bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pressure balanced Telescopic Riser Safety Joint
Authors: Tømmermo Bernt-Olav , Tandberg Geir , Carlsen Hans-Paul , Carlsen Tor-Øystein , Muff David Anthony , Løvland Arne Thor , Orekåsa Ronny , Sundkvist Arild , Sørensen Arvid , Lerstang Joakim 
Published: June 2014

Abstract
Safe operation is fundamental and a prerequisite for all subsea well operations including drilling, completion and well intervention. With an intensified demand for well interventions on mature and live wells globally, there is an increased need for improved system and component safety functions. It shall be known which barriers are established and which function they are intended to fulfill. The pressure balanced Telescopic Riser Safety Joint (TSJ) will become a critical safety element within these systems and replace the traditional Weak Link(s). The TSJ can be configured in a drilling- or workover riser system and is designed to increase the safety and operating envelope of well interventions and drilling operations in the case of unintended operational event. There is no overloading due to accidental excessive top tension, while containing well bore fluids, solving the following fundamental risk elements;Protection of well barriersProtection of rig and personnel andProtection of environment.
This newly developed TSJ is the first system which significantly reduces operational risk from severe accidents due to loss of rig station-keeping or top compensator lock-up. The TSJ enables an automatic overload protection system based on the following functions; Tensile bolts with predefined capacity control the activation. In an accidental event, the bolts get overloaded (rupture) and the TSJ starts telescoping while maintain pressure balance. The telescopic length is longer than the rig heave movements to avoid riser separation. The TSJ will also prevent spill to sea after activation. It includes a bore membrane separating clean hydraulic control fluid from dirty bore fluid for pressure compensation. Once the Safety Joint is activated as a result of excessive top tension, it will provide sufficient time to safely shut in the well and perform a controlled riser disconnect. The Safety Joint can be instrumented and included in a Safety Instrumented Systems (SIS). A full scale workover riser prototype has been built and tested to validate the fundamental principles. This paper provides an overview of the development and testing performed on the pressure balanced Telescopic Safety Joint.
Wave Energy Converter (WEC) - Formulation of Numerical Method to Predict Fluid-Structure Interaction and Wave Energy Potential
Authors: Gullaksen Jóannes 
Published: June 2014

Abstract
Cost of energy is a critical factor to the success of Wave Energy Converters (WEC), in order for wave energy converters to compete with other forms of renewable and fossil-fuelled power generation. Essentially, the energy converted into electricity by a WEC is a function of the resource the converter is placed in, the converter's prime mover, and the converter's power take- off system. This is a dynamic system and changes to one aspect can have a significant influence on another.
Kinematics and kinetics are fundamental in fluid-structure interaction and design for optimizing wave energy camture performance, as well as loadings for mooring and structural analysis. The following analysis domains are covered in this paper:physical description of variables affecting wave energy capyure performancethe kinematics of wave energy converter motion, i.e. the geometrical aspects of motion (variables, reference frames and transformations,the kinetics of wave energy converter motion, i.e. the study of the forces acting on the wave energy converter and the motion they produce,combining the wave energy converter kinematics and kinetics to obtain a dynamic model and 5) description of numerical solution method.
The paper presents the mathematical formulation with numerical method which can be used together with laboratory testing of a WEC. The combination of numerical computations and laboratory testing can be used to produce results to predict how the WEC responds to real wave conditions.
Assessing Well Integrity Using Numerical Simulation Of Wellbore Stability During Production In Gas Hydrate Bearing Sediments
Authors: Long Xiaoyan , Tjok Ko Min , Wright Christopher S. , Witthoeft Alan F. 
Published: June 2014

Abstract
Well integrity during hydrocarbon production from an oil or gas well drilled through naturally occurring gas hydrate bearing sediments (HBS) may be problematic due to hydrate dissociation during well production. Assessment of well casing integrity is complicated because of the many variables involved such as:character, distribution and volumetric concentration of gas hydrate habitat;physical characteristics, in-situ stress-strain history along with thermal and engineering properties of the sediments overlying, within and vertically adjacent to hydrate bearing zones;specific design and installation details of the production well(s) including well tubular depths, sizes and the undisturbed formation temperatures;thermal characteristics of the various well components including tubing, casing, packer fluids, cement, anddetails of produced hydrocarbons including production flowrates over time, reservoir pressures over time, duration of production, produced fluid composition over time and well temperature profile during production.
In this paper, assessing well integrity using numerical modeling of wellbore stability in a natural deepwater offshore environment in the face of in-situ gas hydrate dissociation due to heating is performed and described in detail herein. The simulation includes thermodynamic stability analyses of the hydrates, assessment of fracture development and soil movement prediction considering seepage and soil consolidation effects followed by soil-well interaction modeling to determine potential stresses in the well components. Fracture models of crack dimensions are premised on either (1) development of a pattern of laterally expanding horizontal fractures evenly spaced vertically throughout the hydrate-bearing zone and centered on the wells, or (2) development of vertical fractures which will intersect the seafloor to allow gasses from hydrate dissociation to vent into water column.
For this study, hydrate accumulation (character, saturation and distribution) for field development area is interpreted using seismic inversion and rock physics transform along with available geophysics seismic data and offset well log data. Sensitivity analyses with parametric variations of sediments and wells indicate that well design (in terms of insulation) and an increase in soil capacity for fluid flux will have a distinct impact on reduction of soil motions and casing stresses.
With computational efficiency, the numerical simulation can provide bounding estimate of gas hydrate dissociation effects around producing wells. The model is very useful for a sound understanding of key parameters that determine HBS response to hydrocarbon production and the well integrity.
Using Generalized Linear Regression Of Multiple Attributes For Modeling And Prediction The Formation Permeability In Sandstone Reservoir
Authors: Al-Mudhafer Wathiq J. 
Published: June 2014

Abstract
In this paper, we present an efficient flexible algorithm for modeling the formation permeability with respect to other well and core petrophysical properties for a well in sandstone formation in West Africa.
In Generalized Linear Regression, the monotonic link function, glm, has been used to generate the relationship between the core permeability and the explanatory variables such as caliper log (CCL), deep induction log, medium induction log, gamma rays, neutron porosity, core porosity, deep resistivity, medium resistivity, spontaneous potential (SP), density & corrected density, in addition to rock facies.
Meanwhile, the glm function has been adopted for attaining normal distribution for the continuous variables and multinomial distribution for the discrete (rock facies). The link function relates the expected value of the distribution to the predictor variables. Fitting of a GLM model was achieved through optimization of maximum likelihood estimates by an iteratively reweighted least-squares mechanism.
The Root mean square errors (RMSE) is not a sufficient indicator of bias for an estimate because RMSE could be changed due to a change in variance, with no change in bias. Consequently, variance, analysis of deviance, and RMSE have been considered for model comparisons. In GLM results, a significant overall reduction in model deviance with less variance, residual deviance, and RMSE that reflects the reduction in both variance and bias and the validity of the fitted linear model.
Need For Industry Ready Education: Flow Assurance Course - A Case Study
Authors: Kondapi Phaneendra 
Published: June 2014

Abstract
Subsea developments continue to escalate in quantity and complexity as the exploration and production companies ramp up exploration of deepwater and ultra-deepwater reservoirs with complex formations in harsh environments with increased challenges. Overcoming these challenges is the job of subsea engineers. Hence there is an immediate need to train and enhance their skills through practical education to enable them to manage and take ownership responsibility of these larger and complex fields at greater depths. In this "Great Crew Change" phase, the subsea industry is looking for people who are not just bright and smart but also be able to do productive work right away the moment they are hired. The challenges and expectations of both the subsea industry and academia are very high in terms of knowledge. So, in this highly competitive world, the need for practical subsea engineering knowledge at the college level is very much increasing in order to prepare the next generation of technical professionals.
In order to meet the subsea challenges and industry needs a new and effective course has been developed to teach flow assurance at University of Houston, the first three credit-hour university level industry-ready course in the US that has been designed to meet direct subsea applications with academic standards. The motivation of this course is to make students acquire the ideas and solution strategies necessary to figure out an industry problem in a classroom setting and hence train the prospective subsea engineers for work in industry by successfully learning the concepts. The flow assurance course provides an understanding of multiphase flow fluid dynamics and analyses, overview of flow assurance and the fundamentals of flow management for subsea production systems. The course benefits include an understanding of basic sciences, engineering and flow assurance principles, as well as their application in the assessment, prevention, mitigation and remediation of flow assurance issues encountered in deepwater subsea systems using state of the art prediction tools.
Live Well Display & Automated Data Analysis To Improve Timely Well Control & Drilling Optimization Decision-Making In MPD Operations
Authors: Gumus Ferhat , Pobedinski Ilia , Hannegan Don , Valiullin Khaydar , Simpkins Douglas R. 
Published: June 2014

AbstractA state-of-the-art MPD system should have not only highly accurate sensors measuring critical mud flow data and PLC automated chokes to precisely maintain desired annular pressure, but also the ability to aggregate, analyze and display this real-time information on monitors on the rig floor and in remotely located centers. In the past, this flow monitoring and detection capability that was primarily based on mass flow balance has helped safe and effective drilling of complex wells through early identification and interpretation of critical events such as kicks vs. ballooning and has enabled the safe drilling of prospects deemed un-drillable using conventional technology.This paper describes a number of enhancements including the system's ability to display and analyze not only the critical parameters of drilling hydraulics, but also other information that allows looking at the totality of the closed-loop system from different perspectives. It provides just-in-time engineering that improves the decision making process in time sensitive scenarios by increasing awareness and decreasing reaction time. It does this by utilizing a user friendly "live well display". The real-time MPD automation software platform that has been developed allows the conducting of advanced well hydraulics and drilling dynamics simulations, providing engineering calculation tools and customizable plug-in controls for multiple hardware components.By employing real-time models such as hydraulic, well control, swab-surge and T&D, the system displays information from different perspectives and aids in understanding what are the real limits during a drilling operation. The expandable database structure allows capturing more valuable data while continuity of data streams is secured with implementation of "heart beat" technology. The ability to control not only chokes but multiple components such as RCD, PRV, remote valves etc. provides further automation possibilities and minimizes the possibility of human errors. Finally, putting engineering and operational analysis, real time drilling process control and even automated reporting on the same software platform maximizes operational efficiency and increases safety for people and rig equipment during well control events and MPD applications.
How to Execute a Successful Petrotechnical Data Donation Project
Authors: Thomson James A. , Thorn Barbara , Tucker Julieta 
Published: June 2014

Abstract
This paper describes the methodology used to design and execute a project for donating multiple high-resolution datasets simultaneously to a number of university geoscience departments. A step-by-step process shows how an integrated, multidisciplinary team consisting of data specialists, geoscientists, attorneys, administrators and others verified that the datasets were sound, eligible for distribution and consistently delivered to recipient universities. The steps include obtaining permissions from four internal BP asset teams and four external data co-owners, and assuring ownership and distribution rights through the data acquisition contractor.
Efficiencies in the data donation process were achieved by batch issuing the data to a group of universities under a single round of permissions granted by internal BP data owners and a Letter Agreement executed between BP and each of the data co-owners. The permissions and agreements put in place will cover additional qualified research and teaching institutions that may be identified in the future, allowing subsequent data donations without the need for supplementary rounds of approvals.
After executing Confidentiality Agreements and distributing data to a group of 15 targeted U.S. University Geoscience Departments, additional universities have applied for, and received, the datasets, with selected universities outside the U.S. also receiving data. Originally, data were delivered on a physical disk drive however, more recently, a digital data download system has been enabled.
The BP Data Donation Project met the initial goal of delivering high-resolution geophysical datasets from four BP deep-water developments in the Gulf of Mexico to multiple universities in 2011. BP have seen that these universities are using the data in teaching and research and that expertise in using these data types is developing in the recipient Geoscience Departments. Research results based on the donated datasets have enhanced our understanding of seafloor and shallow subsurface geology. The data donation effort has enabled graduate research projects and the first manuscripts based on research using the data are beginning to be published.
The data donation project will eventually be shut down, with one potential trigger being a drop off in demand for the high-resolution datasets. However, alternative datasets may become eligible for donation in the future, possibly including a collection of proprietary, high-resolution 3D seismic data.
Operability in Design - Fast, Flexible and Economical Design Tool for Subsea Gas Compression Design and Verification
Authors: Storvik Marit , Irmann-Jacobsen Tine Bauch , Bakken Asbjørn 
Published: June 2014

Abstract
The introduction of subsea gas compression systems in a network of wells and flowlines has increased the complexity and number of design elements, each with their individual effects on the total production system. As we move into deeper water, longer flowlines, colder environment and marginal field developments, the need for correct design decisions early in the project become even more important. To maximize the economics of a subsea development, it is important to understand how the technology selection impacts performance, risks, costs and ultimately the attractiveness of subsea compression. In the quest to ensure the operability of such a system, it is vital to address the complete production system from wells to topside. All design elements that affect the upstream or downstream conditions should be included to identify their influence on the overall production; temperature, pressure, capacities and sizes of main process elements on the station (e.g. compressor, scrubber, cooler, pump), process control and flow assurance issues such as hydrate formation, flow regimes, wax deposition, corrosion, erosion and vibrations. It is also important to simulate all operational scenarios over the life of the field.
In order to define a model that provides the most realistic system response, it is vital that realistic inlet and outlet conditions of the compression station are used. In practice this often implies using the reservoir conditions and arrival conditions at receiving facility as boundary conditions.
This paper presents an operability design process including an Engineering Simulator tool that has been developed to include the full production system from reservoir to receiving facilities. This provides a powerful means to screen design alternatives to identify the optimal field solution and subsea compression station design in a fast, flexible and cost efficient way. An example case is described, and highlights from the results of using the operability design process and engineering simulation tool are shared.
Challenges of Lowering a Live Subsea Buried Gas Pipeline by 6m
Authors: Thusyanthan N. I. , Williams K.A.J. , Selwood T. , Smith P. , Jegandan S. , Robert D.J. 
Published: June 2014

Abstract
There are hundreds of kilometers of subsea pipelines around the world, forming a network for the extraction and transportation of oil and gas products. When near shore subsea pipelines cross shipping channels to ports, these pipelines can limit the size of the ships that enter the port. This is because the shallow burial depth of the existing pipeline can prevent any additional dredging required to deepen the shipping channel to accommodate larger vessels. An attractive solution under such circumstances is lowering the pipeline section throughout the width of the channel so that the channel can be deepened. The option of shutting the line down or installing a re-routed new line has cost implications. However, the alternative of lowering a pipeline while it is fully operational has engineering risk, operational challenges and the offshore industry is not very experienced in such projects. This paper presents a case study of such a key project where a 16" gas pipeline was successfully lowered from -3 m to -9m below the seabed whilst fully operational. The live gas pipeline was crossing a shipping channel and was buried at 3m below seabed. In order for the port to expand and allow bigger vessels to enter the port, the shipping channel needed to be deepened. Thus the pipeline was required to be lowered a further 6m for a stretch of 350m where the pipeline crosses the shipping channel. The lowering operations had to be carried out whilst the pipeline was fully operational as it was a 70km pipeline with key supply. This paper presents detailed overview into engineering challenges and operational issues faced on the project. The paper discusses all the stages of the project, risk assessments; integrity assessment for pipeline lowering; geotechnical assessment of trench stability; detailed pipeline lowering stress assessment; pre-operational planning; pipeline survey and pipeline lowering operation; post lowering integrity assessment. The pipeline lowering was successfully completed to meet the project requirement after 14 lowering passes. This successful lowering of a live gas pipeline by 6m is considered to be world's first such lowering. Recommendations on how a pipeline lowering project should be approached, assessed and executed are presented in this paper.
Improved Temperature Performance PolyArylEtherKetone Polymers for use in HPHT Conditions
Authors: Chaplin A. , Clemensen Patrick , Duckworth C. , Warmington K. 
Published: June 2014

Polyaryletherketone polymers have proven performance with 30 years of experience in Oil and Gas applications due to their excellent creep resistance, wear and chemical resistance under high pressure, high temperature (HPHT) conditions; increasing the reliability of oilfield equipment and extending the life of equipment in the ever more challenging oilfield environment. An example application is back-up rings used to prevent extrusion of the elastomeric seal materials under high differential pressures. Current PolyArylEtherKetones, in reinforced formulations, can typically withstand temperatures in excess of 260°C (500°F) and 20, 000 psi. In more demanding HPHT conditions, there may be a requirement for a polymer with a capability of over 288°C (550°F) and 30, 000 psi.
A new semi-crystalline PolyArylEtherKetone polymer has been developed, with the aim of meeting this requirement, whilst also showing good resistance to aggressive chemicals likely to be encountered, such as sour gas. The polymer has a glass transition temperature of approximately 200°C (390°F) at ambient pressure and a melting point of approximately 400°C (750°F). It is semi-crystalline and has good retention of modulus above Tg. PVT data was used to construct a Tg versus pressure plot, indicating a Tg of 288°C (550°F) at 30, 000 psi. The new polymer was found to have significantly enhanced Creep/Compression performance at 260°C (500°F) compared to an existing PolyEtherEtherKetone (PEEK) formulation. After exposure to sour-gas at high temperatures (1000 hours at 175°C / 350°F, gaseous), retention of mechanical properties was good with 90% tensile strength retention.
In summary, an improved temperature performance PolyArylEtherKetone polymer that retains its performance advantage under HPHT conditions in a chemically aggressive environment, has been developed. This has the capability to further extend the opportunities for use of polymers in increasingly challenging HPHT environments, in applications such as seal back-up rings.