bluuebunny/crossref_metadata_2025_split huggingface dataset:
From Completion Design to Efficiency Analysis of Inflow Control Device: Comprehensive Approach for AICD Implementation for Thin Oil Rim Field Development Efficiency Improvement
Authors: Solovyev Timur , Mikhaylov Nikolay 
Published: October 2021

Abstract
The complex interbedded heterogeneous reservoirs of the Severo-Komsomolskoye field are developed by horizontal wells in which, as part of the pilot project's scope, autonomous inflow control devices (AICD) are installed to prevent early coning and gas breakthroughs in long horizontal sections and reduce sand production, which is a problem aggravated by an extremely low mechanical strength of the terrigenous deposits occurring in the Pokur formation of the Cenomanian stage in this area.
The zones produced through AICDs are separated by swell packers. The issue of AICD effectiveness is discussed in the publications by Solovyev (2019), Shestov (2015), Byakov (2019) and some others.
One of the methods used for monitoring horizontal sections with AICDs is production logging (PLT). However, due to the complexity of logging objectives, the use of conventional logging techniques makes the PLT unfeasible, considering the costs of preparing and carrying out the downhole operations.
This paper provides some case studies of the Through-Barrier Diagnostics application, including passive spectral acoustics (spectral acoustic logging) and thermohydrodynamic modelling for the purpose of effective estimation of reservoir flows behind the liner with AICDs installed and well integrity diagnostics.
As a result of the performed diagnostics, the well completion strategy was updated and optimised according to the log interpretation results, and one well intervention involving a cement squeeze with a straddle-packer assembly was carried out.
Dynamic Modeling of the Gas Discharge of a Mine in the Karaganda Coal Basin Under High Uncertainty Using a Multiple Realization Approach
Authors: Bigeldiyev Asfandiyar , Batu Assem , Berdibekov Aidynbek , Kovyazin Dmitry , Sidorov Dmitry , Temirkhassov Aidos , Zhumagulov Almas , Narimanov Yernar 
Published: October 2021

Abstract
The current work is intended to show the application of a multiple realization approach to produce a strategic development plan for one of the mines in Karaganda coal basin. The presented workflow suggests using a comprehensive reservoir simulator for a history matching process of a coal pillars on a detailed 3D grid and application of sensitivity and uncertainty analyses to produce probabilistic forecast.
The suggested workflow significantly differs from the standard approaches previously implemented in the Karaganda Basin. First, a dynamic model has been constructed based on integrated algorithm of petrophysical interpretation and full cycle of geological modeling. Secondly, for the first time in the region, dynamic modeling has been performed via a combination of history matching to the observed degassing data and multiple realization uncertainty analysis. Thirdly, the described model parameters with defined range of uncertainty has been incorporated into the forecasting of degassing efficiency in the mine using different well completion technology.
From the hydrodynamic modeling point of view, the coal seam gas (CSG) reservoir is presented as a dual porosity medium: a coal matrix containing adsorbed gas and a network of natural fractures (cleats), which are initially saturated with water. This approach has allowed the proper description of dynamic processes occurring in CSG reservoirs. The gas production from a coal is subject to gas diffusion in coal micropores, the degree of fracture intensity and fracture permeability. By tuning these parameters within reasonable ranges, we have been able to history match our model to the observed data. Moreover, application of an uncertainty analysis has resulted in a range of output parameters (P10, P50, and P90) that were historically observed.
Performed full cycle of CSG dynamic modelling including history matching, sensitivity, and uncertainty analyses has been performed to create a robust model with the predictive power. Based on the obtained results, different optimization technologies have been simulated for fast and efficient degassing through a multiple realization probabilistic approach. The coal reservoir presented in this work is characterized by very low effective permeability and final degassing efficiency depends on well-reservoir contact surface. The decrease of the well spacing led to a proportional increase of gas recovery which is very similar to unconventional reservoirs. Therefore, vertical and horizontal wells with hydraulic fractures have been concluded the most efficient way to develop coal seams with low effective permeability in a secondary medium.
Pilot Project Evaluating WAG Efficiency for Carbonate Reservoir in Eastern Siberia
Authors: Zharko Valentina , Burdakov Dmitriy 
Published: October 2021

Abstract
The paper presents the results of a pilot project implementing WAG injection at the oilfield with carbonate reservoir, characterized by low efficiency of traditional waterflooding. The objective of the pilot project was to evaluate the efficiency of this enhanced oil recovery method for conditions of the specific oil field.
For the initial introduction of WAG, an area of the reservoir with minimal potential risks has been identified. During the test injections of water and gas, production parameters were monitored, including the oil production rates of the reacting wells and the water and gas injection rates of injection wells, the change in the density and composition of the produced fluids. With first positive results, the pilot area of the reservoir was expanded. In accordance with the responses of the producing wells to the injection of displacing agents, the injection rates were adjusted, and the production intensified, with the aim of maximizing the effect of WAG. The results obtained in practice were reproduced in the simulation model sector in order to obtain a project curve characterizing an increase in oil recovery due to water-alternating gas injection.
Practical results obtained during pilot testing of the technology show that the injection of gas and water alternately can reduce the water cut of the reacting wells and increase overall oil production, providing more efficient displacement compared to traditional waterflooding. The use of WAG after the waterflooding provides an increase in oil recovery and a decrease in residual oil saturation. The water cut of the produced liquid decreased from 98% to 80%, an increase in oil production rate of 100 tons/day was obtained. The increase in the oil recovery factor is estimated at approximately 7.5% at gas injection of 1.5 hydrocarbon pore volumes. Based on the received results, the displacement characteristic was constructed. Methods for monitoring the effectiveness of WAG have been determined, and studies are planned to be carried out when designing a full-scale WAG project at the field.
This project is the first pilot project in Russia implementing WAG injection in a field with a carbonate reservoir. During the pilot project, the technical feasibility of implementing this EOR method was confirmed, as well as its efficiency in terms of increasing the oil recovery factor for the conditions of the carbonate reservoir of Eastern Siberia, characterized by high water cut and low values of oil displacement coefficients during waterflooding.
Evaluation of Residual Oil Saturation With Use of Single Well Chemical Tracer Test Swctt For Estimation of Eor Efficiency. From Theory to Experiment
Authors: Koryakin Fedor Andreevich , Tretyakov Nikolay Yuryevich , Vershinin Vladimir Evgenyevich , Ponomarev Roman Yuryevich 
Published: October 2021

Abstract
This article provides a brief overview of the theory of tracer studies, describes approaches to the interpretation of tracer studies using both analytical methods and hydrodynamic modeling, compares the results of analytical and numerical interpretation. The article also describes the problems that arise during the interpretation of real case study.
A 3-Step Reaction Model For Numerical Simulation of In-Situ Combustion
Authors: Rojas Allan A. , Yuan Chengdong , Emelianov Dmitrii A. , Saifullin Emil R. , Mehrabi-Kalajahi Seyedsaeed , Varfolomeev Mikhail A. , Sudakov Vladislav A. , Lotfullin Bulat R. , Shevchenko Denis V. , Ganiev Bulat G. , Lutfullin Azat A. , Zaripov Aza T. 
Published: October 2021

Abstract
In-situ combustion (ISC) is an effective thermal enhanced oil recovery method. However, it is still not widely implemented in oilfields. One of the factors limiting the wide application of ISC is the challenge in its simulation and prediction. In this work, the oxidation experiments of maltenes and asphaltenes in reservoir rock were performed in the porous media thermo-effect cell (PMTEC) to establish a simplified reaction model based on non-isothermal measurements and to use it in numerical simulation of ISC process. It was found that the oxidation reaction process of oil fractions can be divided into different regions depending on generated self-energy rate and oxygen consumption rates that is up to the temperature. In order to propagate reactions from one mode to another, a specific oxygen consumption per unit mass of oil fractions is required. The average oxygen requirement for crossing LTOad (low temperature oxidation, oxygen addition reactions) boundary into LTC (low temperature combustion) mode was 64 mgO2/g(maltenes) and 10.4 mgO2/g(asphaltenes). To propagate reactions into HTO mode from the LTC mode, it requires about 646 mgO2/g(asphaltenes) for asphaltenes fraction. Moreover, this characterization seems to be a key tool when designing air injection in field pilots. Additionally, it was revealed that asphaltenes are more exothermic and require lower oxygen uptake per unit of temperature increment in comparison to maltenes. Furthermore, the mass conversion data obtained from non-isothermal measurements of oil fractions allow for the estimation of the stoichiometry coefficients of two low temperature oxidation reactions, i.e. oxidation and cocking processes, which can be included into a numerical simulation model to replicate combustion tube (CT) results. The numerical simulation model reveals that the simplified reaction model from a 6-step into a 3-step reaction scheme can reproduce ignition process, temperature profiles, combustion velocity, and fluid production, which thus makes it suitable for the upscaled modelling of ISC.
Screening of Surfactants for Huff-N-Puff Injection into Unconventional Reservoirs
Authors: Scerbacova Alexandra , Ivanova Anastasia , Mukhina Elena , Ushakova Alexandra , Bondar Mikhail , Cheremisin Alexey 
Published: October 2021

Abstract
The gradual depletion of conventional oil reserves and the growing demand for hydrocarbon feedstock have led to shale deposits development necessity, which are characterized by high reservoir temperatures and very low permeabilites. One of the methods proposed for unconventional reservoirs development is surfactant injection in huff-n-puff mode. Unlike surfactant flooding, where the main effect is achieved through the displacement mechanism, the huff-n-puff method is based on capillary imbibition. Surfactant solutions decrease oil-water interfacial tension, change rock surface wettability to water-wet, lead to desorption of adsorbed hydrocarbons and increase relative permeability to water, thus increasing oil production.
A number of commercially available anionic and nonionic surfactants were selected for laboratory investigation. Compatibility with reservoir fluids and thermal stability were tested for 14 days. For the stable compositions, the interfacial tension at the boundary with oil was measured with the spinning drop method. Special attention was paid to the study of initial reservoir wettability and the ability of the selected surfactants to shift it towards water-wet. Wettability at the macro level was determined by the "sessile" drop method.
As a result of the screening, two surfactant compositions capable to alter the wettability of the rock surface to strictly water-wet were selected, as this is the key point when selecting surfactant compositions for low-permeable reservoirs. The optimum operating concentrations were selected to avoid the formation of a Winsor III microemulsion, which can lead to plugging of narrow channels and fluid flow blockage in the formation. Values of static adsorption onto crushed rock were also evaluated. The most effective composition was investigated in a huff-n-puff filtration experiment and positive results were obtained.
Nanoparticles were also screened as potential components of surfactant compositions. It was found that nanoparticles forming stable dispersions in surfactant solutions improve their ability to change the wettability to a water-wet state.
As a result of the laboratory work performed, it can be concluded that the huff-n-puff technology is applicable in unconventional reservoirs with very low permeabilities. The huff-n-puff mode for surfactant solutions injection is preferable due to lower surfactant consumption, targeted effect, and shortened well response time. Successful implementation of this technology on an industrial scale can improve the efficiency of shale oil production.
The Role of Emulsification and Interfacial Tension Ift For the Enhanced Oil Recovery Eor in Surfactant Flooding
Authors: Li Xiaoxiao , Yue Xiang'an , Zou Jirui , Zhang Lijuan , Tang Kang 
Published: October 2021

Abstract
In this study, a visualized physical model of artificial oil film was firstly designed to investigate the oil film displacement mechanisms. Numerous comparative experiments were conducted to explore the detachment mechanisms of oil film and oil recovery performances in different fluid mediums with flow rate. In addition, the of influencing factors of oil film were comprehensively evaluated, which mainly includes: flow rate, surfactant behaviors, and crude oil viscosity.
The results show that, (1) regardless of the viscosity of crude oil, flow rate presents a limited contribution to the detachment of oil film and the maximum of ultimate oil film displacement efficiency is only approximately 10%; (2) surfactant flooding has a synergistic effect on the oil film displacement on two aspects of interfacial tension (ITF) reduction and emulsifying capacity. Giving the most outstanding performance for two oil samples in all runs, IFT reduction of ultra-low value is not the only decisive factor affecting oil film displacement efficiency, but the emulsifying capability plays the key role to the detachment of oil film due to effect of emulsifying and dispersing on oil film; (3) the increasing flow rate of surfactant flooding is able to enhance the detachment of oil film but has an objective effect on the final oil film displacement efficiency; (4) flow rate have the much influence on the detachment of oil film, but the most easily controlled factor is the surfactant property. The finding provides basis for oil film detachment and surfactant selection EOR application.
The Use of a Sensor Modules System for Measuring Drilling Parameters in a Bit, Significantly Reduces the Construction Time of Wells in Eastern Siberia
Authors: Rebrikov Andrey Alexandrovich , Koschenkov Anton Anatolyevich , Rakina Anastasiya Gennadievna , Kortunov Igor Dmitrievich , Koshelev Nikita Vladimirovich , Dubrovskiy Maxim Petrovich , Bekasov Vladimir Olegovich , Yakimov Yuriy Anatolyevich , Grechikho Pavel Anatolyevich , Ataev Magomed Adamovich 
Published: October 2021

Abstract
Currently, production and exploration drilling has entered a stage of development where one of the highest priority goals is to reduce the time for well construction with new technologies and innovations. One of the key components in this aspect is the utilizing of the latest achievements in the design and manufacture of rock cutting tools – drill bits. This article presents some new ideas on methods for identifying different types of vibrations when drilling with PDC bits using a system of sensors installed directly into the bit itself.
In the oil and gas fields of Eastern Siberia, one of the main reasons for ineffective drilling with PDC bits are vibrations, which lead to premature wear of the cutting structure of the bit and the achievement of low ROPs in the dolomite and dolerite intervals. For efficient drilling of wells of various trajectories with a bottom hole assembly (BHA), including a downhole motor (PDM) and a PDC bit, special attention is paid to control of the bit by limiting the depth of cut, as well as the level of vibrations that occur during drilling process. Often, the existing complex of surface and BHA equipment fails to identify vibrations that occur directly on the bit, as well as to establish the true cause of their occurrence. Therefore, as an innovative solution to this problem, a system of sensors installed directly into the bit itself is proposed. The use of such a system makes it possible to determine the drilling parameters, differentiated depending on the lithological properties of rocks, leading to an increase in vibration impact. Together with the Operators, tests have been successfully carried out, which have proven the effectiveness of the application of this technology.
The data obtained during the field tests made it possible to determine the type and source of vibration very accurately during drilling. In turn, this made it possible to precisely adjust the drilling parameters according to the drilled rocks, to draw up a detailed road map of effective drilling in a specific interval. Correction of drilling parameters based on the analysis of data obtained from sensors installed in the bit made it possible to reduce the resulting wear of the PDC bit cutting structure and, if necessary, make changes to the bit design to improve the technical and economic indicators. Thus, the use of a system of sensors for measuring the drilling parameters in a bit ensured the dynamic stability of the entire BHA at the bottomhole when drilling in rocks of different hardness, significantly reduced the wear of the drilling tools and qualitatively improved the drilling performance.
7-inch Casing While Drilling CWD With Retrievable Bottom Hole Assembly BHA
Authors: Usmanov Askhat Radikovich , Shishkin Anton Mikhailovich , Merzlyakov Alexander Sergeevich , Karimov Jalal Lalash Ogli , Fedotov Anton Valeryevich , Khlebnikov Vladimir Ivanovich 
Published: October 2021

Abstract
Casing drilling technology, as an alternative to conventional drilling, has been known for a long time. This method is mainly used for wells with geological complications, such as lost circulation or wellbore instability of various nature. By using drilling on a string for a section or part of it, the problem interval is immediately cased, eliminating the time spent on additional operations, such as pulling the bottom hole assembly (BHA), wiper trips and running the casing. Thus, this allows to reduce the time for well construction, reduces the risk of accidents and non-productive time associated with the complication zone.
Casing drilling has become widely for drilling vertical surface conductors and technical casing with a drillable shoe, as well as for drilling with retrievable BHA in inclined sections for 324- and 245-mm casing.
The aim of this work was to perform directional drilling on a 178mm production casing in an interval where the client had geological problems associated with running casing due to a zone of rock collapse. The uniqueness of the task lies in the fact that no one in the world has yet performed drilling on a casing with a building inclination and landing into a horizontal plane. It was necessary to follow the designed well trajectory, to build inclination from 67 to 85 degrees with the planned dogleg severity of 1 degree / 10m.
Continuous Improvement: Rotary Steerable System with Electromagnetic Telemetry as Approach to Reduce Well Time
Authors: Rakhmangulov Farit , Dorokhin Pavel 
Published: October 2021

Abstract
One of the main challenges from operating companies is the continuous reduction of well construction time. During drilling, considerable time is spent on static measurements to determine the wellbore location and to verify that the actual well path matches the planned one. The electromagnetic telemetry system (EMT) allows the taking of static directional survey measurements during connections, when the drill string is in slips. Transmitting commands to the rotary steerable system (RSS) through the EMT does not cause the drilling process to stop, which also reduces well construction time.
The work describes well drilling experience with the use of the electromagnetic channel for communication with the rotary steerable system and the positive displacement downhole motor not only in horizontal section but in all well sections, starting from the top hole. Combined use of the complete logging while drilling tools (LWD) with this type of the telemetry system is a valuable finding. The article describes BHA, operational principles of this type of the telemetry system, and problems which may arise during operation.
Collaborative Approach Overcomes Cementing Challenges in Narrow Pressure Window Environment
Authors: Lobastov Denis , Nafikova Svetlana , Akhmetzianov Ilshat , Zaripov Shamil , Krivolapov Dmitry 
Published: October 2021

Abstract
The collaborative approach used for cementing the production liner in an onshore development well in Russia is presented. The reservoir has a narrow window between pore and fracture pressures, which has previously caused formation instability and severe lost circulation issues during well construction, compromising zonal isolation objectives.
Total loss of fluids experienced while cementing the 114.3 mm production liner in the first appraisal well in the field led to revising the cementing strategy. Collaboration among various parts of the drilling department and the opportunity to define a new approach resulted in a decision to introduce managed pressure drilling (MPD) to address the challenges associated with a narrow pressure window and uncertainty in pore pressure while drilling and cementing. This enabled implementing the optimal mud weight and adjusting equivalent circulating density (ECD) during cementing with minimum overbalance.
Reducing the mud weight from 1.20 SG to 1.05 SG eliminated losses after running the liner and while cementing it. As a result, pre-job circulation rates and pumping rates during cementing could be increased, improving mud removal efficiency and achieving top of cement at the required depth. The constant-bottomhole-pressure mode of MPD was used to maintain the same ECD during displacement of the well to a lighter fluid and during cementing, avoiding well influx during pumpoff events by compensating for the annular friction pressure loss with surface backpressure. This first onshore managed pressure cementing operation executed within the same field in Russia (later named as field A) was completed flawlessly, with no safety or quality issues, zero nonproductive time, and achievement of the required zonal isolation across the challenging production section.
The collaborative approach used was a novel strategy, with the mud weight program strategically adjusted before and during the cementing operation to achieve zonal isolation objectives.