bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of Transducer and Electronics Technology for an LWD Ultrasonic Imaging Tool
Authors: Leonard Z. S. , Rahman S. , Steinsiek R. R. 
Published: April 2017

Abstract
A new logging-while-drilling (LWD) ultrasonic imaging tool was designed and tested to acquire high-resolution borehole surface images in any type of drilling fluid. The LWD ultrasonic imaging tool uses ultrasonic transducers to acquire pulse-echo signals from the borehole wall and pulser/receiver and acquisition electronics to store the ultrasonic image and caliper data. The transducer, pulser/receiver electronics, and acquisition electronics have been successfully tested to meet functional targets.
The design of the transducer incorporated ultrasonic modeling to achieve the desired sensitivity and bandwidth using a composite piezoelectric element, two impedance matching layers, and a high-impedance backing. Two designs variants of the transducer were built and tested. The final design was selected by evaluating the performance of each transducer design before and after environmental testing.
The pulser/receiver electronics were designed to deliver wideband excitation with optimal damping to reduce transducer ringdown. The acquisition electronics necessitated a low distortion path, variable gain control, a low noise floor, and consistent channel-to-channel performance. Functional testing on the electronics system verified the analog front-end had low channel-to-channel variation with various input signals and with exposure to 165° C.
A Digital Signal Processor (DSP) and a Field Programmable Gate Array (FPGA) managed the high-capacity memory to store the high-resolution ultrasonic image and caliper data with a high spatial sampling rate. The FPGA was verified with Universal Verification Methodology (UVM) and with code coverage and functional coverage metrics. UVM increased design reliability and reduced development time by facilitating the creation of many test vectors.
The LWD ultrasonic imaging tool has a sufficient spatial sampling rate to fully sample the borehole in the typical ROP and RPM ranges experienced while drilling. Sample downhole images show the LWD ultrasonic imaging tool compares favorably with wireline ultrasonic and resisitivity images and correlates well to LWD resistivity images in water-based mud.
Estimating Natural Frequencies of Monopile Supported Offshore Wind Turbines Using Alternative P-Y Models
Authors: Senanayake Asitha , Gilbert Robert B. , Manuel Lance 
Published: April 2017

Abstract
The objective of this paper was to evaluate the sensitivity of the natural frequency for an offshore wind turbine monopile in normally consolidated marine clay to different p-y models being used in practice: API RP 2GEO (2011), which is the existing Recommended Practice for offshore structures; Matlock (1970), which formed the basis for the discretized curves presented in API RP 2GEO (2011); and Jeanjean (2009), which was recently developed to model lateral soil resistance for piles at small displacements to predict fatigue life for offshore well conductors. The following conclusions are drawn:
Estimates of the natural frequency based on API RP 2GEO (2011) can be significantly lower than those based on the Matlock (1970) due to the poor resolution of the discretized p-y curves (particularly at small displacements) presented in API RP 2GEO (2011). The Jeanjean (2009) model predicts a stiffer response and higher natural frequency for typical service conditions compared to the API RP 2GEO (2011) and Matlock (1970) models. The pile length for a typical offshore wind turbine founded on a monopile in a normally consolidated marine clay may be governed by the lateral stiffness and not the axial capacity, and the differences between the p-y models can lead to significant differences in the required pile length.
Construction Management – A Simplified Approach
Authors: Cohen Jessica , Obi Chukwuemeka 
Published: April 2017

Abstract
The process of issuing, reviewing, and approving Contractor documentation has gotten so out of hand as to eclipse the fundamental requirements for technical assurance and to build in unnecessary manhours, cost and schedule constraints into the construction management planning phase. The selection of the Engineering, Procurement and Construction (EPC) contractor is heavily influenced by the question: Have they done this before and for us? Yet, once the engineering is underway, the Contractor is treated like this is all new technology, and requires heavy review of multiple procedures. Why do we re-invent the wheel when it comes to managing subsea installation? In this downturn, when efforts are required to achieve project cost economies, this is an opportune time to reflect on how we manage offshore construction and identify ways to streamline what is essentially the same process for each and every project. This paper identifies areas for simplifying subsea construction management in the same way DnV (Det Norske Veritas) published their Recommended Practice for subsea hardware [1]. This paper seeks to simplify the installation documentation process, without diluting the technical content, applicability and impacting technical risk.
Well Control Course Redesign for the 21st Century
Authors: Arnold Michael , Randall Fredrick , Lyon Andrew 
Published: April 2017

Abstract

Objectives/Scope
This paper describes a new approach to the design and delivery of well control training. The modifications and improvements largely address IOGP and industry guidelines. Conventional and newly-required well control training subjects are addressed by applying Andragogy, adult-learning theory. The flipped classroom is described.

Methods, Procedures, Process
The new generation of drillers and learners expect new learning dynamics and methods, including collaboration with social groups, cloud based material and non-connective based training that is interactive. Students today are changing the way people of this new generation learn. This course material and delivery addresses these learning protocols.
The course was developed around adult learning theories and assurance concepts.

Results, Observations, Conclusions
A Human Factors approach was used todevelop the course. This approach identified the critical technical components needed in a well control event, determined what a supervisor needs to do in a crisis and how they work together in a team. Key leadership elements are assessed. Well control event scenarios are used in the course. The course was designed using a Know – Assess – Decide – Act methodology. Students are led to understand how initial information, unfolding events and how the results of their actions affect the potential success of controlling the well after an influx.

Novel/Additive Information
Andragogy, learning styles and methods and a flipped classroom are used in the course. The course design does away with the typical pedagogical learning used today and replaces it with adult learning theory. The improvement outcome for this redesigned well control training program is to give confidence that the right decisions will be made at the right time. This assurance is critical for the students, their employers, accreditation institutions and government bodies.
Horizontal Wave Impact Loads for Column-Stabilized Units Operating in Harsh Environment
Authors: Szalewski Piotr , Lu Jenny Yan , Johannessen Thomas B. 
Published: April 2017

Abstract
The objective of this paper is to share lessons learned with the industry from a recent accident and provide a recommended procedure for evaluating airgap and possible horizontal wave impact loads for column-stabilized units operating in harsh environments.
On 30 December 2015, when operating on the Troll field, a column-stabilized drilling unit, COSL Innovator, was hit by a steep wave that impacted directly on the forward port side of the deck box. This resulted in several damaged windows, one fatality, four injuries and structural damages to the front of the deck box.
Following the accident, there is increased attention and concerns raised by some regulatory bodies for safe operation of semi-submersibles in harsh environment. In order to evaluate the adequacy of Class rule requirements and pertinent industrial design practices, DNV GL has investigated and analyzed the circumstances surrounding the accident. The conclusion from this work is that there is a need for improved guidelines for calculating horizontal wave impact loads on deck box structure if a column-stabilized unit is designed to operate with a negative airgap, together with improved methods for calculating the airgap with a prescribed annual probability of occurrence. DNV GL has developed "Offshore Technical Guidelines" (OTGs) that can be used to document compliance with classification rules stipulated in DNVGL-OS-C103 [1]. Development of these guidelines has brought a deeper understanding with respect to airgap and associated horizontal wave impact loads on column-stabilized units.
This paper discusses the technical challenges related to airgap prediction and wave impact load calculation, provides the technical background and insight of recently released Offshore Technology Guidance OTG-13 [2] and OTG-14 [3], and suggests a way forward.
The Use of Motion-Based Technology in Oil and Gas Supply Chain Logistics
Authors: Ulrich Matt 
Published: April 2017

Abstract

Objectives / Scope
The objective of this paper is to ascertain if motion-based GPS technology can replace the complex RFID infrastructure for the automated logistical control over consignment stock movement globally. This shall be demonstrated through field data results and benefits of using motion-based GPS technology in oil and gas supply chain logistics to monitor the movement and location of offshore equipment and materials through findings of a pilot project.
Over the past few years, the adoption of asset tracking technology in oilfield operations has provided operators and service companies with increased visibility of the supply chain leading to a reduction in operational costs.
New motion-based GPS technology is more advanced than a time based locator (traditional GPS technology provides one-way communication every 12-24 hours) to a movement based locator providing two-way communication.
This has the potential to provide an overview of when materials are transported and has the ability to accurately illustrate events such as arrival at an offshore platform, vessel movement or onshore at quayside/ remote locations which triggers customer billing.

Methods, Procedures, Process
100 cargo carrying units (CCUs) were tagged for a pilot project to test this technology. Each of the CCUs processed through a cycle of leaving customer site onshore, being transported to port/quayside, shipped offshore and returned to the original onshore site. The GPS unit reports based on motion of the unit progressing through the cycle, as opposed to daily pre-set time scheduled reporting, providing customers with a complete overview of their CCU movement cycle. The accuracy of this turnaround was compared to results gained using current RFID infrastructure which is generally accepted as being a more accurate technology.

Results, Observations, Conclusions
The pilot confirmed that motion-based GPS is more accurate and can replace RFID for the automated logistical control over consignment stock movement globally.
The following results were obtained from the 205 entry and exit events: RFID reported 75% accuracy, reporting 164 events and missing 41Motion-based GPS reported 99.01% accuracy, reporting 203 events and missing 2

Novel, Additive Information
Motion-based GPS technology has been illustrated to be a consistent, viable approach to controlling consignment stock on a global basis providing two-way communication, greater control and oversight to the customer as conveyed through our pilot project. The adoption of this new technology is also cost-effective to implement compared with the current complex infrastructure set up required through RFID.
New Criteria of Hydrate Inhibitor Requirements in Tropical Shallow Waters
Authors: Meng Weihong , Kak Ashutosh 
Published: April 2017

For oil and gas development projects in shallow waters in the tropic areas the water temperature is usually high (above 16°C all year around). Low fluid temperature is possible during operations due to Joule-Thompson cooling in early life when reservoir pressure is high. The nature of hydrate plug formation risk in the tropical shallow waters is very different than that in the deepwater projects (where ambient temperature is about 4°C). In tropical shallow waters the low temperature is mainly created by gas expansion or significant choking. Heat will be transferred continuously from the pipe wall toward the bulk fluid stream. At certain pressure and temperature hydrates may form, but the low thermal conductivity of a hydrate layer makes it difficult for hydrate particles/aggregates to stick to the pipe wall and form plug. Understanding this phenomenon will significantly reduce the hydrate inhibitor requirements and ease operations of the production system.
In this paper hydrate physical properties were collected from literature. Based on these properties the heat transfer rates and hydrate layer dissociation rate is estimated. The results show that at 10°C of sub-cooling, hydrate layer will not adhere to the wall in a tropical flowline, therefore, a hydrate plug could not form. If this concept is applied to operations of an existing asset, hydrate inhibitor usage can be significantly reduced whilst improving operation efficiency and flexibility. For a new facility design hydrate inhibition injection rate and storage volume can be significantly reduced, which will result in CAPX and OPEX savings. Application of this philosophy will significantly reduce the weight requirements and extending supply period of the hydrate inhibitor for a production platform, lower the hydrate inhibitor consumption over the field life, ease the operation of the asset, and increase the chance for successful offshore projects.
Digitalization of Oil and Gas Facilities Reduce Cost and Improve Maintenance Operations
Authors: Devold H. , Graven T. , Halvorsrød S. O. 
Published: April 2017

Abstract

Objectives/Scope
The digitalization of oil and gas facilities is becoming a new theater of operations. Effective solutions can be employed to convert data into information and knowledge, which can then be used to improve maintenance operations. Wear and tear can be discovered before faults occur, which enables cost reductions and safety improvements. All relevant data can be made securely available in cloud repositories, and big data techniques can be used to analyze failure patterns and failure modes for equipment categories, and identify the performance characteristics associated with particular manufacturer or equipment types.

Methods, Procedures, Process
This paper describes some technologies employed in digitalization, ranging from the basic connectivity infrastructure to data-gathering and storage and techniques for extracting new information from big data. We also discuss how organizational form affects the ability to realize value from integrated operations and digitized assets.

Results, Observations, Conclusions
One main issue for these facilities is data "lock in", in the sense that data availability across departments, to other systems and external experts is limited by proprietary data models and systems. However even if a cloud type repository is desirable, this also gives challenges in cyber security and protection of proprietary data. A second challenge in the implementation and deployment phase is to underestimate or even neglect the need to change work processes, including operation model. We present the "8 steps to a maintenance plan including CBM and PBM" developed as a result of these experiences.

Novel/Additive Information
In normal situations, even fractional improvements in plant uptime is by far the largest contributor to improved earnings. About 40% of production loss is related to preventable operator errors. In a normal plant, this could account for 1-2 % of total plant production capacity. The second contribution to plant uptime comes from elimination of unplanned shutdown. Condition based maintenance systems assist the operator in correct response to possible malfunction e.g. by shifting to redundant equipment or reduce load on equipment until maintenance action can be performed. In-operation failures can be reduced by over 90% and contribute an additional 2-3 % points to plant availability. Critical safety events are often the result of multiple maintenance safety issues, each non-critical, developing into an unmanageable situation. Finally, the actual cost of maintenance is reduced by 15-40%. In typical projects the total cost of maintenance operations is equivalent to half the EBITDA of the plant and so is a significant contributor to financial performance.
Quantification and Modelling of the Dynamic Wake Effect for Floating Offshore Wind Turbines
Authors: Singapore Wala Abdulqadir Aziz , Ng Eddie Yin-Kwee , Bahuguni Anand , Srikanth Narasimalu 
Published: April 2017

Abstract
Modelling the aerodynamic forces on floating offshore wind turbines (FOWTs) is a challenging task due to the motion of the floating platform, which result in flow transients and associated aerodynamic effects. Each of these needs to be modelled and implemented, before a complete aerodynamic model of the FOWT can be presented. Of special interest is the dynamic wake effect, a result of the time lag between rotor forces and the air flow deceleration within the wake. The dynamic wake effect may present itself significantly in several scenarios including gust loads, changing wind speeds and direction, and the oscillatory motion of the rotor due to platform motion from wave forces. The complexity of the problem is substantiated by the added mass effect, which must be accounted for when considering rotor motions through the air. Computational fluid dynamics (CFD) simulations and blade element momentum (BEM) computations have been performed for the NREL 5MW virtual wind turbine in axial flow and surge motions at different frequencies and amplitudes, to quantify and model the dynamic wake effect, including the added mass effect for rotor motion. This dynamic wake model is then implemented in an unsteady blade element momentum (uBEM) code, for a more complete model of wind turbine aerodynamics.
The Value of Pressure Relief in Hydraulic Fracturing Operations
Authors: House Ryan , Pry Mike , Pitcher Jason 
Published: April 2017

Abstract
In hydraulic fracturing operations, pressure pumping companies have long required a mechanism to relieve overpressure events prior to damage occurring to the systems. Traditionally, pressure pumpers have used mechanical or hydro-mechanical devices that are either one-time use, such as burst disc, or springs under compression. Both systems have fundamental disadvantages in the context of efficient and cost effective operations. There is also the case that if the well requires pressure operations within the setting tolerances of these systems, they are not employed at all, risking overpressure damage to frac iron or wellhead equipment.
This paper introduces a new method of pressure threshold assurance, with a pressure monitoring system that is responsive enough to control a new design of rapid acting hydraulic valve actuator. In this application, this is mated with a standard gate valve that is installed on a bleed off leg from the frac flow lines. This allows very fast acting pressure relief, proactively protecting the system against costly over pressure events and potentially averting screen outs.
A discussion of the design and function of the new solution, with due regard to limitations, best practices and workflows will be demonstrated, providing an examination of the results of operational case histories. Some of the benefits that have already been realized, and the potential for further implementation are proposed, as well as highlighting operational differences vs current technology that deliver value to pressure pumpers and operators.
With a proven ability to relieve pressure within very tight tolerances, this new system allows for operational gains associated with resetting the system and retaining system integrity, but also allows operators to pump jobs in a much tighter pressure window than before. Unexpected benefits are that lower pressure wellhead equipment can be safely used without risk of costly integrity issues. Other examples of how this system provides surety to pressure pumping operations are examined.
A More Holistic Approach to Oilfield Technology Development
Authors: Sequeira M. , Elshahawi H. , Ormerod L. 
Published: April 2017

The latest oil industry downturn has had a dramatic impact on innovation in the oil and gas industry. Staff and budgets have been cut dramatically, large field developments have been deferred, and new technology initiatives have been severely cut or entirely cancelled. As a result, most oil and gas companies and their supply chain have radically downsized. Some have simply right-sized, and others have completely capsized. Finally, new oil & gas discoveries around the world dropped the last couple of years to their lowest levels since the 1940s after companies sharply cut back in their search for new resources amid falling oil prices. This makes offsetting natural depletion of existing fields even more challenging and can lead to potential supply shortages by the end of the decade. This type of implosion is symptomatic of dramatic commodity price collapses. Remaining competitive in this challenging environment requires a more strategic and holistic approach to oilfield technology development.
Experience shows that the vast majority of R&D and technology initiatives fail to reach commercial deployment. Success is often measured as the ability to progress through a mostly technical stage-gating process, with little consideration given to the commercial validity of continuing to invest time and resource. This results in far too many projects tenaciously marching into the classic "Valley of Death" - the virtual chasm that separates innovation from commercial demonstration. Yet technology and innovation will still be needed to safely find, develop and operate especially with the operating conditions and overall business environment becoming ever more challenging. Service companies must also remain technically and commercially competitive as a matter of urgency, if not survival. Thus, while technology leaders must be prepared to intervene by cutting, stopping, or divesting programs that are off track, they must also continue to replenish and rationalize their technology portfolios to differentiate their companies.
The approach described in this paper takes a holistic view of technology maturation which addresses both technical and non-technical risks, which is by design more concurrent than serial. The definition of success is expanded to include the establishment of successful, commercially viable, and sustainable solutions that meet end user needs and requirements. Improving the efficiency and effectiveness of technology development and investing smarter allows operators and service providers to leverage new technologies to address existing and evolving challenges and to remain competitive now and in the future.