bluuebunny/crossref_metadata_2025_split huggingface dataset:
Safaniya Electrification Using High Power Field Power Supply Challenges: Design, Procurement and Shallow Water Installations
Authors: Al-Rashed Riyadh 
Published: April 2015

Abstract
The purpose of this paper is to share the knowledge and experience that Saudi Aramco went through during the execution of the "Upgrade Crude Gathering and Power Supply Facilities, Phase I - Safaniya Field" project. The paper focuses on the challenges associated with providing reliable power supply to the Safaniya field via a high voltage power system that includes high voltage submarine cables and the required topside substations and structural facilities.
The project will interface with SEC's 380 kV gas insulated switchgears (GIS) at Ma'aden and Manifa BSP substations. This project will expand Manifa 380 kV GIS to allow for the tie-in of the 380 kV transmission lines to be installed at Safaniya under this project . Additionally, the project will connect to Ma'aden 380 kV GIS. Additionally, the project will interface with existing 69 kV GIS switchgear at TP-17 and TP-19. The project shall disconnect existing 69 kV cables and preserve them (for emergency use) at both TPs and connect new 69 kV cables from TP-20.
With the aging of oil wells and the increase in water cut, Saudi Aramco decided to implement artificial lift solutions by installing electric submersible pumps (ESPs) in Safaniya field wells. This solution requires significant power upgrades as each ESP has is designed for 500 horse power (HP), leading the over power requirement to reach 200 MW in the North Safaniya field alone. To support the artificial lift approach, Saudi Aramco designed, procured, constructed and installed dedicated offshore power supply facilities including the world’s longest subsea 230 kV three-core, cross-linked polyethylene (XLPE) cable.
The implementation of the solution has gone through several challenges associated with the high voltage submarine power cable design, supply and installation, and the topside tie-in platform sizing and installation. This paper presents the challenges, the steps taken to overcome them and the unconventional installation technique that was successfully implemented.
Subsea Well Response Project - Simultaneous Operations (SIMOPS) Multi Vessel Operations - Guidance for Marine Based Response to Subsea Well Incident
Authors: Kallaway Kris 
Published: April 2015

The Subsea Well Response Project (SWRP) was established in 2011 on the recommendation of the International Association of Oil and Gas Producers as part of its efforts to further improve subsea well capping response readiness and to further study the need for, and feasibility of, global containment solutions. Through SWRP, international oil and gas companies have worked together on an unprecedented scale to share knowledge, expertise and best practices to enhance international subsea well incident intervention capabilities and to minimise the environmental impact in the event of a subsea well control incident.
This paper will present present key drawings that consider 9 phases of work that may or may not be completed during a subsea well response incident which are:
site survey,
debris clearance & removal,
dispersant injection,
capping,
subsea installation,
flaring & incineration,
relief well placement,
offloading,
Containment operations @ three water depths (end game)
SIMOPS is a collaborative, risk based mitigation process using a formal written exchange of information between concerned parties or vessels working in close proximity to each other when responding to a marine based source control event.
Modelling of Wave-Structure Interaction of a Cylinder in Irregular Sea Waves with Vessel Motions Using Coupled Transient CFD and Diffraction Methodology
Authors: Jia D. , Agrawal M. , Schofield P. 
Published: April 2015

Abstract
This paper is a continuation of previous paper (OMAE2014-23225) where a parametric study was performed for wave- structure interaction on a hollow cylinder in regular sea waves without vessel motions, and the effect of waves and current on the motion of the cylinder and the associated forces using a high fidelity methodology (OMAE2013-11569) to couple CFD with diffraction analysis. This approach was demonstrated for predicting the motions and loads of subsea equipment and structures during offshore operations. Instead of relying on simplified equations or empirical formulations to calculate and estimate the hydrodynamics coefficients, or using steady-state CFD simulation on a stationary equipment and structure to predict drag and added masses on submerged structures in traditional approaches, this methodology couples the transient CFD with diffraction analysis. In this paper, we extend the solution to include wave-structure interaction in irregular sea waves and vessel motions. Irregular waves are modelled using a JONSWAP wave spectrum. Simulations are performed to investigate effect of significant wave height, peak wave frequency (time period) of irregular sea waves, and vessel motions on the motion of a hollow cylinder in irregular sea waves. The results are compared with the traditional approach in current practice.
The time domain diffraction simulation is coupled with multiphase CFD simulation of subsea equipment and structures in waves. A transient CFD model with rigid body motion for the equipment and structure calculates added masses, forces and moments on the equipment and structure for diffraction analysis, while diffraction analysis calculates linear and angular velocities for CFD simulation.
The results provide better understanding of structure motion and associated forces in waves using this coupled methodology. The coupled methodology eliminates the inaccuracy inherited from assumed or calculated hydrodynamic properties that are obtained by using simplified equations or empirical formulations, or by using steady - state CFD analyses in traditional decoupled approaches. This coupled methodology has potential applications in analyses of the motions of subsea equipment and structures in waves during offshore operations.
Recent Advances in Soil Response Modeling for Well Conductor Fatigue Analysis and Development of New Approaches
Authors: Zakeri Arash , Clukey Ed , Kebadze Buba , Jeanjean Philippe , Walker Dan , Piercey Gerry , Templeton Jack , Connelly Larry , Aubeny Charles 
Published: April 2015

Abstract
Well fatigue assessment is an important aspect of the design and integrity assurance of deepwater riser-well systems. Fatigue damage arises from stress changes in a conductor due to cyclic loading. In practice, the lateral cyclic soil response is typically modeled using Winkler type springs known as the soil resistance-displacement (p-y) springs. An appropriate soil model for conductor-soil interaction analysis should predict the absolute and incremental magnitudes of stresses and the resulting impact on fatigue. Monotonic p-y relationships (backbone curves) which were originally developed for piled foundations are not appropriate for well conductor fatigue analysis. To determine the appropriate soil response an extensive study involving physical model testing in a geotechnical centrifuge and numerical analyses was initiated. The intent was to develop a robust and comprehensive approach to cover a wide range of seabed soils and loading conditions specifically for conductor fatigue analysis. Soil p-y models were developed for conductors installed in normally consolidated to lightly overconsolidated clays, medium-dense sands and over-consolidated clays. The models rely on the cyclic response of degraded soil at the steady-state condition and provide fatigue life predictions with high accuracy. This paper provides an overview of the past and recent studies that led to development of the fatigue p-y models. It presents the results of two centrifuge test series conducted in normally consolidated clay and medium dense sand. Ultimately, the paper provides recommendations for developing p-y springs specifically for well conductor fatigue analysis.
High Quality and Efficient Seismic Acquisition for Frontier Deepwater Areas
Authors: Cunnell C. , Bloor R. , Biswas S. , Bunting T. , Beasley C. 
Published: April 2015

Abstract
The trend towards frontier deepwater (FDW) exploration plays around the world creates new challenges for seismic data acquisition, processing and interpretation. Technical challenges focus on the need for high-quality seismic data to allow good understanding of geology from seafloor to target - so as well as providing an image of the drilling targets, the seismic survey is must deliver reliable information about the overburden to mitigate drilling surprises. In addition, economic challenges reflect the need to acquire data over large areas in a cost-effective manner, but without compromising data quality.
This paper reviews a new class of marine seismic technology that aims to address these previously contradictory demands. The technology is based on multimeasurement streamers that combine traditional hydrophone (pressure) measurements of the seismic wavefield with densely spaced accelerometer measurements that derive the wavefield gradient in vertical and horizontal directions. These measurements are combined to perform dense seismic wavefield reconstruction. The results provide greater detail of the seismic wavefield between the streamers and build a true 3D representation of the seismic wavefield that is equally and finely sampled in all directions.
In the context of FDW exploration, this offers two main benefits. The first relates to the ability to generate high-resolution earth models of the overburden, where fine-scale isometric subsurface characterization can help define safe and efficient well trajectories. This offers protection against noise and other artefacts in the seismic data, which, despite the typical characteristics of ultra-deepwater environments, may otherwise introduce interpretational uncertainty. It also mitigates inaccuracies and bias in the shallow velocity model impacting the deeper earth model construction.
Secondly, the ability to accurately reconstruct the seismic wavefield between streamers presents options for acquiring data faster, more cost effectively, and with less operational and environmental exposure. For example, using two- and three-boat operations to double or triple subsurface coverage with a single recording vessel. A selection of examples using real and modelled data will be used to illustrate both these key aspects.
Successful seismic imaging for FDW means understanding the pathway to the target reservoir as much as the target itself. A broad technology portfolio is required to provide integrated workflows, and multimeasurement seismic acquisition can be a key component in the solution; addressing aspects of enhanced resolution, wavefield sampling, and 3D deghosting, whilst also providing options to acquire data more efficiently without compromising quality.
Water Injection Pressure Protection System (WIPPS) in Deep-Water Development Offshore Brazil
Authors: Dave Hugg , Murat Kilic 
Published: April 2015

Abstract
This paper presents an overview of the development and implementation of a Topsides safety and control system to mitigate the risk of a downhole caprock breach in the BC-10 Phase 2 waterflood development.
For the water injection development in deep water offshore Brazil (SS-BC-10 Phase II), there is a strict operational pressure envelope for the water injectors. Excessive pressurization of the sand can lead to fault reactivation and/or a breach of cap rock (shale) integrity. A breach in turn can lead to out of zone injection, propagation of the injected water to the seabed and release of hydrocarbons to the environment. The efflux of reservoir fluids to the seabed constitutes a major HSE hazard with potentially significant impact to environment and company reputation.
Current subsea pressure measurements cannot be utilized in any Safety Instrumented Function (SIF), as these measurements are transmitted by equipment that is not rated for use in safety systems. Instead, we derived a relationship between the pressure of the water injection distribution header (WIDH), and the subsea pressure. From this relationship, we calculate a maximum pressure for the WIDH as the trip setting for a high pressure SIF.
To implement this we have designed a Water Injection Pressure Protection System (WIPPS) that includes a safeguarding function as well as control funtion. The safeguarding function will provide a dynamic trip setting and will stop the water injection pump, and will close an isolation valve on the water distribution header. The control function consist of an override pressure controller for each water injection well, which will limit the flow of injection water if any injection well's pressure exceeds a specified setpoint.
We concluded that the safeguarding and control system are compliant with our requirement for a Safety Integrity Level 3 (SIL3) safeguarding system. The safeguarding system requires regular testing and calibration to maintain this SIL. The WIPPS has been commissioned succesfully without any HSE incident and to date there has been no demand on the safeguarding function.
We realize that it would be better to safeguard the injection wells by using direct measurements that are close to the injection point. However, this will require us to have a means to securely communicate subsea pressure measurements to the Safety Logic Solver (SLS). For this purpose we are developing new instruments that make use of a secure communications framework called Black Channel Communications.
Integrating Onboard DP Systems into Model Test Facilities and Offshore Bridge Simulators
Authors: Voogt Arjan , Hallmann Rink 
Published: April 2015

Abstract
After the first model tests confirmed station keeping performance for Dynamic Positioned (DP) drilling units, many research projects have helped improve the positioning accuracy. Universities and research institutes developed their own closed loop dynamic positioning systems and started Joint Industry Projects to study the efficiency and interactions of thrusters. These models continue to challenge the state of the art, but are less suited to study operations with existing DP systems. Therefore, an alternative setup is developed in which the DP system to be used on board of the vessel can be coupled to the model tests or bridge simulations.
The new setup has been successfully applied to confirm station keeping offset limits and power utilization at model scale for the actual onboard DP system. Due to the applied Froude scaling the onboard DP system needs to respond faster than real time, but this proved feasible. The setup provides the best of both worlds: The model tests help to account for the hydrodynamic interactions correctly, while the onboard DP system ensures that all functionality in the control is identical to the actual operation. In addition, this setup allows institutions to study possible improvements to the onboard DP system in reproducible environmental conditions and in a safe and manageable manner. The paper describes the integration of an onboard operational system into a model test facility and a bridge simulator. It also discusses the main findings from the model tests and simulations thus far.
Subsea Membrane Water Treatment Progresses Towards Application
Authors: Hegdal T. , Pinchin D. 
Published: April 2015

Abstract
Treating seawater on the seabed for injection into reservoirs will deliver a new and significant capability to the industry's expanding subsea toolkit. This paper will describe the latest developments in the Subsea Water Intake & Treatment (SWIT) system and its ability for long lasting production on the seabed of ‘tailor made’ water for any IOR & EOR application.
In addition to ‘normal’ waterflooding, adding membrane treatment can adjust the chemical composition of injection water to suit specific demands of any reservoir. The injection of low salinity water in many reservoirs has shown significant increases in recovery factor of the oil in place, whereas removal of sulphate ions from injected seawater will prevent scaling and provide the ultimate protection against reservoir souring.
This paper will discuss the findings of a 2012-2013 JIP that showed that the SWIT technology, when coupled with membrane systems, has the ability to deliver ‘tailor made’ water quality, reliably and for several years without intervention directely on the seabed. The success of this JIP has raised enthusiasm for a technology qualification program with Oil Majors and many other companies. The paper will present status of this (already started) program and include technology gaps identified and measures required to close them. In addition to the ‘ready to go’ SWIT system, membrane treatment of seawater on the seabed is making significant progress towards becoming a qualified process in the subsea tool-box.
Free from all topsides restrictions, this technology enables new levels of flexibility in reservoir drainage strategy. Reservoir engineers will have the ability to significantly increase recoverable reserves and production rates in a cost effective and environmentally friendly manner.
Design and Manufacture of a Harsh-Environment Riser System
Authors: Burke R , Botros T , Stoica V 
Published: April 2015

Abstract
BP have worked with Wood Group Kenny (WGK) since 2010 to design a robust riser system which will service a harsh-environment FPSO for the next 25 years, in some of the most hostile environmental conditions in the world. Quad204 is located approximately 130 km west of Shetland in 400 m water depth.
In order to deliver hardware which would match the expected facility uptime, and to provide a best-in-class toolbox for integrity management of the riser system during operation, a design program was set up with heavy emphasis on learning from operational experience in the region, and incorporating more onerous Metocean conditions for the new production platform, the turret moored Glen Lyon FPSO, which is significantly bigger than her predecessor, Schiehallion.
A detailed review of BP's West of Shetland (WoS) and Northern North Sea (NNS) operational experience, including previous riser system designs and integrity concerns was carried out in 2010-11. This led to the specification for the Quad204 dynamic riser system which incorporated several unique features to address the location and platform constraints, as well as the restricted construction season.
These particular features were identified as value-adding early in the process, and built into the specification, and subsequent detailed design process, to enhance the system integrity over a lifetime operating in this environment: additional layers of tensile armour to extend riser corrosion fatigue life; double outer sheaths to obviate the consequences of installation damage; autonomous annulus monitoring; enhanced turret/end-fitting venting capacity; turret motion response monitoring; riser I-tube inspection facilities and pipe specimen retention. An extensive program of inspection and dissection of recovered Schiehallion hardware was also carried out to confirm the integrity of the retained brownfield infrastructure. The design, qualification and manufacture of the biggest bend stiffener produced by the supplier transpired to be a significant risk for the project and the program to address this is described herein.
The final riser system - a combination of bespoke hardware and supporting integrity management tools - is believed to be state of the art for harsh-weather floating production systems.
Kick Detection at the Subsea Mudline
Authors: Toskey E.D. 
Published: April 2015

Abstract
On land or offshore, kick detection is primarily achieved by means of measurement and observation at surface of the drilling fluid and drilling equipment. A kick, if not controlled, will progressively grow in the wellbore until it becomes a blowout. Control of a kick is dependent upon time-to-detection. Kick detection in a subsea well is more problematic because the subsea well contains a large volume of drilling fluid between the wellbore and the surface kick detection – the volume of mud in the riser – which can mask a kick or delay detection. This additional volume in the riser may be up to twice as much as the volume in the wellbore. In any case, control of a kick in a subsea well can be improved if detection of the kick can be made sooner.
In this work an investigation was made to develop kick detection sensors that could work at the subsea mudline. By detecting kicks just above the wellhead, at the base of the subsea riser, the time for corrective action can be increased by as much as a factor of three. Two sensors, ultrasonic and hydrostatic, were tested to detect changes in the fluid density caused by the presence of oil, gas, or water in the drilling fluid.
Developing an Innovative Deepwater Riser System: From Concept to the Full Production of Buoy Supporting Risers (BSR)
Authors: Hiller Daniel , Karunakaran Daniel , Cruz Ivan , Tadeu Marcus 
Published: April 2015

Abstract
This paper describes the evolution of Buoy Supporting Risers (BSR), from inception to successful deployment and full production in the Santos Basin development, offshore Brazil. It was a process that started with the early engagement of the operator and contractors on concept and feasibility studies, through identification of potential application scenarios and into a fast track development of basic engineering, bidding, detailed design and construction. The process involved the early selection of development partners and the joint management of R&D and engineering in order to identify and develop existing and emerging technologies, as well as managing the construction of assets and identifying methodologies, all under a single commercial structure. Then, the specifications and work scopes were jointly developed and fixed lump-sum prices were agreed, under a competitive bidding. This model avoided the going back-and–forth and eliminated most of the delays, introducing a great deal of collaborative spirit and transparency. In this case, following an initial feasibility engagement some 20 years before and the identification of a real application scenario, through the above process, it has been possible to develop the major BSR decoupled riser technology from concept selection to full production mode in about five years. The major portion of such period is related to the complete execution of the largest EPIC SURF project executed in Brazil up to that date, where several world-first technologies were implemented in a harsh weather environment, allowing the operator to achieve the production ramp-up plan. In this journey, it took a lot of focus and tenacity from all involved parties to overcome major challenges and ensure that pioneer technology is implemented and available for further applications.