Understanding the performance of hydraulically fractured wells in the laumontite-rich tight glutenite formation

Chen, Beibei; Xu, Bin; Li, Biao; Kong, Mingwei; Wang, Wanbin; Chen, Huasheng

doi:10.1016/j.petrol.2019.106600

Cited by 19 publications

(4 citation statements)

References 32 publications

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“…Due to the change in interstitial materials in the reservoir, the anorthite content in rock cuttings varies, albitization occurs, and the laumontite content increases. The reservoir cement has strong heterogeneity, and the laumontite content increases toward the depression's center (Cai et al, 2020;Chen et al, 2020). The element logging data show that the aluminum content decreases signi cantly, the sodium increases signi cantly, and the potassium slightly increases below 6500 m from the bottom of the Wuerhe Formation, indicating that the albite in the mineral components of the reservoir increases, and the shale decreases.…”

Section: Cementation Of Special Mineralsmentioning

confidence: 99%

Evolution mechanism of diagenesis of deep sag area in the central Fault basin—A case study of the Wuerhe Formation of the Dongdaohaizi sag in the Junggar basin, Northwest China

Wang

Xie

2023

Preprint

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The Junggar basin is a typical terrestrial fault basin. The stratum in the central area is deeply buried and its sedimentary and rock types are diverse. Its diagenesis is complex and the evolution law of reservoir pores is challenging to characterize, which is not conducive to oil and gas exploration in this region. In this paper, the Dongdaohaizi sag in the central deep basin was taken as an example to be detailed on its sedimentary facies, diagenesis, and micropore structure, revealing the diagenesis sequence and pore evolution law of the deep buried reservoir. First, the sedimentary facies type of the focus stratum (Wuerhe Formation) is assigned to the fan delta, its source is from the northwest, and the rock type is conglomerate, pebbly sandstone, sandstone, and siltstone. The debris content is high among the clastic grains and can reach 40%, showing near-source transport characteristics. Second, the primary diagenesis types and evolution sequence of the Wuerhe Formation is cleared according to experiment data, and the influence degree of the compassion, cementation, and dissolution of the target reservoir rock is clarified. Finally, the sandstone pore evolution model is established, the diagenesis facies is classified, the contribution degree of the unstable clasts and cemented minerals to the secondary pore is determined, and the comprehensive factors with the greatest impact on the late densification of the reservoir are clarified. The diagenesis and pore evolution of the deep rocks in the deep central sag are revealed.

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Section: Cementation Of Special Mineralsmentioning

confidence: 99%

Evolution mechanism of diagenesis of deep sag area in the central Fault basin—A case study of the Wuerhe Formation of the Dongdaohaizi sag in the Junggar basin, Northwest China

Wang

Xie

2023

Preprint

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“…Although it is rarely seen in typical shales, tight sandstones, or tight carbonates, it is relatively rich in the Wuerhe formation in the Mahu-1 play. Each unit cell of the laumontite crystal has 8 sites that can bond 18 water molecules during hydration, and XRD results indicate that the cell volume can expand 2–6%. ,, Compared with montmorillonite, laumontite does not significantly swell after reacting with water; although it can affect drilling and fracture propagation due to different mechanical properties from the reservoir rock, no stabilizer has been developed for preventing the swelling of laumontite during hydraulic fracturing. , …”

Section: Introductionmentioning

confidence: 99%

“…12,25,26 Compared with montmorillonite, laumontite does not significantly swell after reacting with water; although it can affect drilling and fracture propagation due to different mechanical properties from the reservoir rock, no stabilizer has been developed for preventing the swelling of laumontite during hydraulic fracturing. 2,27 When water-sensitive minerals swell after reacting with water, fine particles can detach from the rock due to the electrostatic repulsion; migrant of these fine particles can further plug small pores and pore throats, as well as the created hydraulic fractures. Meanwhile, water−rock interaction can also soften the matrix and even damage the rock skeleton; this can further result in the embedment of proppants and the closure of created fractures.…”

Section: Introductionmentioning

confidence: 99%

Optimization and Evaluation of Stabilizers for Tight Water-Sensitive Conglomerate Reservoirs

Zhang

Cheng

et al. 2022

ACS Omega

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The upper Wuerhe formation in the Mahu-1 play is a tight conglomerate reservoir that has characteristics of low porosity and low permeability. During the early stage of field development, it has been noticed that horizontal wells typically have a high flowback ratio and an extremely low oil production rate during the early production, and this is likely attributed to the water–rock interaction that causes the closure of generated hydraulic fractures. In this study, a stabilizer and its dosage in a fracturing fluid are optimized, and its effect on clay antiswelling and rock stabilization is evaluated. Experimental results indicate that a mixture of a salt and an inorganic cationic polymer can effectively inhibit the water–rock reaction by minimizing the clay swelling and compressing the electric double layer on the rock surface. The antiswelling rate of montmorillonite can reach 93.56%, and that of the reservoir rock powder can reach 75.32%. Meanwhile, Brazilian splitting tests are conducted to evaluate the mechanical property change of reservoir rocks before and after being submerged in fracturing fluids with different stabilizers. Compared to 4% KCl, which is currently used in the field, the new formula can enhance the breakdown pressure by more than 10% without increasing the cost. The findings of this work provide a solution for fracturing water-sensitive reservoirs and also establish a set of laboratory methods for optimizing stabilizers as fracturing fluid additives.

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“…Glutenite reservoirs are widely distributed throughout the world, including the Los Angeles Basin in North America, the Argentine Basin in South America, and the Bohai Bay Basin in Eastern China. The development of glutenite reservoirs has attracted wide attention in recent years (Chen et al, 2020; Ju et al, 2018). The tight heterogeneous glutenite reservoirs are typically characterized by high variable lithology, low/ultra-low permeability, poor pore connectivity, and significant heterogeneity.…”

Section: Introductionmentioning

confidence: 99%

Investigation on the mechanism of hydraulic fracture propagation and fracture geometry control in tight heterogeneous glutenites

Zhai

Wang

et al. 2021

Energy Exploration & Exploitation

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The tight heterogeneous glutenites are typically characterized by highly variable lithology, low/ultra-low permeability, significant heterogeneity, and a less-developed natural fracture system. It is of great significance for economic development to improve hydraulic fracture complexity and stimulated reservoir volume. To better understand the hydraulic fracturing mechanism, a large-scale experimental test on glutenite specimens was conducted and the hydraulic fracture propagation behaviors and focal mechanism were analyzed. A three-dimensional numerical model was developed to reproduce the hydraulic fracture evolution process and investigate the effects of operating procedures on hydraulic fracture geometry and stimulated reservoir volume. A simultaneous variable injection rate and fluid viscosity technology was proposed to increase the hydraulic fracture complexity and stimulated reservoir volume. The results indicate that four fracturing behaviors can be observed, namely, penetration, deflection, termination, and bifurcating, in the laboratory experiment. Tensile events tend to appear during the initiation stage of hydraulic fracture growth, while shear events and compressive events tend to appear during the non-planar propagation stage. The shear and compressive mechanisms dominate with an increase in the hydraulic fracture complexity. The variable injection rate technology and simultaneous variable injection rate and fluid viscosity technology are effective techniques for fracture geometry control and stimulated reservoir volume enhancement. The key to improve hydraulic fracture complexity is to increase the net pressure in hydraulic fractures, cause evident pressure fluctuations, and activate or communicate a wide range of natural discontinuities. The results can provide a better understanding of the fracture geometry control mechanism in tight heterogeneous glutenites, and offer a guideline for treatment design and optimization of well performance.

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Understanding the performance of hydraulically fractured wells in the laumontite-rich tight glutenite formation

Cited by 19 publications

References 32 publications

Evolution mechanism of diagenesis of deep sag area in the central Fault basin—A case study of the Wuerhe Formation of the Dongdaohaizi sag in the Junggar basin, Northwest China

Evolution mechanism of diagenesis of deep sag area in the central Fault basin—A case study of the Wuerhe Formation of the Dongdaohaizi sag in the Junggar basin, Northwest China

Optimization and Evaluation of Stabilizers for Tight Water-Sensitive Conglomerate Reservoirs

Investigation on the mechanism of hydraulic fracture propagation and fracture geometry control in tight heterogeneous glutenites

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