Analytical Solution of Transient Multiphase Flow to a Horizontal Well With Multiple Hydraulic Fractures

Shojaei, Hasan; Tajer, Ehsan

doi:10.2118/165703-ms

Cited by 10 publications

(4 citation statements)

References 35 publications

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“…Analytical solutions have been used in petroleum industry for different purposes, including the prediction of flow and pressure behavior of traditional vertical wells (Van Everdingen and Hurst, 1949) and more-complex multi-fractured horizontal wells (Shojaei and Tajer, 2013). Analytical solutions are faster and more convenient as compared to numerical techniques, but lack generality in most cases.…”

Section: Methodology Analytical Solutionsmentioning

confidence: 99%

Evaluation of Annular Pressure Losses while Casing Drilling

Dokhani

Shahri

Karimi

et al. 2013

Day 1 Mon, September 30, 2013

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Casing Drilling is an innovative drilling method wherein the well is drilled and cased simultaneously. The small annulus of Casing Drilling can create a controllable dynamic ECD (Equivalent Circulating Density). Casing Drilling technology permits the same desired ECD as conventional drilling to be achieved using a lower, but optimized, flow rate, rheological properties, and mud weight. In this paper, the frictional pressure loss during Casing Drilling operation is evaluated using Computational Fluid Dynamics. Annular pressure losses have received substantial attention in theoretical analyses, laboratory assessment and actual well measurements. Combinations of casing motion, annular eccentricities, wall roughness and fluid temperatures along the length of the annulus affect fluid flow regimes that control annular pressure losses. Current analytical solutions have limited applicability for complex conditions with pipe rotation and eccentricity. In this study, the pressure losses during Casing Drilling operation are investigated using computational fluid dynamics. The results are compared against the available analytical solution and field data. The effect of pipe rotation and eccentricity on the frictional pressure loss is investigated as well. According to the simulation results, the pipe rotation reduces the frictional pressure loss for Yield-Power-law fluid which would be beneficiary during the casing drilling operation. It is found that the pipe eccentricity has a significant effect on the ECD calculation. The industry is moving towards more challenging jobs in narrow pressure window scenarios such as deep-water and HPHT applications. Drilling with casing/liner is among the primary options to complete these sections due to strengthening effects associated with plastering the wellbore wall and also eliminating conventional drill pipe trip. Having accurate models for ECD including the effects of pipe rotation and eccentricity in the narrow annulus is essential to the success of these challenging jobs.

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Section: Methodology Analytical Solutionsmentioning

confidence: 99%

Evaluation of Annular Pressure Losses while Casing Drilling

Dokhani

Shahri

Karimi

et al. 2013

Day 1 Mon, September 30, 2013

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“…The 3D volume of the microseismic pointset can be estimated as the maximum extent of the stimulated fracture network. Mayerhofer et al (2006) implied that reservoir simulation model (Shojaei et al, 2013) is necessary to understand the effects of the SRV variations on a well's future production. However, SRV is not the only driver of well production.…”

Section: Correlation Of Srv To Productionmentioning

confidence: 99%

Correlation of Stimulated Rock Volume from Microseismic Pointsets to Production Data - A Horn River Case Study

et al. 2014

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Hydraulic fracture monitoring from microseismic allows operators to optimize completions through a clear understanding and correlation of the reservoir response to stimulation. Furthermore it helps operators to improve production and avoid out of zone growth by identifying patterns of fluid movement, fracture growth and connectivity. These critical insights allow refinements to the treatment plan, and provide useful insights for long-term improvements regarding well spacing, well design, and completion design. Shale reservoirs with very low permeability in the nano darcy range require a large fracture network to increase well performance. In these reservoirs, unless natural pre-existing fractures and faults have been reactivated and hydraulically opened to create a complex and well-connected network, pore pressure changes do not permeate far from the fractures. As a result, the microseismic pointset roughly corresponds to the size of the real fracture network which offers a means to estimate the stimulated rock volume (SRV). Although the producing fracture network could be smaller than the total SRV by a substantial percentage, it is expected that the effective network and the total SRV show a positive correlation. However, SRV is not the only indicator of well productivity. In a given SRV, the quality of the reservoir and parameters such as fracture conductivity and fracture spacing will affect production and can have a major impact on recovery calculations. In this study, stimulated rock volumes obtained from microseismic pointsets are correlated with actual field production. The correlations are used to illustrate how this concept can optimize treatment design, well spacing, and stage spacing through correlation of the reservoir response to hydraulic fracturing and production data. The correlation between production and SRV for each well shows that larger SRVs result in higher well production regardless of the percentage of the SRV that contains proppant filled fractures. The direct relationship of the microseismic pointsets and production can be used to predict a new well's potential productivity immediately upon completion of the stimulation job. This suggests that a key completion strategy is to create a large and effective SRV to provide maximum recovery and well performance monitored microseismically to provide production prediction.

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“…There are a number of analytical solutions for estimation of productivity of a multifractured horizontal well [1,2,3,4,5]. Although requiring very limited computational resources, these solutions are obtained under restrictive assumptions and simplifications, which limits the area of their application.…”

Section: Introductionmentioning

confidence: 99%

Fluid flow in a reservoir drained by a multiple fractured horizontal well

Головин¹,

Gadylshina²

2016

Preprint

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A mathematical model for computation of the fluid pressure in a reservoir drained by a horizontal multiple fractured well is proposed. The model is applicable for an arbitrary network of fractures with different finite conductivities of each segment, for variable in space and time physical parameters of the reservoir and for different field development plans. The variational formulation of the model allows effective numerical simulation using the finite element method.Case studies demonstrate how the main flow characteristics (well productivity, pressure distribution) depend on the geometrical and physical characteristics of the reservoir and of the fracture network. The presented model is suitable for estimation of the productivity of a multiple fractured well and as an optimization tool for efficient reservoir development.

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Analytical Solution of Transient Multiphase Flow to a Horizontal Well With Multiple Hydraulic Fractures

Cited by 10 publications

References 35 publications

Evaluation of Annular Pressure Losses while Casing Drilling

Evaluation of Annular Pressure Losses while Casing Drilling

Correlation of Stimulated Rock Volume from Microseismic Pointsets to Production Data - A Horn River Case Study

Fluid flow in a reservoir drained by a multiple fractured horizontal well

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