bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of a Transient Deposition Model for Hydrate Management in a Subsea Gas-Condensate Tieback
Authors: Charlton Thomas B. , Kegg Stuart , Morgan Julie E. P. , Zerpa Luis E. , Koh Carolyn A. , May Eric F. , Aman Zachary M. 
Published: April 2019

Abstract
This study provides valuable insights into hydrate management strategies as the industry transitions away from complete hydrate avoidance, particularly for the development of deep-water reservoirs with stricter economic margins. Transient simulation tools, such as the deployed hydrate deposition model, extend our ability to estimate blockage likelihood from heuristics to quantitative predictions. The model is applied to an insulated subsea tieback to identify the optimal no-touch-time (NTT) and depressurization pressure (DPP) following an unplanned shutdown. Two water-production scenarios are considered, from the lowest expected to the highest manageable rates. A complete hydrate blockage is predicted when the NTT was extended several hours beyond the nominal value for the highest water-to-gas ratio (WGR). Complete blockages are predicted for both low and high WGRs when the flowline is only partially depressurized, however, longer cooldown times for the high WGR case (due to greater volumes of residual liquids) meant a blockage took more than twice as long to occur than for the low WGR case. Fully depressurized restarts are both difficult and time consuming, leading to hydrate volume fractions (with respect to the pipe volume) exceeding 30 vol.%. An alternative hydrate management strategy is identified for cases with high volumes of water production, in which the flowline is only partially depressurized once the nominal NTT has elapsed, utilising the increased heat capacity of residual liquids. This reduces the quantity of gas sent to flare and simplifies the restart procedure.
What Offshore CCS Will Look Like in the Gulf of Mexico - Perspectives from Texas
Authors: Meckel Tip A , Hovorka Sue , Trevino Ramon 
Published: April 2019

Abstract
Since 2009, the Gulf Coast Carbon Center at the Bureau of Economic Geology (The University of Texas at Austin) has undertaken multiple integrated geologic and geophysical studies to evaluate the continental shelf in the Gulf of Mexico for CO2 storage. Funding for these studies has come primarily from the U.S. Department of Energy (NETL), but also from the State of Texas General Land Office, which administers the State offshore resources. A recent award-winning publication (BEG Report of Investigations No. 283) compiles the diverse topics explored during this long history of characterization: Geological CO2 Sequestration Atlas for Miocene Strata Offshore Texas State Waters. This is the first attempt to comprehensively address CO2 storage topics for the near offshore in the Gulf Coast. Topics addressed in the volume include Miocene stratigraphy and depositional systems with regional cross sections, implications of petroleum systems for CO2 storage, microscopic and stratigraphic evaluation of anticipated primary seals, regional static capacity estimates, and field-scale examples of storage reservoirs (including modelling and simulation). Detailed stratigraphic and structural interpretation of hundreds of wells and faults using integrated 3D seismic data is now continuous over an area greater than 5,000 square kilometres (2,000 square miles). In three localities a total of 137 square kilometres (53 square miles) of novel high-resolution 3D seismic data has been acquired to understand technological capabilities for imaging the overburden above injection reservoirs, and to address characterization, risk reduction, and monitoring needs. General conclusions from this work are that the inner shelf of the Gulf of Mexico presents superb geology for CCS with ample storage capacity. Sources and developing pipeline infrastructure are well located for development of offshore storage hubs. The thick and relatively young and porous clastic Miocene stratigraphy has multiple regional confining intervals deposited during regional sea level transgressions. Static CO2 storage capacity estimates beneath the Texas State waters between Mexico and Louisiana total more than 30 Gt, including both depleted hydrocarbon reservoirs and saline intervals. More regional assessments identify approximately 125 Gt of storage. This offshore geologic CO2 storage resource is regionally and nationally significant, is available for both CO2 sequestration and enhanced oil recovery (EOR), and is likely to be the most appropriate region for giga-tonne scale storage in the United States.
A Case Study – A Systems Approach for 20 ksi Equipment Qualification
Authors: Raney James Brian , Walz Gregg , Kaminski Dennis , Moscalu Stella , Dighe Sourabh , Maguire Pat Glen , Peurifoy Charles Kenneth , Quates Ron Duane , Rettie Stuart Douglas , Swider Jan , Wilson Alan Lee , Baskett David Charles , Boster Patrick , Byrd Mike , Dickerson Gregg , Douglas Scherie , Gallo Charley Daniel , Graff Richard Lee , Hennig Jake , Hodge Quincy Michael , Kluk Dan Joseph , Pham Man , Rowe Adam C , Smiles Les John , Urquhart Robert James , Parker Wanda June 
Published: April 2019

Anadarko started the initial development and qualification of 20 ksi equipment in 2013 for a Gulf of Mexico (GoM) project. That journey included an analysis of using depth-adjusted working pressure of 15 ksi equipment that allowed exploration and appraisal drilling of a high-pressure GoM prospect. It continued with the goal to develop and qualify a complete set of 20 ksi equipment for a deepwater GoM high-pressure development. The scope of development and qualification of High-Pressure, High-Temperature (HPHT) equipment included:
20 ksi deepwater Mobile Offshore Drilling Unit (MODU);
20 ksi subsea Blowout Preventer (BOP);
20 ksi Completions equipment for the upper completion including a subsurface safety valve, packers, chemical injection, wireline plugs, etc.;
20 ksi Intervention equipment including a thru-riser intervention string, a Tree Tieback Tool, workstring connection and an Integrated Workover Control System (IWOCS);
20 ksi Subsea Production equipment including wellhead, tree and a High Integrity Pressure Protection System (HIPPS).
Anadarko formed the ‘20A project team’ initiative in order to qualify these critical deepwater components with a Rated Working Pressure (RWP) greater than 15 ksi. This project is coming to a close in 2019, with the qualification of over 200 components and assemblies to industry standards and meeting U.S. government requirements. This six year development journey of 20 ksi equipment development and qualification presented challenges and achieved breakthrough technologies for the industry. This journey, its organizational approach using systems engineering techniques and integration processes are presented.
The Subsea Sand Management Challenge – What to Do with the Sand?
Authors: Rawlins Charles H. , Ditria John C. 
Published: April 2019

AbstractSand is a limiting design factor for facilities in terms of operability, throughput, and maintenance. These effects are more critical when dealing with subsea processing due to the equipment access and risk exposure. Technologies for erosion management, sand separation, and solids disposal are well proven for surface facilities. For example, the wellhead desander, located upstream of the choke, effectively separates sand from the multiphase well flow and can be marinized for subsea use. However, the crucial question is "What to do with the sand?" This white paper provides a focal point for the discussion on sand management in subsea processing. The broad categories for dealing with sand include neutralization of the effects, improvements in conventional design, and separation with disposal. These categories have been analyzed based on the conventional design, treatment of the solids, and removal of the solids. More than thirty discrete treatment routes were surveyed, including conventional production limits, flow path modification, chemical treatment, sand cleaning, mechanical attrition, slurry fracture injection, and accretion disposal. Many of these technologies have analogues in other particulate processing industries that can be adapted to upstream oil and gas production. This work is part of ongoing research in Facilities Sand Management with the goal of improving the hydrocarbon recovery through inclusionary sand production.
Maximize the Recovery Factor of Offshore High Water Cut Reservoir
Authors: Ma Kuiqian , Sun Zhaobo , Shi Hongfu 
Published: April 2019

Abstract
As the Offshore oilfields enter the high water cut stage, it encounters new and prominent problems such as difficulty in developing remaining oil, increased water breakthrough and rapid decline in production. How to maximize the recovery of high water cut offshore reservoirs and improve economic efficiency is a challenge.
This paper reviews the lessons learned on how SZ field improves water injection to stable reservoir pressure. Architecture unit-based well pattern improvement, Increasing injection and big-pump enhanced liquid production including renovation and capacity expansion of Water treatment system; Polymer flooding, Modifying reservoir flow pattern with Gel Treatment, Polymer Microspheres.
The wells display positive responses from the water injection. The responses include stable reservoir pressure, slower production increase, and slightly water cut increase. Enough and high quality water injection is extremely essential to maximize the recovery of a mature offshore heavy oil.
An Experimental Study of Using Plasma Shock Wave for Rock Damage
Authors: Cai Zhixiang , Zhang Hui , Li Jun , Yang Maolin , Yu Qing , Zheng Jiadong , Liu Kerou 
Published: April 2019

Abstract
Plasma shock wave (PSW) has been proven to be able to destroy rocks and improve the ROP for conventional rotary drilling. The aim of this paper is quantify the damage caused by PSW generated by different discharge energies, and to study the mechanism and characteristics of PSW damage to rocks.
The PSW has been extensively used in many areas, such as alternative fracturing. In the tests, the PSW reactor generated the electrohydraulic effect to convert electrical energy into mechanical energy, which was sufficient to destroy the hardest rock. Firstly, the experiment was carried out using concretes instead of real rocks. Secondly, three types of discharge energy were used to generate PSW to damage samples. Finally, the amplitude attenuation coefficient (AAC), the damage variable and the drillability were used to quantitatively analyze the damage of the samples.
Experimental results showed that samples were impacted to produce many circular holes and cracks and the damage to samples increased as the energy increased. However, when the energy rose to a certain extent, there was a gradually decrease in the growth rate of damage. In addition, it was found that the AAC measured at different locations was different for the same sample, which indicated that the internal damage of a concrete sample produced by the PSW was anisotropic. Finally, the average drillability was improved after the sample was subjected to PSW impact.
The findings gained will help understand the mechanism by which the PSW destroys rocks It also provide some methods to quantitatively evaluate damage of rock.
Application of Data Science and Machine Learning Algorithms for ROP Optimization in West Texas: Turning Data into Knowledge
Authors: Noshi Christine Ikram 
Published: April 2019

Abstract
A high rate of penetration (ROP) is considered one of the most sought-after targets when drilling a well. While physics-based models determine the importance of drilling parameters, they fail to capture the extent or degree of influence of the interplay of the different dynamic drilling features. Parameters such as WOB, RPM, and flowrate, (Mechanical Specific Energy) MSE, bit run distance, gamma ray for each rock formation in West Texas were examined. Ensuring an adequate ROP while controlling the tool face orientation is quite challenging. Nevertheless, its helps follow the planned well trajectory and eliminates excessive doglegs that lead to wellbore deviations.
Five different Machine Learning algorithms were implemented to optimize ROP and create a less tortuous borehole. The collected data was cleaned and preprocessed and used to structure and train Random Forest, Artificial Neural Networks, Support Vector Regression, Ridge Regression, and Gradient Boosting Machine and the appropriate hyperparameters were selected.
A successful model was chosen based a minimized deviation from planned trajectory, minimized tortuosity, and maximized ROP. A MAE of 10% was achieved using Random Forest.
The algorithms have demonstrated competence in the historical dataset, accordingly it will be further tested on blind data to serve as a real-time system for directional drilling optimization to enable a fully automated system.
Reducing Costs in Building a Dataset Using Deep and Active Learning
Authors: Castro Filipa , Costa Pedro , Marques Filipe , Parente Manuel 
Published: April 2019

Abstract
Deep learning, a subset of machine learning, allows computers to perform certain tasks, such as image or video recognition, with human level performance. However, deep models need huge amounts of data to learn from, which requires that experts spend their time in the repetitive and non-scalable task of labelling datasets. Active learning suggests that one can minimize the cost of annotation if a model is allowed to smartly choose the best data samples to be labelled. Therefore, we propose a deep and active learning approach that aims to minimize the labelling effort while maximizing the performance of a model for a certain task. We present the task of detecting fish in Remote Operated Vehicles (ROV) videos as a real world problem in which our framework can be successfully applied. To start with, we demonstrate that active learning outperforms random sampling, which is the simplest approach for building a dataset. Besides, we study several active learning settings for the given task, namely different acquisition and aggregation functions. Finally, the proposed methodology is shown to achieve top performance in detecting fish by using only 19% of the available data, thus reducing the cost of building our fish dataset by more than 80%.
New Pressure Sensor Technology in the Offshore Industry
Authors: Andrew David Alexander 
Published: April 2019

Abstract
A new pressure sensor technology packaged with a target for high stability and high reliability applications has been released, a single crystal integrated capacitance sensor that shows promising results for use in subsea and offshore environments. This paper details the laboratory results of qualification tests with a comparison to industry-leading technologies and presents some examples of how this sensor technology can be used to benefit the industry. Design validation testing was undertaken to full transmitters, in many cases with a direct comparison to quartz-based sensors.
This technology could open doors to new applications, and it can be configured to the target application. The use of the sensor in certain applications has the potential to reduce costs and increase yield in offshore exploration and production. The qualification data presented here could provide insight into available transmitter capabilities.
The single crystal integrated capacitance sensor could fill a gap in the industry for a sensor that stabilizes rapidly to thermal effects while exhibiting excellent long-term drift behavior. The thermal transient error is less than that of the quartz sensors it was tested against, and it allows for larger, continuously changing thermal gradients, with fewer errors. This sensor also allows for an increase in duration between zeroing, unlike typical piezoresistive sensor specifications.
The packaging and electronics are customizable for a wide array of solutions. The configuration of the transmitters detailed in this paper was specifically tailored toward data rates of 1Hz or less, 175°C operation, and tolerance to H2S containing environments. Future possibilities can target higher resolution, data rates, and alternate temperatures.
50 Years of Offshore Technological Innovation Illuminates Millennia of Archaeological Discoveries
Authors: Faulk Kimberly L. 
Published: April 2019

For millennia, humanity has and continues to leave imprints on the physical world. Archaeologists have often turned to technology for help in interpreting these past imprints. This is especially so in the realm of underwater archaeology where sites may range from submerged prehistoric landscapes to what was for thousands of years one of human kind's most technologically complex objects, the ship.
Since the close of the Second World War, offshore technology has increasingly created opportunities and tools for subsea scientists to better map, explore, and understand both our natural world and humanity's interaction with it. The growth of offshore oil and gas exploration technology did not go unnoticed by archaeologists who were quick to modify these technologies and create new methodologies to use them for site analyses.
Starting with shallow water locations and ultimately moving into ultra-deepwater, marine archaeologists in the energy sector have greatly benefited from technological improvements originally aimed at the exploitation of offshore oil and gas. Beginning with echosounders, side-scan sonars, and magnetometers in towed arrays, before moving into high-resolution side-scan sonars, multibeam bathymetry and multibeam backscatter systems, subbottom profilers, and gradiometers, improving technologies have directly impacted marine archaeology.
This paper provides a review of the technologies archaeologists have appropriated for the purposes of revealing humanity's past with examples of some of the discovered sites from around the globe.
The Definition and Manufacture of a Seawater Compatible Surfactant for an Offshore Chemical Enhanced Oil Recovery Pilot
Authors: King Timothy E , Doll Mike J , Crom Lori A , Barnes Julian R , Kunkeler Paul J 
Published: April 2019

Abstract
Experiences from a chemical supplier perspective are presented to define, optimize and manufacture a surfactant for use with seawater in an offshore enhanced oil recovery (EOR) test. This includes laboratory screening test results followed by quality control checks during manufacture. The surfactant concentrate was successfully manufactured, diluted with seawater, and injected as the main component of a surfactant-polymer (SP) formulation.
A branched C12,13-alcohol-7PO-sulfate surfactant was designed for use with seawater. Particular pH buffer chemicals were screened for inclusion with the manufactured surfactant concentrate to give compatibility with seawater. The optimization of the surfactant concentrate with buffer included tests to assure acceptable aqueous solubility, storage stability and rheology. A quality control protocol was used that included decision gates with the operator and key stakeholders.
Laboratory testing showed good aqueous solubility of the branched C12,13-alcohol-7PO-sulfate in seawater with about 3.5% TDS and 1800 ppm divalent ions (minor calcium and major magnesium ions). The pH buffer selected for this application gave a pH of 7 to 9 to: Prevent precipitation of Ca and Mg divalent cations that could otherwise lead to fluid injectivity issues, andKeep the pH stable and above 7 (preventing acid-catalyzed hydrolysis of the sulfate group) for good storage stability of the surfactant concentrate from time of manufacture to time of use.
Ultimately, a 15% AM surfactant concentrate with Newtonian viscosity characteristics was manufactured and deployed due to transfer equipment handling requirements. However, for the future, concentrations of 70+% AM, also with Newtonian rheology, are possible for deployment.
Implementation of the surfactants in EOR to date has been largely restricted to onshore applications due to the challenges associated with offshore use. This paper provides a real-world example of the manufacture of a surfactant concentrate that was used in an offshore SP field project from the perspective from a chemical supplier. Information relating to the quality assurance and control during surfactant concentrate upscaling is also critical and included in this paper.
Observations and Modelling of Deep-Water Circulation in the Colombian Caribbean
Authors: Jaramillo Sergio , Morey Steven L , Cardona Yuley , Guarin Manuela , Williams Benjamin 
Published: April 2019

Abstract
In the deep waters of the Colombian Caribbean in situ measurements of current speed and direction in the water column are scarce. To address this gap, we conducted a 1-year metocean field campaign that included the deployment of three instrumented moorings at 1400 m, 2160 m and 3675 m water depths. We present results from these new observations and from numerical modelling of the long-term circulation in the Colombian basin.
Moorings were designed to obtain current speed and direction through the full water column, with higher resolution near the surface and near the seabed. To examine the spatial variability of the observations, hydrographic measurements were conducted during deployment and service visits to the moorings. To better understand the deep-water dynamics of the region, two numerical models (NCOM and ROMS) were configured to simulate 20-years of circulation in the Colombian Caribbean.
Measurements at the northernmost and deepest mooring near the Guajira Peninsula record several anti-cyclonic eddies moving generally towards the west with speeds upwards of 1 m/s in the top 1000 m for periods of up to one month. Observations from 1000 m down to 3 m above the seabed at this deepest mooring are remarkably coherent in speed (~0.2 m/s) and direction (NNE). This mooring also recorded five events resembling topographic Rossby waves with periods of ~60 days and clear bottom current intensification. The upper circulation at the two moorings near the central Colombian Caribbean flows mainly towards the NE and presents several energetic episodes (maximum speeds ~1 m/s). Measurements at all sites show many eddies that are not confined to the near-surface layers but are submerged below 200 m with no clear connection to the upper circulation. Statistical comparison with HYCOM hindcast reanalysis data shows good agreement near the surface, but a rapid deterioration of model skill below 500 m depth. The two models configured to simulate the circulation inside the Colombian basin show good general skill, but still misrepresent some of the observed current features.
Our observations show that in the Colombian Caribbean, the northern region’s upper 1000 m are dominated by the NW-flowing Caribbean Current and the anti-cyclonic eddies entrained in it, while below 1000 m to near the seabed, circulation is controlled by a nearly vertically-uniform, deep current moving in the NNE direction. To our knowledge, this is the first time that this deep current system and its oscillations are reported. The central and southern regions are dominated by the variations of the Darien Countercurrent in the upper layers, and by flow-topography interactions near the seabed. Submerged eddies are common to all areas observed.