bluuebunny/crossref_metadata_2025_split huggingface dataset:
Performance Testing of an Integrated, Subsea Compact Separation System with Electrocoalescence for Deepwater Applications
Authors: Olson M.D. , Grave E.J. , Juarez J.C. , Gul K. 
Published: April 2015

Abstract
ExxonMobil Upstream Research Company (EMURC) recently completed a subsea technology development and qualification program which included performance testing of an integrated, subsea compact separation system with electrocoalescence for ultra-deepwater applications. To the authors' knowledge, this was the first time that an electrocoalescer had been tested with a gravity-based, compact separator (e.g., a Pipe Separator).
One challenge often seen with conventional gravity separators is the formation and build-up of stable emulsion layers, mainly associated with the processing of medium and heavy oils. In an earlier test program, the Pipe Separator, the primary oil-water separator in the subsea compact separation system, performed well; however, emulsions that were not separated in the main pipes of the Pipe Separator tended to accumulate in the outlet section. There, the emulsion layer then had to either flow out of the oil outlet (penalty on the oil quality) or the water outlet (penalty on the water quality).
The medium and heavy oil trials were particularly challenging, especially at lower water cuts. In order to achieve the desired oil and water qualities, the total liquid flow rate through the system had to be reduced. To overcome this limitation, additional trials were performed later with a compact electrocoalescer, the Compact Electrostatic Coalescer (CEC™) supplied by Fjords Processing (formerly Aker Process Systems), which effectively coalesced dispersed water droplets in the oil-continuous feed into larger droplets such that they could be separated easier in the downstream Pipe Separator. The results from the additional trials demonstrated that electrocoalescence enhanced the oil-water separation performance of the integrated system at flowing and operating conditions that would have otherwise been very challenging. This paper presents a summary of the results from these additional trials.
The cost of developing and deploying a subsea separation system is significant; and therefore, it may not be economical if the system is unable to achieve a sufficient capacity. The design of subsea processing systems is often a balance between what is practically achievable under the module size/weight constraints, and what production rate is required for project economics. By understanding, with confidence, the maximum liquid handling capacity of the integrated system with electrocoalescence, technical risks could be minimized, and a future subsea separation project could become more attractive. As such, the results from this test program may be of interest to operating companies considering similar technologies or future subsea separation projects.
The Cylindrical Hull Concept for FLNG Application
Authors: Odeskaug Lars 
Published: April 2015

Abstract
Cylindrical hulls are currently in use for FPSOs, drilling rigs and accommodation units. The objective of this paper is to describe how the cylindrical hull concept now has been developed to also be applicable to FLNG.
To provide a more stable and economical hull configuration, the use of a cylindrical hull as a platform for the gas pre-treatment and liquefaction plant has been studied and generically developed using advanced analytical design tools. The behavior of the cylindrical hull has been model tested and a significant amount of data is also available from the cylindrical FPSOs in operation. The cylindrical hull has significantly less pitch and roll motions than a conventional ship shaped hull, and eliminates the need for a turret and swivel. Hence it provides a stable platform for the process plant and and has the potential to enhance project development and operations.
The cylindrical FLNG concept is a further development of the proven cylindrical FPSO design. The hull meets the requirements of the International Gas Code and has been developed to accommodate both SPB and Membrane cargo containment systems.
The hull has double sides and bottom, and the ballast tanks are in the double sides. There are three decks, main deck, intermediate deck and the process deck.
Utility and safety equipment, such as lifeboats, water-makers, heat exchangers, etc. are located on the main and intermediate decks. The gas pre-treatment and liquefaction plant along with power generation and living quarters are on the process deck.
For offloading a novel development using an L-shaped DP assist vessel is proposed. This allows for loading of standard LNG Carriers at a safe distance from the FLNG in seastates of Hs 4m.
The L-shaped unit is a specially designed vessel that attaches to the LNG carrier and guides it during approach and departure and keeps the LNG carrier at a safe distance of 150 – 200 m from the FLNG during the offloading operation.
The cylindrical FLNG in combination with the novel offloading technology for offshore LNG transfer offers a safe, reliable and cost efficient solution to the emerging FLNG market.
Application of Sand Control and Stimulation Technology with Fiber Fracturing on Unconsolidated Deepsea Sandstone Reservoir
Authors: Shi Y. , Gao Y. , Zhou F. , Yang X. , Xiong C. , Liu X. , Han X. , Liao Y. , Peng J. 
Published: April 2015

Abstract
To meet the challenges from an unconsolidated, deep sea sandstone reservoir, this paper developed a stimulation and sand control method through fiber fracturing. The key points of the technology are as follow: (1) This paper developed instantizing guar gel fracturing fluid system based on seawater, which can be online mixed with in-situ seawater. Transport of fresh water will not be required for the new system, and the application of new fluid can save platform space. (2) The fracturing design was optimized with orthogonal analysis method to improve the stimulation effect. (3) Fill fiber and resin proppant into hydraulic fracture to form an artificial screen, preventing the fine sand production.
This method had been applied in a low-perm unconsolidated deep sea reservoir. Before the fiber fracturing, the pilot well was shut off because of no production. After treatment, the production reached to 20m3/d, and no sands were found in produced liquid.
Standardized Offshore Wellhead Platforms for Optimized Offshore Execution
Authors: Samuel Johnson , Al-Dossary Ghassan H. , Raja Abid 
Published: April 2015

Abstract
An improvement in the engineering, procurement and fabrication of offshore facilities was needed to support the Crude Production Program. The standardization of wellhead platforms was initiated by Saudi Aramco with the intent of developing a design suitable across all of its offshore oil fields. This resulted in the introduction of an innovative, standardized offshore wellhead platform design. The newly designed wellhead platform structure has an optimized layout to handle current and future operational requirements. The standard design using a 3D model was used repeatedly, eliminating the need for a customized design.
The standardized design enabled the advanced procurement of bulk materials and long lead equipment to support the fabrication yards for efficient execution of the offshore workload. This reduced the lead time for all new offshore platforms. As a result, the delivery of the supporting structures ("jackets") based on the standard design was also improved, which supported the drilling program.
The standard design allowed the implementation of Long Term Agreement (LTA) contracts with unit rates resulting in an optimized schedule and cost savings. This approach allowed the Offshore Program to secure the scarce offshore resources in the region exclusively. This provided an opportunity for Saudi Aramco to develop an inKingdom fabrication yard, which has already delivered numerous projects.
The standardized design eased fabrication procedures and assisted the contractor to fabricate multiple platforms in parallel tracks based on similar designs. As a result, the transportation and installation procedures were simplified and made applicable for multiple facilities with optimization leading to a reduced installation schedule.
Offshore Well Integrity Management with MPD Tools and Technology
Authors: Hannegan Don , Mahmood Azfar 
Published: April 2015

Abstract
Important key performance indicators of offshore well integrity management include mitigating drilling hazards without inducing others and maintaining control of the well in the process. Offshore applications of Managed Pressure Drilling (MPD) tools and technology have been steadily increasing over the past decade primarily for these reasons. Its growing acceptance has been influenced by drilling prospects deemed to be un-drillable with conventional circulating fluids systems for safety, economic, and/or technical reasons, increasing recoverable reserves in the process. MPD's pristine onshore well control track record is now being recognized as a safer way to drill a growing number of offshore prospects that could not be drilled with a conventional open-to-atmosphere mud returns system4.
There are four variants of MPD practiced offshore; Constant Bottomhole Pressure (CBHP), Pressurized Mud Cap Drilling (PMCD), Returns Flow Control (RFC-HSE), and Dual Gradient Drilling (DGD). CBHP for drilling in narrow, shifting or relatively unknown safe mud weight windows, PMCD for drilling in severe to total loss zones, RFC-HSE to augment safety systems and methods when drilling with an otherwise conventional fluids program, and DGD for reducing equivalent mud weight (EMW) when drilling depleted formations from shallow water rigs and eliminating gross overbalanced conditions when drilling from deepwater rigs8.
Over the past decade, key enabling tools have been developed to enable the safe and effective practice of MPD on all types of offshore rigs and water depths; marine series rotating control devices, MPD automated control systems, MPD hydraulic flow modeling, MPD well control matrix, etc. Early kick and loss detection is a flagship capability, as well as ability to conduct formation integrity and leak-off tests more frequently than industry norm by doing so while drilling, quantify and virtually eliminate ballooning3, closed-loop cementing, and managed pressure wellbore strengthening, all of which represent state-of-the-art well integrity management capabilities.
Whether it be in shallow water, deepwater, or ultra-deepwater, a growing number of otherwise promising prospects are deemed un-drillable with conventional circulating fluids systems. The industry has already drilled the majority of the available ‘easy’ wells with drilling hydraulics whose root principals were developed over a century ago. MPD is poised to become the next ‘conventional’ way to drill in marine environments within the next decade. This presentation will illustrate to the offshore drilling industry, regulatory and stakeholders why that is expected to be the case.
Risk Evaluation Methods of Gas Hydrate When Shallow Strata Drilling in Deepwater Area
Authors: Xu Yuqiang , Guan Zhichuan , Xu Chuanbin , Zhang Hongning , Zhang Huizeng 
Published: April 2015

Abstract
Natural gas hydrate often occurred blocking BOP and resulting in other accidents when drilling in deepwater, particularly in shallow strata. So this paper's objective is to establish risk evaluation methods of gas hydrate when shallow strata drilling in deepwater area. With comprehensive consideration of gas hydrate equilibrium conditions and borehole temperature and pressure field, we established method for prediction of gas-hydrate formation region in the shallow strata of deepwater drilling and method for prediction of gas-hydrate formation region when shallow drilling in deepwater area. On this basis, with comprehensive consideration of hydrate formation processes and its factors, we established the qualitative risk evaluation method of gas hydrate based on expert scoring method, meanwhile, established the semi-quantitative risk evaluation method of gas hydrates which takes the influence weight of multiple factors into account and based on Analytic Hierarchy Process. Through the analysis, shallow layer drilling in deepwater area has greater risk in natural gas hydrate than deep drilling. The example shows that: The level of hydrate formation risk near the subsea wellhead and the lower part of conductor is highest; Identification of shallow gas, gas hydrate strata identification, risk level within the predicted gas hydrate formation region as well as the water depth and geothermal gradient, etc. have most influence weight of gas hydrate when shallow strata drilling in deepwater area, we can according to this and combine the actual situation to optimize the design and construction of drilling, thus reduce or avoid the risk.
Subsea Power Supply Based On Submarine Propulsion Technology
Authors: Frühling C. , Schiemann M. 
Published: April 2015

Abstract
The paper reports on the development of electrical subsea power generation and storage systems based on non-nuclear air independent submarine propulsion technologies. Proven submarine technology represents a promising base for innovative and high-performance subsea solutions. Reliable and cost efficient electric power supply can be regarded as one of the most important factors for the successful development and operation of future subsea facilities. Long step outs, large water depths and remote locations without topside infrastructure pose challenges to cable based solutions. Submarine technologies can help to overcome these issues. Within the scope of the paper, an overview of conventional (non-nuclear) military submarine propulsion technology and its perspectives to be applied for civil subsea power supply systems is given. The outlined technologies include diesel-electric propulsion, lead and lithium ion batteries, and air independent propulsion (AIP) systems. For the latter, fuel cells and closed cycle diesel systems are described. The present work highlights the potential of such technologies to be applied as an energy supply for subsea systems. A modular concept is presented which is applicable for water depths up to 3000 m. It consists of battery components to satisfy large intermittent power demands as well as AIP modules which will be able to offer moderate base loads. This way, tailored hybrid battery/AIP solutions can be created which fit the needs of specific stationary and mobile subsea appliances. The concepts can easily be scaled in power and energy.
Geological Interpretation of Mass-Transport Complexes in the Gulf of Mexico: The Benefits of Integrating Borehole Geology, Borehole Geophysics, and Reservoir Engineering
Authors: Zimmermann Eric , Guzman Carlos , Vercher Mike , Hewitt Stan , Kumar Anish , Mahnke Michael , Mishra Vinay K. , Ruiz Elizabeth , Charmelo Nellyana 
Published: April 2015

Abstract
The deepwater Gulf of Mexico is one of the most actively explored deepwater basins in the world, with hundreds of wells drilled to date. However, although much knowledge has been derived from extensive drilling experience, the Gulf's geology offers many surprises. In general, if the horizons of interest are not located subsalt, then seismic-derived attributes can provide a reasonable understanding of the subsurface geology. In practice, the deepwater Gulf of Mexico geology is sufficiently complex that technology such as borehole imaging, borehole seismic data, and pressure and fluid sampling need to be included in the well evaluation to complement the surface seismic interpretation. Incorrect subsurface interpretations impact the drilling and well placement decisions to result in additional well and facilities costs.
In an example from the Gulf of Mexico, the sub-seismic-scale geological interpretations from borehole image data and high-frequency vertical seismic profile (VSP) reflection data were integrated with state-of-the-art lower frequency surface seismic data. The dip and image data obtained from the borehole imager, VSP, and surface seismic appeared to be contradictory when individually considered; however, a careful evaluation of the data reconciled the differences and provided a more complete picture of the subsurface. The example demonstrates how the combination of these different borehole data types was able to identify cycles of high-energy mass-transport deposits followed by relatively lower energy phases of sand deposition.
The impact of geological deformation affects the geological interpretation and the connectivity and types of fluids present in the reservoir. Pressure and fluid analysis from formation testing data confirmed nonlinear relationships at different depths, which were analyzed for implications to the reservoir.
In the challenging geology of the deepwater Gulf of Mexico, geological analysis based on only one kind of data often leads to incomplete understanding of the reservoirs, and that, in turn, can lead to ineffective field development plans. Integrating surface seismic, borehole seismic, borehole geology, and reservoir pressure and fluid data is essential for better understanding Gulf of Mexico deepwater reservoirs, especially in regions of complex geology.
Beyond the Watch Circle Wellhead System Global Weak Point Analysis
Authors: Grohmann Andrew J. , Kaculi Jim T. 
Published: April 2015

Abstract
Watch circles are established by operators to ensure a dynamically positioned vessel does not induce loads that exceed wellhead system equipment capacities. In the event the vessel moves off station, beyond the boundary of the watch circle, loads could be transmitted that may approach or exceed the equipment ratings and possibly cause failure. A whole system weak point analysis approach is required to determine and identify the likely failure modes and locations throughout the system.
This paper presents a system weak point analysis using a 3D finite element analysis (FEA) of an API Studded BOP Flange, Hydraulic Wellhead Connector, and Subsea Wellhead System. The FEA models include the first 200 ft below the mudline and are used to evaluate the capabilities of the entire system to failure. To ensure accurate load transfer between the components the actual field installation sequence was modeled, which included contact between components, all preloads, soil resistance, casing string weights, and cements. Subsequently, the global external loads from the rig were incrementally increased beyond the rated load capacities of the entire system to determine failure points. Loads, stresses, and strains in each component were determined as a function of the global external loads. Each component of the system was modeled using elastic-plastic material properties per ASME BPVC, Section VIII, Division 3, Paragraph KD-231.4.
Critical points throughout the wellhead system were monitored for failure which was defined as either through wall plastic strain or through wall stress above yield across the entire wall of a component. A sequential order of limiting locations, or weak points, was determined (first limiting location, second limiting location, etc.). The weak point analysis performed provided valuable information to assess and help mitigate risk. The analysis results also provided valuable insight and context to the equipment manufacturer to develop more robust and reliable system designs.
The insights gathered by doing a weak point analysis using large 3D FEA models of the entire system, inclusive of the wellhead system, wellhead connector, and flanged connection, are presented and provide a better understanding of the system behavior and failure mechanisms.
A diverless chain connector for the high integrity connection of mooring legs
Authors: Bedini Mauro , Bauduin Christian 
Published: April 2015

Abstract
This paper presents a new design of chain connector that allows disconnection of the mooring line, and inspection and possible replacement of the chain connector's articulation bushes, without the assistance of divers. This design brings dual benefits: Reduced risk of mooring line failure caused by unexpected wear or damage to chain connector articulations, which could not have been inspected with traditional chain connector designsIncreased safety by removing the need for diver intervention.
The paper presents the development of the chain connector, including the latching system that enables connection and disconnection without diver assistance. The development has been performed following a structured process with milestones. The main development steps have been the concept engineering phase, an extensive phase of sub-component testing, a phase of assembly prototype testing at a reduced scale, realization of detailed engineering phase of the component, and the development of full scale prototype test rig.
Chain connectors are a key component of any mooring system, transferring the load from the mooring leg to the FPU. The chain connector also forms an articulation between the mooring leg and structure, and its reliable behaviour is fundamental to avoiding Out-of-Plane Bending (OPB) fatigue failure of the chain links. The described development process and especially the system testing demonstrate the functionality of the diverless chain connector having as aim the high integrity of the mooring legs. Furthermore, it allows assessing the envelope of its connection and disconnection functionality, given different mooring line configurations. Testing provides complete and reliable results of connection and disconnection functionality for different values of in plane and out of plane angles, and pretension. In addition to that, the testing results allow sizing the installation winches adapted to different mooring line configurations.
The trend towards offshore developments in increasing harsh environments is leading to increased technical challenges in ensuring the integrity of Floating Production Units. In parallel, the design life of these systems is increasing above 20 years, and up to 50 years. The ability to monitor the condition of the chain connectors, and to safely maintain or replace any element in case of unpredicted aging effects is the benefit given by the component development described here.
Dynamic Risers for Floating Production Systems API Standard 2RD, Second Edition
Authors: Garrett David L. , Stanton Paul N. , Sharma Partha 
Published: April 2015

Abstract
Since the first edition of API RP 2RD, Recommended Practice for Design of Risers for Floating Production Systems (FPSs) and Tensioned-Leg Platforms (TLPs), was issued in June 1998, hydrocarbon exploration and production in deep water environments have increased significantly. As a consequence, the need was identified to update that code of practice to address the issues and lessons learned from that experience. The title of the document has been changed to eliminate reference to any one type of floating hull. A broad scope of marine dynamic risers is covered, including various steel catenary risers and top tensioned risers.
A fairly high level review of clarifications is presented followed by a brief overview of the content of the standard.
Conceptual Design for Offshore Pipeline Replacement in Mature Field, Using Reinforced Thermoplastic Pipe for CAPEX optimization in F-Field Pipeline Repair and Replacement Program
Authors: Yananto Hanto , Girindra Yuyung , Kennedy Steven 
Published: April 2015

Abstract
A study was initiated to evaluate the benefit of low capital cost and low maintenance cost technologies to rehabilitate pipelines in marginal fields and apply artificial lift solutions to marginal wells to keep them running profitably and with an attractive return on investment (and with no sacrifice to safety and environmental risks).
The challenge is to have a new technology with lower "Total" cost from design, procurement, installation, operation and maintenance during its life time. In addition, the technology must meet the required planned production flow, which, in some cases, can be higher than current flow.
RTP per API15S was shown as the most cost effective solution in rehabilitation of pipelines in marginal fields.