Modeling Proppant Transport Through Perforations in a Horizontal Wellbore

Wu, Chu-Hsiang; Sharma, Mukul M.

doi:10.2118/179117-pa

Cited by 44 publications

(9 citation statements)

References 17 publications

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“…Sensitivities to particle size, orientation, velocity, and concentration are presented. Recently, Computational Fluid Dynamic (CFD) simulations have been employed to investigate the problem of particle turning into a single perforation [3,4,5,6]. Results demonstrate that under certain conditions there is no sensitivity to particle size and carrying fluid viscosity, which seemingly contradicts the observations of [1].…”

Section: Introductionmentioning

confidence: 99%

A model for proppant dynamics in a perforated wellbore

Dontsov¹

2023

Preprint

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This paper presents a model to simulate behavior of particle-laden slurry in a horizontal perforated wellbore with the goal of quantifying fluid and particle distribution between the perforations. There are two primary phenomena that influence the result. The first one is the non-uniform particle distribution within the wellbore's cross-section and how it changes along the flow. The second phenomenon is related to the ability of particles to turn from the wellbore to a perforation. Consequently, the paper considers both of these phenomena independently at first, and then they are combined to address the whole problem of flow in a perforated wellbore. A mathematical model for calculating the particle and velocity profiles within the wellbore is developed. The model is calibrated against available laboratory data for various flow velocities, particle diameters, pipe diameters, and particle volume fractions. It predicts a steady-state solution for the particle and velocity profiles, as well as it captures the transition in time from a given state to the steady-state solution. The key dimensionless parameter that quantifies the latter solution is identified and is called dimensionless gravity. When it is small, the particles are fully suspended and the solution is uniform. At the same time, when the aforementioned parameter is large, then the solution is strongly non-uniform and resembles a flowing bed state. A mathematical model for the problem of particle turning is developed and is calibrated against available experimental and computational data. The key parameter affecting the result is called turning efficiency. When the efficiency is close to one, then most of the particles that follow the fluid streamlines going into the perforation are able enter the hole. At the same time, zero efficiency corresponds to the case of no particles entering the perforation. Solutions for the both sub-problems are combined to develop a model for the perforated wellbore. Results are compared (not calibrated) to a series of laboratory and field scale experiments for perforated wellbores. Comparison with the available computational results is presented as well. In addition, the comparison is presented in view of the parametric space defined by the dimensionless gravity and turning efficiency. Such a description allows to explain seemingly contradictory results observed in different tests and also allows to highlight parameters for which perforation orientation plays a significant role.

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Section: Introductionmentioning

confidence: 99%

A model for proppant dynamics in a perforated wellbore

Dontsov¹

2023

Preprint

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“…An optimal proppant distribution increases the likelihood of maximizing production from unconventional shale gas and oil resources. Therefore, several investigations were conducted to understand the proppant distribution behavior numerically using computational fluid dynamics (CFD). − …”

Section: Introductionmentioning

confidence: 99%

Experimental Investigation of the Impact of Particle Size on Its Distribution within a Horizontal Wellbore

Alajmei,

Budiman,

Aljawad

2023

ACS Omega

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Fracture conductivity is directly affected by an uneven proppant distribution, which affects the productivity of a well. The distributions of 40/70 mesh white sand compared to 100 mesh brown sand in a horizontal wellbore were investigated in this study. The apparatus used to conduct these tests was a 30 ft-long transparent horizontal wellbore with three perforation clusters. The proppant distribution was examined experimentally by injecting slurries at three different injection rates ranging from 20 to 75 gpm. The proppant concentration of both sands increased for each test from 0.5 to 2 ppg. The proppant concentrations and injection rates were used with multiple perforation configurations (orientations) including extreme limited entry perforations. The results confirmed that the injection rates significantly affected the proppant distributions across the different perforation clusters. Even distribution of the 40/70 mesh sand can be obtained using a 1 shot per foot (SPF) top perforation design. The 100 mesh sand was evenly distributed using a 4 SPF perforation configuration. The settling percentage was calculated for each experiment to determine the quantity of 40/70 mesh and 100 mesh sand settled at the bottom of the horizontal wellbore. A carrier fluid can suspend the sand more effectively with a higher injection rate, reducing the average sand settling to 2% in the case of the 100 mesh sand compared with approximately 8% for the 40/70 mesh sand at similar injection rates. This research confirms the need to use a 100 mesh at high injection rates to reduce sand settling during the hydraulic fracturing process.

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“…The coupled CFD–DEM approach has a great advantage for obtaining microscale particle-motion information and precisely capturing the movement of proppants in the wellbore under different suspension flow conditions. Wu and Sharma modeled the proppant transport through perforations in a horizontal wellbore for understanding the proppant placement mechanism. A series of suspension flow parameters on particle transport efficiency were investigated.…”

Section: Introductionmentioning

confidence: 99%

Modeling Temporary Plugging Agent Transport in the Wellbore and Fracture with a Coupled Computational Fluid Dynamics–Discrete Element Method Approach

et al. 2021

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As the consumption of oil and gas resources is increasing, secondary exploitation in old wells and unconventional oil and gas exploitation methods are becoming increasingly important. As a result of complex reservoir environments and the reservoir properties, such as ultralow porosity and permeability, hydraulic fracturing is an important means to achieve effective recovery. Temporary plugging fracturing is currently an efficient fracturing technology and is suitable for refracturing of old wells and multi-stage fracturing in unconventional reservoirs, which is conducive to constructing complex fracture networks and increasing production. Recently, in the field of temporary plugging fracturing, how to design the operation parameters of temporary plugging fracturing still remains ambiguous and empirical. In this paper, a numerical simulation study of the liquid–solid two-phase flow of the temporary plugging agents and the fracturing fluid was conducted using two physical models: a wellbore flow model and a wellbore–fracture temporary plugging model. The transport processes of the temporary plugging agents along with fracturing fluid in a vertical wellbore, in a horizontal wellbore, and at a fracture position were simulated. Simulations that coupled computational fluid dynamics and the discrete element method were used in the simulation process. The effects of the temporary plugging agent concentration, particle size, particle size ratio, fracturing fluid rate, and fracturing fluid viscosity on the migration process of the temporary plugging agent were investigated. The simulation results show that a higher concentration and viscosity of a temporary plugging agent help to sustain the flow stability in the vertical wellbore, while the viscosity and flow rate of the fracturing fluid have an impact on whether sedimentation of the temporary plugging agent occurred in the horizontal wellbore. In addition, the particle size ratio and concentration of the temporary plugging agent are the key factors for a successful bridging and plugging. For a specific field application in Longmaxi Formation, Sichuan Province, the operation parameters of temporary plugging fracturing have been designed and achieved a successful refracturing treatment.

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Modeling Proppant Transport Through Perforations in a Horizontal Wellbore

Cited by 44 publications

References 17 publications

A model for proppant dynamics in a perforated wellbore

A model for proppant dynamics in a perforated wellbore

Experimental Investigation of the Impact of Particle Size on Its Distribution within a Horizontal Wellbore

Modeling Temporary Plugging Agent Transport in the Wellbore and Fracture with a Coupled Computational Fluid Dynamics–Discrete Element Method Approach

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