bluuebunny/crossref_metadata_2025_split huggingface dataset:
Solving the Problems in the Hydrodynamic Modeling of the Eastern Siberia Field with Salted Deposits
Authors: Komalov Saidabror , Shelest Natalia 
Published: October 2019

Abstract
Maintaining reservoir pressure is one of the prerequisites for ensuring production levels to be achieved. However, its implementation is not always a trivial task. Revised oil field is located in East Siberia and complicated by fault, insufficient level of exploration degree and located at isolated location, on the other hand it has a high hydrocarbon potential. Also target oil filed is characterized by deposits of halite in the reservoir, which significantly reduce the reservoir capacitive characteristic and filtration ability, high mineralization and increased viscosity of the formation water, complicates reservoir pressure maintenance, presence of significant lateral and vertical reservoir heterogeneity. All above factors require nonstandard approaches to field development design and engineering solutions for effective oil and gas recovery.
Geology Driven History Matching
Authors: Matveev Ivan , Shishaev Gleb , Eremyan Grachik , Demyanov Vasily , Popova Oksana , Kaygorodov Sergey , Belozerov Boris , Uzhegova Iuliia , Konoshonkin Dmitry , Korovin Mikhail 
Published: October 2019

Abstract
This paper proposes the method of an automatic history matching (HM) with the ability to preserve geological realism and an example of its application in one of the fields in Western Siberia. The method assumes takes into account all identified uncertainties at the early stages of geological model construction and their synchronized variation within realistic limits during HM.
There are interrelations between petrophysical and geological uncertainties, which significantly affect on the reservoir dynamics. Hence, changes in one of the parameters during HM should influence the synchronous change of the others in order to preserve the geological consistency of the simulation model within the given geological concept. As a result, engineer gets a set of history matched models providing a range of predictions, which can be used for investment decisions.
Coupled Reservoir – Well Model of Sand Production Processes.
Authors: Lezhnev Konstantin , Roshchektaev Aleksei , Pashkin Vsevolod 
Published: October 2019

Abstract
Sand production is often observed during the development of weakly consolidated reservoirs. In this paper the physico-mathematical models of the main processes associated with sand production are presented. These models are combined into a single process that allows calculating the dynamics of skin-factor of the well, estimate the risk of well plugging with sand and estimate the concentration of the solids in the flow at the wellhead. Model can also be used for the optimization of the filter.
Coupled model consists of three parts: geomechanical module for estimating the amount of solid particles flowing out of the formation, module for calculating the filter efficiency, and module for solids transport in the well. To evaluate the geomechanical failure of the formation the radial semi-analytical model was used that considers plastic deformations of the weakly consolidated rocks. Pressure drop in the filter was calculated with the one-dimentional suspension model with multiple solid particle sizes. The evaluation of solids transport the was based on the one dimentional model of the multiphase flow. One-way coupling was used to combine these modules. Information about concentration of solid particles in the flow is passed from geomechanical module to the filter module and then to the well transport module.
Presented coupled model covers most significant processes affecting the oil production from weakly consolidated reservoirs. In the course of the work, the dynamics of the near-wellbore area failure was modeled and the dependence of the concentration of solid impurities in the inflow was calculated over time. This data is used as input parameter for the filter model. Calculation of the filter allows estimating the pressure drop across the filter and well's skin factor. The model takes into account the particle size distribution of reservoir particles, which allows it to be used for the optimization problem of filter selection. The constructed model of sand transport along the well allows calculating the risk of sand blockages formation and find the fluid production rate that is sufficient of carrying solids to the welltop. Further development of the model will allow taking into account the erosion of submersible equipment, estimate the turnaround time and calculate the multiphase flow in the near-wellbore area.
Uncertainty Analysis and Integrated Modeling Application During Field Development
Authors: Dmitruk V. V. , Mironov E. P. , Mulkamanov A. A. , Kharkovskiy A. , Bayguzov R. , Komin M. , Timakova O. , Chernyak V. , Shakhov D. , Krivokorytova M. 
Published: October 2019

Severneftegazprom OJSC is the operator of the Yuzhno-Russkoye field. In accordance with the field development strategy, in 2018 the commercial development of the Turonian formation began, envisaging the drilling of more than 100 wells to a formation with abnormally high pressure and low permeability and their tie-in to the existing gas gathering network. The task that faces the company is to assess the attainability of the planned targets on the basis of the existing field development concept and surface facilities configuration. A separate focus is on the geological uncertainties analysis of the Turonian formation and their impact on the gas production profile.
For the uncertainty analysis, a sector hydrodynamic model was built and history matched, which included the first launch clusters with the U-shaped wells and the multistage hydraulically fractured wells (MSHF). The assessment was made for the impact of geological uncertainties, the alternative well locations, as well as the number of hydraulic fracture stages and fracture parameters on the cumulative gas production.
To study the interference of new wells with the existing network, an integrated model was created, which combined the full-scale Black Oil hydrodynamic models of the Cenoman and Turonian reservoirs with the unified compositional gathering network with more than 250 wells.
Conceptual Approach to Field Drilling – Minimizing Risks And Economic Costs
Authors: Freze Aleksandr 
Published: October 2019

Abstract
The existing, until recently, design system provided no connection of the surface and underground parts of the field in a complex, as a result of which further implementation of design solutions had problems with placement of well clusters on the surface and well profiles drilling. The introduction of a conceptual approach in the design of the field allows you to accurately determine and optimize the cost of construction of wells and construction of oilfield at the design stage.
Comprehensive Evaluation of Costs at the Early Stages of Project Development: Costs of Equipment not Included in the Construction Estimate
Authors: Maksimov Yuri , Skudar Oleg , Yanina Irina , Pashkevich Lev , Sandler Ilya , Ulyashenko Vladislav 
Published: October 2019

Abstract
This article describes the method developed by Gazprom Neft to evaluate capital expenses required to purchase the equipment not included in the construction estimate using the automatic calculation module. Work in this direction is to Gazprom Neft a relevant and logical continuation of the cost engineering development vector. Having a methodology and tool for calculating the costs of equipment not included in the construction estimate will optimize the decisions made by increasing the accuracy and substantiation of the CAPEX amount evaluated for the newly introduced and developed assets.
The method of calculating the costs of equipment not included in the construction estimate includes itemized decomposition by well type and method of well operation. The full list of equipment is defined, the algorithms of equipment selection depending on the technological pre-requisites are described, the cause-and-effect relationships are established according to the principle "technical parameter x cost", an economical and mathematical mechanism is suggested.
The tool for evaluating the costs of equipment not included in the construction estimate includes full automation of the calculation process in accordance with the methodological provisions as relates to the region under consideration where the asset is located. Engineering modules are integrated which calculate the frame size, capacity, length and other characteristics of equipment. The tool helps to perform calculations for both individual well types and in general in accordance with the fluid / oil / associated gas production / water injection.
Impact of Compressibility Change due to Overpressure on HC Volume on Karachaganak Gas Condensate Field
Authors: Ibragimov Abdulmalik , Kan Andrey , Kalmuratov Nurbolat 
Published: October 2019

Abstract
Inappropriate surface infrastructure sizing due to overestimation of initial reserves may lead to financial losses for a company. One of the many reasons why surface facilities are inappropriately sized is due to lack of subsurface understanding, misinterpretation or lack of data [1]. The current work is dedicated to give more understanding on possible expected behavior of the Karachaganak field based on hard data and its implications on hydrocarbons in place.
The Karachaganak gas condensate field is 20% overpressured reservoir. Current production is mainly focused on oil rim. Gas production is delayed to later times, as a blow down process. Based on real cases in the past for overpressured gas reservoirs there was developed a special material balance equation where it assumes different compressibility for a reservoir before and after reaching hydrostatic pressure. There are two main theories that explain the causes of overpressured reservoir material balance calculations [2]. Rock collapse theoryShale water influx theory
The Karachaganak field is a carbonate field with negligible amount of shale which excludes the shale water influx theory. Repeated well test data measured on the same well during a different period of the well life clearly show how rock collapse theory works in the field thus supporting the first theory occurrence on the field.
Based on the current simulation model with implementation of changing compressibility to reflect pore collapse, authors provide calculations and its impact on original oil and gas in place volumes.
Multiphase Inflow Monitoring in Horizontal Wells Producing from Oil Rims Based on the Advanced Production Logging Suite Data
Authors: Minakhmetova Roza , Aslanyan Irina , Nagimov Vener , Shigapov Llnur , Kosolapov Vladimir , Virt Vitaliy 
Published: October 2019

Abstract
Today, oil reservoirs with a gas cap on top are mainly developed by drilling horizontal wells of various design. In the course of well operation, early increase in gas-oil ratio or water cut can often be observed. These may be caused by both well integrity failure and the geology feature of the target formation when formation water breaks through from the bottom of the producing formation and gas inflows from the top of the reservoir as a result of coning.
One of the ways of controlling unwanted water and gas production sources and reservoir fluid production rates is monitoring of production profiles along the horizontal sections of the well using a reservoir-oriented production logging survey. This paper describes an example of such monitoring at a horizontal well drilled into the oil-rim reservoir at the Novoportovskoye field. The paper provides the results of a series of logging surveys performed in 2, 18 and 24 months after the well commissioning. The first (reference) survey was performed at the earliest stage of the well production; the second and the third ones - when the gas-oil ratio started to increase. The advanced production logging survey included high-precision temperature logging, distributed capacitance measurements and spectral acoustic logging. The spectral acoustic logging data identified the producing intervals of the reservoir along the horizontal section of the well. According to the first survey results, the production fluid was flowing uniformly along the wellbore. The third and second surveys had identified the intervals of gas breakthrough in the reservoir. After all the survey results had been compared to one another, it was identified that the gas breakthrough could have been localized even during the first logging survey. In each survey, the multiphase inflow profiling was perfomed using a temperature modelling.
Information generated as a result of production logging survey in the horizontal well allows localizing and predicting gas breakthroughs in wells drilled in oil rims. Using this data, such gas breakthroughs may be immediately prevented. The data can also be used when designing new wells to increase the efficiency of development of such fields.
Creation of a Source Rocks Integrated Petrophysical Model Based on a Special Core Analysis Results
Authors: Alekseev Aleksey 
Published: October 2019

Summary
Integrated petrophysical models have been broadly applied in geological and petro-elastic modeling to forecast hydrocarbon accumulations and to estimate resource potential. Methodological basis of building those models have been well developed for conventional terrigenous and carbonate reservoirs; as regards the so-called "shale-type" hydrocarbon-bearing rocks, however, there are objective difficulties determined by a range of various factors that may include multi-component composition of rocks, core recovery problems, as well as process-related peculiarities of laboratory methods. This paper offers a program of special laboratory core analysis of the samples from the Bazhenov formation and an algorithm for the processing of the results with the view to build an integrated petrophysical model of an unconventional "shale-type" oil pay.
Permeability and Porosity Study of Achimov Formation Using Digital Core Analysis
Authors: Yakimchuk Ivan , Evseev Nikolay , Korobkov Dmitry , Varfolomeev Igor , Dinariev Oleg , Khan Vladimir , Koroteev Dmitry , Orlov Denis , Muravleva Ekaterina , Belozerov Boris , Krutko Vladislav , Kondratev Artem 
Published: October 2019

Abstract
The first application of digital rock technology (digital core analysis) with direct hydrodynamic modeling based on density functional theory for the Achimov formation is described. The technology consists of imaging core samples by X-ray microtomography, construction of corresponding digital rock models of pore space geometry, and multiphase hydrodynamic simulation on a pore scale by the density functional method. Despite the extremely low permeability values (less than 1 μd), digital measurements of relative permeability curves were completed successfully for model oil and water in steady-state flow mode whereas laboratory measurements in steady-state flow regime were unfeasible for the studied samples. The required spatial resolution of the digital rock models for the studied samples was about 1 μm and higher. At the same time, for a reasonable selection of a representative sample, it is desirable to conduct a larger sample scan with a coarser resolution. For the first time in the industry, a direct two-phase relative permeability simulation was performed on a record-size model of 1300 × 1300 × 1500 voxels. Also, for the first time, two-phase filtration experiments were carried out on a core miniplugs in the permeability range of less than 1 μd.
Seismic Survey Capability for Oilfields Development Monitoring Using SAGD Technology
Authors: Nevmerzhitskiy Yan , Bykov Alexander , Semaka Vadim , Polnikov Evgeny , Zavyalov Ivan , Zavyalova Natalya , Miroshnichenko Dmitry , Sayfutdinov Rauf , Grinevsky Anton 
Published: October 2019

Abstract
The paper is devoted to the investigation of possibility of seismic methods using for steam chamber growth monitoring during heavy oil fields development using steam assisted gravity drainage method. For this purpose a program for simulation of compositional flow of high-viscosity viscoplastic oil as well as a program for simulation of acoustic wave propagation in three-dimensional heterogeneous medium. The features of steam chamber influence on the seismic wavefield are detected and technique of their interpretation is developed.
Oil and Gas Bearing Complexes of the Sedimentary Cover of the Arctic Zone of the Siberian Platform Marginal Zones of the North of the Siberian Platform?
Authors: Dmitrievsky Anatoly , Eremin Nikolai , Shabalin Nikolai 
Published: October 2019

Abstract
The report discusses issues related to the assessment of the resource base and the development potential of the Arctic zone of the Siberian platform along the Northern sea route, the region of Russia with a high concentration of oil and gas resources. The basic concepts on the geological structure and the oil and gas potential of the Arctic zone of the Siberian platform are based on seismic data tied to existing deep exploratory wells. To date, five petroliferous complexes have been described in the Yenissei-Khatanga (the Yenisei Bay, the Yenisei-Khatanga regional trough) Anabar-Khatanga (Anabar-Khatanga saddle, Khatanga bay) Anabar-Lena oil and gas regions (Anabar-Lena trough and adjacent shallow shelf of the Laptev Sea) and the South Laptev sea promising oil and gas region for the main oil and gas complexes: Riphean, Vendian, Vendian-Middle Paleozoic, Upper Paleozoic and Mesozoic.
The report considers the results of the analysis of estimates of the filtration-capacitive properties of the sedimentary cover rocks in the marginal zones of the north of the Siberian platform available on 01/01/2019. Open fields are briefly described. The obtained results allow for the adjustment of state programs for the development of the Arctic zone of the Siberian Platform (Yenisei-Khatanga, Anabar-Khatanga and Anabar-Lena oil and gas regions, South-Laptev Sea promising oil and gas region).
Green Seismic
Authors: Nazyrov Dmitry , Dakirov Valikhan , Tarasov Sergey 
Published: October 2019

Summary
Today we can clearly see that the world's leading oil companies strive to improve not only the quality of explorations but also tighten industrial and environmental safety requirements to this work. Green Seismic is a complex of methodologies, technical means and organizational measures applied to seismic explorations to ensure they efficiently achieve the following goals: Narrowing the width of the signal reception and excitation linesReducing personnel injuries in the course of seismic surveysGetting access to restricted exploration areas and improving seismic data qualityReducing the number of seismic crew personnel
The need for this project is caused by the technology challenges faced by Gazprom Neft's seismic operations. These challenges, that significantly complicate seismic work when it is performed by standard methods, include a large number of industrial facilities, infrastructure networks, residential areas, agricultural lands, thick forests, mountainous terrain and everything else that makes it impossible to deploy seismic crews, does not allow achieving sufficient density of seismic lines, extends the time for preparation of driveways for heavy equipment, increases the risk of injury to personnel when performing tree cutting work, and generally affects the Company's image in aspects related to the introduction of environmentally friendly technologies.
The main purpose of this project is the establishment of an innovative technology that would allow the Company to remove or minimize negative factors of seismic operations performed by standard exploration methods.
Borehole Acoustic Reflection Survey in Horizontal Wells: High Resolution Reservoir Structure to Guide Properties Distribution
Authors: Karpekin Yevgeniy , Orlova Svetlana , Tukhtaev Rustam , Ovchinnikov Alexey , Kuntsevich Vitaly 
Published: October 2019

Abstract
The article discusses the method of borehole acoustics reflection survey for detecting the presence and reconstructing the position of various reflecting surfaces, such as of large fractures, faults, bed-boundaries, in the near-well space at a distance up to 30m or more. The measurement principles, data processing, visualization and interpretation workflow developed by us based on the best published practices and supplemented by our solutions that significantly improve the quality and usability of the images are explained. A study of fractured zones identification and characterization in three horizontal wells based on the electrical microimager and the reflected acoustic survey is presented. Possibility of imaging the bed-boundaries of the host layers above and below the wellbore and specifying their position relative to the well's trajectory is demonstrated. Confinement of rocks with different reservoir quality within certain sub-layers of the target productive strata, identified with acoustic reflected survey, brings possibility to populate these properties more accurately in a refined structural model.
Conditions of Secondary Fracture Reorientation for Cases of Vertical and Horizontal Wells
Authors: Martemyanov Andrey , Shel Egor , Bratov Vladimir , Chebyshev Igor , Paderin Grigory , Bazyrov Ildar 
Published: October 2019

Abstract
An approach to determine stress field near wellbore with existing hydraulic fracture accounting for rising pressure and fluid filtration along the crack has been developed. An estimations of secondary fracture initiation time near wellbore as well as moment of primary crack growth start have been produced. Factual data about mechanical rock properties, stress state and pore fluid pressure was used. It has been shown finally that reorientation of secondary fracture in the case of vertical well is improbable during reinjection. Calculations were made with various magnitude and rate of pumping pressure increasing, value of pore pressure inside formation and main tectonic stress ratio acting at infinity. Similar analysis in the case of horizontal well demonstrated several alternative mechanisms of secondary fracture initiation: simulteniously with existing crack growth new fractures along and orthogonal to well trajectory may appear. Which of type will become dominant depends on actual geomachanical conditions and primary fracture characteristics. Obtained estimations have been compared with field observations.
Hydraulic Fracturing Overflush on Conventional Reservoirs
Authors: Chaplygin Dmitry , Khamadaliev Damir , Yashnev Victor , Gorbachev Yaroslav , Chernyshev Alexey 
Published: October 2019

Abstract
After hydraulic fracturing treatment, wellbore clean-out takes significant amount of time, and therefore, the commissioning of the well is delayed. In addition to production losses, production companies CAPEX and OPEX are also increasing proportionally to frac fleet activity. As a common practice, in western Siberia fracturing treatment is underflushed by about 0.5 cubic meters. This is supposed to prevent unintentional overflush and, as a result, hydraulic fracture closure at the wellbore. The loss of contact between the propped fracture and the perforated section of the well can neutralize the effect of hydraulic fracturing. This can happen in the first days of production after the operation or in a long-term perspective.
On the other hand, overflush during hydraulic fracturing is common practice for unconventional formations. It allows to use various well completion technologies with the cemented liners and significantly reduces time required to complete multistage fracturing treatment.
The objective of this paper is to show the approach and experience of the company "Salym petroleum development" (SPD). Positive result was obtained with proppant slurry overflush operation during treatment of conventional reservoirs.