bluuebunny/crossref_metadata_2025_split huggingface dataset:
You can Plan the Most Productive Well Path and Drill it, too
Authors: Hoeink Tobias , Cotrell David , Ghorpade Sachin 
Published: April 2020

The significant capital investment of constructing a well, in combination with its ex ante uncertain performance, creates one of the most difficult choice sets for the exploitation of hydrocarbon reservoirs. A fundamental component is planning the well trajectory. Currently, well trajectories are planned with isolated, manual processes and numerous revisions involving geoscientists, geomechanics specialists, drilling engineers, and asset managers. The planning process can take days, weeks, or months, but even then, the truly optimal well might not be identified, because not all possible well trajectories can be evaluated by humans in reasonable time.
We present a novel, integrated method of finding the optimal wellbore path in a given reservoir that considers distributed reservoir properties such as porosity, permeability, saturation and satisfies constraints such as pipe bend curvature limits, wellbore stability considerations, anti-collision assurance, and avoids obstructions and no-go zones within the reservoir. The selection of the optimal wellbore path can be posed as a constrained optimization problem, which we solve with a novel methodology. Starting at either the wellhead or a particular survey location along an existing well, we automatically create multiple possible well path trajectories. As each path is progressively constructed, we enforce drilling constraints, wellbore stability constraints, and anti-collision constraints. Each successfully created wellbore path is scored with an objective function based on reservoir properties, e.g., the length of the well exposed to reservoir rock that exceeds thresholds on porosity, permeability and hydrocarbon content.
Early applications of this method suggest significant time savings when planning well trajectories in heterogeneous formations. We find excellent coverage of solution space for formations in a range of geological complexity, from simple reservoirs to dipping formations with strong compartmentalization due to faulting.
This approach can accelerate well trajectory planning by orders of magnitude compared to existing workflows and provide a systematic coverage of parameter space. One key benefit of this method over existing manual workflows and processes, and over other computational schemes, is the possibility of near-perfect parallelization, because each possible wellbore path is independent from any other wellbore path. In addition, the proposed solution is guaranteed to find a solution, even when the valid solution space is miniscule. Furthermore, the technique can easily consider additional constraints and can readily be expanded to include the optimal placement of multiple wells.
Digital Twin for Well Integrity with Real Time Surveillance
Authors: Anjos Jorel Lopes , Aranha Pedro Esteves , Martins André Leibsohn , Oliveira Felipe Lima , Gonçalves Clemente José , Silva Douglas Ribeiro , Dudek Cesar Luis , Lima Claudio Benevenuto 
Published: April 2020

During the production phase of the PW1 well, an unintentional operation depressurized the annulus A below its design limit, causing a progressive casing collapse from the surface casing to the tubing string, resulting in a well failure and a subsequent an abandonment operation. This event was detailed in a previous publication (Campos et al., 2019). After a detailed investigation of the events that drove the well failure and using casing design software to simulate the well behavior with the historical time series data, it was possible to identify the exact moment of the casings collapse through mathematical modelling.
Based on that, considering innovation as critical success factor (Rocha, 2012), PETROBRAS started an R&D project to evaluate, in real time, critical integrity events during production phase. The approach proposed consists on the integration of a transient fluid flow model (Bonizzi, 2003) and (Bonizzi, Andreussi and Banerjee, 2009) with a structural model (AraÚjo et al., 2019) of the well and loads being calculúated in real time as a function of the production data (PDG’s, X-TREE and Topside). The process described was named as Well Integrity Surveillance (WIS) and its being designed to work 24/7 in a collaborative environment, integrating well handover information, inspections and intervention reports, production data and flow modeling.
The objective of this paper is to present the well integrity case study of a deep-water field in the Brazilian coast, through a real time digital twin approach, highlighting the main technological solutions, developed to ensure the assets operational envelope, during its lifetime.
With the well integrity surveillance digital twin, PETROBRAS successfully implemented a pilot project on three offshore production units in Brazil, increasing the knowledge of the well structural behavior and consequentially the assets operational safety during its lifetime.
Using “Digital Twin” Of Coriolis Meters For Multiphase Flow Measurement
Authors: Mahalingam Sakethraman , Arsalan Muhammad 
Published: April 2020

Abstract
Multiphase flow meters are often built based on one or many single-phase flow metering technologies. Following the trend, Coriolis meters are being increasingly used in upstream applications in conjunction with an independent water cut meter to measure multiphase flow. Coriolis meters are well-known for fiscal metering applications as they offer unparalleled accuracy without having to input detailed information on the fluid being metered. They offer two distinct measurements: density, and mass flow rate, which is often not possible with other metering technologies. Subsequently, under multiphase flow, the biggest problem with liquid Coriolis meters is their tendency to stall when large amounts of gas flows through them. Many manufacturers over the last 10 years have developed techniques to adjust the drive gain to enhance the ability of these meters to handle increasing amounts of gas. There have also been several developments in using advanced signal processing and machine learning methods to help the meters to self-calibrate and correct for the presence of gas. These methods range from a simple error analysis on certain raw measurements to more sophisticated "Digital Twin" based concepts to simulate the behavior of the Coriolis meter internally. The paper describes the concept of "Digital Twin" in detail and outlines the reasons for the superiority of such an approach.
A New Automated Cutting Volumes Model Enhances Drilling Efficiency
Authors: Al Rubaii Mohammed Murif , Gajbhiye Rahul N. , Alyami Abdullah S. , Glatz Gunther , Haq Bashirul , Aljohar Abdulwahab S. , AlDogail Ala S. 
Published: April 2020

Cuttings concentration in annulus that are generated while drilling due to the rate of penetration have several problems if it is high and has exceeded the maximum limit. Cuttings accumulation in annulus can lead to hole problems such as lost circulation coincident, stuck pipe incidents, and slow drilling rate which still a difficult challenge once it comes to plan, design and drill wells. If a proper hole cleaning efficiency can be achieved, that ultimately will enable the drilling team to have satisfied well drilling performance. To empower hole-cleaning performance, it must be engineered. In this paper, a new real time model of cuttings concentration in annulus (CCA) enhances drilling performance that will ensure optimized improvement and avoid stuck pipe problems. Knowledge from this paper will help in modeling and monitoring cuttings concentration in annulus while drilling precisely and therefore facilitate improving ROP without jeopardizing the well drilling performance. In addition, the paper spoke about the environment impact, drilling waste management and economics and wellbore instability related to cuttings concentration in annulus.
Huge number of models, techniques, charts, chemicals, tools, methods, and designs, experimental studies and to enhance the hole cleaning, but these things are just based on theory, lack proper experimental data, not compatible with drilling scenarios and operations. Cutting Concentration in Annulus (CCA) can provide a clue or a knowledge for maximum ROP that is save and compatible with rig equipment limitations such as the knowledge about maximum amount of cuttings generated while drilling that can be transported to surface and that the shale shakers can handle without causing hole troubles. The size of hole sections (OH), ROP, flow rate of mud pump (GPM), annular Velocity, Critical velocity (Vc), Drill pipe size (OD), cuttings rise velocity (Vcr), slip cuttings velocity (Vsc) and transport ratio (TR) properties in certain hole sections were collected and analyzed first to determine the effect of them on hole cleaning and ROP performance. The data selected are from the same hole size, formation type and mud type.
The relationships between the collected properties and CCA were t evaluated to determine how strong it is and demonstrate the significance of properties on estimating CCA. CCA was monitored controlled and evaluated to be able to have improved hole cleaning performance to enhancement of the drilling operations and decrease well drilling time. This is the first time to for hole cleaning optimization to lead for ROP improvement by using real time CCA model. The developed model has been validated using field data during drilling hole sections. It has shown high drilling rate performance in the hole sections tested and helped mitigate stuck pipe incidents, increased ROP by more than 52%.
Effective Use of Real-Time Remote Monitoring System in Offshore Oil Wells Optimization, Case Study from Gulf of Suez - July Field
Authors: Sayed Raed Ahmed Fouad , Hashim Sameh Mohamed , Shahin Eman Sayed , Abd-Elmaksoud Mohamed Hammam 
Published: April 2020

Abstract
The objective of this paper is to show the value of using real time remote monitoring system (Automation) in offshore wells and to show a case study from Company for how we successfully used the system to detect well anomalies in real time and perform the suitable corrective action to optimize the well production and maximize well recovery with minimum man-hours.
Our company is a leading Egyptian petroleum company with + 200 oil producers on 70 offshore platform; 27 % of platforms include automation system, in platforms without automation system we detect wells problems by performing periodic site visits and check the operating parameters per well., normally it take weeks between two successive platform visits. For platforms with automation system, we install pressure sensors on WH, Manifold, and casing head and temperature sensor on WH., The data being transferred from sensors to office instantaneously, which we successfully made use of, to respond quickly to the problems and achieved maximum well recovery.
The offshore oil producer well J-100 was drilled and put on production on Nov. 2015, the well was producing naturally from the attic of the reservoir, it was a mandatory to control the production rate to keep the well producing beyond the calculated critical production rate to avoid water coning. After a while of putting the well on production, well sensors showed several successive abnormal changes in readings which had been captured in real time with the help of automation system, and with data analyzing we found the causes of each phenomena every time (like loading up, a problem in the production choke, etc.) and we succeeded to prepare the action plan, and perform the scope of work as soon as possible. Without the automation system, it would take weeks to detect the problem based on the site visits plan. However, installing the automation system will enhance the response efficiency by saving the time required for problem detection, and improving the quality, density and accuracy of well data. In addition, it will decrease the losses in production rate, and maximize the recovery by optimizing the production rate based on the field depletion plan.
In summary, this paper discussing a case study for the value of using real time remote monitoring systems in offshore fields and we used this case to highlight the need to expand the system to include more wells in our field to maximize the field recovery and add considerable benefit to the business.
Improving Drilling Geohazards Assessments of the Overburden Section by Performing Seismic Multi-Attribute Analysis
Authors: Sanchez Yosmel , Kucera Michael , Zhang Zijian 
Published: April 2020

Abstract
We propose a more robust procedure than the traditional 3D seismic maximum negative amplitude volume extraction analysis to improve shallow gas assessments for sites on the North Slope, Alaska. 3D seismic maximum negative amplitude volume extractions have proven unreliable for prediction of shallow gas accumulations for sites on the North Slope (e.g. Qugruk-2 and Cirque-1 wells uncontrolled fluid release to the environment, and Kookpuk #1 gas influx to the wellbore). The incorporation of seismic multi-attributes to the traditional maximum negative amplitude analysis has improved the geohazards assessment within the overburden section for more than 40 wells in the North Slope of Alaska. This study uses a publicly available 3D seismic data set to reproduce and share the procedures applied over proprietary data for identification of gas-related amplitude anomalies with a focus on an evaluation of seismic amplitudes, relative acoustic impedance, sweetness and automatic gain control. The results reveal that when multiple seismic attributes are correlated and show a consistent response, they appear to be significantly better predictors than maximum negative amplitude analysis alone or other individual attributes as revealed by reported drilling results. This study contributes an improved 3D seismic method for predicting gas accumulations within the reservoir overburden section at proposed drilling sites on the North Slope.
Stepping Through the 3D Printing Workflow for Production Part Qualification
Authors: Vasquez Mike 
Published: April 2020

Abstract
As more organizations incorporate additive manufacturing systems to produce production parts, it is becoming clear that successfully moving beyond prototyping requires a more advanced and thoughtful qualification strategy. To achieve the desired outcomes, organizations in the oil and gas sector now need to learn how to build a methodical and scalable system for measuring and characterizing materials, processes, and parts. This paper will discuss best practices and standards for developing and executing a successful strategy for both metals and polymers -- from benchmarking properties, to creating appropriate operating/storage instructions, to testing and then ultimately digitally tracking the lifecycle of materials throughout a production workflow.
This will include a review of industry best practices that could be used to determine accuracy, part yield, and cost efficiencies of the additive manufacturing processes. The manuscript will summarize key findings illustrating the significance of process variables within the entire additive manufacturing workflow. This includes elements of the design, material inputs, process parameters, post processing, and inspection. The critical nature of this information for building a scalable Additive Manufacturing process for production will be discussed. Additionally, the importance of ensuring the process is robust will be reviewed in the context of setting up an Additive Manufacturing facility incorporating key elements such as safety standards and operating procedures that empower teams to deliver on production requirements. Finally, a detailed framework will be presented to assist engineers in oilfield applications build a specification list for Additive Manufactured parts. The literature for quality management in the additive manufacturing is very limited in scope. This makes it difficult for organizations to assess the usefulness of the technology for their operations beyond an R&D capacity. The information provided in this paper shows the critical considerations and approaches that should be applied in oilfield applications.
Prescriptive Analytics for Real-Time Optimization of Deepwater Casing Exits
Authors: Popp Timothy , Broussard Grant 
Published: April 2020

Casing exits provide operators with an additional wellbore path in which subsequent well operations may be performed. In many instances, a casing exit operation provides an operator with an economic method for accessing a known reservoir zone from an existing wellbore. This is especially true in deepwater settings, which have higher baseline costs. However, milling casing in a deepwater application is often cumbersome and unreliable. The downhole environment is complex, the nature of the formation is often unknown, and directional steering capability is ineffective in casing. Therefore, optimizing casing exits is essential to minimize costs of rig operation, especially in high-cost and high-risk deepwater settings like the Gulf of Mexico. This paper presents a real-time optimization solution using data analytics to improve casing exit efficiency, quality, and consistency. In this respect, a prescribed milling schedule is developed using advanced analytics on historical job data. Further, the use of downhole data and telemetry tools enables the collection and transmission of real-time downhole measurements. Finally, a surface acquisition system provides real-time readouts of the downhole measurements to ensure BHA parameters are optimized in real-time.This optimization methodology was successfully employed in the Gulf of Mexico in collaboration with an operator. Using prescriptive analytics, a milling schedule was provided before a casing exit. During operation, the schedule for downhole weight-on-bit (WOB) and surface rotary speed (RPM) was followed and adjustments were made using real-time downhole measurements. The 13 5/8-in casing exit was successfully performed in a single run and resulted in a high-quality window. Vibration and window drag were minimal, and the milling time was reduced by 10% compared to the average for similar casing exits.
On the Modelling of Long Heating Cables for Electrically Trace Heated Pipe-in-Pipe ETH-PiP Systems
Authors: Jez Radoslaw , Ejma-Multanski Jakub , Vivet Romain 
Published: April 2020

Abstract
Active heating technologies can be applied to subsea pipelines to tackle challenging reservoir flow assurance constraints that could take place during production shut down and normal subsea field operation (i.e. hydrate, gelling, wax and/or high oil viscosity). Implementation of active heating to subsea pipelines enables i) field architecture simplification and ii) long subsea tie-backs. The Electrically Trace Heated Pipe-in-Pipe (ETH-PIP) is a standard reelable PIP system enhanced with up to 4-off trace heating cables and 2-off fiber optic (FO) cables, for temperature monitoring purposes, spiraled against the inner pipe and covered by high thermal performance insulation allowing a high thermal system efficiency. The high thermal efficiency combined with a primarily resistive electrical system makes the ETH-PIP the most energy efficient active heating technology.
Long power heating/transmission line can be described by the fundamental parameters resistance/inductance of conductor and capacitance/conductance of insulation. The analysis of the overall heating system can be assessed using three alternative models: i) the most simple and compact RL model where only total resistance and total inductance of line is included, ii) more advanced RLC model where the total capacitance of insulation is additionally included and iii) the most advanced distributed RLGC (resistance, inductance, conductance, capacitance) model where total length of line is modelled as a chain of shorter RLGC segment lengths. The accuracy of each model depends on multiple aspects such as: heating/transmission line parameters, required heating power, total length of line, mode of operation, environmental conditions, etc. The proper and careful selection of the appropriate model to ensure effective computation and results accuracy is paramount.
The paper includes the detailed description of each heating/transmission line model. Additionally, each model is illustrated on a set of theoretical examples.
Decommissioning Of Subsea Structures In Brazil: Impact Of Invasive Species And Genome Sequence Of The Invasive Azooxanthellate Coral .
Authors: Batista João Humberto Guandalini , Rebelo Mauro , Soares-Souza Giordano 
Published: April 2020

Abstract
Decommissioning of offshore assets in Brazil is subject to high level of uncertainty because of invasive Sun Coral Tubastraea sp. This species has an improved capacity of dispersion and recruitment, and has been associated with the replacement of native species in rocky shores causing severe impact to native biodiversity. Because of that, colonized artificial substrates will require cleaning and actions to avoid dispersion to the surroundings. This paper is proposing to study biology of Tubastraea sp, aiming to identify methods to eliminate and/or decrease its spreading.
A colony of Tubastraea sp. was collected by scuba diving in Angra dos Reis (23o3.229'S / 44o19.058'W), Rio de Janeiro state, Brazil and transferred to a laboratory to proceed with a comprehensive analysis of morphology, cytogenetics, transcriptome, mitochondrial and nuclear genome. Colony morphology was analyzed and the skeleton was deposited in the zoological collection of the National Museum of Brazil (MNRJ 7129). Deoxyribonucleic acid (DNA) extractions were performed in clone polyps for the preparation of sequencing libraries. Bioinformatics was applied to assemble the first draft of the nuclear genome which was subsequently improved for contiguity using molecular and computational scaffolding methods.
Our study showed the genome of Tubastraea sp is organized in 23 chromosome pairs and has 1.4 Gb making it the largest coral and Cnidaria genome sequenced to date. The hybrid assembly using short and long-reads has a N50 of 180,044 pb, 12,320 contigs and high completeness estimated as 91.6% of BUSCO complete genes. Results showed that almost half of the genome consists of repetitive elements, mostly interspersed repeats. Gene content was estimated as about 94,000, a high number that warrants deeper scrutiny.
The Tubastraea sp. genome is a landmark study promising to provide insights not only about the genetic basis for the extreme invasiveness of this coral, but also to understand the adaptation flaws of some reef corals in the face of anthropic-induced environmental disturbances. We expect the data generated in this study will foster the development of efficient technologies corals species management, whether invasive or threatened.
When oil&gas industry has a problem where conventional methods are not efficient enough, a multidisciplinary approach becomes necessary. This study consists in an innovative example of a partnership among high reputation biological entities and one operator was established to bring a broad understanding of an invasive species in Brazilian waters, extremely impactful to Decommissioning activities in country.