bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reliable Detection and Power in an Electronic Sliding Sleeve Multistage Completion System
Authors: Walton Zachary , Fripp Michael 
Published: October 2018

Abstract
A new electronic sliding sleeve has been developed for hydraulic fracturing that provides the operational efficiency of sliding sleeves while enabling an unlimited number of fracturing zones and eliminating the milling of the baffle seat. This system uses electronic sensors and battery power to determine when the next stage of the fracture is ready for pumping. The reliability of the sensors, electronics, and batteries must be addressed to achieve a reliable fracturing system.
Traditional sliding sleeves use a series of progressively smaller-sized balls that shift sleeves by landing on progressively smaller-sized baffles. The new electronic sliding sleeve has the intelligence to enable opening the sleeve without the use of progressively sized balls and baffles. The result is a monobore construction that enables stimulating an unlimited number of zones and simplifies well completion design and installation. The electronic implementation improves the mechanical reliability beyond mechanical monobore fracturing tools but introduces other concerns of reliability. This paper reports on the reliability testing of the electrical components including the electronics, sensor, and battery.
Electrical reliability of the new sliding sleeve was evaluated at high temperature, extended service duration, and high pump rates. The sleeve operates by counting the passage of frac balls and then shifting the sleeve when the programmed number of balls has passed. This battery-powered electronic sliding sleeve has an onboard sensor and processor equipped to count the balls. Once the programmed number of balls has been detected, an actuator commands the sleeve to shift. The sliding sleeve requires reliable operation of all components. A probabilistic model is used to account for stochastic variation in batteries and electronics. The magnetic sensors detected the frac ball over a wide temperature range and at flow rates ranging from near static to more than 100 bbl/min. The batteries were characterized for operating life, passivation, and self-discharge. Power consumption and reliability of the electronics were tested to accurately predict remaining operational life of the electronic system under a wide range of conditions. The resulting electronic sliding sleeve also increases mechanical reliability.
A programmable battery-powered electronic sliding sleeve increases flexibility, reliability, mechanical simplicity, and robustness for multistage hydraulic fracturing. This new fracturing system is particularly applicable in extended reach applications by offering an unlimited number of zones with a simple monobore construction.
Implementation of the Intellectual Gas Control System for Gas Lift Optimization at Orenburgskoe Oilfield
Authors: Ulyanov Vladimir , Kuchurin Alexey , Kibirev Evgeny , Gryzunov Andrey , Bak Viktor , Rymarenko Konstantin , Nukhaev Marat , Dadakin Nikita 
Published: October 2018

Summary
The gas-lift operation is widely internationally used in the oil production. At present, this production method is used at the Orenburg oil and gas condensate field as one of its options—a natural-pressure gas-lift well operation method. The advantage of the natural-pressure gas-lift well operation method is a significant reduction in operating costs (electricity, electric submersible pump rent). At that both, new wells drilled into the gas cap and production wells where a breakthrough of gas has occurred can be used as a donor well. A feature that defines this operation method is a need for continuous control over pumping down each borehole. This is due to the fact that a donor well provides several producing oil wells with active gas, the operational parameters of these may significantly differ from each other. A system with automatic lock shield valves was adopted to automate the injection of gas in the Orenburg oil and gas condensate field, it allowed tuning up the injection, constantly monitoring and metering consumption of gas for each well.
This paper outlines the Gazpromneft-Orenburg experience in adopting an intelligent system for gas injection monitoring. It is described as a stage of a technical task preparation, conducting pilot runs at several wells, adjusting requirements to the equipment based on the results of pilot runs, full-scale implementation of the project at all wells of the deposit, optimization of gas-lift wells throughout the well stock.
The automated gas-lift process control system adopted at the Orenburg oil and gas condensate field allowed: collecting and processing information coming from primary transducer-converters;managing the actuators ensuring optimal well performance;operatively ensuring well operation mode alternations;accumulating the information received to gather statistical data and monitor the oil wells status.
Bringing the Sucker Rod Pumping Unit into the Classroom with the Use of the Internet of Things
Authors: Teodoriu Catalin , Pienknagura Erik 
Published: October 2018

Abstract
Artificial lift and particularly sucker rod pumping units are the most applied technologies for oil wells. While the equipment as such requires strong mechanical background, the use of the equipment remains solely the responsibility of petroleum engineers. Teaching them the working principles and functions of the equipment could be a challenging process when using only classroom related tools such as multimedia, short pieces of equipment, etc. As a response to this shortcoming, a new laboratory has been developed at the University of Oklahoma, which includes a large-scale pumping unit that is capable to be programed to simulate any situation in real time and use the Internet of Things to gather real time data and create tailored diagnostic tools that students and laboratory staff can utilize for many applications.
This paper focuses on the need to add a hands-on teaching experience to the classroom, and what type of data can be mined and used to accomplish specific objectives. It is required for our future petroleum engineers that they know how to apply basic industry principles and increase problem solving skills involving machinery. The proposed laboratory would be capable to deliver all standard monitored parameters of a sucker rod pumping unit to any classroom through a networked connection and allow the students to make decisions or experiment in real time with the setup. By being a large-scale setup, students can easily observe how the unit works, visualize downhole pumping operations, identify where the sensors are placed, and learn how to use raw data for any intended purpose. In other words, the entire artificial lifting process can be seen and operated from any classroom on campus remotely, and advanced analysis can be performed by the students or staff.
Peculiarities of Identification of Reservoir Fluids Properties of Two-Phase With Oil Rim and Gas Cap Deposits: From Sampling to Justification of the Parameters for Calculating Reserves and PVT Data for Hydrodynamic Simulation of Field Development
Authors: Promzelev Ivan , Brusilovsky Alexander , Kuporosov Dmitriy , Yushchenko Taras 
Published: October 2018

Abstract
Substantiation of the composition and properties of hydrocarbon (HC) reservoir fluids is one of the important stages in the calculation of reserves and has a significant impact on the results of field development planning and engineering. The article discusses the current methodological issues of identification of PVT properties of reservoir oil and free gas (gas cap) in a twophase deposits.
The first part of the article is devoted to the problem of obtaining representative samples of reservoir oil in two-phase deposits and describes the methodical approach allowing to reproduce properties of the formation oil which is in thermodynamic equilibrium with the existing gas cap. The identification procedure is based on the complex use of the results of laboratory and theoretical studies, the basis of which is the mathematical modeling of the phase behavior of multicomponent hydrocarbon systems. The results are illustrated by the example of reservoir oil from the West Siberia field. It is confirmed that in the case of partially degassed (unrepresentative) deep oil samples, the saturated hydrocarbon fluid can be restored by modeling the process, reverse degassing in reservoir conditions.
In the second part of the article, a scientific and methodological approach to the restoration of the composition and reproduction of the PVT properties of reservoir oil of two-phase deposit is proposed in the case of limited input information. On the basis of the identified composition of the reservoir oil, its thermodynamic model is created, which adequately reproduces the results of laboratory and field studies.
The composition of the gas cap is determined using the fundamental physical foundations of the phase equilibrium in multicomponent systems and free gas thermodynamic properties are estimated on the basis of PVT-modeling. PVT models of reservoir oil and gas-condensate mixture of the gas cap can be used in the design and monitoring of the development using modern hydrodynamic simulators based on both Black Oil and compositional models. The application of the method is illustrated by the example of a real deposit.
The suggested methodological approaches are recommended to be used in the estimation of reserves and design of fields development.
A Novel Multi-Well Interference Testing Model of a Fractured Horizontal Well and Vertical Wells
Authors: He Youwei , Cheng Shiqing , Qin Jiazheng , Tang Hewei , Chai Zhi , Wang Yang , Chen Zhiming , Yu Haiyang , Killough John 
Published: October 2018

Abstract
High water-cut has been observed for many multi-fractured horizontal wells (MFHWs) in China soon after waterflooding begins. Available well-testing models of single well ignored the effect of adjacent wells on the MFHW, and they are unable to evaluate whether MFHW (producer) and surrounding vertical wells (injectors) are in good pressure communication. To fill this gap, this work presents a multi-well interference testing (MWIT) model to consider the interference of injectors and further match the interference pressure data.
The MWIT model is established to investigate the effect of multiple injection wells on transient-pressure behavior of the MFHW. Due to the interferences from injectors, the pressure and pressure-derivative curves of MWIT move down beginning with the biradial flow regime for single MFHW model, and pseudo-radial flow (horizontal line with the value of 0.5 on pressure-derivative curve) disappears. Sensitivity analysis was conducted to discuss the effects of crucial parameters on the pressure response, including total injection rates, unequal injection rates of injectors, well spacing, injector distribution, number and production of hydraulic fractures. When total injection rates are lower than the production rate, the pressure derivative will eventually stabilize at 0.5*(1-Σ(qIncjD)) during the interference-flow regime on the log-log type curves. Since only the positive number can be shown in the log-log graph, semi-log curves are also developed to fully characterize the flow regimes of MWIT. A novel finding is that pressure derivative also ultimately behave as a horizontal line with the value of 0.5*(1-Σ(qIncjD)) when total injection rates are equal or higher than production rates on the semi-log curves. The total injection rates and well spacing between the MFHW and injectors have a significant effect on middle and late pressure behaviors, whereas the number and production of fractures mainly affects the pressure responses during early to middle period. Type curves indicate that the effect of surrounding injectors are significant and cannot be ignored, and the novel characteristics provide potential application of the MWIT model to estimate formation parameters. Case studies highlight the application of the proposed method in effectively matching the interference pressure data. Interference-testing analysis of the MWIT provides a better reservoir evaluation compared to single-well testing model.
Reservoir Development Aspects and Surface Facilities Design of Gas Condensate Fields with Oil Rims
Authors: Shelepov Konstantin , Struchkov Ivan , Poltoranin Vadim , Trusova Anna , Chashchin Mikhail , Kuzevanov Maxim , Buchinskiy Stanislav 
Published: October 2018

Abstract
The operation of gas condensate fields under natural recovery drive is accompanied by retrograde condensation in the well bottomhole zone, which inhibits the movement of hydrocarbons in this area. One of the main methods of maintaining reservoir pressure under these complications is the injection of dry gas into injection wells, which is limited by economic factors. The problem of the development of gas condensate fields with oil rims is that the traditional reservoir pressure maintenance system does not provide a high oil recovery factor. Thus, the effective production of hydrocarbons requires new technologies and technical means. The paper considers a complex strategy for the development of such reservoirs, based on integrated modeling and the use of smart-well solutions.
The paper presents PVT-analysis, special core analysis, geophysical studies and well test results. An integrated field model has been created that allows to identify effective technologies for the development of gas condensate formations and the oil rim, as well as to account for the operational capabilities of surface facilities, while maximizing hydrocarbon recovery. The assessment and recommendations for the long-term development of a gas condensate field with an oil rim are suggested.
Multivariate calculations are performed to assess the productivity of wells and reach the field's maximum potential. The proposed field development strategy involves optimization of the surface infrastructure and hydrocarbon transportation system.
Application of Well Tests for Naturally Fractured Reservoir's Analysis with Complex Void Structure
Authors: Akberova Aigul , Davletbaev Alfred , Chudinova Anastasiya , Efimov Dmitrii , Abdullin Rim , Urazov Ruslan , Nazargalin Eduard , Gizatullin Damir 
Published: October 2018

Abstract
The paper discusses the examples of field study by different well tests in a carbonate field with a reservoir having a complex void structure. For studying the properties of productive layers the researchers used pressure build-up tests with the use of drill stem testing (DST) in open hole, build-up tests after well completion, injection tests, steady flow tests, analysis of production/pressure with the use of downhole telemetric system, well interference testing. Having generalized of the obtained data, the authors have identified the limits of applicability, advantages and disadvantages of each method, as well as the matrix of well-testing methods for the considered carbonate reservoir was developed.
Automatic Well Log Analysis Across Priobskoe Field Using Machine Learning Methods
Authors: Belozerov Boris , Bukhanov Nikita , Egorov Dmitry , Zakirov Adel , Osmonalieva Oksana , Golitsyna Maria , Reshytko Alexander , Semenikhin Artyom , Shindin Evgeny , Lipets Vladimir 
Published: October 2018

Abstract
This paper is devoted to the testing of of automatic well logs interpretation testing, developed on the basis of machine learning methods.
The basis of the method presented in the paper is recurrent artificial neural networks. For their training and adjustment, log curves and their corresponding interpretation of different years are used. The set of well data is divided into training, validation and test samples. The resulting tool is set up on training and validation samples, and then used on a test sample of wells for which the interpretatoin was hidden, in order to automatically predict net pays and compare the results with the interpretation performed by an expert petrophysicist. For the test sample, traditional machine learning metrics metrics and special geological were calculated to assess the quality of the algorithm.
During the work a number of experiments were carried out, in which the dependence of the forecast quality was estimated not only on the different architecture and settings of the artificial neural network, but also on the amount of input data. The iterative approach in the research allowed to determine the best parameters for the solution of the task. For each well of the test set, a forecast of reservoir intervals distribution is made. The resulting interpretation shows high accuracy, both in terms of different mathematical metrics, and the results of analysis and evaluation of the expert petrophysics. Also, during the experiments, an important conclusion was made about the generalizing ability of the proposed methodology. The use of several variants of interpretation of well log data, performed by different specialists at different times and on the basis of different petrophysical models, allows to generalize and use all the accumulated experience of well logs interpretation, thereby improving the quality of the forecast. The main conclusion of the study can be considered a statement about the efficient applicability of machine learning algorithms for automatic well logs interpretation.
The Approach to Modeling and Optimization of Technological Regime of Complex System: Gas Condensate Field – LNG Plant
Authors: Pashinsky Alexey , Sullagaev Alexey , Epryntsev Anton , Yamov Andrey , Valiev Rinat 
Published: October 2018

Abstract
Nowadays many oil and gas companies demonstrate a great interest to technology of liquefying of natural gas (LNG). LNG technology is especially topical for gas and gascondensate fields of Yamal and Gydan Peninsulas located so remote from network of transfer pipelines.
The exploitation of the field, which provides the output to LNG plant, has its peculiarities in compare with traditional approaches. Development of new approaches to the LNG plant start-up optimization is among the foreground tasks today. Failure prediction and monitoring of operation on the field, providing the production to LNG plant, are inconceivable without dynamic multiphase flow simulator.
Main purpose of this work is failure prediction and optimization of South Tambey field operation in the period of start-up and ramp up, taking into consideration posible uncertaincies and risk estimation. In this article authors present the results of predictive computation of the field operation while start-up, and describe their optimization sugestions.
The concept of integrated modeling of the entire system "formation-well-pipeline system-inlet facilities" introduced in this paper could be used for the purpose of subsequent monitoring of operation regime.
Applicability Analysis of Optimization Algorithms for Oil Fields Development Control
Authors: Nuzhin Egor , Yaubatyrov Ramil , Kotezhekov Viktor , Babin Vladimir 
Published: October 2018

Abstract
The paper presents a comparative analysis of advanced numerical optimization algorithms for solving a specific problem of increasing the efficiency of the waterflooding in a mature field (Brownfield).
Via multivariate iterative calculations produced by the optimization algorithm, on the basis of the reservoir simulation model the optimal waterflooding strategy (optimal combination of well modes) is determined. This strategy maximizes the economics of the field which is expressed in the value of net present value (NPV). The optimization process in most practically significant cases is complicated by the following factors: large dimension of the solution space, high complexity of the optimized function and high computational cost of each reservoir simulation. As a result, for the allocated project time the final solution can strongly depend on the chosen optimization algorithm.
Comparison of the algorithms was based on the solution of the real Brownfield waterflooding optimization problem with more than 100 active wells. Relative improvements of the objective function, NPV, were compared with respect to the number of required reservoir simulations. As a result, the set of recommendations for choosing the most effective algorithm depending on the available project time was obtained. For the considered problem, algorithms that show high efficiency (relative increase of NPV by 4-6 times) using comparatively small optimization budget (the ratio between the number of reservoir simulations and the problem dimension varies from 1 to 5) were determined.
Method of Anisotropy Modeling and its Application to Hydrodynamic Simulation
Authors: Kolbikov Sergey , Kuznetsova Yana , Smirnov Artem 
Published: October 2018

Abstract
In the practice of hydrodynamic modeling the anisotropy parameter (the ratio of vertical permeability to horizontal – kv/kh) is usually determined by experts as a fixed value varying in the range of 0.1-0.01, for the formation or for the field as a whole, and it is specified in the adaptation process of the model to the development history. This approach is applicable and is successfully used for deposits characterized by low degree of lateral heterogeneity. However, at the present time, a significant number of deposits are in development, the productive layers of which were formed in continental and coastal-marine environment, and therefore are distinguished by a complex geological structure due to high lateral and vertical anisotropy. For such objects the use of the conventional approach with a fixed value of kv/kh leads to an incorrect consideration of the influence of the heterogeneity on effective vertical permeability. Thus, the necessity of an alternative method for constructing the kv/kh cube, recommended for use in the complex structure of reservoirs, is obvious.
The paper proposes a method for calculation the anisotropy parameter in 3D model cells intersected by wells as the multiplication result of the true anisotropy coefficient by the coefficient of pseudoanisotropy, which is modeled in the interwell space differentially for the facies zones by the method of cosimulation with NTG, reproducing the heterogeneity of the formation structure. The coefficient of true anisotropy is defined as the arithmetic average value from the results of core studies. The pseudoanisotropy coefficient characterizes the vertical heterogeneity of the formation within a single cell of a 3D grid. It is calculated for cells intersected by wells as a ratio of vertical permeability, which is the result of the geometric averaging of well log interpretation values, to lateral permeability, determined as the result of the arithmetic averaging [1]. For other cells of the 3D grid the anisotropy parameter is modeled by the method of cosimulation with NTG, which correlates with pseudoanisotropy coefficient.
The use of the proposed method for modeling of anisotropy cube in process of hydrodynamic calculations allows to take into account the influence of heterogeneity on the effective vertical permeability differentially for facies zones and sedimentological units within facies zones.