Simulating yield stress variation along hydraulic fracture face enhances polymer cleanup modeling in tight gas reservoirs

A, Regina Tayong; Alhubail, Mustafa M.; Maulianda, Belladonna; Barati, Reza

doi:10.1016/j.jngse.2019.02.006

Cited by 5 publications

(5 citation statements)

References 10 publications

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“…Gas production is affected by the length of the natural fractures, and relatively long fractures with high hydraulic fracturing conductivity are required to obtain high gas production. ,, Gas reservoirs with a high natural density and shorter primary fractures are superior . There is a discernible linear relationship between the cumulative gas production and fracture permeability .…”

Section: Results and Discussionmentioning

confidence: 99%

Numerical Analysis for Dynamic Propagation and Intersection of Hydraulic Fractures and Pre-existing Natural Fractures Involving the Sensitivity Factors: Orientation, Spacing, Length, and Persistence

et al. 2021

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Pre-existing natural fractures in a fractured reservoir will intersect with the hydraulic fractures and propagate dynamically during the hydrofracturing process, which has a significant impact on the morphology of the fracture network and subsequent gas production. If the representative properties of the natural fractures cannot be accurately extracted and appropriate numerical models are not established to describe the propagation and intersection behaviors of the fractures, it is difficult to determine the fracturing scheme for naturally fractured reservoirs and to obtain the expected fracture network and gas production. In this study, the combined finite element-discrete element method and discrete fracture network model were used to simulate the hydrofracturing process of naturally fractured reservoirs by controlling different sensitivity factors (orientation, spacing, length, and persistence) of natural fractures. To investigate the sensitivity factors, typical numerical cases were carefully designed and established, and the results of the dynamic propagation and intersection of hydraulic fractures and pre-existing natural fractures were derived. Two typical types of fracture network morphologies are detected when hydraulic fractures intersect the natural fractures: center-type (intersection of hydraulic fractures and the crossed cluster of the natural fractures) and edge-type (intersection of hydraulic fractures and the edge of the natural fractures). The quantitative results of the length and volume of the fracture networks and gas production in enhanced permeability fractured reservoirs were analyzed. The mechanisms by which the sensitivities of natural fractures affect and control the optimal fracturing behaviors are well understood; the conditions of small fracture spacing, large fracture length, or small fracture persistence of natural fractures are conducive for hydraulic fractures to intersect with the natural fractures and form a complex center-type fracture network and improve gas production.

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Section: Results and Discussionmentioning

confidence: 99%

Numerical Analysis for Dynamic Propagation and Intersection of Hydraulic Fractures and Pre-existing Natural Fractures Involving the Sensitivity Factors: Orientation, Spacing, Length, and Persistence

et al. 2021

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“…Due to the lithology of Lucaogou Formation in this paper is similar to the core samples used in Chen's model [42], we introduce his formulas, Equations (14)- (16), for calculating proppant embedment that allows for modifying the stress-dependent porosity and permeability [42] with the results shown in Figure 13.…”

Section: Impact Of Proppant Distributionmentioning

confidence: 99%

“…In Equations 14- (16), w f0 is fracture width before embedment, m; h is the proppant embedment, m; η = 2.1 × 10 −5 , λ = 2.8, when the proppant is 20/40-mesh; and η = 1.6 × 10 −5 , λ = 3.1, when the proppant is 30/60-mesh. Fracture compressibility, KPa -1 2×10 -6 2×10 -5 2×10 -4 Figure 6.…”

Section: Impact Of Proppant Distributionmentioning

confidence: 99%

“…However, field data show that the recovery efficiency of tight oil or gas wells is generally low, and a remarkable fraction of fracturing fluid remains in the reservoir even after long-term production [11][12][13][14]. Scholars have carried out some work to clarify the problems arising after hydraulic fracturing and to help improve the clean-up operation in low permeability formations [15,16].…”

Section: Introductionmentioning

confidence: 99%

“…Similar negative impacts were also found in studies of tight shale [33][34][35], where water retention might cause water blocking or damage to hydrocarbon phase relative permeability. Moreover, for tight formations, the invasion of fracturing fluid into the matrix did not require much depth to cause enough damage [15,16].…”

Section: Introductionmentioning

confidence: 99%

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Numerical Investigation of Fracture Compressibility and Uncertainty on Water-Loss and Production Performance in Tight Oil Reservoirs

Liao

Zhang

et al. 2019

Energies

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Multi-stage hydraulic fracturing along with horizontal wells are widely used to create complex fracture networks in tight oil reservoirs. Analysis of field flowback data shows that most of the fracturing fluids are contained in a complex fracture network, and fracture-closure is the main driving mechanism during early clean up. At present, the related fracture parameters cannot be accurately obtained, so it is necessary to study the impacts of fracture compressibility and uncertainty on water-loss and the subsequent production performance. A series of mechanistic models are established by considering stress-dependent porosity and permeability. The impacts of fracture uncertainties, such as natural fracture density, proppant distribution, and natural fracture heterogeneity on flowback and productivity are quantitatively assessed. Results indicate that considering fracture closure during flowback can promote water imbibition into the matrix and delay the oil breakthrough time compared with ignoring fracture closure. With the increase of natural fracture density, oil breakthrough time is advanced, and more water is retained underground. When natural fractures connected with hydraulic fractures are propped, well productivity will be enhanced, but proppant embedment can cause a loss of oil production. Additionally, the fracture network with more heterogeneity will lead to the lower flowback rate, which presents an insight in the role of fractures in water-loss.

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Special Issue on International Conference on Oil & Gas Engineering and Technology (ICOGET 2018) by Universiti Teknologi PETRONAS

Foroozesh

Negash

Hamdi

et al. 2020

Journal of Natural Gas Science and Engineering

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Simulating yield stress variation along hydraulic fracture face enhances polymer cleanup modeling in tight gas reservoirs

Cited by 5 publications

References 10 publications

Numerical Analysis for Dynamic Propagation and Intersection of Hydraulic Fractures and Pre-existing Natural Fractures Involving the Sensitivity Factors: Orientation, Spacing, Length, and Persistence

Numerical Analysis for Dynamic Propagation and Intersection of Hydraulic Fractures and Pre-existing Natural Fractures Involving the Sensitivity Factors: Orientation, Spacing, Length, and Persistence

Numerical Investigation of Fracture Compressibility and Uncertainty on Water-Loss and Production Performance in Tight Oil Reservoirs

Special Issue on International Conference on Oil & Gas Engineering and Technology (ICOGET 2018) by Universiti Teknologi PETRONAS

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