bluuebunny/crossref_metadata_2025_split huggingface dataset:
Modern Solution for Oil Well Multiphase Flows Water Cut Metering
Authors: Sottsau Aliaksei , Akbashev Ramir , Peratsiahin Alexandr , Garnaev Vadim 
Published: October 2021

Abstract
An innovative technology for determining the water cut in well products (without preliminary separation into liquid and gas fractions) uses the results of electrical impedance measurements and its dependence on the alternating current frequency. Water cut meter's sensor includes measuring and current electrodes, between which there is a well's multiphase flow. Imaginary and real components of the impedance quantitatively describe the component composition of the studied oil and gas-water mixtures. In this process, machine learning methods and developed algorithms for features extraction are used. Depending on the type of emulsion, two independent sensors are used in the oil pipeline, one of which measures in a direct emulsion, the other in an inverse emulsion.
Tests of the described water cut meter on flow loops in the Russian Federation and in the Netherlands, as well as studies of well flows in oil production facilities in the Russian Federation and the Kingdom of Saudi Arabia, have shown high measurement accuracy in the full range of water cut, with high gas content, as well as at high salinity and in a wide range of flow rates. To do so, modern methods of data classification based on neural networks and regression modeling implemented using machine learning are employed. It was found that the flow rates of liquid and gas do not affect the results of measuring the water cut due to the high frequency of the impedance measurements - up to 100 thousand measurements per second. Use of in-line multiphase water cut meter makes it possible to apply intelligent methods of processing field information and accumulate statistical data for each well, as a big data element for predicting and modeling in-situ processes. It will also allow to introduce promising production processes aimed at increasing oil production and monitoring the baseline indicators of the well.
Novelty of the presented technology:
Solution of the problem of high-speed determination of water cut in a multiphase flow without preliminary separation using impedance metering. Creation of mathematical models of multiphase flow and methods for determining the type of flow and the type of emulsion. Machine learning methods and neural networks employment for high-speed analysis of flow changes. Development, successful testing and implementation of an affordable multiphase water cut meter of our own design, which has no analogs in industrial applications.
The Local Corrosion Rate Determination According to Weight Measurements Corrosion Coupons in Oilfield Conditions
Authors: Tkacheva Valeriya Eduardovna , Markin Andrey Nicolaevich , Markin Ignaty Andreevich , Presnyakov Alexandr Yuryevich 
Published: October 2021

Abstract
Complications associated with a corrosive environment, according to Rosneft's data as of 01.01.2020, are among the prevailing at oil and gas production facilities and rank fourth among other factors complicating production - 12% the complicated mechanized wells. Failures due to corrosion are the second largest complicating factors. Based on the results of approbation, the article proposes a method for calculating the maximum rate of local carbon dioxide corrosion, applicable in oilfield conditions, including to complicated stocks of oil wells and pipelines of oil gathering systems. Based on the approbation results, a method for calculating the maximum rate of local carbon dioxide corrosion, applicable in oilfield conditions, including to complicated stocks of oil wells and oil gathering pipelines systems is proposed in the article. The proposed technique is realizable according to the results one of "traditional" methods the corrosion monitoring - weight (or gravimetric). The approbation results and application possibility the technique in the pilot tests process in assessing the protective ability of corrosion inhibitors and the selection the effective dosages in relation to local damages, which are the main cause the oilfield equipment failures according the factor "Corrosive aggressiveness" (one of the complicating factors in terms of gradation, adopted in the Rosneft Company regulations). On practical examples the oilfield equipment operation, the results of corrosion monitoring and the summary statistics the corrosive stock of wells (using the example of an oil Company), the current situation with respect to this type of complication and relevance the issue under consideration is shown.
Selection and Justification of Technologies for Enhanced Oil Recovery Methods Using Inter-Well Tracer Survey
Authors: Galimzyanov Artem , Naydensky Konstantin , Huseby Olaf Kristoffer 
Published: October 2021

Abstract
Justified application of enhanced oil recovery (EOR) methods is one of the key tasks of oil operating companies for the effective development of not only brown oil fields at a mature stage of production, but also for green fields. The selection and justification of one or another method of enhanced oil recovery for certain geological conditions often requires not only looking for worldwide experience, conducting laboratory tests on a core, but also performing pilot tests at a polygon area. The subsequent full-field implementation of EOR method requires confirmation of its effectiveness based on the increase in oil recovery factor.
This article describes both the experience of using interwell tracer studies to substantiate the effectiveness of EOR technologies in pilot areas, and the experience of evaluating the effectiveness of EOR technologies with full-field implementation in various fields. The work carried out on the integrated use of tracer studies makes it possible to apply a scientific and engineering approach to the selection of an enhanced oil recovery method by assessing the sweep efficiency before and after the application of the EOR technology. Examples of the use of this integrated approach for different oil fields are given.
The presented technologies and experience of the work performed will significantly speed up the choice of the EOR technology for certain geological conditions and verify the effectiveness of the selected EOR method.
New Generation of Formation Testers – New Horizons: First Experience in Russia
Authors: Novikov Sergey Vasilevich , Charupa Mikhail Viktorovich , Dzhalatyan Yakov Eduardovich , Kuzmin Stanislav Sergeevich , Kaipov Yermek Talgatovich , Kazakevich Eduard Yurevich , Smetanin Yuri Nikolaevich , Kishauov Abilkassym Kalievich , Snokhin Alexey Alexandrovich , Ibragimov Oleg Raisovich 
Published: October 2021

Abstract
As the production of oil and gas in major regions has been declining, exploration efforts are shifting towards hard-to-reach understudied areas with lack of necessary infrastructure. In addition to that, hydrocarbon fields that are being explored today, typically have more complex geological structure than the ones discovered decades ago and are characterized by the presence of multiple reservoirs with individual fluid contacts. The abovementioned reasons cause significant increase in time required to test these reservoirs and estimate their production potential. Therefore, there is a real need for reliable technologies that would expedite the testing of such complex fields.
New wireline formation testing platform has an updated hardware architecture enabling to use it for both traditional formations testing applications as well as the development of new testing procedures deviating from conventional practices. This paper describes the novel testing approach implying the use of wireline formation tester (WFT) in conjunction with a surface multiphase flowmeter, which was implemented at one of the large gas fields located on the Gydan peninsula. A key feature of the new formation testing platform compared to its predecessors is its ability to pump an order of magnitude greater volumes of reservoir fluids, which allows to estimate permeability in the uninvaded zone of the reservoirs and their productivity. Combination of the wireline formation tester with the surface multiphase flowmeter enables measuring surface rates and capture surface samples of reservoir fluids thus making this type of testing comparable to traditional well testing.
At the beginning of the paper we provide a brief description of the acquired formation testing results with stress on key features of the new wireline formation testing platform. The rest of the paper is devoted to Deep Transient Testing (DTT), more specifically, to its design and planning, required hardware and description of results acquired during such tests. We also demonstrate an approach that can be used to estimate reservoir productivity based on the obtained data.
Water-and-Gas Shutoff Technologies in Horizontal Wells on North Komsomolskoe Field: Screening and Successful Trial
Authors: Nigmatullin Timur Eduardovich , Nikulin Vladislav Yurievich , Shaymardanov Airat Rafaelevich , Mukminov Rinat Rifkhatovich , Ivanov Alexandr Yurievich , Akhmadullin Marat Edgarovich , Soltanov Dzheykhun Kamaleddinogly 
Published: October 2021

Abstract
The article describes the choosing a water-and-gas shutoff technology in horizontal wells (HW) drilled in terrigenous reservoirs of the North Komsomolskoye field. The well completion system is characterized by the use of liners equipped with external liner packers and inflow control devices (ICD). To solve the problem, the world experience in the use the water-and-gas shutoff technologies in HW was studied. A matrix for choosing a technology with the use of technical means and combined effect was developed based on the type of isolated fluid, the type of reservoir and the method of well completion. The technology of installing a straddle system with cup packers and a blind inter-packer pipe in a horizontal wellbore was selected to increase the success of work on isolating the inflow of water and gas in difficult geological conditions of the North Komsomolskoye field. The technology was successfully tested: a producing well with almost 100% water cut was return to effective production. A similar straddle system, but with a perforated spacer pipe, was used for directional injection of sealants selected for the conditions of the North Komsomolskoye field into the water cut zone of the horizontal wellbore. The results of pilot field tests indicate that there is a prospect of using water-and-gas shutoff technologies to limit water and gas inflow at the North Komsomolskoye field.
Oil Production Enhancement by EOR Candidates Optimization
Authors: Pisarev Denis Yurievich , Sharipov Ildar Fanurovich , Aslanyan Artur Michailovich , Gulyaev Danila Nikolaevich , Nikonorova Anastasiya Nikolaevna 
Published: October 2021

The study field is located in the Nizhnevartovsk district of the Khanty-Mansi autonomous region. The deposit is located in the Nizhnevartovsk crest zone. The geological section of this deposit features a thick layer (2740-2870 meters) of Meso-Cenozoic era sedimentary rocks starting from the Jurassic period up to and including the Quaternary period, and rests unconformably on the surface of the deposits of the folded Paleozoic basement. The pay zones of study oil and gas fields features mainly sandstone-siltstone reservoirs.
The study formation XX11-2 features interleaved rocks with a high clay content. In the west and south-west of the field, the oil-saturated thicknesses vary on average from 5-10 m, and in the north, the thickness increases to 10-20 m.
This field has a long-lasting production history as a result of drilling vertical and horizontal wells but is currently at production decline stage. The existing reservoir pressure support system assumes that the water-cut trend at the wells will increase. In recent years, there has been advanced flooding in some areas, resulting in a drop in oil production, while the reasons for the advanced flooding are not always clear. This is often due to the progressing spontaneous fracturing in the injector wells (Aslanyan, Akimov et al., 2020).
Formation of a Methodology for Calculating the Optimal Number of Wells in the Development of Lenticular Formations to Achieve Maximum NPV
Authors: Rubailo Vadim Andreevich , Isakov Kirill Dmitrievich , Osipenko Alexey Stanislavovich , Akhmadiev Marcel Mansurovich 
Published: October 2021

Abstract
The work is devoted to the analytical methodology for the development of oil lenticular formations. The method is based on the theory of potentials for vertical and horizontal wells. The work takes into account the interference of wells, geological and petrophysical parameters of lenses, as well as the properties of the reservoir fluid, and a new equation for estimating the inflow to a horizontal well is derived. An assessment of the correctness of this work on the company's assets was made. The dependence for the express estimation of the number of wells depending on the economic parameters at the early stages of project development is obtained.
Challenging Water Channeling in Unconsolidated Heavy Oil Reservoirs: Risks and Management
Authors: Gudz Anton , Ilyasov Ilnur , Podkorytov Alexander , Tomashevskiy Maksim , Glushchenko Nikolai 
Published: October 2021

Abstract
The paper describes the basic features of the East-Messoyahskoe oil field that are important for efficient reservoir development, the key of which are high oil viscosity (111 cP), high heterogenieity and permeability contrast, and the presence of aquifer with a different strength.
The review of the experience in proactive breakthrough risks identification is presented. The actual breakthroughs during waterflooding of the PK-13 reservoir of the East-Messoyahskoe oil field are described and analyzed. The backgrounds and regularities increasing the risks of breakthroughs are identified. The analytical calculations have been made and key influencing factors have been defined.
Based on the obtained results, the methodology of the proactive breakthrough identification was developed. The methodology has been tested in the real conditions of the East-Messoyahskoe oil field. The first results have been received, which confirm the operational efficiency of the developed methodological approach. All wells were rated according to their breakthrough risk, and measures for operative and proactive breakthroughs risk management has been proposed. All listed are combined into a system which permits minimization of breakthrough risks and manages them for the increase of unconsolidated heavy oil reservoirs development efficiency.
Implementation and Intermediate Monitoring Outcomes of the First Commingled Up-Dip SMART Water Injection Well in PA-B Platform Piltun-Astokhskoye Offshore Oil and Gas Field
Authors: Tsarenko Alexander Vitalyevich , Tarsky Valentin Nikolaevich , Robson Lisa Jane 
Published: October 2021

Abstract
The objective of this article is to share an evaluation of the background, drilling outcomes and production and reservoir pressure impacts from two years of monitoring the first commingled up-dip SMART water injector drilled in the Piltun area of the Piltun-Astokhskoye offshore oil and gas field, located in Sakhalin, far east of Russia.
The unique aspect of this water injector is that it was drilled into the up-dip gas caps of two separate reservoirs to provide pressure support to commingled oil producers, complementing the down-dip water injectors already in place. This article highlights some details of the well maturation decisions and expectations based on output of the dynamic modelling studies. Drilling outcomes and well performance is compared to expectations. Initial results of the surveillance programme and field data analysis based on a two-year monitoring period are discussed to show intermediate outcomes of up-dip water injection in the Piltun area. Finally, remaining questions and uncertainties are shared.
Piltun-Astokhskoye is a complex multi-reservoir offshore oil and gas field with sizeable gas caps, significant heterogeneity both between and within reservoirs and a complex production history involving commingled oil producers and water injectors. Limited data is available to assess the impact of development decisions. Integrated analysis using multiple data sources and back-to-basics geology and reservoir engineering is required to understand how the reservoirs are responding to up-dip water injection, in order to predict future performance and make informed decisions to optimise the Piltun development over the long term.
Surveillance data shows that up-dip water injection is effective in increasing reservoir pressure and oil recovery in one of the reservoirs, whilst having little impact on the other. Analysis shows that variable impact is due to the influence of gas cap size on up-dip water injection efficiency and the risk of trapped gas volumes due to water injection into the gas cap. The importance of integration between different sources of surveillance data and analytical tools to complete a comprehensive and reliable analysis is shown.
Geological and Field Feasibility Study of Field Development Management Using Marker-Based Production Profiling Surveillance in Horizontal Wells: The Case Study of the Yuzhno-Vyintoiskoye Field
Authors: Dulkarnaev Marat Rafailevich , Kotenev Yuri Alexeyevich , Sultanov Shamil Khanifovich , Chibisov Alexander Viacheslavovich , Chudinova Daria Yurievna , Katashov Alexander Yurievich , Malyavko Evgeny Alexandrovich , Buyanov Anton Vitalievich , Semyonova Ekaterina Evgenievna , Gorbokonenko Oksana Alexandrovna 
Published: October 2021

In pursuit of efficient oil and gas field development, including hard-to-recover reserves, the key objective is to develop and provide the rationale for oil recovery improvement recommendations. This paper presents the results of the use of the workflow process for optimized field development at two field clusters of the Yuzhno-Vyintoiskoye field using geological and reservoir modelling and dynamic marker-based flow production surveillance in producing horizontal wells.
The target reservoir of the Yuzhno-Vyntoiskoye deposit is represented by a series of wedge-shaped Neocomian sandstones. Sand bodies typically have a complex geological structure, lateral continuity and a complex distribution of reservoir rocks. Reservoir beds are characterised by low thickness and permeability. The pay zone of the section is a highly heterogeneous formation, which is manifested through vertical variability of the lithological type of reservoir rocks, lithological substitutions, and the high clay content of reservoirs. The target reservoir of the Yuzhno-Vyintoiskoye field is marked by an extensive water-oil zone with highly variable water saturation. According to paleogeographic data, the reservoir was formed in shallow marine settings. Sand deposits are represented by regressive cyclites that are typical for the progressing coastal shallow water (Dulkarnaev et al., 2020).
Currently, the reservoir is in production increase cycle. That is why an integrated approach is used in this work to provide a further rationale and creation of the starting points of the reservoir pressure maintenance system impact at new drilling fields to improve oil recovery and secure sustainable oil production and the reserve development rate under high uncertainty.
Problem of Gas Breakthrough Solved through Installation of Recompletion Assembly with Autonomous Gas Inflow Control Devices AGICD in Oil Producing Wells
Authors: Ivanova Ekaterina Yurievna , Khokhlov Danil Igorevich , Shangin Andrey Viktorovich , Nesterov Pavel Vladimirovich , Britov Evgeniy Vitalevich , Arzamastsev Georgiy Georgiyevich 
Published: October 2021

Abstract
During the field tests in oil producing wells at the Verkhnechonskoye field there were autonomous gas inflow control devices (hereinafter referred to as AGICD) applied for the first time as part of a recompletion assembly.
The recompletion technology is based on a well completion design solution with AGICD which consists in dividing the liner into intervals, equalizing the total inflow and restriction of the inflow of adverse fluids in producing wells with increasing flowrates of adverse fluids as well as wells shut in due to water/gas breakthroughs.
The recompletion assembly is run into the previously lowered liner equipped with sand screens and divided into several zones by swellable packers.
The new assembly essentially features the classical completion assembly but comprising original 73-mm-tubing-based equipment such as a shoe, cup packers, a packer hanger, and centralizers. The equipment design allows for its complete retrieval if necessary. Since oil contains a lot of solids and deposits of asphalts, resins, and paraffins, the recompletion assembly has a flush valve enabling acid cleanout of the pay zone of the formation during the operation.
In order to prepare for the recompletion assembly to be run in, intense analytical work was done to study the candidate wells and geological conditions and peculiarities of the Verkhnechonskoye field, to analyze the open hole logging data and the oilfield geophysics vs. its hydro-dynamic model data.
During the field trials, recompletion assemblies were run in two wells of the Verkhnechonskoye field and monitored to assess their operation with AGICD within a set period of time. Then the equipment was pulled out and the wells were monitored again without AGICD. The findings provided the basis for the assessment of the equipment operation.
The analysis of the trials results showed that the equipment is prepared, run in the hole and retrieved in normal mode. The qualitative AGICD performance indicators are based on the stable well operation within the total nonfailure operating time after the recompletion assembly is run in the hole. The quantitative AGICD performance indicators are defined by the achieved gas ratio decrease and oil flowrate rise.
The trials also confirmed the convergence of the AGICD expected and field-proven performance indicators which makes it possible to plan precisely well operation modes when using recompletion equipment.
The trials findings prove that the recompletion technology is reasonable for wells with high rates of non-targeted fluids as well as idling wells (due to water/gas breakthrough) to make them active again.