Gas Condensate Field Research Articles

On the transition of liquid dispersion states and their physical-thermodynamic nature in the development of gas-condensate reservoirs in depletion mode

While the depletion regime for gas-condensate fields may be more cost-effective, it often results in the loss of hydrocarbon condensate, which is economically more valuable than gas, and leads to the inefficient exploitation of the field in terms of condensate production. Therefore, the development of effective exploitation systems for such fields is essential. Effective exploitation of gas-condensate fields involves achieving maximum hydrocarbon condensate production in addition to maximum gas production. From this aspect, managing the condensate factor of reservoir system during the depletion regime is a critical issue. The article experimentally and theoretically investigates the phase transitions or mutual dispersion occurrences between hydrocarbon liquid and gas mixtures that occur with a decrease in pressure at reservoir temperature during the natural depletion of gas-condensate fields. During the exploitation of gas-condensate fields, it has been observed that even at pressures higher than retrograde condensation pressure, the hydrocarbon system undergoes complex phase transitions, resulting in distinct transition points due to the mutual dispersion of hydrocarbon liquid and gas. Additionally, pVT studies conducted in the laboratory have made it possible to determine the transition points of the reservoir fluid in the “liquid in gas” and vice versa dispersion states. The research has demonstrated that dependance of gas condensate factor on pressure under given isothermal natural conditions more clearly reflects the retrograde and maximum condensation, also dispersion points of the liquid components. It was found that proportionality coefficient between condensate ratio and pressure of gas-condensate system is unique for each production facility under isothermal conditions and characterizes the stability of fluid’s dispersion state. The importance of considering such transition points when designing gas-condensate field development projects has been highlighted.

Mathematical formulation of the physical properties of Hydrocarbon Gases and the determination of these parameters in a Gas-Condensate field in Albania

Abstract The physic-chemical properties of fluids that saturate a bed have been followed throughout the course of resource exploitation through different analyses. Fluids released from the formation over time of exploitation change due to the change in the phase state of the fluids, their material balance and energy. Determining the type of reservoir fluid and its properties, including physical properties and chemical properties, play a key role in reservoir engineering for many decisions made in the development of an oil and gas field. In this manuscript, the properties of gases are analyzed step by step in both their physical and mathematical contexts, as well as that of gas. In this context, a gas-condensate field located in Albania was taken into consideration, determining its properties through the relevant correlations and the use of different graphs both for the measured value of the initial pressure of the formation and for the different values of the pressure taken into consideration.

Current condition, geological structure and prospects of oil and gas resources in the Aral sea

The article presents the results of the analysis of the current state of study of the Aral Sea region by geological exploration works, and in more detail – of the Aral Sea aquatory. An attempt has been made to correlate new geological data based on the works of Uzbek geologists and materials of seismic surveys of the Kazakh part of the Aral Sea, since the West Aral oil and gas condensate field has been discovered in the Uzbek part of the Aral Sea water area, the productivity of which is associated with the Middle-Upper Jurassic deposits. Taking into account the history of geological development of the territory and formation of oil and gas bearing zones, it is necessary to carry out geological exploration works in the perspective of the unified model of the Aral Sea basin. On the basis of the discussed model of geological structure the prospects of oil and gas potential of separate structural-tectonic zones were predicted, and a series of recommendations were issued.

Tectono-sedimentary evolution of prolific Permo-Triassic petroleum reservoirs offshore Iran: Insights from seismic stratigraphy

The foreland basin extending through the Persian Gulf is one of the world's most prolific petroleum resource-bearing regions. The structural evolution of parts of that basin has been strongly influenced by Late Proterozoic/Early Cambrian Hormuz Salt formation movements, which have also controlled the distribution of petroleum resource accumulations. Fields SP and BL are characterized to distinguish the tectono-sedimentary evolution of the central and eastern parts of the basin, respectively. Field-SP is located within the Qatar Arch in the central part of the basin, whereas Field-BL is situated in the southeastern part of the basin and is tectonically influenced by the Hormuz Salt movements. 3D seismic data and information from two exploration wells are assessed in detail to define and compare the deformation history of the Permo-Triassic succession in these two fields. The Dalan (Upper Permian) and Kangan (Lower Triassic) formations and their equivalent Khuff Formation to the west host more than thirty-three known gas and gas-condensate fields within the basin that have evolved structurally in this tectono-sedimentary setting. This study integrates 3D seismic, well log, core, and thin section analysis from two wellbores drilled in the two studied fields. It applies seismic stratigraphic methods and principles to distinguish the architecture of relevant depositional tracts and interfaces and determine how they have evolved through geologic time. The results reveal that the different thicknesses of the Hormuz Salt (Cambrian) underlying the two studied fields, and the salt tectonic activity it has driven, are ultimately responsible for the distinctive structural evolutions and Permo-Triassic reservoir qualities observed in those fields. The significance of this finding is that by applying the developed seismic stratigraphy techniques integrated with existing well data on a regional basis offers the opportunity to identify undrilled exploration targets with an improved chance of containing high-quality Dalan/Kangan reservoir sections.

Diatoms’ Diversity in the Assessment of the Impact of Diamond and Oil and Gas Mining on Aquatic Ecosystems of the Central Yakut Plain (Eastern Siberia, Yakutia) Using Bioindication and Statistical Mapping Methods

Diamond and oil and gas production carries risks to the aquatic ecosystem. In Eastern Siberia, on the territory of the Central Yakut Plain, mining development of the Yakut diamond-bearing province and Tas-Yuryakh oil and gas condensate field has been underway for several decades. But the problem of studying negative consequences in the region is covered only from the point of view of the impact on terrestrial ecosystems. The purpose of this study was to assess the impact of diamond and oil and gas production on the aquatic ecosystems of the region using the bioindicative properties of diatoms. The work used previously widely tested methods of ecological mapping, JASP, and species–environments relationship analysis. The results of chemical analysis of water showed that in oil and gas production areas, there is no pollution with petroleum products, but the concentration of silicon and zinc is increased. The study identified key pollutants in the Central Yakut Plain and demonstrated the effectiveness of diatoms as bioindicators. Elevated chloride levels were found in diamond mining areas, and increased copper levels were noted in oil production regions. In the diatom flora of the region, 144 species were identified, of which 137 are indicator species. Natural and anthropogenic clusters of environmental factors are identified, characterized by a specific effect on the species composition and taxonomic structure of diatom communities. The results obtained are suitable for assessing the level of anthropogenic impact on aquatic communities of photosynthetic microorganisms in permafrost conditions.

Accounting for a capillary pressure jump in a saturated porous medium for a more correct calculation of hydrocarbon reserves

Relevance. The correct calculation of hydrocarbon reserves in various fields (oil, gas, gas condensate) is an important state task, because it allows you to properly organize field development in the future and ensure the rational use of natural resources of the state. In particular, the values of geological and recoverable reserves are assigned to a specific subsurface user and are recorded in departmental documents. Aim. To describe the effect associated with the calculations of the thermodynamic equilibrium of the mixture of hydrocarbons of the Karachaganak oil and gas condensate field at various formation depths with the capillary pressure jump taken into account. This makes it possible to clarify the value of the potential condensate-gas factor of reservoir gas and, as a result, to give a more accurate assessment of the geological reserves of hydrocarbon raw materials. Object. Analysis of the thermodynamic equilibrium of the hydrocarbon mixture of Karachaganak oil and gas condensate field, taking into account the capillary pressure jump, which takes place in a porous medium under reservoir conditions. Methods. Numerical modeling, analytical research. Results. Based on the previously developed methodology for calculating the phase equilibrium with the capillary pressure jump the correction of the potential condensate-gas factor of the formation gas of the Karachaganak oil and gas condensate field was carried out at various formation depths. The range of values of the condensate-gas factor difference for calculations both with and without capillary pressure jump was from 7,04 g/m3, with a condensate-gas factor value equal to 393 g/m3 for formation depth of 4000 m, to 64,47 g/m3, with a condensate-gas factor value equal to 547 g/m3 for formation depth of 4600 m. Based on the updated condensate-gas factor estimate, it is possible to clarify the condensate recovery coefficient during the development of a field without maintaining reservoir pressure or with partial maintaining reservoir pressure.

IMPROVING THE ACCURACY OF CALCULATING THE SUPER-COMPRESSIBILITY COEFFICIENT OF HELIUM BASED ON STATE EQUATIONS

To date, the Russian gas industry is developing a large number of deposits with a high helium content in the composition of the extracted gas, such as Chayandinskoye, Kovyktinskoye, Yaraktinskoye oil and gas condensate fields. Helium has never before been the object of detailed study during gathering and treatment, but today helium is an important resource that is used in many fields: military industry, medicine, shipbuilding, laser technology, space technology. The high demand for the component of the extracted gas has created requirements for the creation of a technology for separating it from gas. In addition, helium is a «cold» gas due to the weak interaction of its molecules, so it is difficult to model phase equilibrium at extremely low temperatures. As a result, improving the simulation of condensation of a helium mixture is undoubtedly an urgent task of the industry today. The purpose of the study is to increase the accuracy of calculating the thermodynamic properties of helium based on one of the modifications of the Peng-Robinson equation of state for thermobaric conditions corresponding to helium liquefaction processes.As the methods used in this work, a software module for calculating the selection of the Peneloux correction in the Java programming language was implemented. The results are tested on known experimental data, as well as a specialized software product for calculating the thermodynamic properties of fluids.The features of calculating the superconductivity coefficient of helium based on the cubic equation of state are presented. The optimal range of the Peneloux correction for the Peng-Robinson equation of state has been found, as well as an approximation formula that allows us to find the correction in the low temperature region. The results obtained will allow us to calculate the thermodynamic properties of helium with high accuracy. This will allow us to predict the volume of production and condensation of helium from natural gas, which is certainly an important task for the development of the country's economy.

ANALYSIS OF OIL RESERVES PRODUCTION AT THE BP8 DEVELOPMENT OBJECT OF THE TARASOVSKOYE OIL AND GAS CONDENSATE FIELD

Based on the example of the analysis of the development of the oil facility BP8 of the Tarasovskoye oil and gas condensate field, geological and technological factors that can cause a low current oil recovery factor with a high water cut of the product are considered. It is assumed that: 1) the low waterflood coverage coefficient is associated with artificial fracturing at the initial stage of development which led to a change in the type of reservoir from primary pore to porous-fractured; 2) a decrease in the displacement coverage coefficient is associated with the permeability heterogeneity of the object; 3) swelling of clay particles under the influence of injected fresh water led to a decrease in the displacement coefficient. An analysis of the development of the facility shows that without the use of new effective technological solutions for involving in the development of capillary-pinched oil reserves of the porous-fractured reservoir of the BP8 object, the final technological oil recovery factor will not exceed 0.240 instead of the approved 0.425. To increase development efficiency, it is recommended to carry out pilot work on drilling horizontal wells with multi-stage hydraulic fracturing, equipped with inflow control devices based on intelligent inflow indicators.

ANALYSIS OF TECHNOLOGIES FOR COLLARING LARGE-DIAMETER SECTIONS OF OIL AND GAS WELLS

The article considers issues on construction of deep oil and gas multi-column wells with an extended trunk. Drilling of such wells is relevant, for example, on offshore fields, where drilling from the shore with a vertical deviation of over 1000 m is much more economically feasible than from floating vehicles.For drilling wells with an extended trunk and passing through zones incompatible with drilling for geological reasons, it is necessary to begin construction of a well with landing a large diameter direction – often up to 720 mm. The article analyzes the emerging problems and ways to solve them by drilling large-diameter wells and landing casing string. The results of practical experience in conducting work in the Pechora Sea and at the Astrakhan gas condensate field are summarized, on the basis of which recommendations for carrying out similar works are given.When constructing wells, especially starting with a large diameter, it is not always possible to drill a well efficiently, even with drilling equipment ideally suited to specific geological and technological conditions. And this, in turn, can lead to losses of production time and materials, and in the extreme case – to emergency works. Based on the analysis carried out, the article proposes an algorithm of technological operations for drilling wells and landing large diameter directions, which increases the probability of successful drilling to the design depth.

INVESTIGATION OF STRUCTURAL AND MECHANICAL PROPERTIES OF TUBING STEELS

The study of the structural and mechanical properties of tubing steels used in wells at oil and gas condensate fields is of particular interest due to the resource intensity of these systems and the high cost of their repair and restoration. Tubing is operated under conditions of increased loads under the influence of its own weight, internal pressure and constant contact with highly aggressive media. As a result of simultaneous exposure to corrosive media and operational loads, tubing is the most consumable downhole material. The destruction and, as a result, the breakage of the tubing suspension occurs as a result of mechanical abrasion and cracking of the pipe body, the development of fatigue cracks in the thread, etc. Contact with aggressive agents of the extracted fluid and reservoir waters leads to various types of corrosion damage: ulcerative, pitting, corrosion fatigue, corrosion cracking, meza corrosion, biocorrosion, etc. Corrosion foci are localized on the inner and outer surfaces of pipes. The problem is complicated by the increased content of carbon dioxide (CO2), hydrogen sulfide (H2S), as well as the presence of various bacteria in oil and gas fields.This article is devoted to the study of the mechanical characteristics and microstructure of tubing steels that were in operation under conditions of complicating factors and highly aggressive corrosive environment. Tubing pipes Ø73x5.5 of strength group E. were tested. The following research methods were carried out: visual inspection; determination of the chemical composition of steel; determination of hardness; uniaxial tensile test; optical microscopy.As a result of the tests, quantitative characteristics of the mechanical properties of the steels were obtained. A significant decrease in the hardness, tensile strength and yield strength of steel has been established under prolonged exposure to complicated operating conditions. Metallographic studies have established the contamination of steels with silicates of various shapes, amounting to 3 and 2 points according to GOST 1778. Microstructural studies have been carried out. The fine-grained ferrite-carbide structure of steels has been revealed. This structure corresponds to the heat treatment mode: quenching followed by tempering.

Comprehensive assessment of emergency fire risks during oil and gas well drilling

The study aims to perform a comprehensive assessment of emergency fire risks when drilling oil and gas wells for open flowing of the well with gas flare combustion and the combustion caused by diesel fuel spills. The object is a well site of the oil and gas condensate field in the Irkutsk region. A retrospective analysis of emergency situations during oil and gas well drilling identified the most frequent types of accident - fires at oil and gas production facilities, open fountains and emissions from wells. Scenarios for these accidents were developed and event trees were built. Using them, options with the greatest possible damage caused by a fire were identified. The intensity of thermal radiation was estimated at various distances from the center of the flare with open flowing of the well with the gas flare combustion. The intensity of thermal radiation during a fire caused by diesel fuel spills was calculated for the destruction of three RVS-50 tanks. Safe distances from the accident site and possible fatal injuries to the personnel were identified.

STUDY OF THE EFFECTIVENESS OF THE APPLICATION OF COMPLEX GEOLOGICAL AND TECHNOLOGICAL MEASURES ON THE EXAMPLE OF GAS-CONDENSATE GENERATION IN THE CENTRAL PART OF THE PRIAXIAL ZONE OF THE DNIPROV-DNETZ BASIN

The field development system is the basis of hydrocarbon production, as it ensures the achievement of the necessary technical and economic indicators. Therefore, a high-perfor- mance development system is necessary to ensure maximum profit in the shortest possible time. Empirical studies, analysis and assessment of the effect of implementing a complex of geological and technological measures on the operational facility of a gas condensate field in the central part of the peri-axial zone of the Dnieper-Donets Basin were carried out in order to find methods for improving the existing gas and gas condensate field development systems and increasing gas extraction rates. It is shown that due to hydraulic fracturing, drilling and transfer of wells to the production facility during the five years of production of the produced gas, it is 7.8 % more than in the previous 21 hours, the rate of development of the field from 2015 to 2019 increased from 2.52 %. to 7.9 %, the average well yield increased by 83 % with an increase in the operational fund by 55 %. The results of studies of the effect of the application of geo- logical-technological measures are shown in the form of graphical dependences of the change in the rate of sampling on the number of production wells over time, the rate of daily gas sampling on the number of conducted geological-technological measures on the researched operational object over time. It has been determined that the main driver of the increase in gas production is the hydraulic fracturing of the formation in most of the operational wells, thanks to which the average increase in the output of the wells is 425 %. According to the results of geological and industrial data processing and analysis of changes in the rate of daily gas extraction over time, the effect of the performed operations is divided into three time segments lasting 15–18 months. The decrease in the duration of the effect from the increase in the fund of production wells and the conduct of hydraulic fracturing of the reservoir is due to the decrease in the volume of reservoir energy, therefore the investigated complex of measures will have the greatest effect when implemented at the initial stage of the development of a reservoir with similar geological parameters.

PROSPECTS FOR THE DEVELOPMENT OF THE SHEBELYN GAS CONDENSATE FIELD

The paper provides a brief geological and industrial characterization of the Shebelinsky gas-condensate field, including the height of the gas-bearing layer, the area of gas occurrence, porosity, permeability of collectors, effective gas-saturated thickness of the coppery sandstones, and araucarite strata. The peculiarity of the deposits lies in the low permeability and gas saturation, deterioration of collector properties of productive reservoirs from the lower to the upper and from the central to the peripheral part of the deposit. A structural map of the cover of coppery sandstones and a map of water saturation of all productive horizons are presented. The dynamics of gas reserves and reservoir pressures of the field over the years are shown, along with the authors; forecasts for their future dynamics. Calculations of the volumes of water saturation of horizons and the total volume of reservoir water that has invaded the gas-bearing part of the field have been conducted. An analysis of water saturation and its future prospects has been carried out. Statistical calculations of the dependence of water saturation volumes on time and reservoir pressure have been performed, indicating a decrease in the rates of water saturation at the late stage of field development. A geological section of the Shebelinsky field is presented, indicating the possibility of gas migration through tectonic faults. All factors influencing the maintenance of reservoir pressure within the deposit have been analyzed, including: contour water flooding; surface subsidence; internal waterdrive regime; the elasticity of rock formations, gas, and It is shown that drilling 12 deep wells within the Shebelinsky field did not reveal new deposits or caps but confirmed the presence of gas saturation to a depth of 5.5 thousand meters. The analysis of field development indicates a balance between gas production and its migration from deep horizons as of the year 2023. Approved development indicators and author’s options are provided, supported by actual field development. The conclusion is drawn that, due to migration with a volume of production of 1700– 1900 million m3, the field will operate for another 100 years.

Влияние мелкозалегающего газа на проектные решения по освоению морских газоконденсатных месторождений на шельфе арк­тических и суб­арк­тических морей

The article discusses issues related to shallow gas influence on design decisions for the development of offshore oil and gas condensate fields. The authors show the presence and distribution of shallow gas accumulations in the upper part of the geological section and its influence on the quality of seismic surveys. The release of shallow gas has caused many serious accidents at offshore drilling rigs and oil and gas production platforms. The main danger of shallow gas deposits is when drilling intervals for the conductor and surface casing due to the lack of blowout equipment at the wellhead. The authors analyze the areal and depth distribution of shallow gas in the Arctic and subarctic seas, and find out that small deposits of several hundred meters in size are most common. The main methods of detecting and studying shallow gas accumulations above gas-bearing structures are high-resolution seismic exploration, drilling of engineering-geological wells and pilot holes with well logging. The researchers reveal the main features of the wave pattern indicating the gas saturation in the upper part of the section. They present the main technical solutions for the development of the Lunsky, Kirinsky and Yuzhno-Kirinsky oil and gas condensate fields located on the self of Sakhalin Island and suggest changes in design solutions during their development in view of the shallow gas presence in the upper part of the geological section. The authors substantiate the need to create Russian software systems and methods of automated design for developing offshore oil and gas fields in the Arctic, taking into account geological and geophysical uncertainty, the shallow gas presence and technical factors.

Background Concentrations of Heavy Metals in the Surface Soil Horizon of Oil and Oil–Gas Condensate Fields in Eastern Siberia

Background Concentrations of Heavy Metals in the Surface Soil Horizon of Oil and Oil–Gas Condensate Fields in Eastern Siberia

INFLUENCE OF NATURAL FACTORS OF SUPPORTING RESERVOIR PRESSURE AT THE LATE STAGE OF DEVELOPMENT OF GAS CONDENSATE FIELDS

The object of the research is natural factors that can affect both the maintenance of reservoir pressure in the process of developing gas condensate fields and the recovery of depleted deposits. Such factors include: waterflooding of deposits, subsidence of the surface, elasticity of rocks, water and gas, initial gradients of reservoir pressure in deposits, capillary forces. When studying the recovery of reserves in depleted gas condensate fields, it is necessary to take into account the influence of the above factors on the maintenance of reservoir pressure in order to identify the volumes of gas that flow from deep horizons (external sources). The paper shows the dynamics of waterflooding volumes and average reservoir pressures over the years. It is emphasized that waterflooding does not significantly affect the maintenance of reservoir pressure. Correlation dependencies of waterflooding volumes over time and the dependence of waterflooding volumes on reservoir pressure are given. An original system for calculating the volume of the water pressure system is proposed for the purpose of forecasting further waterflooding of deposits. The influences of all the above factors on the process of maintaining reservoir pressure are taken into account. It is shown that for the Shebelinsky GCF, all these factors do not significantly affect the recovery of reserves. The influence of capillary forces and evaporation of water in deposits on the development processes from the point of view of maintaining reservoir pressure at the late stage of GCF operation is studied.

Simulation and Analysis of Temperature and Pressure Fields in the Wellbore of Self-Injection Well

Aiming at the problem of wellbore waxing in high-temperature, high-pressure and highly-waxed deep gas condensate reservoirs, a wellbore temperature/pressure field prediction model for self-injection wells was established with the site parameters of the Bozi gas condensate field in the Tarim Basin of China using the OLGA software. With the help of the parameters of example wells on site in the Bozi, wellbore temperature and pressure in the process of gas extraction from 10 self-injector wells were predicted, and the following findings were obtained: the temperature decreases gradually in the process of condensate gas well lifting, and the slopes of the temperature profile shown an overall The overall slope of the temperature profile shown a trend of gradually becoming larger, indicating that the temperature drop was increasing, and the single wells in the block reflect similar wellbore temperature profile characteristics. During the lifting process, the pressure gradually decreases, and the slope of the pressure profile does not change significantly, indicating that the pressure drop along the way was relatively constant, and the single wells in the block reflect similar wellbore pressure field distribution characteristics. Combining the temperature gradient and pressure gradient interpretation data of different wells and time interfering test wells in Bozi, and using them as the basis for temperature and pressure profile regression, the above 10 condensate wells in Bozi block were classified according to different temperatures and pressures, and the temperature and pressure profiles were regressed and fitted to fit the actual working conditions, which lays a data basis for the analysis of wax formation in the example wells in Bozi.

Mathematical modeling of thermal impact on a closed hydrate-saturated reservoir

In 2014, a crater was discovered in Yamal near the Bovanenkovo oil and gas condensate field. A number of researchers indicate among the possible causes of its occurrence an avalanche-like release of gas formed during the dissociation of gas hydrates. To carry out numerical experiments for analyzing such phenomena, a mathematical model of gas-liquid flow in a saturated porous medium was constructed taking into account the phase transition “gas + water  gas hydrate”. A two-dimensional axisymmetric formulation of the problem of heating from above through impermeable rocks of a closed hydrate-saturated reservoir, initially containing gas hydrate and gas, was carried out; to take into account external heat exchange, it is assumed that the reservoir is surrounded by rocks impermeable to matter. An algorithm for numerically solving the equations of the mathematical model is presented. A series of calculations was carried out, on the basis of which an analysis was made of the processes occurring in a closed hydrate-saturated reservoir, namely, changes in temperature, phase saturations and pressure. Calculations have shown that during the dissociation of gas hydrate in a closed reservoir, for a certain set of parameters, a significant increase in pressure can occur from 2.7 to 17.4 MPa. It has been revealed that the shallower the depth of a hydrate-saturated reservoir, the smaller its size and the greater the initial hydrate saturation, the greater increase in pressure can be observed, and, accordingly, the greater risk of violating the integrity of a closed impermeable porous medium and the subsequent avalanche-like release of gas from such object.

A Case Study of Gas-Condensate Reservoir Performance with Gas Cycling

The study examines the application of dry gas injection technology (cycling process) in different depletion stages (25%, 50%, 75%, 100% of the initial reservoir pressure, and the dew point pressure) at a gas condensate field. The injection took place with varying numbers of injection wells relative to production wells (4:1, 3:1, 2:1, 1:1, and 1:2). The study assessed the impact of dry gas injection periods, ranging from 1 to 3 years, on increasing the condensate recovery factor in a real gas condensate reservoir named X. A hydrodynamic model was used and calibrated with historical data, resulting in a comprehensive approach. Compared to the traditional depletion development method, this approach led to a significant 9% rise in the condensate recovery factor. The results indicate that injection has a positive effect on enhancing the recovery factor of condensate and gas when compared to primary development methods based on depletion. As a result, these findings facilitate a rapid evaluation of the possibility of introducing similar measures in gas-condensate reservoirs in the future for reservoir systems that have a low and moderate potential for liquid hydrocarbons C5+. The optimised multidimensional hydrodynamic calculations, utilising geological and technological models, are crucial in determining the parameters for the technological production and injection wells.

An Integrated Approach to Geomechanical Modeling of the Urikhtau Oil and Gas Condensate Field to Optimize Well Design

Background: The rock and geological section of the Urikhtau oil and gas condensate field is a complex geological system, including a variety of rocks of different densities and angles of occurrence, as well as disjunctive faults, which in turn complicates the process of designing and constructing wells. This article discusses the experience of geological and geomechanical modeling at this field.
 Aim: The purpose of this work is to consider geological and geomechanical modeling at the Urikhtau oil and gas condensate field as a method for further application in the design of well construction, taking into account the complexity of the geological structure of the field.
 Materials and methods: To build a 3D model, data from seismic and geophysical surveys were used, as well as historical data to correlate calculations.
 Results: The result of the modeling is the development of recommendations for the well profile, its design and optimal values of drilling fluid density, which will create a safe “drillability window” for well construction.
 Conclusion: Geological and geomechanical modeling allowed us to develop key recommendations for well design, including optimizing drilling fluid density and ensuring wellbore stability.