bluuebunny/crossref_metadata_2025_split huggingface dataset:
Practical Application of Flow Diversion Techniques for Development of Fractured Carbonate Reservoirs
Authors: Chorniy Alexey , Khodakov Ilya , Popov Dmitriy , Tkachev Ivan , Sadreev Ernest , Makarshin Sergey , Petrakov Andrey , Rogova Tatiana , Churanova Nina , Kubrak Mikhail , Kurelenkov Sergey , Pham Khac Dat , Ponomarenko Denis 
Published: October 2019

Abstract
Currently the flow diversion techniques (FDT) are quite often used to enhance the waterflooding efficiency at the late stage of field development. In particular, the issue of waterflooding efficiency improvement is specifically acute for the carbonate reservoirs due to complex structure of the reservoir, heterogeneity of reservoir properties as well as the presence of natural fractures. All listed factors result in significant decrease of waterflooding efficiency due to quick water breakthrough into the wells through the low flow resistance channels (LFR) which results in significant decrease of the oil recovery factor (RF). In many cases waterflooding at the similar fields is not applied at all resulting in the produced water disposal issue.
It is evident that for the purpose of solving such issues application of FDT based on the injection of various polymer gel-forming compounds into the formation allowing decrease in conductivity of LFR channels resulting in increase of swept reservoir volume may seem efficient. Considering the development of chemical industry, the FDT market currently offers a lot of compositions and compounds in a wide price range having different technological characteristics and designed for different conditions. Due to this the selection of the most appropriate compositions with account of all factors is an acute task requiring thorough approach with application of often unique laboratory experiments using unconventional equipment as well as performance of pilot works at individual field areas.
This paper presents the sequence of actions (from laboratory studies for the determination of the suitable polymer compositions to the selection of the specific field areas for the pilot works performance) for complete justification of FDT application at one of the Central Khoreyver Uplift fields located in the Timano-Pechora oil and gas province. Apart from presence of the heterogeneous and fractures carbonate reservoir, the field is characterized by high mineral content of the formation water what imposes significant restriction on the use of a number of polymer compositions as well as requires more thorough approach to the selection thereof. The paper also describes the flow experiments held, inter alia, using the actual core samples with use of high-mineralized formation water and shows their results. As a part of this work the justification of injection of two polymer compositions selected after laboratory studies at 2 pilot areas with assessment of incremental production using the simulation model (SM) developed with the account of the annual tracer studies allowing assessing LFR channels properties was carried out. As a result of the performed work, 2 pilot polymer compositions injection works were included into the company's business plan for 2019.
Iterative Approach in Obtaining the Most Reliable Geological Realization for Reservoir Simulation Runs: Yamal-Nenets Autonomous District Gas Field Case Study
Authors: Zunde Dmitry , Gorlanov Aleksey , Shalamov Ilya , Davletshin Anton , Belyansky Victor , Loznuk Oleg , Zakrevsky Konstantin , Abrashov Vadim 
Published: October 2019

Abstract
Existing approaches to the creation of hydrodynamic model based on a single implementation of the geological model, lead to difficulties in adaptation – there is a need for additional artificial adjustments of the initial data, and, as a consequence, inaccurate assessment of the projected technological parameters of the development. In order to make balanced investment decisions on the development of deposits, it is necessary to take a comprehensive approach to the assessment of possible uncertainties. To solve this problem, the iterative modeling approach is used, which provides a comprehensive assessment of possible variants of geological and technological models and allows you to vary the parameters of the model to assess uncertainty and risks in the calculation process.
The article describes the process of creating and selecting the most likely implementation of the geological model of the PK1 formation, providing the best adaptation to the history of development and minimal uncertainty in the prediction of technological parameters for the medium and long term. Implementations of the model include variations of the seismic base, distribution of the lithology parameter, filtration-capacitance properties of non-collectors, the volume of the aquifer and its activity. In the process of work at the first stage, the basic implementation of the geological model was created, at the second stage of them on the basis of the developed complex parameter characterizing the degree of adaptation of the hydrodynamic model, the most probable was chosen.
Geomechanical Considerations when Planning SAGD Wells, a Case Study from Cuba
Authors: Chettykbayeva Kamilla , Ibragimova Margarita , Osipov Andrey , Petrakov Yuriy , Sobolev Alexey , Tatur Olga 
Published: October 2019

Abstract
This article is the first part of the geomechanical calculations performed in order to optimize the drilling and production operations of the first horizontal wells with target formation M in the Boca de Jaruco field, Republic of Cuba. Here, the analyzed data included regional geology, tectonics and stratigraphy, different types of well logging, the pressure curves while steam operations, core samples and drilling history. The outcome of this part of the work is the assessment of the current stress regime, stress directions and the stability windows for the planned wells. Moreover, the program of additional studies and logs acquisition was elaborated, as at this stage there is not enough data to confidently quantify the stress state, the core samples are not yet tested for rock's deformation and strength properties, and it is hardly possible to find carbonate bitumen deposits under development anywhere in the world which are analogous to the Boca de Jaruco field (with the sole exception of Grosmont in Northern Alberta, Canada).
After the wells are drilled (presumably by the end of 2019) and the required information is collected (such as mechanical core testing under elevated temperatures, image logs in the deviated boreholes, etc.), the second part of the work is to be performed, which would include the analysis of the drilling results and the assessment of the cap rock behavior, pore pressure and porosity-permeability changes due to steam injection.
Experience of Gas Wells Development in Complex Carbonate Reservoirs in Different Stages of Development
Authors: Volkov Vladimir , Turapin Alexey , Ermilov Andrey , Vasyutkin Stanislav , Fomin Denis , Sorokina Anastasia 
Published: October 2019

Summary
This paper describes practical experience of perforating of producing horizons under conditions that are incompatible for perforating for geological reasons, as well as methods of killing and developing wells with ALRP.
Practical Application of High-Resolution Reservoir Simulation and High-Performance Computing for Accurate Modeling of Low Permeability Gas Condensate Reservoirs Production
Authors: Sharafutdinov Ruslan , Tyurin Victor , Fateev Dmitry , Skvortsov Sergey , Dolgikh Yuriy , Tokarev Denis , Shakhov Dmitry , Voznyuk Alexander , Pyatkevich Larisa , Kovaleva Elena 
Published: October 2019

Abstract
One of the main aspects that is worth paying attention to when planning the development of gas-condensate (GC) fields is accounting for and reproducing gas-liquid phase transitions that affect the flow of hydrocarbons (HC) in the reservoir as well as gas and condensate production indicators during the entire life cycle of the field. Undoubtedly, this effect will be more significant for cases with a complex gas component composition, high condensate content, as well as under conditions of low reservoir formation permeability and a high degree of areal and vertical heterogeneity. Compositional hydrodynamic modeling is a comprehensive tool for assessing hydrocarbon production capabilities, taking into account the phase behavior for GC field. The purpose of this work is to compare the various methods of improving the accuracy of numerical simulations and the reliability of the hydrodynamic modeling results for this type of reservoirs.
Using a high-resolution hydrodynamic simulator and a high-performance cluster system, multivariate simulations were performed to evaluate the effect of various parameters and options on the results of numerical simulations. The simulations were carried out using a compositional model, which is an analogue of a gas-condensate fields in Western Siberia within Yamalo-Nenetsky Autonomous Okrug (YNAO), based on geology, PVT and core, production history and well test data for vertical and subhorizontal wells, accounting for the presence of hydraulic fracturing. The work started with a detailed study of the challenge while the GC systems modeling on local sectors with further transition to a larger scale models using the results obtained on the previous step, taking into account their cross-validation.
Based on the results of the work, several important decisions (observations) were made, allowing determining the potential limits and the technical capability of modeling the GC systems with the required accuracy of phase transitions. In addition, the degree of influence if the numerical grid resolution and detalization of the PVT model (up to 50 components inclusive) on the gas and oil production and the pressure behavior was estimated. The simulation run time with various numerical schemes were also considered as factors affecting the simulation results on the sector and full-scale models. The analysis carried out and the results obtained can be further used by engineers dealing with GC field development as a guideline for choosing the modeling method depending on the complexity of the task and available computational resources.
Completion Technologies Evolution of Yuri Korchagina Wells and Operation Experience of the Intelligent Wells
Authors: Byakov Aleksandr , Eliseev Denis , Senkov Aleksandr , Shafikov Rustem , Mavrin Aleksandr , Lesnoy Aleksandr , Sibilev Mikhail , Bulygin Igor 
Published: October 2019

Abstract
The Yuri Korchagin field is the first of the fields introduced by LUKOIL in the Northern part of the Caspian Sea. The main object of development – Neocom-Volzhskaya Deposit is represented by a thin oil rim, with the underlying bottom water over the entire area of the Deposit with a massive gas cap.
Given the elongated configuration of the deposits and dimensions of the Eastern and Western parts, for drilling and production of hydrocarbons in the square fields placed one offshore ice-resistant fixed platform (OIFP) in the Western sector and the block-the conductor (BC) on the Eastern section.
In order to ensure the effective development of oil rims of the im field. Yu. Korchagina and reduction of geological risks associated with the lack of detailed information on the geological structure of the layers in the locations of producing wells, the adopted system of field development by horizontal wells of large extent. In total, more than two dozen production wells with the length of horizontal wells from 450 to 4900 meters have been drilled at the field.
In the conditions of the shelf field. Yu. Korchagina the most important aspect in the production of hydrocarbons is to ensure a constant and uniform flow of fluid to the horizontal barrel. The basis for this is to maintain equal depression at all points of the horizontal section and reduce the risks of gas and water breakthrough. This paper describes the evolution of the completion strategy of horizontal wells of extreme length, reveals the main characteristics of the completion systems used, the results of their operation.
Mobile Wellsite Compressors: New Lease on Life for Mature Gas Field
Authors: Sayfullin Ilnur , Vasyutkin Stanislav , Ermilov Andrey 
Published: October 2019

Abstract
These days more and more gas and gas condensate fields are reaching the late stage of development, which characterized with an increasing amount of challenges impeding recovery of reserves. In order to solve the problems, oil and gas companies employ different solutions which have certain conditions of practical application and different efficiency. Gas distributed compression solutions based on mobile wellsite compressors can be considered as one of the most modern and efficient solution. This technology has already established an excellent reputation in CIS countries and overseas by demonstrating the high result of implementation. However, in order to decide whether to implement this technology or not, it is required to elaborate a good feasibility study. The low level of the elaboration can easily overestimate the efficiency of the project as well as underestimate it thereby ensuing refusal of potentially efficient project. Since each project of technology implementation is unique it is not enough just utilize a common approach of project implementation to prepare an excellent feasibility study. Currently, it is quite difficult to find a methodology to prepare a decent feasibility study for mobile wellsite compressor implementation. The author while working on mobile wellsite compressor project has obtained solid experience which is reflected in this paper. Based on a dozen of integrated asset modeling simulations system of criteria for candidate selection for wellsite compressor installation was elaborated. In order to improve the efficiency and flexibility of the wellsite compressor operation an optimized approach to well hookup was advised. With the intention of improving the economic efficiency of mobile wellsite implementation set of recommendations was provided. The paper can be used as a basis for creating a solid feasibility study for wellsite compressor implementation. Recommendations provided in the article will enable not only improve the feasibility study but also minimize time and computational power allocated on the project.
Well Spacing Verification At Gas Condensate Field Using Deconvolution Driven Long-Term Pressure and Rate Analysis
Authors: Aibazarov Muratbek , Kaliyev Bakytzhan , Mutaliyev Galymzhan , Vignati Emanuele , Gulyaev Danila , Krichevsky Vladimir , Buyanov Anton 
Published: October 2019

Abstract
Well spacing optimization is very important at the stage of drilling the reservoir. It is critical for the whole project economics. After the reservoir is already drilled it is very important to understand does existing wells drain all the reserves of infill drilling requires to improve recovery. Such task was solved on a tested area - Western part of Karachaganak gas condensate field. It has a complex geology, built as a massive heterogeneous carbonate reef of a Carboniferous age. PVT properties of the reservoir fluid significantly varies with depth. The area is produced with horizontal wells to maximize contact with the reservoir.
The Multi-well Retrospective Testing (MRT) on base of multi-well deconvolution of historical rate and bottom-hole revealed well drainage area and well interference (1 – Aslanyan, 2018; 2 – Aslanyan 2017, 3 – Aslanyan 2019). The MRT study is showing a strong pressure depletion trend and a fair connection between wells in the certain areas like core of western build up.
Rapid Rock Nanoporosity Analysis Using Small Angle Scattering Fused with Imaging Data Based on Stochastic Reconstructions
Authors: Karsanina Marina V. , Volkov Vladimir V. , Konarev Petr V. , Belokhin Vasily S. , Bayuk Irina O. , Korost Dmitry V. , Gerke Kirill M. 
Published: October 2019

Abstract
Through recent decade pore-scale modelling techniques matured enough to establish their robustness for relatively simple porous rocks, in particular porous media with a narrow pore-size distribution within the resolution window of the X-ray microtomography devices. But modelling of flow properties for rocks with significant amount of nano-scale porosity requires additional multi-scale structure studies. Current imaging techniques are too limited or time-consuming to cover necessary volumes of porous media. Thus, we are in search of a fast, yet robust methodology to assess nan-scale pore structure which can be used to inform pore-scale models and improve the accuracy of flow and transport predictions. In this work we report some preliminary results on the usage of the small angle scattering techniques to access the nano-scale structural properties for two complex rocks: chalk and Bazhenov formation siliceous rock (shale). The pore-size interpretation of X-ray small angle scattering results is compared against mercury porosimetry results and scanning electron microscopy. We argue that obtained results show qualitative agreement which provides an alley for future technology to combine small angle scattering with stochastic reconstructions. To further elucidate the power of such approach we perform 3D stochastic reconstructions based on 2D SEM images and simulate apparent gas permeability using pore-network model accounting for slip and (Knudsen) diffusion effects. Compared to laboratory measurements of gas permeability our results show surprisingly good agreement. We discuss obtained results and future developments of such a novel technology.
Uncertainty of Structural Interpretation in Conditions of Lateral Variability in Middle East Oilfield
Authors: Baykov Ruslan , Butorin Alexander , Groman Konstantin 
Published: October 2019

Abstract
This study focused on developing a technique of structural framework building and uncertainty estimation of one of the Middle East oilfields. The investigated region is characterized by complex geological setting due to compound basin evolution through geological time. In these conditions high velocity variations are present in the subsurface, however the main issue of the given paper is another significant factor – change of stratigraphic patterns in the cross-section, which affects the interferential seismic response and may have a significant impact on the seismic interpretation.
The paper considers an approach to uncertainty assessment of the kinematic seismic interpretation of a complex geological section by the example of one of the Middle East fields located in the fold and thrust belt of Western Zagros.
4D TEM Surveys for Waterflood Monitoring in a Carbonate Reservoir
Authors: Sibilev Vyacheslav , Tokareva Olga , Kolesov Vladimir , Burdakov Dmitry 
Published: October 2019

Abstract
Complex geology, post-depositional alteration, and physicochemical features of sediments and pore fluids often pose problems to reservoir development planning. Meanwhile, lapse-time (4D) shallow resistivity surveys may be a good tool to monitor waterflooding used for formation pressure maintaining and oil recovery enhancement in highly resistive carbonate reservoirs. Testing at an area developed by the Irkutsk Oil Company, with regard to key sweep efficiency criteria, has demonstrated good fit of injection volumes inferred from TEM data to real values. These results have been obtained for the first time for a carbonate reservoir in East Siberia and are useful to enhance petroleum production in the region.
Methodological Features and Case Studies of the Seismic Data Usage on the Stage of Field Development
Authors: Kozyaev Andrey , Kurash Tatyana , Onuchin Sergey 
Published: October 2019

Abstract
Seismic data implementation on the exploration/appraisal stage and field development stage has a significant list of differences, due to varied amount and type of geophysical information available, along with different objectives of the surveys. This paper provides an integrated range of various existing methodological approaches to 3D seismic data usage at the field development stage. Along with recommendations suggested for the seismic survey on each stage, methodological features described and typical mistakes evaluated. To represent a practical side of the survey three case studies of oil fields with different geology provided. Two of the fields are in terrigenous reservoir and located in Western Siberia and one oil field with carbonate reservoir of Proterozoic age is located in Eastern Siberia.
Petroleum Potential of the North-Western Part of the Khanty-Mansiysk Autonomous Region KhMAO on the Basis of Petroleum System Development History Reconstruction
Authors: Bogdanov Oleg , Shuvaev Artem , Abraeva Takhmina , Sabirianova Regina 
Published: October 2019

Abstract
The depletion of traditional row hydrocarbons sources throughout Western Siberia forces new territories development. In such conditions the north–western part of the Khanty–Mansiysk Autonomous Area (KhMAA) characterized by relatively low licensing density may be assessed as one of the prospective region to increase the raw material base. The purpose of this paper is the hydrocarbon potential determination in the north–western part of the Khanty–Mansiysk Autonomous Area within the East–Ural Potential oil and gas area by the basin modeling method based on paleotectonic reconstructions results.
3D basin modeling of the western part of the KhMAA allowed identifying thr main source rocks of hydrocarbons in this area. The maximum mass generation of hydrocarbon was revealed within the boundaries of Frolov Megadepression. Therefore, the generation of hydrocarbon deposits only became possible due to oil and gas source rocks distributed across the Lyapin downwarp, Visim megaswell and Berezov monocline.
According to the basin modeling results, the oil and gas source rocks identified within the Visim megaswell failed to reach hydrocarbon generation windows. A more subsided position of Lyapin downwarp and Berezov monocline expects the presence of the source rocks of hydrocarbons here, especially when they identified here with MK–MK3 and MK1–MK2 catagenesis gradations. Nonetheless, the organic matter maturation is in the interval of 0–5%, which does not allow us to expect large amounts of generated hydrocarbons here.
Therefore, the sedimentary cover of the East–Ural Potential oil and gas area, within the boundaries of north–western part of the KhMAA is characterized by extremely low generation potential. The presence of large petroleum hydrocarbon accumulations there is highly improbable. The Visim megaswell is a potential to discover small (in terms of reserves) gas and gas–condensate fields there. Such fields will have the common source of hydrocarbons with the deposits of the Berezov monocline.
Basin modeling using increases efficiency and reduces the cost of exploration. Determining the stages of formation and destruction of hydrocarbon traps as well as comparing its with the results of modeling, allowes to assesment the prospects of the territories for the presence of large hydrocarbon deposits.