud diapirism and mud volcanismActive fluid seepage and seafloor pockmark formationSeismicity - which may trigger slides - may cause tsunamis and disturb subsurface geological conditions, e.g. pore pressuresExcess pore pressure development, in relation to fluid migration and sediment accumulationAssessment of geotechnical properties of seabed sediments.2
Geohazards may also be manmade. These manmade geohazards include " existing offshore installations, pipelines or cables, shipwrecks, military dumping grounds, and maritime regulations??.3