bluuebunny/crossref_metadata_2025_split huggingface dataset:
Predictive Condition Monitoring for subsea pumping systems
Authors: Eriksson Klas Goran , Homstvedt Gunder , Melboe Hallgeir , Gillespie Alisdair 
Published: July 2009

Abstract
For subsea pumps, regular maintenance is required (in the order of every 5 years or so). Being able to plan this intervention to be "just in time" will reduce downtime, and optimize production enhancement. Being able to state with certainty whether a pump e.g. can be allowed to run one extra year (i.e. 6 years instead of 5) gives reduced downtime. Such techniques have been applied to topside systems for a long time, and are now being extended to subsea systems.
A data monitoring system with algorithms for monitoring certain Key Performance Indicators for a pumping system has been developed and applied, and is used to determine "time to service". Three subsea pumping systems are used as real examples, with results from system testing and operation. Subsea data networks with ??self-healing?? capabilities are briefly described.
Polymer Liner & Connector Qualification For Use In Subsea Pipelines
Authors: Campbell Tom 
Published: July 2009

Abstract
Since 2007 Q2, the work described herein has been carried out to qualify and install polymer liners and suitable connectors in two different carbon steel subsea pipelines for water injection service in the Norwegian and UK sectors of the North Sea using the swagelining technique.
The Norwegian line is 16" diameter × 9.1km long and is the largest size of swagelined pipe to have been reel installed. The pipeline was fabricated at the company's newly commissioned spoolbase for the North Sea located at Vigra near Ålesund in mid-Norway. It was transported and successfully installed by Seven Navica, one of the company's reeled pipeline lay vessels.
The UK line is 6" diameter × 1.3km long. It is the smallest size of swagelined pipe to be installed subsea and forms the first application of swagelining to a pipe contained inside a pipeline bundle. The pipeline bundle was fabricated and launched at the company's purpose built Wester site near Wick in the north of Scotland. The bundle was successfully transported and installed offshore by the company using its controlled depth tow method.
Full scale lining and bending trials plus pressure testing have been conducted to verify the integrity of candidate liners and connectors when subjected to extreme installation and operational design conditions. The trials have been backed up by analysis, metrology, visual examination, non-destructive and destructive testing. The combined results of the trials programme justified the selected materials, component details, lining and jointing methods. Consequently both ends of the size range for swagelining in subsea pipelines has been extended. The work has also served to qualify swagelining for pipeline bundle applications and has provided a firm technical basis on which to proceed with the fabrication, installation and operation of these particular subsea pipelines.
The Paper describes activities at each stage of the qualification process involving definition of requirements, material selection, component detailing, development of test procedures, sample preparations, conduct of trials, data gathering and assessment of results.
In the case of the 16" line for reeled installation, three main features were the focus of investigations :Relative ovalisation of linepipe, weldlink connector and internal compression ring when subjected to reeling strainsIntegrity of liner end seal at weldlink following ovalisationResistance of liner to collapse under reduced internal pressure
For the 6" diameter bundled line, bending stress greater than the steel yield value is not a design consideration as it has to be for reeling. Instead there was focus on the following three features :Resistance to axial stress range on the weldlinkEffect of longitudinal expansion / contraction on the liner end sealPressure containment of the weldlink body which is inlaid at the liner sealing area
Evaluation of Reservoir Connectivity of Gimboa Field, Deep Water West Africa
Authors: De Carvalho Nilton Augusto Barreto , Lazary Joaquina Correia , Pinheiro Nilton Claudio , Mengel Frank , Weinheber Peter John 
Published: July 2009

Abstract
The detection and evaluation of reservoir connectivity and compartmentalization continues to be a significant issue in reservoir characterization, especially in offshore fields that must commit significant upfront costs before production can begin.
It is generally accepted that with most of the petrophysical and formation testing measurements made in the borehole we are able to detect reservoir separation but we are not able to prove connectivity. That is, we can prove the negative but not the positive. However, compartmentalization (proving the negative) can economically doom a project. Therefore it is incumbent upon the practitioner to incorporate and integrate all measurements, including logs, pressure measurements and PVT data, before passing judgment.
In the example discussed in this paper, multiple wells are being drilled as injectors. Connectivity to the producer wells is critical. We evaluate acquired pressures and gradients from formation tester tools in several of these wells. Additionally PVT quality samples were obtained and PVT data from these samples is incorporated intothe analaysis. Compartmentalization within a reservoir can be either vertical, lateral, or both. Evaluation of vertical connectivity can be done by either evaluating pressure or fluid discontinuities. The use of pressure discontinuities is well established. To use fluid discontinuities we assume that fluids in flow communication over geologic time will equilibrate to a predictable fluid gradient. Fluid distributions that are not predictable can be suspected to be not in flow communication and further investigation is warranted.
For lateral connectivity, we evaluate well-to-well data. Formation pressures and samples were obtained from the producer and the injector well. We show how to calibrate the response between different tools in different wells and then describe how the differences can be resolved. Again a statistical analysis of the pressure gradient data is applied to ensure that any inferences made are sustainable given the accuracy, resolution, and repeatability of the acquired data.

Introduction
Block 4 is located at the southern margin of the lower Congo Basin. The area is characterized by detached Cretaceous rafts gliding on a continuous bed of salt, divided by thick Tertiary sedimentary grabens which indicate salt movements until the present day. The Gimboa field is located in the middle part of the continental slope in an area with numerous turbiditic events which occurred during the Miocene period. A general geological crosssection showing the stratigraphy in the area is presented in Fig. 1.
Riserless Drilling with Casing: A New Paradigm for Deepwater Well Design
Authors: Kotow Kenneth James , Pritchard David M. 
Published: July 2009

Abstract
As the deepwater Gulf of Mexico (GOM) drilling operations move into deeper water and well depths there has been a lack of consistent and sustained drilling performance improvement. This is an evaluation of the GOM deepwater wells in an attempt to understand the reason for this poor drilling performance and propose a solution to adapt the well designs for the specific challenges of deepwater drilling. Execution of these very expensive wells, which often fail to achieve objectives, or worse are lost, requires a step change in drilling performance.
The complex deepwater drilling environment has pushed the typical offshore well construction design model to its limits. Many of the well design philosophies and the well equipment itself are not well suited for the unique deepwater drilling environment. This requires step changes in well design philosophy, and the understanding and acceptance of the associated risks of implementing new practices. The acceptance of change has been a monumental driver in our industry. The goal is to ensure that exploration and development of oil and gas continues to be feasible in this industry subject to volatile commodity prices and ever increasing costs. A paradigm shift in well design philosophy that involves managing the drilling risks in the shallow hole sections, where the well costs are minimum, rather than the current practice of incurring risks after significant investment has been made, is critical to future success and economic viability of deepwater drilling.
The well design model presented uses the shallow and rapid growth of the pore pressure/fracture gradient (PP/FG) environment to optimize casing seats. Drilling with Casing (DwC) is an enabling technology that can be a mitigant for managing shallow hazards. The fundamental premise is to use this technology to set the first, and possibly the second, casing strings significantly deeper than current practice.
The proven ability of DwC to mitigate many similar drilling hazards as those encountered in deepwater drilling would allow the casing seats to be based upon the prevailing PP/FG environments, rather than being influenced by the shallow hazards.
This could allow for the following well design improvements:Larger annuli below salt for improved drilling margin management.Less total casing strings in the well.More use of conventional casing strings sizes for drilling and geological contingencies.Enhanced planning and use of solid expandable systems.Decreasing the risk of not obtaining at least an 8-½ in. ID completion, essential for economic success in deepwater environments.Batch drilling into salt, which optimizes horsepower as well as cost, utilizing smaller capacity rigs for the lighter hook load casing lifts.
Bit Selection Using Mathematically Modeled Indices Deliver Significant Improvement in Directional Drilling Performance
Authors: Barton Steven Paul , Card Kirk Dean , Nwachukwu David , Cozon Bertrand , Marinho Cristina , Solarin Adebowale 
Published: July 2009

Abstract
Despite the development of models describing Fixed Cutter (FC) bit performance, selection is still made on the basis of visible, geometric features. Optimal selection is complicated further by the large variation in characteristics of cutting structures, in combination with a diverse range of gauge lengths and geometries.
A set of performance indices is presented for FC bits. These are derived from a sophisticated mathematical model and describe performance in terms of Rate of Penetration (ROP), Durability, Stability, and Steerability. Once the relative importance of each index is established, the optimal bit for the application can be selected.
Due to the growing diversity of directional tools, a specialist interface for Rotary Steerable Systems (RSS) is also presented. This software incorporates logic regarding tool operation and trajectory requirement, and assesses these against key characteristics of the bit including length, profile, gauge, cutting structure, and sidecutting capability. The software will list bits ranked by decreasing suitability.
Bits can now be modeled routinely and described in terms of their technical interaction with the drilling assembly and the formation. Selection on the basis of modeling and this interaction is novel and valuable, and will provide consistent selection and improved performance.
Performance summaries are documented for global RSS applications. Use of the software lead to optimal bit design selection. Some of the designs selected had not been considered suitable from prior visual review. The designs delivered excellent performance in terms of both footage and penetration rates. In addition, they were accurately matched to the specific RSS utilized, enabling the system to efficiently deliver the required directional control.

Introduction
Offshore drilling in West Africa poses several drilling challenges which have limited drilling performance and build rate capabilities in directional applications. The extremely soft sandstone and shale lithologies in the vertical intermediate section are prone to erosion and hole enlargement with high hydraulic energy. Hole enlargement reduces deflection forces for commercial Rotary Steerable (RS) tools as well as mud motors, which significantly decreases build rate capabilities and limits directional plans and capabilities. The associated hole enlargement in the vertical section creates a drilling environment that is subject to increased risk of lateral vibration (bit whirl), which even in soft formations is capable of catastrophic damage to BHA components and the bit cutting structure. This, in turn, results in reduced drilling performance and increased drilling costs.
Agbami Field Development; Subsea Equipment Systems, Trees, Manifolds and Controls
Authors: Kelly Thomas P. , Strauss Richard H. 
Published: July 2009

Abstract
This paper describes the subsea facilities designed and built for the AGBAMI field development as defined by the Subsea Equipment Vendor (SEV) contract issued to FMC Technologies by Star Deep Water Petroleum Limited - an affiliate of the Chevron Corporation in partnership with Texaco Nigeria Outer Shelf Inc, Petroleo Brasileiro Nigeria Limited, Statoil Nigeria Limited, Famfa Oil Limited and the Nigerian National Petroleum Corp. The history of the design, manufacturing, testing and project logistics are described along with useful lessons learned.
The Agbami field is located offshore from the central Niger Delta in water depths ranging from 4,200 to 5,400 feet of water, graphically illustrated in Figures 1 & 2. The physical size of the field can be visualized as fitting tightly within interstate (Loop) 610 which girdles the city of Houston as illustrated in figure 3. The field is being developed using 100% subsea completions tied-back to an FPSO and tanker mooring system. The subsea completion system includes 16 production trees, 6 Gas Injection Trees, 10 Water Injection Trees which will be tied back to 6 production manifolds, 2 gas injection manifolds and 4 water injection manifolds. The SEV contract covers this equipment as well as all flowline and jumper connector kits, electrical flying leads (EFL's) and Hydraulic (Steel) Flying Leads (SFL's), topsides Multiplex (MUX) controls system and installation tooling. The remainder of the subsea kit was supplied by the Subsea Installation Contractor, Technip, including the umbilicals, flexible flowlines, risers, flexible jumpers and subsea umbilical terminations.
Project success was dependent upon more than simple hardware delivery and installation. Included with the contract hardware deliverables were extensive requirements for documentation management, interface management, Nigerian manufacturing and engineering content, technology transfer for sustainable long term development in Nigeria and facilities logistics as well as field and technical personnel support in a location which has limited support facilities for offshore field developments and well as security challenges which had to be managed successfully.
SWIMMER: Innovative IMR AUV
Authors: Tito Nicolas , Rambaldi Eric 
Published: July 2009

Abstract
If deepwater field developments are to continue to integrate complex subsea equipment for seafloor processing, sometimes in harsh environments and remote locations, the offshore industry has to find new means for Inspection, Maintenance and Repair (IMR) interventions that ensure and improve both integrity management and the flexibility and reactivity of the interventions.
" SWIMMER?? is a new AUV incorporating a light work-class ROV with tooling designed for long-term subsea deployment - 3 months minimum - and able to perform light IMR operations such as:valve operation: manual or hydraulic failing valvesequipment survey: subsea production systems, pipelines and risers, umbilicalsprocess monitoring: hydrate localization, thermal leak identification,…light equipment replacement: hydraulic or electric flying leads, …trouble shooting assistance, using an ROV commanded from the surface facilities through the production control umbilical, rather than a dedicated service vessel.
In early 2007, CYBERNETIX, TOTAL and STATOILHYDRO joined their engineering forces to work on a SWIMMER prototype, and set themselves the target of deploying it offshore by the end of 2011.
This paper presents the project's industrial objectives, highlights key component specifications along with challenges such as AUV system, ROV/TMS, AUV payload, docking station, control and power umbilical, topside interface, and puts forward conclusions on feasibility, technological gaps, associated qualification programs and views on industrial integration on subsea oil and gas fields.
Reliability, flexibility and autonomy are the key words in support of the integration of this concept in future field development architectures which could be fine-tuned with a SWIMMER-based operating intervention philosophy.

Introduction
The offshore industry is facing new challenges with new field discoveries. Reservoirs are often deeper, smaller and in remote locations. The fluids are more complex, often heavy, acid and with low energy. To improve oil recovery, operators are seeking to install complex subsea equipment for boosting, or more generally processing production. Consequently, the capital expenditure figures for future developments are soaring and in the meantime, the costs of IMR operations, mainly driven by ROV support vessels and associated resources, have risen significantly. More than ever, innovative solutions have to be found, not only to decrease the operational expenditure but also to improve flexibility and reactivity.
Over the past years, the use of AUV has increased extensively in various industrial sectors such as oil and gas, military and research. AUV are currently employed in seabed mapping where they have proved to be a choice answer. A couple of programs have attempted to demonstrate that AUVs can perform pipeline surveys but so far, no autonomous vehicle has been really used in inspection, maintenance or repair applications. No intervention AUV are currently available on the market.
The Intentions and Achievements of the Angola Deepwater Consortium
Authors: da Costa Ruben Monteiro , Teixeira Jaime Lopes , des Déserts Loïc , Harris Richard J.S. , Burban Pierre-Yves 
Published: July 2009

Abstract
The Angola Deepwater Consortium (ADC) regrouping Sonangol, Doris Engineering and Pride International was created in 2000, at the initiative of Sonangol, with a view to develop a long term relationship, allow transfer of knowledge to Sonangol and perform conceptual studies in order to optimise field development in deepwater Angola and improve Angolan content.
Over eight years, ADC has carried out more than ten studies, on various subjects, including:–Study of a FPSO for Angolan waters, development of the FPSO specification–Review of offloading systems for spread moored FPSOs in Angola–Further development of the FPSO specification as shipyard enquiry package–Review of Angolan yard capabilities and planned future development–Study of multi-purpose intervention vessels to service Angolan deepwater fields–Study on sharing of data on subsea reliability–Study on marginal field development (issues, key enablers)–Creation and management of an Angolan subsea reliability database–Study on metocean data and uses in design, creation of a regional metocean database–Study on pigging operability and application to single production line concepts–Study on soil characterisation and uses in design, creation of a soils GIS database
The studies performed by ADC are selected by Sonangol and the four historical deepwater operators in Angola: BP Angola, Cabinda Gulf Oil Company (Chevron), Esso Exploration Angola (Block 15) Limited and Total E&P Angola, jointly referred to as ‘Participants’.
The studies are driven by a Steering Committee composed of representatives/experts of each Participant. Participants inform the ADC team with corporate expertise, lessons learned or data from their company.

Introduction - Field development in deepwater offshore Angola
Exploitation of the hydrocarbon reserves located in deepwater offshore Angola started less than a decade ago. The first deepwater fields to be developed were Kuito located in Block-14 in 400 m water depth, on stream since late 1999, and Girassol located in Block-17 in 1,450 m water depth and on stream since late 2001. There has been a considerable deepwater activity since then, especially since 2002 following significant security improvement. Several deepwater fields have been developed, either independently from any other development or as tie-backs to existing field facilities. Today there are a number of projects going on and even more prospects identified.
Even though it has gained in maturity over the years, field development in deepwater remains a real challenge which often requires new approaches and highly engineered solutions. The challenge will certainly get bigger in the near future as there will be more and more reservoirs either smaller in size or having characteristics making them more difficult to commercialise.
SS: Exploration Prospect Interpretation and Risking Using Modern Geophysical Technology - Success in Amplitude Anomalies and AvO - Technology has the Might, but the Basics must be Right
Authors: Pettingill Henry S. , Lindsay Richard Owens 
Published: July 2009

Abstract
Advanced technology provides elegant solutions to complex E&P problems. We should never forget, however, to respect the basics of subsurface sciences, since getting the basics right is a necessary prerequisite for applying advanced technology. This holds particularly true for the evaluation of seismic anomalies - Direct Hydrocarbons Indicators (DHIs) and Seismic Amplitude-versus-Offset (AvO) anomalies
The optimal solution is to always force " Low-Tech?? to precede " High-Tech??, and never the reverse, meaning these three " basics?? must be considered first:Basics of Seismic GeophysicsBasics of GeologyBasics of Risk Analysis
With these three areas of basics covered, the higher-end analytical geophysical techniques that are commonly employed to predict risk and reward in DHI and AvO prospects can now be effectively employed to create value rather than destroy it.

Introduction
Technology provides elegant solutions to complex E&P problems. High-speed workstations armed with geoscience software are uniquely capable to address these complex problems. Advanced hardware and software perform the mechanics of E&P geoscience; but when using these technological wonders we should never forget to respect the strength of basics-done-right. This holds particularly true for the evaluation of seismic anomalies - Direct Hydrocarbons Indicators (DHIs) and Seismic Amplitude-versus-Offset (AvO) anomalies
High-end interpretation technology produces beautiful maps, profiles, and cross sections, often combined into 3D volume interpretations. It can also quickly provide predictions of source, reservoir, and seal properties. When added to precise renditions of trap areas, these technologies may lead us to believe that risk is well-understood and resource calculations are fairly accurate. But even the best algorithms can produce mathematically correct solutions that are geologically impossible, leading to inevitable destruction of value!
The optimal solution is to always employ " Low-Tech?? as a prerequisite to " High-Tech??, and never the reverse, meaning " basics?? must be considered first. Ironically, the same high-tech tools that can lead to geologically impossible interpretations when not integrated with basics, can be used properly to more effectively assure the basics are in place. This paper summarizes some concepts and combines them with case examples to address three areas of basics that must be pre-supposed before " High-Tech?? can be employed:Basics of Seismic GeophysicsBasics of GeologyBasics of Risk Analysis