bluuebunny/crossref_metadata_2025_split huggingface dataset:
First Use of Coagulant for Solids in the Drilling Fluid Crude Oil for Underbalanced Drilling in Russia
Authors: Averkin Vadim Nikolayevich , Krylov Andrey Valerievich , Ryabtsev Petr Leonidovich , Lukovkin Yury Valerievich 
Published: October 2019

Abstract
Oil-base drilling fluids provide considerable advantages, however they have a number of limitations mainly related to drilling fluid system contamination with drill solids and formation water. The primary objective is to remove solids from the drilling fluid during the first cycle of their entering into the system in the course of well lengthening. These solids are defined as the concentration of suspended particles. Current solids control equipment does not remove the generated drill cuttings due to the absence of the first stage of solids control – shale shakers; therefore the cuttings transform into fine solids and accumulate as colloidal particles causing the growth of the concentration of suspended particles and reducing reservoir drilling-in quality. To meet the requirement, i.e. quality reservoir drilling-in, it is necessary to ensure effective cuttings removal during the first cycle of their movement.
In 2018 Surgutneftegaz planned and performed field tests of the AKROS coagulant for solids (hereinafter – Coagulant) at the Talakanneft Field Office. The test results enabled conclusions on specific features of the Coagulant use in the drilling fluid – crude oil (hereinafter – crude oil) and identification of the potential for reservoir drilling-in optimization that may expand its applicability.
As part of the New Technological Solution Implementation Program at Surgutneftegaz fields, additional lab equipment was used to obtain extended data, enabling a new interpretation of multilateral well lengthening.
A lengthened multilateral well was drilled at a Surgutneftegaz field using the Coagulant.
Coagulant field test results enabled the following improvements in drilling performance indicators: –reduced torque;–reduced tool weight during pulling out;–improved transfer of load to drilling tool;–increased ROP;–reduced concentration of suspended particles;–removal of formation water from crude oil.
Results achieved on the concentration of suspended particles allow the transfer of crude oil to the following well/interval upon the completion of well lengthening or its injection into an oil reservoir with the minimum concentration of suspended particles. Crude oil treatment with the Coagulant will mitigate risks of heating elements failure, reduce the crude oil volume used for well lengthening, and ensure its reuse without additional replacements and/or dilutions.
The use of the Coagulant demonstrated the ability to reduce the swelling activity of anhydrite occurring in the producing formation when it comes in contact with water contained in the crude oil, making well lengthening operations more technological. Results of the Coagulant use enabled the development of field practices of its application and recommendations on crude oil properties control as well as performance of comparative analysis of the efficiency of solids content reduction and water phase de-emulsification in the crude oil.
First Shallow Kick-off with Push-the-Bit Rotary Steerable System, Sakhalin
Authors: Lebedeva Irina , Shakirova Anastasia , Bravkova Natalia , Famiev Robert , Valshin Oleg , Gaskov Dmitriy , Shakhova Anna , Sandy Adam , Marushkin Dmitry , Bochkarev Vladimir , Surmin Vladimir 
Published: October 2019

Abstract
This article provides the results of the first experience of running a wear resistant "push-the-bit" RSS (rotary-steerable system) for kicking-off at shallow depth in poorly consolidated sand formations.
According to the contractor's best practices, a shallow kick-off in sections with large diameters is performed using PDM (positive displacement motors) with a bent housing angle set up to at least 1.83 degrees. However, for wells in Odoptu field, which is located in the north of Sakhalin island, several specific features pose issues for the effective application of conventional directional drilling equipment to reach the geological targets.
A standard approach for drilling the 17 ½-in. section in Odoptu wells requires two runs:
Run1: A PDM with roller-cone bit are used to build the inclination from zero to 70-degrees in poorly consolidated sand formations
Run2: A conventional RSS with PDC (polycrystalline diamond composite) bit are used for drilling the tangent section.
The project team was challenged to reduce the well construction time by drilling this section in one run, however, there were technical concerns. Drilling with a PDM and roller-cone bit would not provide a high penetration rate in tangent section. Drilling with a conventional push-the-bit RSS might not provide the necessary DLS (dogleg severity) in the sandstone due to formation washouts. In addition, drilling in the sands exposes the drilling equipment to excessive erosion because of the high sand content in the drilling mud. Considering the average section length of 2000 to 3000 m of MD (measured depth), this wear could lead to damaging the costly drilling equipment breakdown and causing unplanned tripping operations.
The project team alongside the field operator decided to test a wear-resistant RSS for one typical well of the Odoptu-Sea field. As a result, the section was drilled in one run, achieving the planned DLS without any equipment erosive wear. In addition, the 17 ½-in. section of this well recorded the highest penetration rate of 58 m/h in the field. The implementation of a wear-resistant RSS saved 6 days of the total section time.
Effective Application of Metal Expandable Packer to Prevent Gas Migration Issues, Leaks of Gas and Fluids in Annulus, Well Integrity Problems
Authors: Lebedev Ivan , Gabdullin Aydar , Pogurets Valeriy , Novikov Sergey 
Published: October 2019

Abstract
This paper reflects the experience of applying modern technologies to prevent annualr gas migration, crossflows and pressures (ACP), well integrity assurance during the gas and gas condensate wells construction in South Tambeyskoye field.
South-Tambeyskoye gas condensate field is the largest in Western Siberia and the Arctic North of the Russian Federation. The development of this field is carried out by the JSC "Yamal LNG" (PSC "NOVATEK") - one of the worlds leading gas and gas condensate exploration & production companies with the participation of Total and CNPC. Proved and probable reserves of the field according to the international classification PRMS are estimated at 926 billion cubic meters of gas and 30 million tons of liquid hydrocarbons.
At the South Tambeyskoye field, several field trial works (FTW) were carried out to prevent ACP on 4 wells: –3 production wells on Valanzhinsky deposits with reservoir pressures up to 350 atm.–1 production well on Jurassic deposits with reservoir pressures up to 820 atm.
Technology effectiveness comparison to standard methods has been conducted based on field trial results. Based on objectives achieved using modern technology, field trial works considered succesfull.
Complex Approach for Gas Lift Wells Optimization for Orenburgskoe Field
Authors: Kapusta Eugene , Rymarenko Konstantin , Nukhaev Marat , Grishenko Sergey , Aitkaliev Galymzhan , Minin Daniil , Kabanov Vasily , Galkin Denis , Karamysheva Tatyana , Ulyanov Vladimir , Dadakin Nikita 
Published: October 2019

Abstract
At the moment in Russia, the gas-lift method of operation is becoming popular again not only because of the significant reduction in operating costs, ease of operation, but because of the involvement in the development of a large number of assets with oil rims. This paper describes an integrated approach to optimizing the operation of wells in the Orenburg oil and gas condensate field, which is characterized by the largest number of wells in Russia that are operated by gas lift. The paper describes traditional approaches to the gaslift well testing as well as a new approach to improve operational efficiency.
Sand Influence Analysis on ESP Operation in Salym Petroleum Development. Effective Methods and Procedures for Sand Protection
Authors: Shamkov Alexander , Gorlov Alexander 
Published: October 2019

Abstract
The current state of the Russian oil industry requires a scientific approach to optimizing the operation of electrical submersible pumps (ESPs) in harsh conditions. Most of the fields are at a late stage of development with high watercut and increasing amount of solid particles. At the new fields and new license areas the main share is made up of horizontal wells with multistage hydraulic fracturing, where sand removal from unconsolidated sandstone and proppant from the bottomhole zone of the well to the electrical submersible pump causes its serious damage and reduces the run life (Haiwen, 2019).
In many scientific papers mathematical models of the given process were described as well as the speed of wear of impellers and bearings surfaces as a result of influence of abrasive particles were defined in laboratory conditions.
At the same time, it is necessary to note insufficient elaboration of questions in estimation of derating rate of pump performance in high amount of mechanical impurities in field conditions, and as a result – the incorrect estimation of the period of effective and trouble-free operation of the submersible equipment.
The proposed researches, first of all, are directed on determination of the degree of influence of solid particles on impellers and diffusers of ESP, character and speed of wear inside an ESP, forecasting of optimum time of operation of ESP. Based on the example of Salym group of fields the analysis is offered, which can be adapted and applied at other fields.
Investigation of Asphaltenes Precipitation Under Immiscible Interaction of Reservoir Heavy Oil and Liquid Carbon Dioxide
Authors: Lobanov Alexey , Fedorovskiy Stanislav , Promzelev Ivan , Tikhomirov Yevgeny , Schekoldin Konstantin , Struchkov Ivan , Kovalenko Vyacheslav , Sergeev Georgy , Lipatnikova Ekaterina 
Published: October 2019

Abstract
A new method for assessing the stability of the asphaltene phase in reservoir fluids using a high-pressure microscope is presented. The new method is based on the observation of the asphaltene particles sedimentation in a vertically oriented sapphire cell. This determines the size of sedimentation particles, their number and sedimentation rate. Experimental results are used as input parameters for calculating solid particles sedimentation of using the Stokes law equation. It makes possible to calculate the density and weight percent of the solid phase, evaluate the aggregative and kinetic stability of the fluid with respect to solid particles depending on thermodynamic parameters (pressure, temperature, reagent concentration). The proposed method was tested in the single-contact study of high-viscosity reservoir oil and liquid carbon dioxide and was compared with the results of asphaltene precipitation gravimetric test. According to the results analysis, were conclusions about the applicability of the new method and the mechanism of asphaltenes precipitation in high-viscosity oil when it contact with carbon dioxide. It is shown that the combination of gravimetric and visual analyzes allows to investigate the asphaltenes precipitaion separately in two processes: reduction of pressure and vaporization of fluids. This makes it possible to assess the likelihood of formation and the effectiveness of reagents for combating solid deposits in the entire process chain of oil production. Concluded that the asphaltenes precipitation in the contact of carbon dioxide and high-viscosity oil occurs according to the complex mechanism and includes intensification due to a drop in oil viscosity and damping due to mass transfer between carbon dioxide and oil phases. From this, inhibitors selection criteria are derived and the using of deasphalted oil as a stabilizer of asphaltenes is proposed.
Evolution of Horizontal Wells Production Logging Using Markers
Authors: Basov Artem , Bukov Oleg , Lazutkin Dmitry , Olyunin Alexey , Kuznetsov Vadim , Ipatov Andrei , Shevchuk Taras , Saprykina Kseniya , Ovchinnikov Kirill , Novikov Igor 
Published: October 2019

Abstract
There has been an increased interest in horizontal wells production logging using markers due to objective difficulties not only in conducting geophysical production logging and data interpretation, but also because existing technologies provide bottom hole data only for a very short time period when the PLT complex is in the well. Marker technologies enable users to obtain data in a much larger volume and practically non-stop for several years without changing the well mode of operation. This in turn allows for analyzing the influence of many external factors on the horizontal well intervals operation.
This article presents the experience of marker technologies that were tested and implemented at Gazpromneft PJSC sites from 2016 to 2019, and is aimed at the systematization of objectives and requirements for the technology, as well as addressing important issues during the tendering procedures for the oil producing companies.
Efficiency Analysis of 30-Stage Fracturing in a Horizontal Well to Oil Rims Based on Through-Barrier Diagnostics
Authors: Nagimov Vener , Virt Vitaliy , Kosolapov Vladimir , Bakhitov Dmitry , Maslennikova Yulia , Spirina Liliya , Shigapov Ilnur 
Published: October 2019

Abstract
Cost-effective reservoir development of oil rims such as Novoportovskoe field requires improving of existing fracturing methods on a way to increase recovery factor. One of the approaches includes the implementation of special completion with renewable fracturing sleeves as well as increasing the number of fracture ports over horizontal wellbore (Belov and others, 2018). This allows to increase profitability from one side, but from the other side, considering the complexity of oil rims geology, this increases the risks of early gas and water breakthrough from the gas cap and water contact respectively via hydraulic fractures induced to untargeted intervals.
Generally, the efficiency of implemented well completion design is evaluated based on conventional production logging, however, high resolution and sensitive well diagnostics are required in case of a high number of fracture ports. An additional challenge is associated with diagnostics of flow in the reservoir behind the liner and completion components integrity evaluation such as packer and fracture sleeves. The better diagnostics is applied the more efficient production profile optimization can be done. The paper describes the through-barrier diagnostics concept and shows a case of the performed survey in a horizontal well to oil rim with 30-stage hydraulic fracturing based on through-barrier diagnostics. Two surveys were conducted: the first survey was done at an early stage of well production, then workover was performed based on the first survey results revealing several zones with high GOR and high water cut. The second survey was conducted after the workover. Additionally, the paper describes a novel method on high GOR and high WC zones identification from spectral acoustic data analysis based on machine learning.
Assessing Efficiency of Multiwell Retrospective Testing MRT in Analysis of Cross-Well Interference and Prediction of Formation and Bottom- Hole Pressure Dynamics
Authors: Aslanyan Artur , Ganiev Bulat , Lutfullin Azat , Shvydenko Maxim , Karimov Ildar , Gulyaev Danila , Krichevsky Vladimir , Farahova Rushana , Zinurov Linar 
Published: October 2019

Abstract
The paper describes the first use of Multiwell Retrospective Test (MRT) on the Devonian formation of the Romashkinskoye oil field.
The paper introduces the technology of MRT and describes the advantages in determining the interference of wells and formation pressure (4-7).
The field case cited in the article describes a specific implementation of an MRT, called "radial deconvolution," in which the central (tested) well is equipped with a bottomhole pressure gauge. As a result, the interference of the offset injection and production wells to the tested well is estimated, as well as the properties of the well and reservoir, taking into account the interference with the offset wells. One of the advantages of this technology is the ability to estimate formation pressure without shutting the well. In this research, a comparative test was performed, in which the reservoir pressure predicted by MRT was checked with a field test.
How not to fail during the Reservoir Test for Low Permeability Formation: Case Study
Authors: Kaipov Yermek , Tyatyushkin Sergey , Kulyatin Oleg , Lomukhin Alexander , Romashkin Sergey 
Published: October 2019

Abstract
This paper presents The Exploration Well test solution under high pressure and low permeability. The work shows a new approach to the qualitative and quantitative description of the low permeability horizons by conducting the well testing before and after hydraulic fracturing. To provide a high degree of reliability, safety and efficiency in terms of time and quality of the received information the special combination of high-tech downhole tools was used.
The previous experience of conducting the well testing in exploration wells at the Yamal-Nenets Autonomous Region showed difficulties due to the deep bedding, low permeability and abnormally high formation pressure.
These types of formations require conducting the hydraulic fracturing to obtain the commercial flow at surface. During the well test after the hydraulic fracturing in a low-permeable reservoir usually it is not possible to achieve infinitely-acting radial flow regime within the allocated time which does not allow to estimate the actual horizontal permeability of the formation.
To perform the complex well testing and effective hydraulic fracturing the combination of downhole tools, run-in hole on a tubing, including the perforating guns, packer, autonomous pressure gauges, downhole valves (tubing and circulation valves) controlled from the surface, was used.
To assess the reservoir permeability the well testing was carried out with the inflow period without natural flow to the surface and pressure build-up shut-in at the bottom before creating the hydraulic fracture. As a result, the formation pressure, permeability and skin-factor are estimated. During this study, a multi-cycle valve controlled with a low-pressure impulse in the annulus played the major role in conducting several inflow periods, pressure build-ups with downhole shut-in and lifting the formation fluid to the surface by reverse circulating through the circulation valve.
Before conducting the hydraulic fracturing, three mini-frac tests were carried out with injection of hydraulic fracturing fluid into the reservoir and recording the pressure fall-off with downhole shut-in. As a result of this period the fracture closure pressure, reservoir pressure, mobility and the effectiveness of fracturing fluid were estimated.
After hydraulic fracturing, flowing periods were conducted to assess the well productivity with a created fracture.
These well testing activities were carried out successfully in a safe manner and achieved reservoir evaluation objectives.
This article discusses the unique experience and lessons learned from conducting the well testing with hydraulic fracturing using high-tech downhole equipment to achieve the successful results in low permeability reservoirs.
Development of an Approach for the Numerical Analysis of Well Interference
Authors: Bukhmastova Svetlana , Fakhreeva Regina , Pityuk Yulia , Akhmerov Rustem , Efimov Dmitrii , Nadezhdin Oleg 
Published: October 2019

Abstract
Information about the interwell space allows one to solve a number of key production problems such as planning of geological and technical measures and enhancement of operating efficiency of wells. Due to the fact that this information is most often recovered from the interpretation models, one of the ways to obtain correct information is the analysis of well interference. It helps to obtain knowledge about the state of the reservoir, the degree of its heterogeneity and the presence of cracks and fractures.
The aim of the study is development of a comprehensive approach for the analysis of reservoir connectivity by identifying well interference based on the mutual accounting of pressure and flow-rate data of well field. In order to solve this problem, we developed programing modules based on the methods of Multivariate Linear Regression (MLR) and Capacity-Resistance Model Injector-Producer (CRMIP). The main advantages of these algorithms are their low cost, high speed of operation, and the absence of the need for knowledge about the location of wells in the field and the physical properties of the formation. The MLR method is based on the pressure analysis with the use of the multivariate linear regression equation. The outputs are the weighting coefficients of well interference. To solve the problem using the CRMIP method we require a history of injection and production, bottomhole pressure of the production wells. The CRMIP takes into account the equation of material balance. On the basis of these data and the solution of the optimization problem we determine the coefficients of well interference, time delay in system response, and productivity coefficients.
The programing modules were tested on various synthetic data in order to quantify the coefficients of well interference and to verify the predictive ability of the models. Good agreement of numerical results with baseline data is obtained. The analysis of the results of numerical simulation indicated that all the interference coefficients are defined correctly.
Selective Oil-Field Exploitation System Features with Horizontal Wells Multi-Stage Fracturing of Achimov Deposits in Case AHRP
Authors: Buzaev Anatolii , Akhmetov Aleksei , Osipenko Aleksey , Sherstoboev Evgenii 
Published: October 2019

Abstract
Achimovsky deposits of the North of Western Siberia are characterized by variability of the reservoir on lateral and in vertical directions that leads to increased development risk. A main objective of the paper is definition of an optimal development scheme of pilot project sector and to use the received results in creation of the systematic plan of studying and drilling of other perspective areas for decrease in geological risks and for eduction of CAPEX on drilling.
In this paper, creation of conceptual geological and hydrodynamic model of BU213 layer of the East Messoyakhsky field is described. Reservoir of achimovsky deposits is characterized by clinoform (lenticular) structure. An optimal development scheme is choosen by multivariant geological and simulation modeling. Number of wells, length of horizontal section, quantity of stages of multistage hydraulic fracturing, proppant volume were varied for choosing an optimal development scheme by multivariant geological and simulation modeling. The additional research of geomechanical parameters was performed; modeling of water-saturated BU212 layer is conducted to find reason of water-cut increasement on production wells, and obtained results were used to re-design fractures for the purposes of low-volume hydraulicfrac fracturing efficiency increasement.
This approach allowed selecting an optimal development scheme – maximization of produced oil with minimization of drilling costs. Pattern of horizontal wells with multistage hydraulic fractures (5 stages) is recomended. For removal of geological uncertainties different development scenarios were provided which allow operative change a designed well pattern depending on drilling result, well tests and wells productivity. At each stage of obtaining information geological and simulation models, updates are planned. That allows specifying probabilistic forecast of liquid, oil and gas production. After obtaining of results, phased drilling plan was generated and studying plan of other object BU213 deposits is approved.