Fractured-vuggy Reservoirs Research Articles

The dual laterolog response of fractured-vuggy reservoirs based on conductivity tensor and Maxwell–Garnett mixing rule

Dual laterologs measure reservoir resistivity at deep and shallow depths around a wellbore, a thorough understanding of the dual laterolog response of fractured-vuggy reservoirs is key for reservoir identification and saturation evaluation. The joint development of the fracture and vugs complicates the laterolog response of fractured-vuggy reservoirs. In this study, the conductivity model of the dipping anisotropic structure on the horizontal plane was analyzed according to the theory of the conductivity tensor. Then, based on the Maxwell–Garnett mixing rule, a conductivity model of the vuggy reservoirs was established. On this basis, the dual lateral conductivity model of fractured-vuggy reservoirs was established by equating the vuggy reservoir to the matrix and the dipping anisotropic structure plane to the fracture plane. Furthermore, based on the dual lateral conductivity model and physical experiments, the dual laterolog responses with respect to the fracture dip angle, fracture porosity, and vug porosity were systematically analyzed. The study revealed that (1) the fracture dip angle significantly affects the separation of the dual laterolog. In other words, at a low dip angle, the fracture shows a negative separation of the dual laterolog, whereas a positive separation at a high dip angle; (2) for vuggy reservoirs, the development of vugs decreases the deep and shallow laterologs, and the more the vugs developed, the greater the decrease; (3) for fractured-vuggy reservoirs, the dual laterolog response is mainly controlled by fractures. The development of vugs did not change the negative or positive separation of dual laterologs with different fracture dip angles.

Automatic Evaluation of an Interwell-Connected Pattern for Fractured-Vuggy Reservoirs Based on Static and Dynamic Analysis

The types of fractured-vuggy reservoirs are diverse, with dissolution holes and fractures of different scales as the main reservoir spaces. Clarifying the connectivity between wells is crucial for improving the recovery rate of fractured-vuggy reservoirs and avoiding problems of poor water- flooding balance and serious water channeling. A traditional dynamic connected model hardly describes the geological characteristics of multiple media, such as karst caves and fractures, which cause multiple solutions from the calculation. The static analysis is the basis for connectivity evaluation. In this study, we designed an intelligent search strategy based on an improved A* algorithm to automatically find a large-scale fractured-vuggy connected path by seismic multi-attribute analysis. The algorithm automatically evaluates the interwell-connected mode and clarifies the relationship between the static connected channel and the fractured-vuggy space configuration. Restricted by various factors, such as seismic identification accuracy, a static connectivity study can hardly determine the filling and half-filling inside the channel effectively, even if it can identify the main connectivity channels. An injection-production response analysis based on dynamic production data can more accurately reflect the reservoir’s actual connectivity and degree of filling. This paper further studies dynamic response characteristics based on multifractals combined with production data. To reduce the evaluation uncertainty, we combined the static and dynamic connected analysis results to comprehensively evaluate the main connected modes, such as large fracture connectivity, cavern connectivity, and fractured-vuggy compound connectivity. We use the Tahe oilfield as an example to carry out an automatic evaluation of the connected pattern. The comprehensive evaluation results of the new algorithm were basically consistent with the tracer test results and can better reflect the interwell space-configuration relationship. Our model has certain guiding significance for the adjustment of working measures during waterflooding in fractured-vuggy reservoirs.

Utilization mechanism of foam flooding and distribution situation of residual oil in fractured-vuggy carbonate reservoirs

The development of fractured-vuggy carbonate reservoirs is extremely difficult because of the complex fractured-vuggy structure and strong heterogeneity. Foam flooding is a potential enhanced oil recovery (EOR) technology in fractured-vuggy carbonate reservoirs. Based on the similarity criterion, three types of 2D visual physical models of the fractured-vuggy structure were made by laser ablation technique, and a 3D visual physical model of the fractured-vuggy reservoir was made by 3D printing technology. Then the physical analog experiments of foam flooding were carried out in these models. The experimental results show that foam can effectively improve the mobility ratio, control the flow velocity of the fluid in different directions, and sweep complex fracture networks. The effect of foam flooding in fractures can be improved by increasing foam strength and enhancing foam stability. The effect of foam flooding in vugs can be improved by reducing the density of the foam and the interfacial tension between foam and oil. Three types of microscopic residual oil and three types of macroscopic residual oil can be displaced by foam flooding. This study verifies the EOR of foam flooding in the fractured-vuggy reservoir and provides theoretical support for the application of foam flooding in fractured-vuggy reservoirs.

Experiments of Gas-water Cooperative Flooding in Fracture Network System

Fractures are the main seepage channels and the critical oil storage space in fracture-vuggy reservoirs. In this paper, the staggered fracture system was abstracted into an orthogonal fracture network. A physical experimental model was made with a laser-etched acrylic plate. The physical experiments of water flooding, gas flooding, water-alternating-gas, and simultaneous-water-and-gas were carried out using the physical experiment model of the fracture network. The results show that gas is more accessible to break through in gas flooding than water in water flooding, resulting in a lower recovery factor. Water-alternating-gas and simultaneous-water-and-gas can effectively improve oil displacement efficiency through the action of gravity difference and the interaction mechanism of gas and water. Increasing the injection rate properly, increasing slug size properly before water and gas breakthrough during water-alternating-gas simultaneous-water-and-gas, and decreasing the gas-water ratio properly during simultaneous-water-and-gas simultaneous-water-and-gas can effectively expand the sweep scope and improve recovery. The experiment provides a basis for efficient water and gas injection development in fracture-vuggy reservoirs.

Research on productivity prediction and identification of main control factors of fractured vuggy reservoirs based on machine learning

For SHB oil and gas reservoir, natural fracture development using support vector machine (SVM) and support vector regression method to SHB oil and gas field with the main fault zone of 18 flowing Wells for the single well production forecast, drilling and well completion by input data, production data and dynamic data, bottom hole flowing pressure, adjoining well production data as the input variables such as time, The predicted output value is used as the output variable for yield prediction. The results show that SVM is not only more efficient than the traditional DCA method, but also avoids geological modeling and a large amount of historical fitting work. It has a certain reference value for the formulation of rational production system in SHB block.

Mechanisms of remaining oil formation by water flooding and enhanced oil recovery by reversing water injection in fractured-vuggy reservoirs

To get a deeper understanding on the formation mechanisms and distribution laws of remaining oil during water flooding, and enhanced oil recovery (EOR) mechanisms by reversing water injection after water flooding, 3D visualization models of fractured-vuggy reservoir were constructed based on the elements and configuration of fractures and vugs, and typical fracture-vug structures by using advanced CT scanning and 3D printing technologies. Then, water flooding and reversing water injection experiments were conducted. The formation mechanisms of remaining oil during water flooding include inadequate injection-production well control, gravity difference between oil and water, interference between different flow channels, isolation by low connectivity channel, weak hydrodynamic force at the far end. Under the above effects, 7 kinds of remaining oil may come about, imperfect well-control oil, blind side oil, attic oil at the reservoir top, by-pass residual oil under gravity, by-pass residual oil in secondary channel, isolated oil in low connectivity channel, and remaining oil at far and weakly connected end. Some remaining oil can be recovered by reversing water injection after water flooding, but its EOR is related to the remaining oil type, fracture-cavity structure and reversing injection-production structure. Five of the above seven kinds of remaining oil can be produced by six EOR mechanisms of reversing water injection: gravity displacement, opening new flow channel, rising the outflow point, hydrodynamic force enhancement, vertically equilibrium displacement, and synergistic effect of hydrodynamic force and gravity.

Prediction of petrophysical classes and reservoir beds through microfacies and pore types characterization, Tahe Ordovician naturally fractured vuggy carbonates

Carbonates commonly present a stacking-pattern architecture determined by the depositional processes despite the diagenetic modifications. This study integrates spectral cyclostratigraphy and petrophysical analysis to locate prolific reservoir beds to optimize reservoir development. This involves subdividing the reservoir succession into different hierarchical units to understand the variation of microfacies and pore-structure types. The variation trends and discontinuity surfaces (chronostratigraphic and lithostratigraphic boundaries) are determined by conjointly interpreting the prediction error filter analysis (PEFA) and integrated PEFA (INPEFA) and synthetic seismic trace and seismogram. We define the rock texture types (microfacies) through self-consistent approximation based on the INPEFA log while considering the variation of depositional sequence and grain size, core/thin-section petrography, and borehole electrical image interpretation. We establish lithology-depth and petrophysical classes-depth profiles using largely well-log data and present new petrophysical classes for naturally fractured vuggy reservoirs. We predict porosity and permeability from the distribution of high-frequency cycles and lithofacies while considering the implications of diagenesis. The results indicate that the depositional processes and diagenesis largely control the quality of the reservoir beds in response to the relative sea-level variations. The reservoir beds comprise the reservoir units with connected-vugs- and fractures-dominated pore systems and the horizons with microporosity-dominated pore systems that are candidates for secondary recovery processes. The study proposes a total porosity variation model that describes an external cardiac compression-like depth profile, revealing alternation between low/tight and high-porosity horizons, with the highly porous intervals associated with the solution-enlarged porosity zones. Permeability varies with the pore type mixing and rock texture type rather than the total porosity. The method well applies to distinguish flow conduits from baffles and barriers in complex carbonate reservoirs.

Amplitude semblance and its fusion with the third-generation coherence for characterization of fractured-vuggy carbonate reservoirs

Abstract In the Tarim Basin, the main hydrocarbon reservoirs of Ordovician carbonate rocks are fractured-vuggy reservoirs, of which the underground river type reservoirs are an important type. Seismic coherence attribute can highlight seismic discontinuity caused by tectonic movements, reservoir boundaries, sedimentary body boundaries or other factors. Thus, it is a widely used key technique in seismic interpretation. There are many algorithms to determine the coherence. Typically, the coherence algorithm based on eigen-structure analysis is the most robust, but is sensitive to waveform differences and insensitive to amplitude differences. This paper proposes an amplitude coherence attribute to measure semblance of root-mean-square (RMS) amplitudes of multiple traces and fuses it with the third-generation coherence (C3) to describe the boundary of underground river. Model test and case study prove that the proposed fused algorithm can effectively identify the amplitude and waveform differences in seismic data.

A novel method for modeling oil-water two-phase flow in fractured-vuggy carbonate reservoirs considering fluid vertical equilibrium mechanism

Fractured-vuggy carbonate reservoirs have great potential for development with diverse reservoir space types and very complicated fluid flow dynamics. The height of high-angle fractures and cavities in fractured-vuggy carbonate reservoirs can reach several meters and fluids are extremely prone to transport and mass exchange along the vertical direction. The vertical equilibrium phenomenon can significantly affect the oil-water spatial distribution in this type of reservoir. However, the existing numerical simulation methods do not consider the effect of fluid vertical equilibrium mechanism, and the predicted results often have large deviations from the actual situation. In this paper, considering the connectivity structure of typical fractured-vuggy unit, several visualized fractured-vuggy physical models are firstly prepared by 3D printing technology, and the vertical equilibrium time of oil and water under different fractured-vuggy combination modes are determined using the vertical equilibrium experiments. ‘Dynamic reconstruction’, a multi-scale vertical equilibrium method, is employed for the decoupling calculation of fluid saturation and pressure profiles in coarse-scale and fine-scale grids of fractured-vuggy reservoirs. Compared with indoor experiments, the simulated results when considering the fluid vertical equilibrium are much closer to the experimental phenomena than that calculated by the traditional method, proving the proposed method's reliability. Finally, the vertical equilibrium model is applied to study two-phase fluid flow in a typical fractured-vuggy unit of Tarim oilfield. The proposed method has been proven to reveal the flow characteristics of oil-water two-phase and remaining oil distribution in fractured-vuggy carbonate reservoir more accurately.

Experimental Study on Production Characteristics of Bottom Water Fractured-Vuggy Reservoir

To assess the high-pressure production characteristics of double-vug reservoirs with bottom water in the Tahe Oilfield, in this study, a high-pressure physical simulation experiment apparatus is built for double-vug reservoirs with bottom water. The high-pressure production characteristics of “vug-fracture-vug” reservoirs under different bottom water characteristics are studied experimentally, and fracture-vug relationship and oil recovery rates are explored. According to the findings, the oil recovery rate significantly affects the development effect of double-vug reservoirs with bottom water, and bottom water provides sufficient energy for reservoir development. Furthermore, considering the possible occurrence of water invasions, the production rate control must receive close attention in the development process to avoid strong water channeling. Constant-pressure bottom water has sufficient energy and can quickly replenish vug energy. Therefore, the recovery percentage and bottom water invasion and retention volume of fractured-vuggy reservoirs with constant-pressure bottom water are higher than those of fractured-vuggy reservoirs with constant-volume bottom water. Under the appropriate control of production factors, the presence of bottom water can noticeably improve the development effect of fractured-vuggy reservoirs.

Preparation of dual network semi-solidified gelled-foam for sealing gas channeling in fractured-vuggy reservoirs

Gas flooding is an effective EOR process for carbonate fractured-vuggy reservoirs worldwide. With the large-scale application of gas flooding, the problem of gas channeling is emerging inevitably and restricts the improvement of oil recovery. Foaming can alleviate such problems due to its high viscosity. However, many factors lead to the poor stability of conventional foam or even gelled-foam in fractured-vuggy reservoirs, such as Ostwald maturation, lack of support from pore-throat units, and weak regeneration ability, dilution of formation water, high temperature, high salinity, etc. Therefore, a novel dual network semi-solidified gelled-foam was designed to solve the gas channeling problem in fractured-vuggy reservoirs. It overcomes the shortcoming of fast foam volume attenuation due to temperature rising. The new foam system consists of an ionic crosslinking network (sodium alginate, Ca2+) and a covalent crosslinking network (acrylamide, polyacrylamide, crosslinking agent). The characteristics of sodium alginate, which can rapidly react with divalent cations (Ca2+) in formation water to generate an ionic crosslinking network, forming a protective film to enhance foam stability in the first stage. Acrylamide, polyacrylamide, and crosslinking agent (methenamine and resorcinol) were used to form the second network (covalent crosslinking network), which can effectively enhance the high temperature stability of the foam. After optimization, the dual network semi-solidified gelled-foam was obtained, and the half-life can reach 15d in a high temperature and high salinity environment (130 °C, 22.37 × 104 mg/L). Meanwhile, the new foam system also showed higher viscosity, high oil tolerance and plugging capability. This unique designed gelled-foam offers high application potential in deep fractured-vuggy reservoirs. It effectively solves the gas channeling problem in gas flooding production in fractured-vuggy reservoirs worldwide.

Structural diagenesis of deep carbonate rocks controlled by intra‐cratonic strike‐slip faulting: An example in the Shunbei area of the Tarim Basin, NW China

AbstractThe Ordovician fracture‐cavity reservoirs in the Shunbei area of the Tarim Basin, China, afford an exceptional opportunity to use petrological and geochemical data to investigate structural diagenesis in deep low‐porosity (‘tight’) carbonate rocks. We obtained the relative timings for the development of fracture veins using petrological and cathodoluminescence analyses of minerals from representative samples. Textural observations combined with geochemical data determined the source and timing of the mineral‐forming fluid. The conceptual model of the overall temporal evolutions of structure and fluid flow developed herein indicates that fluid flow is a consequence of strike‐slip fault activity and the local stress state. Strike‐slip faults control the development of fractured–vuggy reservoir space and provide driving force for fluid flow along and across layers. Simultaneously, the direction of fluid migration can be influenced by local stress conditions, while compressive stress may restrict fluid flow. Results of this study suggest that open fractures develop as a result of structural diagenesis, rather than resulting from a single structural factor. The findings of this study can be used to inform the exploration and exploitation of deeply buried faulted carbonate reservoirs worldwide.

Productivity Prediction of Fractured-Vuggy Reservoirs under Time-Varied Flow Rates and Bottom Hole Flow Pressures

Fracture-vuggy oil reservoirs contain micrometer-sized dissolved secondary pores, fractures, and meter-sized karst caves. Generally, the researches on the flow mechanism of fractured-vuggy reservoirs are based on the assumption of karst cave-fracture-matrix triple medium that gives a partial differential equation which the pressure satisfies. This triple medium flow equation lays the basics for the well testing theory of fractured-vuggy reservoirs. However, the triple medium equation cannot reflect the actual existence of the karst cave volume in geology. Recently, we proposed a theory of fracture-cave seepage flow coupled with vug pressure wave which takes the vug size into consideration and thus can better describe the fracture-vuggy reservoirs. On the basis of this theory, this work combines the change of formation pressure with time, Duhamel’s theorem, and well testing theory to obtain the mathematical expression of time-varied bottom hole pressure and flow rate in Laplace space. Then, the dynamic inflow performance relationship (IPR) curve of fractured-vuggy reservoir is obtained by inverse Laplace transformations. This dynamic IPR curve can predict the productivity for fractured-vuggy reservoirs using parameters from well test interpretations of pressure recovery. The correctness of this productivity prediction method is verified by filed fractured-vuggy oil well. This productivity prediction method not only utilizes and expands the application of well test interpretation data but also shortens the test time and reduces test costs, which is important for oil development.

Research on well selection method for high-pressure water injection in fractured-vuggy carbonate reservoirs in Tahe oilfield

Carbonate fractured vuggy reservoir in Tahe oilfield belongs to fractured vuggy reservoir with strong heterogeneity. After a period of production, the elastic energy of the cave formation weakens caused insufficient liquid supply, It is faced with a series of problems in some single wells, such as low water injection efficiency, high water cut, short production period, and so on. The introduction of high-pressure water injection technology can greatly restore the productivity of single wells and improve reservoir recovery. It is one of the effective new technology to develop fractured vuggy carbonate reservoirs. At present, this technology is still in the initial stage, with no clear guide method that selecting wells for high-pressure water injection. Among them, the determination of the high-pressure water injection well selection method is particularly important for the development effect of a single well. Based on the analysis of the mechanism of high-pressure water injection and combined with the field data, this paper formulates the well selection method of high-pressure water injection from three aspects: Karst Characteristics, reservoir structure and reservoir parameters:①Karst geological data show the characteristics of oil-increasing substances such as many abnormal bodies around the well and wide lateral distribution; ②The reservoir structure has multiple sets of connected karst caves with connectivity potential; ③After the failure of conventional water injection, the fracture passage effect is poor and the energy of the remote well is insufficient. The independent high-pressure water injection development method can reduce the channel seepage resistance, expand the scope of the injected water, and realize increased production. Up to now, Tahe oilfield has used the method to implement high-pressure water injection 41 well, achieving an average single well cumulative incremental oil production of 3211 tons, with an effective rate of 85.4%, which has a satisfactory application value.

Research on the Depletion and Recovery Characteristics of Fault-Karst Reservoirs

A fractured-vuggy carbonate reservoir is a special reservoir formed by long-term physical, chemical, and geological processes. Its reserves are large in scale and widely distributed, showing the characteristics of free flow-seepage coupling. Conventional simulation is usually simplified by equivalent permeability, which cannot reflect the actual development characteristics. Given this, the flow in caves and fractures is treated with free flow, using the Navier–Stokes equation. The seepage simulation is used for other areas, and the Darcy formula is used. Finally, the simulation results are obtained by coupling, and the influence of oil production speed, fracture-cavity size, fracture-cavity location, dynamic viscosity, permeability, and other factors on bottom pressure is analyzed to effectively guide the field development. The results show that the production pressure of fractured-vuggy reservoirs diffuses from the central fractured-vuggy area to the surrounding matrix, and the pressure increases from the fractured-vuggy area to the surrounding matrix. The flow velocity in the seepage area is relatively stable and flows gently into the middle fracture cavity from all directions. There will be eddy current in the free-flow area. Different factors have different effects on the development. The oil production speed and oil dynamic viscosity are positively correlated with it, while the formation permeability is negatively correlated with it. The size and location distribution of fracture cavity will also have a certain impact. Simulation in advance can effectively avoid some reservoir development problems.

The effect of temperature, natural fractures and vugs on the acidizing process in fractured-vuggy reservoirs with hydro-thermal-chemical coupled modeling

Matrix acidizing is a common stimulation measure used for carbonate reservoirs in the petroleum industry. Carbonate rocks are characterized by rich fractures and vugs, however, limited work has been done to date to examine the effect of fractures and vugs on the carbonate acidizing process in three-dimensions (3D). In this paper, the temperature and vugs with high porosity are introduced into the two-scale continuum (TSC) model. The 3D radial fractured-vuggy carbonate acidizing process is simulated using the present hydro-thermal-chemical (H-T-C) coupled model. The sensitivity of temperature, natural fracture and vug parameters on the acidizing process is evaluated. The results show that a high-temperature significantly improves the optimal injection rate of the acid. The existence of fractures and vugs significantly reduces the amount of acid consumed as the acid breaks through the formation. For fractures of the same direction, with the increase of fracture number and fracture length, the normalized initial pore volume (PVBT) is reduced first, and then stabilizes. For intersecting fractures, there is an optimal number and length of fractures with the minimum PVBT value. Furthermore, an increase in the vug size reduces the PVBT value. There is an optimal number of vugs with the minimum PVBT value. Finally, some possible extensions of the current work are discussed.

Experimental research on the mechanisms of improving water flooding in fractured-vuggy reservoirs

Fractured-vuggy reservoirs have extremely complex reservoir characteristics, leading to a large amount of remaining oil not being recovered after water flooding. In order to solve the problem of the low recovery in fractured-vuggy reservoirs, we utilized 3D printing technology to fabricate two-dimensional and three-dimensional experimental models based on the typical reservoir structure. A series of experiments with different models on improving water flooding is conducted to study the production improvement effect. The difference in oil-water distribution or oil saturation distribution before and after improved water flooding is also compared, and the mechanism is analyzed. The results show that the oil-water gravity differentiation is the most critical factor affecting the remaining oil distribution, and changing the injected pressure or its propagation direction is the root of improving water injection. Reversing injection-production wells, increasing injection strength, water plugging, and cyclic water injection can effectively increase the sweeping scope or displacement efficiency. The attic oil, residual oil in filling medium, bypass remaining oil, and water cone remaining oil can be produced by one or more improving water flooding methods. This paper provides effective measures and mechanisms for the efficient and rapid development of fractured-vuggy reservoirs.

Investigation on replacement of blind cave remaining oil by water injection in fractured-vuggy reservoir

Due to the complex connectivity of fractured-vuggy reservoirs, there is always a large amount of remaining oil after water flooding development. The blind cave remaining oil, one of the primary remaining oil occurrence forms, is the most difficult to recover. Based on the distribution pattern of these types of remaining oil, the paper designed and manufactured a variety of tube-cave models. Through physical experiment, numerical experiment and theoretical calculation, the ability for water to displace blind cave remaining oil in different conditions, oil-water convective displacement characteristics and the critical parameters for remaining oil development were studied, respectively. The results show that the interfacial tension, fracture width and oil-water gravity difference are the most important parameters to determine whether the remaining oil can be exploited; the wall wettability and oil viscosity mainly affect the oil-water displacement rate due to the loss of non-wetting internal friction. In addition, the interfacial tension should be reduced to 1 mN/m or lower to accelerate the convective flow in the fractures, so that most of the blind cave remaining oil can be developed. This paper provides the influencing factors and exploitation measures of the blind cave remaining oil in fractured-vuggy reservoirs.

Improved triple porosity model for calculating porosity exponent of fractured-vuggy reservoirs based on Maxwell-Garnett mixing rule and anisotropic conductivity analysis

Porosity exponent (m) is a key parameter for calculating reservoir oil and gas saturation and evaluating reservoir effectiveness; the development of matrix pores, vug pores, and fractures makes the m response regularity of fractured-vuggy reservoirs unclear, which makes the accurate calculation of saturation difficult. By applying Maxwell-Garnett mixing rule to vuggy reservoirs and conductivity tensor analysis to fractured reservoirs, an improved Triple Porosity Model considering fracture dip angle is established. The newly improved Triple Porosity Model clarifies the response regularity of m to the matrix pores, vug pores, fracture pores, and fracture angles. Based on the improved Triple Porosity Model, the response regularity chart of m is further established. The findings show that: (1) m increases with the increase of fracture dip angle (θ) and the development of vugs; (2) m increases with the development of high-angle fractures and decreases with the development of low-angle fractures; (3) in fractured reservoirs, the fracture dip angle of 33° is the critical dip angle that determines the relationship between m and matrix porosity exponent (mb); (4) an increase in matrix porosity will weaken the influence of vugs, fractures, and fracture dip angle on m, which will eventually make m converge to mb. The field application of fractured-vuggy reservoirs shows that the water saturation calculated by the improved Triple Porosity Model is better in agreement with the core analysis results.

Numerical Study on Particle Transport and Placement Behaviors of Ultralow Density Particles in Fracture-Vuggy Reservoirs

Summary A solid/liquid two-phase flow numerical model based on the computational fluid dynamics-discrete element method (CFD-DEM) model was established to study the transport and settlement law of ultralow-density (ULD) particles during the waterdrive channel adjustment of the Tahe carbonate fractured-vuggy reservoir. The mass, momentum, and turbulence equations of the fluid phase were established in Euler coordinates, whereas the particle motion equations were established based on Newton’s second law. The interaction between the ULD particles was described using a soft sphere model, and the water and particle phases were bidirectionally coupled. Meanwhile, virtual experiments were conducted to calibrate the contact parameters of the particles, and parallel plate experiments were performed to validate the model. Using numerical simulations of particle transport behavior in fractures, the process and characteristics of particle transport and placement in fractures are demonstrated, which can be described by the settlement profile angle and equilibrium gap height. According to parameterized simulations, the change law of the settlement profile angle and equilibrium gap height with different parameters such as particle size, pump displacement, and fracture width are demonstrated, which is helpful for the prediction of migration and accumulation of ULD particles in fracture-vuggy reservoirs.