bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Rapid Nondestructive Testing Method for Detecting and Quantifying with Material Property Changes Using Vipulanandan Impedance Corrosion Model
Authors: Vipulanandan C. , Ganapathy C. , Gebreselassie K. A. , Pan D. , Panda G. , Ganpatye A. S. 
Published: April 2019

AbstractIn this study, carbon steel corrosion was evaluated in salt water solutions using the newly developed non-destructive electrical method which can be easily adopted in the field for real-time monitoring and the results were compared to some standard test methods such as weight loss, corrosion rate and potential difference. The average weight loss in 10% salt solution (accelerated corrosion and also representing the hydraulic fracking fluids) in one year was 1.05% and corrosion rate was 1.54 mm/year, using the ASTM G1 method. Vipulanandan correlation model was used to represent the weight loss versus time relationship. The potential difference between the corroding steel and standard calomel electrode in 1M salt solution reduced from -0.680 V to -0.791 V in two years, a 15% total change. The use of the new nondestructive electrical method was to detect and quantify the surface and bulk corrosion in the field. Tests were performed to first verify the best electrical property that will be highly sensitive and represent the steel corrosion. The findings from this study indicated changes in the newly developed electrical corrosion index for the surface (2D representation) and the resistivity (second order tensor, 3D representation) for the bulk material using the Vipulanandan Impedance Corrosion Model. Corrosion development in 30 inches long steel specimens were studied in the 3.5% salt solution (simulating sea water) for 500 days. The changes in the specimens were monitored at regular intervals using the new two probe method and measuring the impedance-frequency relationship using alternative current up to a frequency of 300 kHz. The surface corrosion was quantified using the new electrical corrosion index parameter, which changed from point to point on the surface of the corroding steel and the change was over 200%. The change in the bulk resistivity along the length of the steel specimen was over 40,000 times (4,000,000%) in 3.5% salt solution compared to the weight loss and reduction in the potential difference. Hence the electrical resistivity for the bulk material and the new corrosion index for the surface corrosion are highly sensing parameters for detecting and quantify the corrosion in the steel.
The High Pressure Expander Process Technology for LNG Applications
Authors: Liu Yijun , Pierre Fritz , Nagavarapu Ananda Krishna 
Published: April 2019

Recent focus of the LNG industry has been on developing technologies to decrease capital investment and increase operational efficiency to reduce overall cost of supply. Pursuing this target, a novel, compact, and high efficiency expander-based liquefaction technology has been developed to monetize gas assets. The technology uses a single phase methane refrigerant stream operating at distinguishingly high pressures followed by a single phase nitrogen refrigerant stream. Such a configuration dramatically improves energy efficiency (by 10 - 25 %) and train production capacity (by 100 - 150%) compared to other expander-based technologies, while maintaining process simplicity, lower equipment count, and lighter weight relative to mixed-refrigerant based liquefaction processes. Furthermore, integrating with a front-end heavy hydrocarbon removal unit, the technology also enables standardized liquefaction train design for a wide range of gas composition around a nominal train capacity. The standard design is well suited for parallel train configurations and phased development philosophy to drive design and execution efficiency. In addition to CAPEX savings, the weight and footprint savings are beneficial in locations where space is at a premium.
While the technology platform is broadly applicable for both offshore and onshore opportunities, this paper will focus on a recent offshore LNG project which showcased the technology's significant benefit in CAPEX, weight, footprint, personnel safety, insensitivity to ocean motion, refrigerant handling and many other operation advantages. It even enabled production capacity increase from 3.5 to 4.6 on the same circular hull floating facility, proving itself as a game changer to reduce cost of supply of this liquefaction project.
Implementing Innovation: Partnerships and Problem-Solving in the Defense POW/MIA Accounting Agency
Authors: Davis Kara E , Wright Jeneva P 
Published: April 2019

AbstractDefense POW/MIA Accounting Agency's (DPAA) mission, the fullest possible accounting of our nation's defense personnel lost in action, drives all agency direction. This includes novel applications of multidisciplinary solutions towards maximizing agency capabilities. By building collaborations and harnessing applications for advancing technology, DPAA's Partnerships and Innovations Directorate has been a key facilitator for implementing this imperative and has proven the benefit to challenging the operational status quo. The partnership paradigm represents a game-changing model that forces stakeholders to think differently and creatively, and ultimately deviate from traditional operations.
Effective Strategies for Flow Assurance Process Design and Execution
Authors: Kondapi Phaneendra , Creek Jefferson , Chin Y. Doreen , Moe Randi 
Published: April 2019

The objective of this paper is to provide the results of key offshore oil and gas developments across the globe for common strategies and significant exceptions to those strategies. Most oil and gas companies have development processes consisting of the resource and terms attractive enough for development, what is the optimal path for development; detailed engineering and design; build and commission; operate and look back.Within this study, the projects examined reflect different producing basins, fluid type, and water and reservoir depths. Flow Assurance can be expressed as the coupling of multiphase flow and fluid phase behavior. There are only three questions to be answered for a pantheon of problems that can impede flow over the life of the development. The three questions are 1) will there be a flow assurance risk?; 2) how often will the issue require treatment?; and 3) can the risk be effectively managed by thermal, mechanical, and chemical means?The limitations of the strategies are becoming increasingly apparent as the requirements for system performance continue to become more demanding with changing and challenging offshore environment in the current dynamic market. Subsea technologies continue to be asked to facilitate recovering oil and gas while lowering cost while improving safety and operating efficiency to meet current industry challenges. Hence, there is a greater need to understand the flow assurance strategies to reduce overall field development costs and risk, and improve operability and reliability.Key flow assurance strategies adopted in various deepwater projects were considered for this study with an aim to summarize common strategies that arise and exceptions that could provide new strategies going forward.
Finding the Repeatability in One-Off Projects to Improve Performance
Authors: Shenoy Ramachandra Ganesh 
Published: April 2019

Abstract
Project teams generally believe that large oil and gas capital projects typically have unique scope and are comprised of highly customized elements. For this reason, when they hear about new technical frameworks, such as Project Production Management (PPM) (Shenoy & Zabelle, 2016), sometimes described as "applying manufacturing techniques to projects", it leads them to believe such methods only apply in scenarios with highly repeatable and predictable conditions in tasks and processes. Consequently, many experienced project professionals find it difficult to see how to apply PPM. They mistakenly believe that PPM implies a "manufacturing approach" and reject it as appropriate for the work activities in capital projects.
We show that large capital projects in oil and gas have a lot of inherent repeatability, using a well-known analysis of processes and products called the Product-Process Matrix (Hayes & Wheelwright, Link Manufacturing Process and Product Lifecycles, 1979) (Hayes & Wheelwright, The Dynamics of Process-Product Lifecycles, 1979). We use this observation to show Project Production Management applies to the execution and delivery of all projects, large or small, customized or standardized, and will improve upon prior conventional project management practices.
Project Production Management is based on the operations research foundation of production systems. We elaborate upon this foundation underpinning the PPM framework, showing how it allows one to take advantage of repeatability occurring in project work activities in different forms – knowledge, process and products. We start by identifying the assumptions of repeatable knowledge implicit in the disciplines used in conventional project management. We review the prior literature and taxonomy of a production system. All manufacturing systems are production systems. However, not all production systems are manufacturing systems. Manufacturing systems are but one type of production system. We explain that the belief that PPM is a simple application of line flow – also known as high volume manufacturing – is an overly simplistic characterization of PPM. A deeper analysis of the work activities of projects shows different types of production systems embedded within a typical project. Describing the work activities encountered in a project as a set of inter-connected production systems makes them amenable to the modeling and analysis tools of PPM, such as Little's Law and Kingman's Formula, which can be used to predict the limits of project execution and where best to manage variability by the strategic allocation of buffers such as capacity, inventory and time. We illustrate the concepts by identifying examples of repeatability present in an actual oil and gas capital project, an offshore rig.
Why Not Boosting? Uncover the True Value of Your Subsea Asset
Authors: Stenhaug Morten , Dong Hongkun , Hjelmeland Mads 
Published: April 2019

The first subsea multiphase boosting system was installed in 1994 and it is today a proven technology with a global track record. In addition to bringing increased production and recovery, multiphase boosting may also reduce flow assurance issues, reduce project CAPEX and OPEX, improve operability and safety as well as reduce the greenhouse gas emissions when compared to gas lift, the default lifting solution.
A review of the evaluation process and drivers during subsea artificial lift evaluations over the last three decades indicates that in general only a few of the actual upsides of subsea multiphase boosting have been considered, suggesting that there is a need for a more complete overview of the advantages and an approach to uncovering and quantifying the actual value.
This paper discusses the different aspects of subsea multiphase boosting through a comprehensive list of tangible benefits that may support the field development decision process towards identifying the potentially significant and hidden value of subsea multiphase boosting. Referencing experience from more than 30 installations it also provides a historical summary of the various aspects of subsea boosting and which drivers were and were not considered during the decision making process.
The Experiences and Lessons Learned from the Development of High Temperature and High Pressure Buried Hillss Reservoir
Authors: Luo Xianbo , Zhu Zhiqiang , Yue Baolin , Shi Hongfu , He Yifan 
Published: April 2019

Abstract
The Archean buried hillss reservoir of Z Oilfield is the first one developed in the Bohai Bay Basin in recent years. In order to develop the offshore metamorphic buried hillss reservoir with limited wells, several solutions were present in the process of ODP (Overall Development Plan) implementation.
The characterization and quantitative description of fracture: The seismic forward modeling was used to identify the relationship between seismic attributes and fracture. The results showed that pre-stack shear wave impedance inversion could predict favorable reservoir development and the different frequency properties could detect the fracture. Furthermore, the rock stress field simulation based on rock physical properties was implemented to study the direction of fracture, the detailed characterization of fractured system, the quantitative prediction of high quality reservoir space distribution including porosity of fracture. This paper studied the development mechanism of buried hills reservoir with double system-fracture and matrix by comprehensive physical simulation, numerical simulation and other data. A new injection-production pattern named PT-IB (produced wells on the top of hills and injected wells in the bottom of hills) was proposed to maximize recovery factor. A new method was adopted to avoid the injected water channeling along the fractures and to enlarge the sweep efficiency by periodic change flow field. This paper also put forward a plan about early warning and judging the water channeling based on improved water oil ratio and water oil ratio derivative curve.
Innovative Oil Offloading System for Deep Water
Authors: Araújo Jairo Bastos , Fernandes Antonio Carlos , Jr. Joel Sena Sales , Thurler Ana Clara , Vilela Alexandre Mattar 
Published: April 2019

Abstract
Offshore oil production with the employment of FPSOs (Floating, Production, Storage and Offloading) unit faces the challenge of increasing well volumes, processing and storage capacity and ultimately oil offloading and transportation. Following the natural activity development in some oil fields, the number of spread-moored FPSOs and the employment of Dynamic Positioning Shuttle Tankers increased, however represent altogether a bottleneck for the production capacity and considerable transportation cost increment. The need to implement alternatives for the use of larger and conventional tankers is evident, and several attempts and use of technology are being tested and proposed. The work presents preliminary numerical and cost analysis of an innovative Oil Loading Terminal (OLT) for deep water.
Based on field data, metocean studies and extensive practical experience, the OLT should allow direct offloading from the FPSOs onto conventional shuttle tankers including VLCCs. The OLT concept allows the transfer of oil from an FPSO to a conventional tanker moored in CALM Buoy through submerged oil offloading lines (OOLs) supported by a tethered submerged buoy. The conventional tanker will receive the oil through a floating hose string.
The cornerstone of this OLT concept is the subsurface buoy application to support the OLLs and consequently de-coupling the FPSO and CALM Buoy motions simultaneously. As a result, the OOLs loads and fatigue efforts under the CALM Buoy also decrease. The paper evaluates an OLT specific conception for the Brazilian offshore pre-salt area and results related to the numerical analysis carried out are presented considering one submerged buoy connected to a FPSO and CALM Buoy via flexible offloading lines respectively. The results appoint to a technically feasible solution that can be complementarily laboratory and field tested. Further, the solution cost impact has been assessed and initial figures demonstrate that the final testing, construction and installation of one system will need investment that cost a fraction of tanker lifting costs currently requiring Ship-to-Ship oil transfers.
The economies assessed with the use of this innovative solution include total avoidance of Ship-to-Ship costs; cuts transportation cost per ton in up to 50% (fifty percent), eliminates offloading bottlenecks allowing better use of FPSO storage and plant processing capacity, and ultimately decreases the number of tanker offloading operations with considerable benefit to operational safety by reducing risk exposure.
Experimental and Pilot Tests of Deep Profile Control by Injecting Small Slug-Size Nano-Microsphere in Offshore Oil Fields
Authors: Su Yanchun , Li Yanlai , Wang Liliei , He Yifan 
Published: April 2019

Abstract
In order to test the effectiveness and efficiency of nano-microspheres which can be used to effectively reduce water cut with a small slug size, a series of experimental tests have been conducted to evaluate the performance of nano-microspheres and factors affecting the performance. Those tests include hydration swelling characteristics, blocking and migration characteristics, salt resistance, shear resistance and so on. Based on the experimental study, detailed pilot test design were conducted by considering the different reservoir pore structures and microsphere sizes used for oil displacement, so that the slug size is minimized while the net revenue is maximized. Since 2009, deep profile control technology by injecting small slug-size nano-microsphere has been developed in offshore oilfields in Bohai Sea. The main mechanism of nano-microsphere is different from the traditional approaches which increase the water phase viscosity to improve mobility ratio. In nano-microsphere deep profile control technology, nano/micron level microspheres were dispersed in the water phase. Along with the water injected into formation, microspheres swell under the formation condition, plug the water channels, reduce the permeability of high permeable zone, dynamically change the water flow paths, thus increase the water sweeping efficiency. Since 2009, a total of 17 well patterns have implemented in QHD, BZ28, BZ29 oilfields in Bohai Sea. In all those tests, small slug sizes in the range from 0.01 to 0.02 PV were used. Water cut is reduced from 80% to 70% and cumulative oil production was increased by 13.1×106m3. The economic evaluation suggests that for every one dollar investment on this technology, 3.1 dollar can be made even when the oil price is $30 per barrel. So the project has a good technical and economic outcome even in extreme low oil prices.
Revolutionizing Subsea Field Development Planning Through System Integration and Advanced Diagnostics
Authors: Chidiac Cedric , Holyfield Simon , Roberts Ian , Sauve Robert , Simpson Nicholas , Huynh Uyen , Torres Jose 
Published: April 2019

Abstract
Field development planning (FDP) is a multidisciplinary process that is complex, time consuming, and inefficient. Existing workflows are domain centric and involve many discrete software programs, making the process linear, limiting optimization, and often preventing cross-domain collaboration.
Although a few software tools exist for parts of the field layout design, no existing software integrates the equipment selection, systems knowledge, field layout, economics, and software simulations spanning the entire planning process from feasibility studies to detail design and optimization.
This paper demonstrates how a novel FDP software package revolutionizes integrated concept development within the industry, supporting the process from reservoir engineering through to definition of the subsea system.
In early FDP stages, including feasibility and concept selection, operators plan for the development of a field that will produce for 20 years or more, making critical decisions with very limited reservoir information and a high level of uncertainty. Because these early stages are short, operators rarely have the time or resources necessary to evaluate all possible development scenarios, and decisions are delivered with less conviction than is desirable. Hence, operators are in constant search for tools and processes that enable evaluation of more options to help them make better-quality decisions in these early stages, where reducing uncertainty and making decisions are critical to achieving first oil faster.
The paper describes an innovative FDP methodology that utilizes the industry's first cloud-based collaborative subsea FDP software environment and provides efficiency and optimization by combining full-field economic calculations with reservoir engineering, production assurance, systems engineering, subsea technology selection and installation knowledge spanning the entire planning process in one visually rich environment.
The paper demonstrates how the solution provides the ability to evaluate technical feasibility and economic viability of hundreds of development scenarios during early FDP stages more accurately and in less time compared with traditional methods. The impacts on the industry are numerous and include efficiency gains, risk reduction, and significant system cost savings, thereby improving cash flow and reducing payback periods.
A Family of Practical Foundation Models for Dynamic Analyses of Offshore Wind Turbines
Authors: Page Ana María , Løkke Arnkjell , Skau Kristoffer Skjolden , De Vaal Jacobus Bernardus 
Published: April 2019

Abstract
The concept of macro-element modelling – which was first introduced almost 30 years ago – has proven to be a convenient and accurate technique for modelling offshore foundations, but historically these models have mainly been used for academic purposes. Recent developments in foundation modelling now allow for application of such models in engineering practise and design. One such example is the family of new macro-element models that have been developed in the research project REDWIN to represent the foundation behaviour in dynamic analyses of Offshore Wind Turbines (OWTs). These models exhibit characteristic foundation behaviour such as nonlinearity, coupling of the load from different load components and hysteretic load dependent damping.
This paper presents two of the REDWIN models, one applicable for monopile foundations and one for skirted suction caisson foundations. Use of the models are demonstrated through two practical problems that reflect typical design analyses of OWTs: the first example shows a fatigue damage assessment for a monopile, and the second considers an extreme load event for a suction bucket jacket. The structural response is computed using the REDWIN foundation models and compared with the response based on distributed API p-y springs for the monopile and clamped legs at seabed for the jacket. Special emphasis is devoted to how the model input is obtained to guide readers on practical use of the models.