bluuebunny/crossref_metadata_2025_split huggingface dataset:
Full Integrated Model as a Tool for Strategy Evaluation of the Greenfield
Authors: Platon Denis Nikolaevich , Gatin Aidar Ramilovich , Fomin Matvei Nikolaevich , Korostelev Nikita Sergeevich 
Published: October 2021

Abstract
The main goal of this work is to evaluate and select the best strategy for the development of the field in the first stage of development. To solve this problem, a full-scale integrated model was created that takes into account the physics of the reservoir, wells and surface infrastructure, as well as their mutual influence. The integrated model was calculated for the full development of the asset.
The integrated model of the A. Zhagrin field is based on three simulation models, well models and surface infrastructure, which are linked through an integrator program. All constituent parts of the model are configured to accurately reproduce their actual operation.
Greenfield is characterized as active drilling, so the planned well count is modeled by replacing wells with "typical" well models, which are selected by taking into account the expected input flow rate, well design, well completion and well trajectory. Fields of the first stage of development are characterized by limitations related to oil transportation and treatment. These constraints are also specified and taken into account in the model
The concept of surface infrastructure is formed depending on the potential production capabilities of the reservoir and has considerable variability.
The total number of actual and planned wells in the field is more than 1,300, including more than 700 production wells and about 600 injection wells. All wells are ESP lifted.
Considering infrastructure capacity constraints and requirements for optimal pipeline utilization, the use of different numbers of drilling rigs directly affecting the utilization of oil treatment and delivery facilities was evaluated.
29 main variations of the field development strategy until 2060 were formed and calculated, based on the integrated model. The main parameters of variation were the capacity of preparation facilities, the degree of oil separation, the scheme of product transportation, gas utilization capabilities, drilling rigs and subsurface equipment. All scenarios in the integrated model took into account constraints - on target bottomhole, wellhead and line pressures, in order to operate real facilities in accident-free mode.
In the course of calculations, an optimal scenario was selected, which made it possible to increase oil production in 2021 by optimizing the transportation of produced products to the treatment facilities. This scenario formed the basis of the asset development strategy.
Experience of Surfactant-Polymer Flooding Simulation on a Sandstone Reservoir
Authors: Kudryashov Alexey , Karseka Kiryl , Mityurich Denis , Lompik Vasilii , Cheremisin Alexander , Spivakova Margarita 
Published: October 2021

Abstract
The aim of the work is to create representative 1D- and 3D-models of surfactant-polymer flooding, considering the most significant physical and chemical phenomena that occur during this process, and further efficiency evaluation of the method. The paper describes approaches to reproduce and verify laboratory experiments results of recovery factor increase during surfactant-polymer flooding on core samples using 1D-model, as well as approaches to optimize the compositions and injection schemes of chemicals during the efficiency evaluation of the technology on a 3D-model of the pilot site.
A Critical Review of Capacitance-Resistance Models
Authors: Alghamdi Ahmed , Hiba Moaz , Aly Moustafa , Awotunde Abeeb 
Published: October 2021

Abstract
A Capacitance Resistance Model (CRM) is an analytical model that only requires production and injection rates to predict reservoir performance. The CRM input is the injection rates and the output is the production rate. The input and output are related by the CRM parameters. The first parameter is the time delay (also called time constant) and is a function of pore volume, total compressibility, and productivity indices. The second parameter is the connectivity (also called gain, or weight), which quantifies the connectivity between producers and injectors (i.e. how much of the input is supporting the output).
The CRM was developed for fields with minimum reservoir data, or for small fields not requiring a full reservoir simulation model, which can be time-consuming and expensive. The CRM is a quick, powerful analytical tool that is simple to use and requires readily available data. Most of the time, the injection and production rates are measured accurately and frequently, either weekly or bi-weekly. By solving the continuity equation for a homogenous reservoir (i.e. constant reservoir and fluid properties throughout the reservoir) the solution of the continuity equation can be indicative of the injection and production relation and therefore can be used to optimize injection schemes for higher ultimate hydrocarbon recovery. It is important to recognize that the CRM is not supposed to replace numerical reservoir simulators, which, in essence, are the most accurate means of reservoir performance prediction. Instead, the CRM aims to be a quick and easy way to infer reservoir performance in the absence of full-fledged simulation.
The CRM has been used for several purposes as seen in the literature. First, as a tool to optimize waterflooding in oil reservoirs. The CRM can infer inter-well connectivity which will allow the engineer to adjust water injection rates to ensure uniform sweep in the reservoir and reduce the chance of early water breakthrough. The CRM was also used to optimize CO2 sequestration, whereby CO¬2 is captured from the atmosphere and stored in subsurface formations.
The main hypothesis in CRM is that the characteristics of the reservoir can be inferred from analyzing production and injection data only. CRM does not require core data, logs, seismic, or any rock or fluids properties. This hypothesis can be challenged easily since most reservoirs have gradients of fluid properties, multi-porosity systems, and heterogeneous formations with different wettability presences. Albeit, several publications have shown that CRM can result in high certainty output.
The objective of this report is to explain the concept of the CRM, conduct a critical review of the main CRM publications, compare CRM to other reservoir characterization tools and finally demonstrate some applications of the CRM.
Metrology and Standardization in Geomechanical Modeling - A Quantitative Assessment of Uncertainty Window Based on Calibration Data
Authors: Tatur Olga , Petrakov Yuri , Sobolev Alexey 
Published: October 2021

Abstract
Geomechanical modeling is an integral part of the oil and gas industry and is used in all life cycles of the field - monitoring and improving the efficiency of well construction, choosing a completion system, modeling hydraulic fracturing processes, modeling development processes taking into account changes in the stress state of the reservoir, taking into account the fault, salt tectonics, control over the development of the reservoir, control of subsidence of the earth's surface. The success of geomechanical modeling directly depends on the quantity and quality of input data. In contrast to the geological and hydrodynamic models, in geomechanics there is still no unified approach and algorithm for quantifying the model error. The quality of the geomechanical model is defined as "satisfactory" / "not satisfactory" and "confirmed by actual data" / "not confirmed by actual data". In a series of articles on "Metrological support of a geomechanical model", the authors show an algorithm for a quantitative assessment of the error of a geomechanical model. The proposed algorithm takes into account the measurement error (in the well and in the laboratory), the quality of logging data, direct measurements or reconstructed measurements, the tightness of correlations (both for the results of core studies and for the reconstruction of missing logging data), the calculation of the uncertainty taking into account the calibration information.
This paper describes a generalized algorithm for quantifying the error of a geomechanical model, presented in previous articles, and provides a method for quantifying calculate the uncertainty, taking into account calibration information, such as measurements of horizontal stresses, core studies in laboratory conditions.
Recovery of Lithium from Associated Water of Oil and Gas Deposits
Authors: Gavrilov Anton Yurievich , Bandaletova Alexandra Alexandrovna , Devleshova Natalia Alekseevna , Galin Evgeny Vladimirovich , Pisarev Mikhail Olegovich , Liss Dmitry Alexandrovich 
Published: October 2021

Abstract
Current production conditions and development of oil fields are complicated by the development of increasingly difficult-to-recover reserves as well as by the consequences of 2020, which include a change in the structure of demand and a collapse of the oil market, the global trend towards low-carb fuel systems and the implementation of the principles of environmental, social and managerial responsibility (ESG).
This research paper is focused on diversification of the oil and gas business by extracting lithium from reservoir waters of oil and gas condensate fields. This method allows to increase the profitability of deposits. The paper also carries out a technical and economic assessment of the process of the sorption lithium extraction from the formation waters of oil fields.
The Productivity of Horizontal Wells in an In-Line Development System in Fields with Oil Rims
Authors: Samolovov Dmitriy Alekseevich , Varavva Artem Igorevich , Polyakov Vitalij Olegovich , Sandalova Ekaterina Evgenevna 
Published: October 2021

Abstract
The study proposes an analytical method for calculating the productivity of horizontal wells in a line-drive development pattern in fields with oil rims. The paper presents an analysis of existing techniques and compares them with the results of detailed numerical experiments. It also shows the limited applicability of existing techniques. On the basis of the obtained solution of a single-phase flow equation for a line-drive pattern of horizontal wells, an analytical formula was obtained which more accurately describes the productivity of wells beyond the limits of applicability of existing methods. The resulting formula is in good agreement with the results of a detailed numerical experiment.
Prediction of Dynamical Changes Hydrogen Sulfide Concentration During South-West Gissar Gas-Condensate Fields Development
Authors: Descubes Elena , Yessalina Svetlana , Kuvanyshev Amir , Zhelezova Anna , Shaikhina Dana , Chertenkov Mikhail Vasilyevich , Barannikov Andrey Valeryevich 
Published: October 2021

Abstract
An unexpected raise of hydrogen sulfide levels during development of several gas condensate fields in Southwestern Gissar, producing from naturally fractured carbonate reservoirs, observed within a year, lead to necessity of full scale comprehensive investigation. For planning of effective mitigation strategy important questions related to the reasons of hydrogen sulfide level growth and prediction of its further behavior have been addressed in the present study.
The entire investigation process encompassed both theoretical and practical parts. Theoretical part covered evaluation of sour gas sources that was crucial in respect to selection of conceptual methodology for predictions. All possible contributing sources including primary and secondary have been investigated to discern the causes and consequences of hydrogen sulfide occurrence. Practical component of the study employed cut to edge technologies tested and implemented in reservoir simulation.
Based on conceptual constraints with the use of existing field data, interpretation results and regional knowledge basin and 3D static models with fracture network have been developed. Obtained modeling results have been integrated into compositional model, allowing to predict with applied uncertainty analyses further H2S content change during field development.
Study of Reservoir Properties of Turonian Formation Using Digital Core Analysis
Authors: Yakimchuk Ivan , Korobkov Dmitry , Pletneva Vera , Ridzel Olga , Varfolomeev Igor , Reimers Iryna , Safonov Ilia , Evseev Nikolay , Dinariev Oleg , Denisenko Aleksandr , Samokhvalov Andrey , Khan Vladimir , Kusov Anton , Tyurin Evgeny , Korolev Aleksandr , Sitdikov Rustam , Maksimov Evgeny , Loznyuk Oleg 
Published: October 2021

Abstract
The work demonstrates results of reservoir properties evaluation using a complex of laboratory and multiscale digital core or digital rock analysis. Rock properties (including relative phase permeabilities) were studied at different scales: from nanometers to meter (whole core).
For the first time, cores from Turonian formation were characterized with digital rock analysis, which provided stationary relative permeabilities for gas-water under reservoir conditions. Lab determination of relative permeabilities was rather challenging for some low-permeability samples (&lt;0.02 md), while digital analysis was successful even for them. Gas recovery in a depletion mode from different rock types was studied on a whole core model for different capillary pressures. Such studies are not conducted in the lab.
Digital Rock Extension of Laboratory Core Test Results for Acid Treatment Optimization
Authors: Ivanov Evgeny , Korobkov Dmitry , Sidorenkov Alexander , Varfolomeev Igor , Stukan Mikhail 
Published: October 2021

Abstract
Nowadays acidizing became one of the most common approaches used to increase the hydrocarbons production from carbonate reservoirs. An acid solution injected under pressures below the formation fracture pressures dissolves the rock matrix and, thus, facilitates the fluid flow.
However, the overall treatment efficiency is crucially dependent on the acid composition and injection scenario, since the different dissolution patterns are created depending on the effective reaction rate (i.e. acid composition and matrix mineralogy) of the reactive fluid and the fluid injection rate. At slow injection rates, when the acid is spent before penetrating deep into the rock, the face dissolution scenario is observed. On the other hand, fast injection results in uniform distribution of the acid along the treatment zone and similar uniform dissolution of the matrix. The best result from production improvement point of view is achieved when the acid creates a set of thin channels - the so-called wormholes. This optimum regime corresponds to the minimum in the pore volume to breakthrough (PVBT) dependence on injection rate (Fredd, 1998; Zhang, 2021). Where PVBT is defined as the amount of treatment fluid (measured in core pore volumes) required to be injected before the appearance of macroscopic flow channel linking the opposite faces of the core. Thus, since the optimal acid composition and the injection rate are determined by geology and lithology of the reservoir, to achieve the best effect, each treatment should be preceded by experiments on representative rock samples.
In addition to that, the parameters to be optimized for a typical acidizing job also include the sequence of injected fluids and the amount of the fluid to be injected (Yudin A., 2021), which requires an extensive laboratory study. Unfortunately, the amount of the core material available is usually not sufficient for such a comprehensive laboratory analysis. Moreover, the destructive nature of acidizing experiments imposes the fundamental limitation: experiments are performed on different core samples, which makes the results less conclusive.
Application of the Results of Chromatic Technology Data Interpretation in Seismogeological Modeling of Continental Deposits of Western Siberia on the Example of the Zapadno-Ust-Balykskoe Field
Authors: Igitov Semen Mikhailovich , Esipenok Ivan Nikolaevich , Ishkinov Azat Mavlutovich , Vanina Anastasiia Sergeevna , Olkhovsky Konstantin Gennadievich , Romanov Denis Vladimirovich , Lyubimov Sergey Anatolyevich , Goncharova Natalia Alexandrovna , Krikunova Valeriya Sergeevna 
Published: October 2021

Abstract
The aim of the article is creation a conceptual model based on the data of chromatic technology data interpretation to improve the quality of forecasting potentially productive areas of occurrence of Jurassic formations of the Tyumen formation, as well as ranking the deposit by priority zones based on multifactor analysis. The article uses methods of complex reinterpretation of seismic and geological-geophysical materials in order to search for and localize highly productive zones of the Tyumen formation formations. The result of the work is a detailed strategy formed: the exploration and production drilling of the J2 formation. A significant increase in the expected ability of potentially productive objects in the inter-well space in the conditions of complex reservoirs due to modern processing technologies and interpretation was noted. The prospects of translating the methodology for optimizing the development of Jurassic objects of the Tyumen Fm at the fields of Slavneft-Megionneftegaz and other assets of Russian oil producing companies are revealed.
Managing Gas Well Blowouts: Case Studies from Assam-Arakan & Krishna-Godavari Basin
Authors: Bharadwaj Rishabh , Kumari Bhavya , Patel Astha 
Published: October 2021

Abstract
E&P activities are the early stage of energy production and pivotal for generating and sustaining economic growth. However, negligence and evaluating the circumstances incorrectly during these operations can lead to calamities like blowouts. This paper discusses two such tragedies, the Pasarlapudi (Krishna-Godavari) Gas Well Blowout of 1995 & Baghjan (Assam-Arakan) Oil Field Blowout of 2020, and provides possible well control measures and lessons learned.
Pasarlapudi blowout incident occurred during the drilling operations. The pipe stuck-up situation at 2727m MD (Measured Depth) was detected by conducting a stretch test. Further analysis could include circulating brine, checking lost circulation and identifying casing leaks by measuring Sustained Casing Pressure (SCP), Operator-imposed Pressure (OIP), and Thermal-induced Pressure (TIP). Baghjan's gas well at the depth 3870m was producing at 2.8-3.5 MMSCFD. The aim was to plug the lower producing zone and recomplete the well in the upper Lakadong+Therria sand zone. Well was killed using brine, cement plug was placed and BOP installed. BOP was removed after the plug was set to begin the process of moving the workover rig. Well blew gas profusely during this process.
Simulating a blowout and facing one, are two completely different situations. In Pasarlapudi's case, the well blew with an enormous gas pressure of 281.2 ± 0.5 kg/cm2. While drilling the production hole (8.5 inch), either differential pressure sticking, presence of water-swelling clay formation or the partial collapse of wellbore formation caused the pipe stuck-up situation. By conducting stretch test along with circulating brine, root cause of this problem could be identified. If differential sticking occurred, lost circulation could be checked & cured, while keeping the hole full. Circulating brine should solve the problem of swelling clay formation while formation collapse could have occurred due to the presence of plastic formation like salt domes.
In the case of Baghjan gas well blowout during workover operations, probable safety measures could include placement of 2 or 3 backup cement plugs along with kill fluid or going for squeeze cementing before placing the cement plug & kill fluid while abandoning the lower producing zone. Attempts were made to bring the well under control by adequate water spraying, installing BOP. Water was pumped through the casing valve and a water reservoir was dug near the well plinth for the placement of pumps of 2500 gallon capacity.
Proper safety measures should be used even when they're not the cheapest to avoid repetition of treatments and detrimental situations. SCP, OIP and TIP should be measured periodically whenever possible and the root cause of situations like lost circulation, pipe stuck-ups, kicks, casing leaks should be identified before proceeding towards drastic remedial operations. Innovations in countering well-control situations should be promoted invariably.
Technology for Monitoring Gas and Water Breakthrough Intervals using Chromate Desorption Systems in the Development of Fields in the Caspian Sea
Authors: Shtun Sergey , Senkov Alexsandr , Abramenko Oleg , Nikishin Igor , Efimov Evgeny , Minakhmetov Radik , Platonov Igor , Nukhaev Marat , Kabanov Vasilii 
Published: October 2021

Abstract
The paper presents a novel technology for determining the intervals of gas and water breakthrough in the development of fields on the Russian shelf of the Caspian Sea. The proposed technology is similar to traditional production logging and monitoring of horizontal wells using fiber optic systems.
The technology aimed at determining the phase components is based on chromate desorption systems (CDS) with individual selective analytes used. CDS are installed on the lower well completion equipment (sand filters, inflow control devices, multistage hydraulic fracturing equipment and so on) and have a unique combination of pairs of oil-, water- and gas-soluble analytes for each interval. From the CDS, an analyte begins to release when in contact with a target fluid to surface with this fluid. At the wellhead, samples are taken according to a specific program, then laboratory analysis by chromatographic methods and mathematical interpretation of the composition of the inflow are performed. The paper presents an example of work when the intervals of gas outs were determined directly in the field using a micro-chromatograph.
Workflow of Petrophysical Analysis Performed at Mine in Karaganda Coal Basin
Authors: Bektybayeva Makpal , Mendybaev Nurhat , Bigeldiyev Asfandiyar , Basu Subhro , Abetov Auez , Temirkhassov Aidos , Tyulebayeva Ranida , Yermukhanbet Aiyazhan 
Published: October 2021

Abstract
For accurate coal bed methane (CBM) reserves estimation, it is necessary to evaluate reservoir characteristics. We present a workflow for formation evaluation of coalbed-methane wells, by interpretation of a limited number of legacy logs, including data preprocessing, lithology identification, proximate analysis and estimation of gas content of coal beds.
This workflow allowed the estimation of ash content from the available logs, including selective log (analogue of photoelectric absorption), which was recorded only on the territory of the former Soviet Union and never used for such calculations before. Even though the logs were recorded by old tools with low vertical resolution, we were able to identify heterogeneity of coal seams, using the principle of core ash content distribution. Integrated analysis of old core data and recent laboratory measurements of samples from coal pillars allowed to calculate proximate properties of the coal, which showed good match with observed data and could be considered as input parameters for property distribution in the geological model.
Also, it is worth to mention that an advanced plug-in was deployed to perform calculation of proximate properties and gas content for all available options and to significantly reduce time for screening different algorithms and rapidly analyzing results.