bluuebunny/crossref_metadata_2025_split huggingface dataset:
Use Of Tracer Technology to Improve Reservoir Understanding
Authors: Al Agbari Zainah , Chatterjee Monalisa , Hewitt Paul , Mohamed Ihab , Sudarev Maxim , Latypov Eduard , Al Bairaq Ahmed , Al Amri Ammar 
Published: November 2019

Abstract
Using a tracer as a monitoring technique to measure the migration of the injected fluid in the reservoir is relatively inexpensive method, and it applied in numerous fields throughout the world. The application of tracer can assess the volumetric sweep to quantify the amount of fluid flowing from injectors to producers. It gives an indication of offending injectors. Tracer helps in addressing the communication between different reservoir units. Another objective is delineation of flow barriers to identify the geological features that dominate the flow directionality (i.e. high permeability streaks, faults, fractures, etc) to determine directional permeability trends. The information obtained from tracer can reduce the model uncertainty and provide better tuning for future prediction.
The tracer data is used to generate not only qualitative information but also a substantial amount of quantitative data. Primarily, chemical tracers should be tested against a number of reservoir formation rocks and found not to adsorb or retard. Tracers are injected in the injectors and the samples are collected from nearby producers. Analysis of tracer concentration versus time curves from individual producing wells enables interwell flow characteristics to be determined so that improvements can be made to optimize sweep effectiveness of the hydrocarbon reserve. A record of base line sampling and analyses from all producers should be conducted. A frequent sampling and analysis are performed to understand the reservoir characteristics and performance.
After the application of tracer technique, the following results were observed: The first breakthrough was detected after about one year; due to the short distance between the injector and the producer. The second breakthrough was detected after about three years; due to the reservoir characteristic in the producers. An identical patterns of tracer response was seen, indicates almost homogenous reservoir in the tracer injected. This points out towards a similar depositional pattern across the reservoir. Most of tracers are observed downward towards the flank area. Tracer direction was to the least pressure area (flank) due to high offtake. No breakthrough was observed in the attic wells due to high pressure area.
Tracer technology is inexpensive method used to provide inflow directional information, and it has no impact on the completion design and effectively prove the reservoir characterizations and well performance.
Modelling of Permeability and Strain Evolution in Chemical Creep Compaction Experiments with Fractured and Unfractured Chalk Cores Conducted at Reservoir Conditions
Authors: Kallesten Emanuela , Østebø Andersen Pål , Berawala Dhruvit Satishchandra , Korsnes Reidar Inge , Vadla Madland Merete , Omdal Edvard , Zimmermann Udo 
Published: November 2019

Abstract
Understanding the impact of typical water-related IOR techniques is fundamental to the development of chalk reservoirs on the Norwegian Continental Shelf (NCS). We investigate the contribution and interplay of key parameters influencing the reservoir's flow and storativity properties such as effective stresses, injecting fluid chemistry and geomechanical deformation. This is done by developing a mathematical model which is applied to systematically interpret experimental data. The gained understanding is useful for improved prediction of permeability development during field life.
The model we present is for a fracture chalk core where fluids can flow through the matrix and fracture domains in parallell. The core is subject to a constant effective stress above yield resulting in time-dependent compaction (creep) of the matrix, while the fracture does not compact. Reactive brine injection causes enhanced compaction, but also permeability alteration. This again causes a redistribution of injected flow between the two domains.
A previous version of the model parameterizing the relation between chemistry and compaction is here extended to quantify the impact on permeability and see the impact of flow in a fracture-matrix geometry. A vast set of experimental data was used to quantify the relations in the model and demonstrate its usefulness to interpret experimental data. Two outcrop chalk types (Aalborg and Liege) being tested at 130 °C and various concentrations of Ca-Mg-Na-Cl brines are considered. However, assumptions were required especially regarding the fractures behavior since directly representative data were not available.
The tests with inert injecting brine were used to quantify the impact of matrix and fracture mechanical compaction on permeability trends. To be able to explain the tests with reactive brine, an important finding is that permeability not only decreased due to enhanced porosity reduction, but also because of a quantifiable chemistry related process (dissolution-precipitation).
Sensitivity analyses were performed regarding varying fracture width, injection rate and chemistry concentration to evaluate the impact on chemical creep compaction and permeability evolution in fractured cores. The model can be used to highlight parameters with great influence on the experimental results. An accurate quantification of such parameters will contribute to refining lab experiments and will provide valuable data for upscaling and field application.
Challenges Faced in Design & Selection of Umbilical for Offshore Facilities
Authors: Kumar Naresh , Paul Raju , R.Kamal Faris , Takieddine Oussama 
Published: November 2019

Abstract
The present trend is to use the umbilical for transmitting electrical power, instrumentation signals and to transport fluids & gas in one assembly over long distance to the Offshore Oil and Gas facilities. The installation of power generation facilities at offshore platforms is not a preferred option due to space constraints and the huge installation and running cost. Hence, the electrical power is transmitted from onshore generation facilities to offshore facilities by composite subsea cables.
Similarly for example the cost of installing corrosion inhibitor package at offshore facilities is huge considering the space occupied by the package skid which in turn increases the structural cost. The electricity required to run the corrosion inhibitor pump motor and other auxiliaries will result in higher power demand and subsequently the higher installation and operation cost. Hence, it is economical to transfer the corrosion inhibitor from nearby onshore facilities to offshore facilities by using instrumentation tubes, pipes and hoses.
The use of umbilical which houses the composite subsea cable and tubes carrying fluids/gases in one assembly result in substantial cost savings in terms of installation, transportation and laying cost. The housing of submarine composite cable with tubes in one assembly poses many challenges for the design and selection of umbilical. This paper provides comprehensive ideas about design, testing and selection of umbilical, the challenges faced and the way forward to overcome the challenges in selection of umbilical.
Successful System Schedule Integration for a Complex Multi Package Mega Project
Authors: Saat Sahaiza 
Published: November 2019

Abstract
The Pengerang Integrated Complex (PIC) is a US$27b multi package fast-tracked mega project with execution period of 60 months to ‘Ready for Start-up’ in Q1 2019. One of the largest project of its kind in the world constructed at a single time and location, PIC consists of a Refinery and Petrochemical Integrated Development (RAPID) and supporting facilities. A successful integrated system schedule was established towards achieving on-time project completion by early 2019.
The key challenges lie in the immense complexity of the project with involvement of over 140 organizations including more than 40 EPCC packages, supported by 13 licensors and over 200 suppliers and Contractors, around 250k EPCC schedule line items and alignment of 117 Integrated Networks across over 30 main process units. To drive a successful system schedule integration, three key guiding principles were followed: a pre-emptive schedule management guideline for systemization and start-up sequence, integrated critical path schedule alignment engagements with EPCC Contractors and a lean task force collaboration by project planning and operation on prioritized critical utilities delivery for EPCC commissioning activities.
As a result of the successful system schedule alignment and integration, the critical utilities i.e. power, steam, cooling water, fuel gas and fire water, were successfully delivered in quick successions according to the respective EPCC packages needs, allowing commissioning activities within the packages and the Integrated Networks crossing over multiple EPCC packages. The cohesive pre-commissioning, commissioning and start-up schedule between all EPCC packages propelled PIC project to a momentous "Finish Strong".
The critical success factor comprising of early creation of special task force driven by project planning and operation personnel in managing system schedule prioritization and strong collaboration with EPCC Contractors, maybe the answer to future projects looking for integrated smart solutions.
Floating Roof Storage Tanks Life Extension: A Novel Risk Revealed
Authors: Al Omari Ammar , Herzalla Osama , Toubar Ashraf , Almalood Naser , Al Hammadi Hassan 
Published: November 2019

Abstract
External floating roof crude oil storage tanks are widely used in the Oil & Gas industry due to many advantages. Floating roofs in storage tanks are well-known in minimizing product losses due to evaporation. The floating roof systems also mitigate fire risk by eliminating vapor space beneath the roof. However, the operation of such massive structures brings different challenges. This paper reveals the relation between floating roof mechanical deformation and tank floor settlement. This research studies a real case of a floating roof storage tank. The double deck floating roof experienced an excessive mechanical distortion in form of bulges and undulations at roof lower deck. A Finite Element (FE) Analysis studied the relation between tank bottom plate settlement and roof deformation while roof is in parking position. The roof bulges were dimensionally surveyed and compared with FE results. The FE Analysis results of stresses and strains were utilized to decide the integrity condition of the tank roof and to study the behavior of the existing bulges for continued operation of the tank roof.
During storage tank major overhaul, bulges were reported in the lower deck of the floating roof with 50-100 mm depth. The bulges are in form of waviness and they are more severe in the roof middle pontoons. The simulation results showed that while the roof is parked over a floor with non-uniform settlement, some of the roof supporting legs will be engaged with the tank floor earlier. This will lead to a non-uniform weight distribution of the tank roof over the legs, and overloading the roof lower deck with bending stresses. The FE results were able to define the location of the induced high stresses that may lead to cracking in the welding lines of the roof lower deck plates. It was decided to conduct a magnetic particle inspection at those critical lines to ensure they are crack-free. Results showed that the stress levels in the roof will reduce dramatically after refilling the tank and floating the deformed roof, this is due to the redistribution of the roof weight uniformly over the product surface. After refilling the tank, plates with elastic bulges will recover and plastically deformed bulges will have lower stress levels. The assessment concluded that storage tank floating roof is fit for service. The relation between storage tank floor settlements and floating roof deformations has never been analyzed to this depth of engineering analysis. The storage tanks international codes state that bulge sizes in the floating roof shall be kept as minimal without providing any acceptance criteria. This research quantifies the acceptance limits of floating roof bulges based on an advanced engineering simulation.
Application of Machine Learning Approach for Intelligent Prediction of Pipe Sticking
Authors: Abbas Ahmed K. , Almubarak Haidar , Abbas Hayder , Dawood Jawad 
Published: November 2019

Abstract
Stuck pipe has been recognized as one of the serious problems in drilling operations that has a significant impact on drilling efficiency and well costs. The events related to the stuck pipe can be responsible for losses of hundreds of millions of dollars each year in the drilling industry. This paper presents a study on the application of machine learning methodologies to predict the stuck pipe occurrence which can be utilized to modify drilling variables to minimize the likelihood of sticking. The new models were developed to predict the stuck pipe incidence for vertical and deviated wells using artificial neural networks (ANNs) and a support vector machine (SVM). The proposed models were examined using a few examples of real stick pipe cases from the field. The results of the analysis have revealed that both ANNs and SVM approaches can be of great use, with the SVM results being more promising.
The present analysis supplies knowledge that can be used during well pre-planning and developmental phases to make informed decisions that will avoid pipe sticking problems and essentially optimize drilling performance. The risk of pipe sticking can then be minimized and the costs associated with its occurrence will be reduced.
The First Deployment of a Fully Electrical Intelligent Completion System in 3-Dimensional Complex ERD Wells in the Caspian Sea
Authors: Kosset Talgat , Sissenov Olzhas , Novokshenov Stanislav , Niverchuk Andrey , Golenkin Mikhail , Zvyagin Vasily , Nabiullin Renat , Dadashev Afrand 
Published: November 2019

Abstract
Extended-reach drilling (ERD) from a fixed offshore platform poses unique challenges for anticollision directional drilling and wellbore construction. Wells completed in multilayered reservoirs, multilaterals with compartments of varying pressure, and ERD wells are becoming common in the Russian sector of the Caspian Sea. An integrative approach and advancements in drilling and completion technologies in the Korchagina field have enabled enhanced hydrocarbon recovery through extreme reservoir contact from ERD wells.
Various issues, such as wellbore stability, borehole geometry, torque and drag, and borehole condition can affect the deployment of completion hardware to the desired depth. This paper presents the installation of ground-breaking technology in an ERD well in which the longest fully electrical intelligent completion was landed successfully through proper design and careful planning. The paper will also present the planning and execution of three ERD wells completed by use of a fully electrical intelligent completion consisting of multiple downhole active flow-control devices controlled by a single downhole electrical line. The installation of these completion systems allowed the operator to control the breakthrough of water or gas or both, to selectively produce additional hydrocarbons from multiple zones and compartments in real time, and to minimize the number of required production logging tool runs.
In 3D complex well profiles, while running the long completion string, axial drag is accumulated along the string, which exposes it to sinusoidal and helical buckling. Excessive compressional loads in the string beyond the buckling limit of the pipe can lead to lockup and ultimately prevent the string from reaching the setting depth.
This paper presents a structural integrated approach for successfully deploying a fully electrical multipoint pressure and temperature measurement completion systems on 3 ½-in. and tapered 3 ½ × 4 ½-in. tubing by using a wireless electric connect-disconnect system.
Middle East Gas Field Case Study Proves Step Change in BHA Reliability Through New HFTO-Isolation Tool
Authors: Heinisch Dennis , Kueck Armin , Herbig Christian , Zuberi Mamoon , Peters Volker , Reckmann Hanno 
Published: November 2019

Abstract
Self-excited torsional vibrations of the bottomhole assembly (BHA) at frequencies above 50 Hz, so-called "high-frequency torsional oscillations" (HFTO), can damage drilling tools and can increase non-productive time (NPT). A recently developed HFTO-isolation tool protects the drilling tools above this tool from these harmful vibrations. More than 200 field runs were investigated to evaluate the changes in reliability and benefits.
The concept of the isolation tool works similarly to a two-mass flywheel used in automotive drive trains. The design was simulated, lab-tested and first deployed in a field run in 2018. Since then, the isolation tool was successfully used in various fields and applications in the Middle East. HFTO severity while drilling was measured and recorded below and above the isolation tool to verify functionality and to quantify reduction in torsional loads (torque, tangential acceleration) for the measurement while drilling (MWD), mud pulse telemetry (MPT), and logging while drilling (LWD) tools above the tool. In addition, HFTO-related incidents and other drilling performance indicators with and without the new tool were analyzed.
Analysis of the recorded vibration data from several field runs with an additional high-frequency MWD-tool reveals that the isolation principle works consistently. As predicted by simulation, the measured torsional vibration amplitudes above the tool are significantly lower than without using it, demonstrating the effective protection for MWD-, LWD-, and MPT-tools in the BHA.
The tool has proven consistent performance in more than 16,000 accumulated circulating hours. Tool failures caused by HFTO were eliminated, compared to 22 percent of all failures without the isolation tool. The results of an analysis of individual MWD- and MPT-tools used in runs with and without the isolation tool show a significant increase in distance drilled per tool deployment and re-run decisions. This directly translates to increased asset utilization, fewer trips for failure, and BHA handling operations that results in less non-productive time (NPT) and enables drilling in extremely challenging environments more efficiently.
Application of Machine-Learning to Construct Simulation Models from High-Resolution Fractured Formation
Authors: Santoso Ryan , He Xupeng , Hoteit Hussein 
Published: November 2019

Abstract
In modeling fractured reservoirs, outcrops may offer useful insights about the subsurface characterization of the heterogeneous rock formation. They provide analogs that could be replicated in the reservoir to capture the fracture and matrix characteristics, which are crucial to assess the governing recovery mechanisms. Constructing outcrop-based reservoir models is a labor-intensive process, which is subject to personal interpretation and error. In this work, we propose a novel workflow for modeling fractured reservoirs within a deep learning framework. The workflow consists of three main steps that include fracture network recognition to map explicitly the fractures from digital images, fracture characterization to provide an assessment of the fracture effective hydraulic apertures, and reservoir model construction to integrate the multi-scale data and construct the up-scaled simulation model. In this paper, we focus on the first step in the workflow.
The fracture network recognition starts with segmentation for the images of the fractured formation. The ultimate objective is to identify the fractures from RGB, greyscale, or hyperspectral images. We developed a U-Net-based algorithm to perform the segmentation using 64×64 pixel-resolution. This resolution is carefully selected to accelerate the fracture recognition process and to narrow down the variability in the training set. The inputs are images of the fractured medium with any resolution which are pre-processed before feeding it to the recognition process. The output is a list of the identified fractures, where each fracture is composed of a set of segments, and each segment is defined by the coordinates of its end-points. The output format could be readily processed by any fracture modeling software.
We demonstrate our workflow to recognize and identify fractures from different 2D images, where we discuss the machine-learning (ML) training and testing stages. The algorithm shows accurate predictions and identifications for the fractures. This workflow has the potential to be extended and applied at the field scale.
A Case Study of High H2S Aquifer Production Testing : Planning and Execution
Authors: Aman Shah Muhammad Kamal , Mudaliar Kokulananda , Mamat Mohammad Shahrin , Salleh Zaimi 
Published: November 2019

Abstract
This paper shares a case study of production testing of a large Middle East dolomitic aquifer containing high concentration of H2S. The aim of this paper is to discuss on the HSE aspects primarily on wellsite and operation safety by sharing the issues, challenges and mitigations at various stages of planning and execution.
As part of field X development strategy, water flooding is required to maximize recovery. However, due to water scarcity Operators had to look into ground aquifers to support water injection leading to dolomitic reservoir being identified as the best source. The initial planning was based at 30 ppm H2S limit centered on samples obtained from nearby field located 400 km from field X. Based on actual bottomhole samples from field X, it was found that the reservoir contained higher H2S concentration which requires the operator to re-strategize the production testing operation within a limited time frame to cover safety and security aspects.
The operation involved multidisciplinary collaboration encompassing DST design, process safety and security. As the well is located in a densely populated area, a first of its kind H2S dispersion study in aqueous solution was introduced.
The DST operation was successfully conducted with no major HSE and security incident recorded. The well was tested up to a maximum rate of 20 kbl/d and through the introduction of multiple injection point, the concentration H2S was successfully reduced to 2 ppm.
The H2S dispersion study in aqueous phase played a pivotal role, assisting in risk identification and quantification. Through the study, many critical HSE aspects were addressed and resolved, expediting the planning stage and improved the whole system. The modelling was based on worst case scenario where all 18,000 ppm of H2S will disperse to air. On the other hand, for normal operation, some portion of H2S is expected to dissolve in water during discharge. It is also noteworthy to mention that understanding the limitation of the model is equally important to assist in planning and executing the operation effectively.