bluuebunny/crossref_metadata_2025_split huggingface dataset:
Autonomous Non-Destructive Remote Robotic Inspection of Offshore Assets
Authors: Ivan Vladimir , Garriga-Casanovas Arnau , Merkt Wolfgang , Cegla Frederic B. , Vijayakumar Sethu 
Published: April 2020

Abstract
Offshore assets suffer from material degradation over their lifetimes. Regular inspections are necessary to prevent failures and to reduce the cost of maintenance. These often require downtime of the asset and can involve risk to human workers who have to be sent to the offshore location. In this work, we present a non-destructive (NDE) system in conjunction with a robotic platform, which can perform inspections of the thickness of a component, for example from the outside of a tank or a pressure vessel. The NDE system consists of a digital acquisition system and an electromagnetic acoustic transducer (EMAT). The EMAT generates an acoustic wave, which reflects from the internal features of the component. The wave is received by the same device. The received signal is then processed by the acquisition system to determine the thickness of the component. The NDE system is integrated with a robotic platform that can autonomously or semi-autonomously perform scans of the asset. The robot platform presented in this work uses sensor fusion, machine vision and state of the art motion planning techniques to build a map of the material quality in 3D. This is achieved by exploiting the precise movement of the robot end-effector along the surface of the asset and then integrating the position of the NDE sensor. The collected data is then presented to the remote operator in a user-friendly way, which allows them to evaluate the state of the asset. We validate this system using material samples with known defects. We performed experiments in a controlled environment, and we demonstrate the system in a case study at a testing facility operated by our industrial partners.
Dynamics of Hydrate Behavior in Shut-In and Restart Condition in Two and Three Phase System
Authors: Kakitani Celina , Marques Daniela C. , Neto Moisés A. Marcelino , Teixeira Adriana , Valim Leandro S. , Morales Rigoberto E. M. , Sum Amadeu K. 
Published: April 2020

Abstract
The oil and gas production in deeper water scenarios (e.g. pre-salt) has been increasing due to the growth in industrial production. The exploration fields under more severe conditions is accompanied by concerns about solid precipitation/deposition and hydrate formation. Transient operations, involving shut-in and restart is the most challenging scenario with risk for hydrate problem. The residence time of the production fluids associated to the rate of heat loss to the ambient seabed during the period of shut-in may increase the potential risk of hydrate blockage. This work is focused on understanding the hydrate formation, breakup, agglomeration and deposition, reproducing the shut-in and restart conditions in a lab-scale. Experiments were performed using a high pressure cell coupled to a rheometer using a custom-designed impeller and a rocking cell experiments with visual capabilities. A two-phase (water and gas) and three-phase (water, oil and gas) systems were used in the experiments. Also, the impact of the shear applied at restart on the hydrate morphology was evaluated. The viscoelastic behavior was observed in most shut-in and restart tests. Understanding the mechanism of hydrate formation and agglomeration during transient conditions may help to develop strategies to avoid hydrate plugging and allow the formation of a hydrate slurry yielding flowable conditions.
Bottom-Up Analysis to Unravel Potential Problems and Emphasize the Impact of Individual Steps in Closed-Loop Field Development
Authors: Loomba Ashish Kumar , Botechia Vinicius Eduardo , Schiozer Denis José 
Published: April 2020

AbstractClosed-loop field development (CLFD) is a feedback-based approach to optimize production strategy by utilizing new information iteratively during field development. Positive and negative results have been presented in previous work using CLFD, so this paper presents a bottom-up assessment of CLFD workflow to exhibit the impact of individual steps on the workflow, highlighting associated potential problems and, finally, proposing a methodology to tackle these problems.Our CLFD workflow consists of updating static information, assimilating dynamic data to select an appropriate subset of models and, finally, selecting representative models to optimize the production strategy under uncertainties. We performed four activities to expand our understanding of CLFD by applying the workflow on UNISIM-I, a benchmark case study: (1) applying the aforementioned CLFD workflow, (2) applying the workflow after modifying objective function of optimization process, emphasizing the likelihood of success of optimized production strategy over the ensemble of simulation models, (3) applying the workflow after modifying the objective function, as well as the criteria for selecting the appropriate subset of models, post dynamic data assimilation, and (4) reanalyzing the results of activity 1 after using flexibility of drilling (FoD) - an approach proposed to partially imitate the real-time decision-making process to ensure that the heel of a well is not drilled in a non-reservoir zone, by utilizing the available information.The application of the initial CLFD methodology (first activity) led to an increase in expected monetary value (EMV) based on simulation models, but we observed a decrease in EMV when we implemented this optimized strategy in the reference case UNISIM-I-R (a very refined model that emulates a "true field"). This negative result formed the basis for our motivation to perform the bottom-up analysis. During the second activity, our attempt to improve the optimization process using a new objective-function, led to a significant improvement in EMV for the reference case, compared to the first activity. Re-applying the CLFD workflow using this newly tested objective function, while using stricter criteria for selecting approved models (third activity), provided an optimized production strategy for the reference case. Last activity provided a deeper insight into the CLFD workflow. Application of FoD, during the fourth activity, revealed that the poorer results during the first activity can be segregated into two separate components: (a) relatively poorer CLFD workflow and, (b) ignoring FoD to ineptly drill the wells in non-reservoir zones.The bottom-up approach helped us systematically improve the CLFD workflow. Implementation of the improved workflow ensured that the optimized production strategy not only improved EMV for simulation models, but also the reference case.
The Science of Sequencing Well Programs
Authors: Danner George Earl 
Published: April 2020

Abstract
The order of drilling a collection of wells matters. One possible sequence gives you an NPV and a total duration and another slightly different sequence of the same wells can yield an altogether different outcome, even simply swapping two wells in order. The nonlinearity of optimizing the sequence means that above a very small number of wells it is impossible for a human to intuitively identity the optimal sequence—the one sequence that yields the "best" possible outcome. As a guide, sequencing 13 wells has a surprisingly large solution space of 6.2 billion possibilities.
We must harness computing power to understand the optimal sequence of wells to drill and complete. Facilities have to be timed perfectly to be in place when the wells are ready for production. Zipper frac opportunities arise in a once-in-a-billion chance when two adjacent wells allow it to be done in a practical way. The special math of optimization is used within a computer model to calculate the optimal sequence, and the associated KPIs such as profitability and total program duration. In effect, it is as if the computer model tries every single one of the billions of possible sequences, and places the leaders on an ever-shifting leaderboard as it goes along.
In our talk we will elaborate on three past projects where we have applied analytical engines to discover optimal well sequences with lessons on how to reproduce this work in your own drilling operations.
Conventional approaches to optimization, such as those found in downstream applications like refining do not always work adequately for well sequencing due to the highly non-linear nature of the constraints, such as spatial interference between bit positions of adjacent wells. We will discuss a heuristic (non-traditional) approach that was required in one particular case of well sequence optimization.
Soil Modeling for Pile Driving Simulations Using a Vibro Hammer
Authors: Bielefeld Marcel , Moscoso Nicolas , Verbeek Gerald 
Published: April 2020

Abstract
As vibratory driving is increasingly used to install offshore foundations, especially for offshore windfarms, an accurate soil model is key to reliable pile driving predictions and thus to improved project planning and execution. During the pile driving, the soil properties, and thus the soil parameters, do not remain constant. For vibratory driving, this effect is generally simplified by the application of the Beta Method, which was first proposed by Jonker in 1987[1]. While this simplified approach could be justified based on the computing capabilities at that time, a more sophisticated soil model should be used as part of pile driving simulations to ensure that the results are more accurate.
In this paper, the state-of-the-art soil model for vibratory driving will be described and then illustrated through two brief case studies where the pile driving simulation results are compared with the actual installation records. The paper will show that while the predictions are not perfect, they forecast the pile driving process realistically. To further enhance prediction capabilities, the paper will suggest that pile driving with vibratory hammers is monitored and that the recorded data be used for post-processing to gain a more in-depth understanding of the soil behavior.
Standardization Of Procurement Equipment Specifications: Establishing A Strong Foundation For Oil & Gas Capital Project Development And Delivery
Authors: Postema Adri , Ray Tony , Jack Bristow 
Published: April 2020

Abstract
Industry-wide standardization is needed for operators to manage the $3 trillion in CAPEX expenditure forecast for 2018-2025 (Global Data, 2018), while maintaining competitiveness and mitigating risks.
With the backing of the World Economic Forum, Joint Industry Program 33 (JIP 33) was initiated to drive industry-level standardization for the procurement of equipment items, moving the industry structurally – across the value chain - towards common engineering designs and solutions established by means of cross-company collaboration.
Fourteen (14) standard specifications have been delivered to date. Their adoption by 12 major operators is being measured and is progressing well. This enables the program to capture and evaluate successes, challenges, key learnings and feedback. The program is also establishing a process for future maintenance of JIP33 specifications in order to achieve sustained benefits.
A further 35-40 supplementary specifications are being developed, based on recognized industry or international standards by the end of 2020.
This paper will present the status of the JIP33 program and showcase some of its early successes, challenges and learnings. Experience with digital requirement developments will be shared, as well as learnings from the adoption and use of the Phase 1-2 specifications by JIP33 members.
Risk-Based Offshore Decommissioning Standards and Regulations
Authors: Pollett Buford Boyd 
Published: April 2020

Abstract

Objectives/Scope
This paper will examine the current process in establishing decommissioning standards and regulations for the offshore energy industry. Further, this paper will examine the extent some of the current decommissioning standards and regulations utilize a risk-based approach to setting standards and promulgating regulations.

Methods, Procedures, Process
The author will review how the classification societies establish standards and certain government agencies execute regulations concerning offshore decommissioning activities.

Results, Observations, and Conclusions
Since standards and regulatory policies and procedures can substantially impact the profile of companies investing and operating in the petroleum industry, this paper will highlight how risked based standards and regulatory policies and procedures may enhance reliability for end of life cycle activities.
Similarly, other sectors of the energy industry should also appreciate that the end of life-cycle regulatory regime the petroleum industry now faces in many cases may be the regulatory regime that these sectors will face going forward.
Therefore, professionals and stakeholders should work together to promote transparency, and collaboration as well as a practical approach to ensure that decommissioning standards and regulations are both realistic and sufficient.
This paper will discuss the areas of coordination to enhance safety, mitigate against environmental risks, and otherwise provide potential solutions in achieving and maintaining a social license to operate.

Novel/Additive Information
Also, the paper will promote knowledge sharing of risked-based decommissioning standards and regulations in a collaborative effort to enhance the protection of stakeholder interests. Correspondingly, this paper will examine the potential pros and cons of using risk-based assessments in establishing decommissioning standards and regulations.
Deep Learning Toolkit: Shallow Geohazards Case Study
Authors: Krueger Ana , Endresen Paul , Omoboya Bode , Lartigue Benjamin 
Published: April 2020

Identification of shallow hazard features at the sub-surface are performed via seismic interpretation of high-resolution three-dimensional (3D) seismic surveys. Today, seismic interpretation is a fastidious and time-consuming process. Usually an interpreter must spend weeks or months to fully interpret this type of survey and its volume. Deep learning methodologies utilizing neural networks are currently revolutionizing seismic interpretation by accelerating the speed in which geologic features such as faults, salt diapirs, and gas chimneys can be mapped. It has become an industry goal to utilize neural networks for all uses of seismic interpretation, including shallow hazard identification.
There have been challenges to the adoption of machine learning, to the interpretation of shallow hazards. The results of this interpretation have a direct impact on drilling safety and therefore its accuracy is paramount. Traditional machine learning technologies do not consider the human experience and abstract thinking required for seismic interpretation. For interpreters to fully trust the results of the neural networks, they must spend an extensive amount of time conducting quality control of the results and editing as needed. Traditional machine learning technology requires a significant amount of time to be spent on data preparation.
Our project has two main goals. The first goal is to create technological improvements to enable humans to work interactively with neural networks. The second goal is to reduce the amount of time spent in data preparation to zero. We present a new interactive deep learning methodology, that differs from existing methodologies and achieves these two goals. We have built our methodology on top of our proprietary technology that provides random data access to seismic data, enabling interactivity between the neural network and the geoscientists, therefore putting geoscientists in complete control. Our methodology eliminates the burden of data preparation methodologies, because it does not require prior randomization of the seismic data like older technologies. We achieve acceleration, and improved results in the seismic interpretation of shallow hazards.
Streamlining Zinc Removal From Completion Fluid Flowback And Produced Water In Offshore Oil & Gas Production
Authors: Broussard Shane , Burclaff Philip 
Published: April 2020

Abstract
This paper and its presentation provides an overview of an innovative way to treat zinc-contaminated water that might, for example, result from the use of completion fluids with extremely dense zinc bromide—up to 19.2 pounds (8.7 kilograms) per gallon—in high-pressure wells. Traditional approaches to treating zinc from completion fluid flowback and produced water are cumbersome and costly, with potential for perpetual liabilities associated with onshore in-ground disposal. Discussed will be a simpler, highly effective system that can save as much as 25 percent or more in zinc treatment and disposal costs.
The patented system combines two technologies—reverse osmosis (RO) membrane and ion exchange (IX) resin—to minimize zinc waste volumes. It works without chemicals and has a relatively low residence time. By selectively removing zinc, the remainder of the salts and most of the water can be discharged to the ocean. The zinc-removal system is available in two options: (1) RO with IX and (2) IX only. Both components arrive in a skid-based, offshore package. The entire system is fully compliant with API RP 14C safety standards and can operate as a standalone or integrated with pre-treatment systems that separate oil and other contaminants from completion fluid flowback or produced water.
In a 2019 efficiency test with a large independent E&P operator in the Gulf of Mexico, the system treated 36,387 barrels of water using five pairs of IX resin columns that together averaged 5 barrels-per-minute flow rates, with four total backwash cycles. Because the TDS of the produced water was already high, RO was not needed as part of the treatment system. Ultimately, the operator was able to discharge 35,400 barrels of water overboard instead of being collected and sent ashore. Only 900 barrels of zinc water from the IX resin columns needed to be sent ashore for disposal, although that amount was reduced by 75 percent to just 225 barrels upon the system's second deployment a month later.
Accelerating Petroleum Project Delivery Through a Lean Operational Readiness Structure
Authors: Kusumawardhani Mayang , Markeset Tore , Kumar Rajesh 
Published: April 2020

Abstract
Delivering a petroleum project on time and on budget in a safe and quality manner is one of the main goals in every project. Especially with the fluctuating oil price, the need of meeting the budget, quality and schedule increases. The paper proposed to improve the project delivery time through integration of functions in the operational readiness and assurance (ORA) structure.
This study was validated by broad respondents of industry practitioners to review the suitability of the proposed structure. The study also aims to gain insight into ORA from the industry practitioners, since most of the available methods are patented or owned by the organizations.
In addition, the ORA processes will focus on identifying and minimizing the potential operation risks early in the project phase and ensuring that the project delivers the best possible value to the business. The process will be illustrated and explained in the paper. The paper will guide the Readers through the control and alignment of actions, tasks and deliverables organized under the knowledge areas that are maintained throughout the project.
Suction Pile Seabed Landing and Vents Calculation
Authors: Løkke Arnkjell , Rahim Amir , Schrøder Knut 
Published: April 2020

Abstract
A computer program has been developed to simulate the landing of suction piles on the seabed. The procedure is based on the dynamic analysis procedure outlined in DNVGL-RP-N103 (DNVGL 2017) and calculates the pile motion as it penetrates the soil using a time integration scheme to simulate the dynamic seabed landing. The analysis method considers all significant forces acting on the pile with their time-dependent values, including gravity, buoyancy, crane wire tension, hydrodynamic pressure within the pile, and soil resistance. The program can be used for a given pile geometry to determine the maximum allowable lowering velocity that does not lead to foundation failure. Or for a given lowering velocity, determine the minimum allowable vent area in the pile.
The DNVGL procedure is numerically challenging to implement because iterating on the main unknown variable (the incremental soil displacement) using the last known state parameters will not necessarily lead to convergence towards the ‘correct’ solution. The use of a line search algorithm is proposed to overcome this issue. The results of a sensitivity study are briefly presented to investigate how the main parameters influencing the results.
The dynamic analysis method is also compared to the traditional ‘simplified method’ of DNVGL-RP-N103 Section 6.2.6 which considers only static forces acting on the pile and neglects the beneficial dynamic effects of damping. The advantages of using the dynamic method over the simplified method is discussed.
Gas Hydrate Formation & Transportability During Transient Shut-In/Restart Conditions
Authors: Pickarts Marshall A , Croce Daniel , Zerpa Luis E , Koh Carolyn A. 
Published: April 2020

Abstract
Hydrates are crystalline water compounds that may form in deepsea pipelines and have the ability to quickly and efficiently plug flow. Given this issue, gas hydrate formation tests have been conducted and reported in a number of published articles. However, most published data has focused on continuous "steady-state" operations and a gap exists for the more complicated, yet interesting transient shut-in/restart scenarios. Motivation to study such systems are further exacerbated given that industrial fields can operate outside the gas hydrate formation region during continuous production. Hydrates become a major concern especially during unplanned shutdowns and restarts. Therefore, this work focuses only on hydrate transient results. Industrially relevant scenarios are investigated by looking into gas hydrate formation and its effect on fluid transportability through visualization and pressure drop during shut-in and restart in a laboratory-scale flowloop.
The effects of parameters such as water content and dispersion state, shear, chemical injection, and oil properties on hydrate formation under transient conditions are reviewed and general agreement is shown between the studies. Overall, the general consensus is that lower water contents, dispersed water, high shear, thermodynamic inhibitor injection, dosing of anti-agglomerants or kinetic hydrate inhibitors, higher oil viscosities, and oils with natural chemical surfactant properties can be favorable for ensuring successful restart of hydrate forming systems.
Flowloop tests in a gas-dominated system show that film growth over and around the liquid pool at the bottom of the pipe could lead to plugging in a significant portion of the flowline. This could continue to build up over time (with the addition of fresh hydrate forming materials in an actual system) and inhibit gas flow. Further tests on an oil-dominated system with an intermediate water content demonstrate how shut-in conditions could potentially increase the risk of plugging compared to dispersed lower water content systems. In the former case, water accumulation to low spots in the flowloop allowed for localized areas of high water concentration, where rapid hydrate bed formation in partially dispersed oil-water sections controlled the overall fluid transportability.