bluuebunny/crossref_metadata_2025_split huggingface dataset:
Experience and Optimization of Essential Multistage Fracturing Technology with Coiled Tubing at the Well for the Vinogradova Oilfield
Authors: Parshin Nikolay , Burdin Konstantin , Starodubtseva Ksenia , Novikov Maxim , Demkovich Mikhail 
Published: October 2018

Abstract
In the article presented 2 years of experience gained during multi-stage hydraulic fracturing (MSF) on 17 wells, by means of coiled tubing (CT) without lifting it to the surface, performed in years 2017 – 2018 on Vinogradova oilfield, KhMAO, Russia. In 2017 it was successfully implemented innovative technology, where fracturing operations are combined with coiled tubing (CT) operations and are run together with CT inside the well. Current method is based on operating reusable fracturing ports, where opening and closing is carried out using coiled tubing with subsequent performace of MSF along the CT/Tubing annulus. During these jobs, considerable experience was gained, the technologies were optimized and raised issues solved, including excessive abrasive wear of the coiled tubing pipe, leaks, etc.
Vinogradova oilfield is a unique oil-saturated low-permeable reservoir with a small effective thickness, characterized by considerable stratification and gas-saturated porous layers.
MSF technology demonstrated high efficiency and proved its reliability. Starting from February 2017 till June 2018 it was 17 wells accomplished, where 246 fracturings were carried out. All the wells were successfully commissioned. The implementation of innovative approaches to multi-stage hydraulic fracturing while coiled tubing remains in the well, resulted in 2-fold work time reduction, while the amount of frac ports doubled per well. The time frame of CT work between fracturing stages was minimized from 4 to 1.5 hours. During the job on one of the wells, it was encountered a leak in the completion (liner) in the shoe area, in order to continue MSF job, the isolation packer was run and temporary installed, which allowed to accomplish the operation.
The performance of MSF technology without lifting coiled tubing to the surface proved its efficiency and economic feasibility, becoming more and more popular among operating companies, it has great potential for future implementation both in Russia and in the rest of the world. The area of distribution and application of MSF using CT is growing every year, the most relevant technology found in oil fringe with a gas cap or bottom water. The accumulated experience in this project creates the basis for the wide introduction and application of technology on other projects
Analysis of Time-Dependent Behavior of Dynamic and Static Parameters of Preheated Westerly Granite for Microseismic Fracture Monitoring Experiments
Authors: Dotsenko Artyom , Stukachev Vladimir , Andrade De Carli Jean Carlos , Shevtsova Anna , Charara Marwan 
Published: October 2018

Abstract
A detailed analysis of time-dependent and strain-dependent behavior of dynamic and static properties of preheated to 650°C Westerly granite, which should be considered for microseismic fracture monitoring surveys, is presented in this paper. A thermally treated cylindrical Westerly granite specimen was compressed hydrostatically to 5 MPa and loaded axially to 415 kN until failure in a triaxial loading cell at the strain rate of 3.2 × 10-6 s-1. Longitudal wave (P-wave) velocities were measured periodically with triaxial ultrasonic system of transdusers along three orthogonal directions during loading time, until failure. Both dynamic (P-wave velocities along three orthogonal axes, and anisotropy of these velocities) and static (axial, lateral and volumetric strain) properties of the sample demonstrated significant variation with time (e.g., vertical P-wave velocity first increased by 58%, from 3100 m/s to 4900 m/s, and then dropped by 38%, down to 3048 m/s). Onset of fracture initiation occured at 0.5% of axial strain. During the initial stage, axial compaction prevailed in tested Westerly granite sample, inasmuch as closure of thermally generated cracks oriented horizontally was dominating. After axial strain reached 0.5%, the specimen lateral dilatancy was uncovered. Afterwards, opening of vertically oriented stress-induced fractures started to dominate, which had a response in both ultrasonic and mechanical data. It lead to presence of stress-induced anisotropy of the dynamic properties. As the velocity anisotropy, as well as the wave velocities, strongly vary with time and with increasing axial strain. At axial strain equal to 0.78% microscopic failure of the specimen was detected. For accurate localization of microseismic events during fracture monitoring a reliable time-dependent and anisotropic velocity model should be implemented.
Bazhenovskaya Suite of Severo-Demyanskoe Field: Multi Fracturing Well Completion – Story of Success
Authors: Sigarev Sergey , Kustaryov Dmitry , Prokhorov Alexey , Nikitin Pavel , Samoylov Mikhail , Koltypin Oleg 
Published: October 2018

Abstract
In recent years, the issue of the Bazhenov development as one of the main hard-to-recover oil reservoirs is getting more and more pressing for the Russian oil industry. Lack of knowledge about this reservoir underpins difficulties that arise both in hydrocarbons production and in well construction and completion. This paper presents a story of success in well construction with a multi-stage frac design in the Bazhenov Suite of the Severo-Demyanskoye Field (OOO RN-Uvatneftegaz). One of the distinctive features of this project is a wide use of the Russian domestic equipment and technologies.
It is not possible to obtain economic oil rates from the Bazhenov without additional flow stimulation. The selected stimulation method was multi-stage hydraulic fracturing with a considerable proppant mass (large-volume multi-stage fracturing). The average frac job was 80 tons of proppant each; the mixture pumping rate was 5.5 m3/min, thus making it possible to place the defined amount of proppant and create the expected fracture geometry.
To ensure accident-free drilling and well completion as well as to update the data needed for hydraulic fracturing, advanced preliminary geomechanical studies were carried out.
In order to maintain operability of the well equipment while waiting on frac jobs (over 8 months), Russian-made heavy potassium formate brine was used as a completion fluid for the first time in Russia.
Complete Assessment of Complex Unconventional Saudi Arabian Producer Using High Definition Spectral Noise Logging and Numerical Temperature Modeling
Authors: Oparin Maksim , Altayyar Tayyar , Al-Otaibi Nashi , Sheshtawy Mohamed , Yassin Maged , Frolov Alexander , Vorozhikhin Sergey 
Published: October 2018

Abstract
Unconventional hydrocarbon production has been known to revolutionize the oil and gas industry in the last decade. Though the advancement of drilling and well completions associated with tight sands and shale production, the assessment of downhole completion and fracture production remains challenging. The paper illustrates innovative approach to assess the success of multistage fracturing systems, evaluate both hydraulic and swellable packer condition, behind liner flow, and quantitative assessment of stages contribution.
The paper will discuss logging techniques using high definition spectral noise logging and numerical temperature modeling to assess flowing fractures, horizontal liner and behind liner well integrity including isolating packers and quantitative estimation of stage production in unconventional horizontal producer.
Downhole logging including a set of conventional multiphase sensors alongside with high precision temperature and high definition spectral noise logging was run in one of Saudi Aramco largest unconventional reservoirs to provide complete assessment of the horizontal section integrity and stage contribution.
The survey confirmed the success of fracturing process across the horizontal section and application of the new type of the completion.
Numerical temperature modeling was used to quantify flow across each production ports and at the top of each stage. The integration of all data set provides complete understating of well completion and production in one run. The quantitative assessment provided by numerical temperature simulation was in good correlation with the bore hole conventional array production logging results.
The results of the survey provided detailed assessment of the horizontal lateral production with high resolution across every producing port and provided valuable information about behind liner fracturing efficiency and completion packers’ integrity in one run.
Logging tools didn't include mechanical rotating parts, providing high degree of safety and reliability and leaving a very low foot print on the well. Comparison with array production logging run completed separately.
Fatigue Tracking for Mud Motors and MWDs in Unconventional Wells
Authors: Mills Kathleen , Menand Stephane , Dao Ngoc-Ha 
Published: October 2018

Abstract
As the industry continues to drill increasingly complex wells, the demand put on drilling equipment has increased and will continue to increase. Preventive maintenance often falls to the wayside in favor of keeping the same equipment operational for longer until a failure occurs, which can be very costly and potentially catastrophic to the equipment provider. Fatigue tracking makes it possible to predict failures ahead of time and prevent such incidents. However, the most commonly used fatigue tracking methods are based only on rotating hours and do not take the bending stress into account. Electronic drilling recorders (EDR) coupled with bottom hole assembly (BHA) models allow for better estimation of the fatigue performance by calculating the actual bending stress along each piece of equipment, such as the mud motor or measurement while drilling (MWD) tool, leading to a more reliable fatigue tracking method.
A case study of fatigue on a common motor and MWD over the drilling life of a well provides valuable information on how to monitor and react to different fatigue scenarios. By using an advanced stiff string model to calculate stress distribution along the motor or MWD coupled with standard fatigue prediction models, valuable information can be learned about the motor and MWD conditions.
One case that will be examined involves a typical well trajectory such as those drilled in the US land market today which involve a high dogleg curve to reach a target formation, with dog leg severity (DLS) locally reaching 18 (deg/100') generating high bending stress and thus fatigue. The consequence on fatigue life can be dramatic through the BHA for even just one exceptionally high dogleg. By using the continuous surveys taken by an MWD tool, to account for the actual tortuosity of the well, the potential fatigue becomes even more significant. Another decision that is commonly made without much regard for fatigue consequences is that of stabilizer placement along the BHA which can dramatically shift the distribution of bending moment and thus extend the life of a mud motor. Simulations will show how wellbore tortuosity can affect dramatically the fatigue life of mud motor and MWDs.
By illustrating several common examples of fatigue influencers, engineers will be better equipped to determine the impact of different decisions on the potential motor and BHA fatigue. Better understanding of the nature of fatigue and the consequences of larger bend motors, higher doglegs, and better surveying practices, for example, can lead to better decision making and the reduction of fatigue failures.
Design and Development of Relational Geospatial Database Aimed at Gathering and Systematization of Wide Range of Geological and Geophysical Data
Authors: Kolmakov Aleksandr , Kilyakov Aleksey 
Published: October 2018

Abstract
The work represents the results of design and development of object-relational geospatial database which combines the diversity of geological and geophysical data and enables to represent the data as an object of linear algebra for further analysis by means of machine learning algorithms.
Evolution of Integrated Models From Simplified Approach to Complex Reservoir - Well - Surface Network Representation at Different Stages of Gas Condensate Field Lifecycle
Authors: Voznyuk Alexander , Gataullin Timur , Poushev Andrey 
Published: October 2018

Abstract
The tendency of recent years in the sphere of modeling oil and gas fields and the processes of oil and gas fields' development is an increase of complication of models, revision and abandonment of a number of simplifications, which were necessary earlier due to the limited computing and time resources available to engineers.
This tendency makes more widespread such approach as accounting for the performance and optimization of surface gathering systems becomes a critical task in the case of gas, gas condensate fields, and also - light oil fields. Given the apparent growth in the interest of oil and gas companies in such assets, the popularity of integrated modeling in the industry as a whole is extremely high.
The problem with this technology is that the integrated simulation models are complex in the creation, they require more knowledge from the engineers involved in the project in the related field of activity (the reservoir engineer should have an idea of the principles of operation and methods of managing the surface network, production engineer should understand the physical basis of the work not only of the reservoir, but also of its simulation model, etc.).
Both the network model and the reservoir model can be performed in different variants in terms of the complexity and accuracy of the transfer of the boundary conditions and taking into account the necessary physical effects. This article offers a comparative analysis and possible applications of different types of models, and also describes a number of additional tools that help to eliminate some typical problems of this class of tasks.
The Individual Certified Flowmeter of Liquid in the Well
Authors: Ulyanov Sergey , Sagyndykov Rustam , Davydov Denis , Dolinyuk Valeria , Gilaev Gennady , Totanov Alexander , Nosov Sergey , Ilyin Alexey 
Published: October 2018

Abstract
Liquid and gas production rates assessment is crucial while well operation. Based on the measured data obtained the evaluation of downhole pumping equipment condition, pump productivity and reservoir capability is performed, measures for improving pumping equipment operation and its rehabilitation are designed, well operation modes are defined.
Traditional well metering stations used by JSC “Samaraneftegas" are not only the basic tool to define the volumes of the oil extracted from oil wells but are also one of the costly spheres in oil production. At present, the applied metering stations, compared to old-time automated group metering stations, require either substantiated upgrading aimed at well smart operation and simplification of their structure and higher accuracy in metering, or the optimization of specific costs for the rent of expensive mobile metering stations. [9]
The promising approach to this solution is a budget set of measurements, based on the system of thermal pressure metering that within the frames of the issue considered is transformed into the process of instrumental on-line fluid rate metering. The paper considers the conceptual process and structural changes in geometry and coating of the existing flowmeters that enables us to consider this type of oil-field equipment as a certified metering device to replace the classic flowmeter stations. Taking into consideration the experience of thermal pressure metering system on the wells and the failure of its weakest part which is the communication link, the wireless channel of communication was made transmitting all signals by means of infrasound.
The solution allows introducing the device with no additional costly equipment and is a classical system of measurements with the firmware sensor of measurement of flow rate installed above the electric submersible pump (ESP). Tlike any other oil well provided with the standard unit of electric submersible pump, the complex of thermal pressure metering has the control station and the land-based system of thermal pressure metering. The process of measurement and fixing of parameters is given in fig. 2. [11]
The present design solution also gives a chance to improve the energy efficiency in oil production industry, to reduce the number of damages and service of submersible oil-pumping equipment, to optimize the system of reagent dosing and will bring the significant economic effect without high costs for production.
Single Flowline Tiebacks: Flow Assurance Considerations From Appraisal to Operations
Authors: Monge Juan I. , Bukkaraju Sampath K. , Osorio Nelson F. 
Published: October 2018

Abstract
In addition to the recent downturn in oil price, as tiebacks get deeper, longer and originate from more remote areas, interest in making single flowline tiebacks (SFTs) viable development options continues to grow. SFTs provide a means for smaller operators with marginal projects and large international operators with stranded assets to move projects from concept to producing assets. The main challenges in making SFTs viable are: Development and implementation of mitigation and remediation strategies for addressing the typical flow assurance challenges encountered in deep-water.Development of operational strategies considering the processing and liquid handling capacities of the existing tieback host.
By more clearly understanding the operating conditions from subsurface to surface and systematically addressing each of the field's challenges with novel operating techniques, enhanced facilities and/or chemicals, SFTs have gone from once simply a conceptual idea, to a valid development alternative. The focus of this paper is to apply findings and lessons learned from various SFT projects, ranging from concept selection to decommissioning, to highlight various considerations. It is the hope and intent that by highlighting these considerations we, as an industry, can continue to mature SFTs. This maturation will then be able to provide an alternative development option to make certain projects economically viable, while not making them unfeasible, difficult and unsafe to operate.
Unorthodox Fluids for Unconventional Completions: Maximizing Production and Avoiding Pitfalls
Authors: Carman Paul , Li Chunlou , Wheeler Richard 
Published: October 2018

Abstract
The burgeoning development of shale and unconventional formations in the face of a limited supply of guar, the primary gellant for fracturing fluids, created a demand for an alternative fluid. The new fluid, a modified friction reducer, capable of generating high viscosity with increased loadings and containing unique chemistry to facilitate breaking of the fluid provides a cost effective way of proppant transport. Since 2011, it has been used together with different types of proppant to treat various formations in the United States, both conventional and unconventional. Even with a wide technological acceptance, this fluid is not a solution for all situations. This study presents the application results, positive and negative, which are equally important for the continuous improvement of fracturing stimulation.
Mining an in-house treatment database, this study collects treatment designs and operation parameters for all fracturing jobs performed in the following five major unconventional plays: Bakken/Threeforks, Eagle Ford, Marcellus, Utica and Wolfcamp. By using the publicly available FracFocus database, offset wells nearby the wells of interest were identified and their basic treatment information was collected, analyzed and normalized based on geography. Production performance metrics such as peak production and cumulative production in near and long term were used to evaluate the production performance of wells included.
This study shows that this technology has been successfully deployed in temperatures up to 300°F. Many wells treated in the Bakken have measured depths (MD) over 20,000 ft and true vertical depths (TVD) over 11,000 ft. Proppant with various mesh sizes from 100 to 20/40 are carried by this type of fracturing fluid. Due to the complex nature of unconventional formations and a long list of designing and operating parameters, it demonstrates outstanding performance in certain cases and may show why it has unfavorable results in others.
In comparison to other studies, this evaluation incorporates the near and long term results. The detailed analysis of this fracturing fluid technology and how its production performance sheds light on some questions that completion engineers are longing to answer: In which formation does this fluid have the best results and what types of formations should be avoided? What can be modified in job design to improve its performance?
Perfecting Operational Execution: The Journey to High Reliability in the Oilfield
Authors: Tower Patrick , Williams Austin , Sakievich Sam , Howdeshell Tony , Kearley Patrick , Motruk Lonny , McCullough Tony 
Published: October 2018

Abstract
High Reliability Organizations (HROs) are organizations with systems that maintain exceptionally low failure rates while operating in environments where the nature of the risk and complexity of serious incidents would be anticipated. HROs such as nuclear submarines, aircraft carriers, and the fire service have no fail missions because the costs of failure are extremely high. Applying the same systems and tools that created their passionate commitment to excellence that permeates every aspect of their operations, other industries can produce their own culture of high reliability where nearly perfect safety and service quality are the norm.
The aim of this paper is to illustrate how the principles, concepts, and processes of HROs, including Crew Resource Management (CRM), can optimize operational execution of a pressure pumping company through increased levels of safety and quality. The contemporary oilfield operating environment requires teams to be proactively aware of emerging threats and to trap errors or incidents to prevent them from escalating into significant incidents.
The paper includes the following themes: A literature review of the principles and concepts of traditional and established HROs from other industries;The process and systems to operationalize HRO principles and concepts within the energy industry; andTwo case studies demonstrating how HRO principles and concepts allow teams in the oilfield to reduce system failures and to notice, confront, resolve, and learn from unforeseen problems and failures when they do occur.