Experimental and Simulation Studies of Energized Fracturing Fluid Efficiency in Tight Gas Formations

Wilk, Klaudia

doi:10.3390/en12234465

Cited by 5 publications

(3 citation statements)

References 35 publications

(17 reference statements)

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“…These rocks are characterised by a high content of clay minerals [54], a significant contribution of organic matter [55,56], and low permeability [57,58]. Due to low permeability of the shales, hydraulic fracturing is performed within them [59][60][61][62][63][64]. Hydraulic fracturing causes the development of a dense network of fractures and fissures in the fractured rock layer, allowing for the exploitation of shale gas [16][17][18][19]65].…”

Section: Methodsmentioning

confidence: 99%

Anisotropy of Strength and Elastic Properties of Lower Paleozoic Shales from the Baltic Basin, Poland

2021

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The paper presents the results of laboratory studies on the strength–strain properties of shales representing four siltstone-claystone lithostratigraphic units occurring in the Baltic Basin. Laboratory studies in a triaxial stress state were conducted as single failure tests on cylindrical samples oriented parallel and perpendicular to lamination within the rocks. Mutually perpendicular samples were cut out from the same drill core sections in order to determine mechanical anisotropy. Samples oriented parallel to lamination were characterised by values of the static Young’s modulus twice as high as from samples oriented perpendicular to lamination. Similar variability was observed in the case of maximum differential stress values and Poisson’s ratio. Samples parallel to lamination registered notably lower axial strains, which influenced increased values of Young’s modulus and Poisson’s ratio. The rocks studied are characterised by VTI type (vertical transverse isotropy) internal anisotropy of the rock matrix, which significantly influences the anisotropy of their geomechanical properties.

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Section: Methodsmentioning

confidence: 99%

Anisotropy of Strength and Elastic Properties of Lower Paleozoic Shales from the Baltic Basin, Poland

2021

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“…Traditional polymer fracturing fluids can severely damage the formation and cause environmental problems. Foam fluids have been widely studied because of their unique advantages as fracturing fluid. , Foam fluid is easier to recover, reduces the number of injections, and causes relatively little potential damage to the formation. In addition, during the fracturing process, the foam fracturing fluid causes relatively little damage to the fractures filled with the proppant, which can improve the maintenance of the appropriate rheological parameters and ensure a continuous suspension capacity of the proppant. , However, foam fracturing fluids are limited in their generation of complex fractures…”

Section: Hydraulic Fracturingmentioning

confidence: 99%

Reservoir Stimulation Technologies for Natural Gas Hydrate: Research Progress, Challenges, and Perspectives

Liang

2023

Energy Fuels

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The energy crisis has intensified in recent years. The current global economic environment and increasing cost of mining necessitate additional energy access channels. Previous studies have shown that natural gas hydrate reservoirs (NGHRs) contain a large number of natural gas resources. However, several problems are associated with the safe and efficient exploitation of the NGHRs. Reservoir stimulation technology is expected to address these issues. This study introduces the properties and mining difficulties of NGHRs and reviews their stimulation scheme and related research progress based on three perspectives: hydraulic fracturing, burden sealing, and near-well reconstruction. The principles, advantages, and limitations of the three schemes are compared. In addition to the stimulation effects of the three aforementioned methods, this study focused on the fracability of NGHRs, the factors influencing fracture initiation and development, and the fracturing fluid, proppant, completion fluid, and slurry suitable for NGHR stimulation. In addition, the principles, current challenges, and future research prospects for reservoir stimulation are summarized to provide a reference for the commercial exploitation of natural gas hydrates in the future.

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“…The issues with cleaning the fracture from treatment fluids is particularly visible for gas reservoirs with low temperatures, reservoir pressures, and permeability [16]. In the case of such reservoirs, to avoid contamination of fracture by fracturing fluid residue, foamed fluids (fluids with addition of nitrogen, carbon dioxide) are used [17,18].…”

Section: Introductionmentioning

confidence: 99%

Laboratory Testing of Fracture Conductivity Damage by Foam-Based Fracturing Fluids in Low Permeability Tight Gas Formations

2021

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In the case of fracturing of the reservoirs using fracturing fluids, the size of damage to the proppant conductivity caused by treatment fluids is significant, which greatly influence the effective execution of hydraulic fracturing operations. The fracturing fluid should be characterized by the minimum damage to the conductivity of a fracture filled with proppant. A laboratory research procedure has been developed to study the damage effect caused by foamed and non-foamed fracturing fluids in the fractures filled with proppant material. The paper discusses the results for high quality foamed guar-based linear gels, which is an innovative aspect of the work compared to the non-foamed frac described in most of the studies and simulations. The tests were performed for the fracturing fluid based on a linear polymer (HPG—hydroxypropyl guar, in liquid and powder form). The rheology of nitrogen foamed-based fracturing fluids (FF) with a quality of 70% was investigated. The quartz sand and ceramic light proppant LCP proppant was placed between two Ohio sandstone rock slabs and subjected to a given compressive stress of 4000–6000 psi, at a temperature of 60 °C for 5 h. A significant reduction in damage to the quartz proppant was observed for the foamed fluid compared to that damaged by the 7.5 L/m3 natural polymer-based non-foamed linear fluid. The damage was 72.3% for the non-foamed fluid and 31.5% for the 70% foamed fluid, which are superior to the guar gum non-foamed fracturing fluid system. For tests based on a polymer concentration of 4.88 g/L, the damage to the fracture conductivity by the non-foamed fluid was 64.8%, and 26.3% for the foamed fluid. These results lead to the conclusion that foamed fluids could damage the fracture filled with proppant much less during hydraulic fracturing treatment. At the same time, when using foamed fluids, the viscosity coefficient increases a few times compared to the use of non-foamed fluids, which is necessary for proppant carrying capacities and properly conducted stimulation treatment. The research results can be beneficial for optimizing the type and performance of fracturing fluid for hydraulic fracturing in tight gas formations.

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Experimental and Simulation Studies of Energized Fracturing Fluid Efficiency in Tight Gas Formations

Cited by 5 publications

References 35 publications

Anisotropy of Strength and Elastic Properties of Lower Paleozoic Shales from the Baltic Basin, Poland

Anisotropy of Strength and Elastic Properties of Lower Paleozoic Shales from the Baltic Basin, Poland

Reservoir Stimulation Technologies for Natural Gas Hydrate: Research Progress, Challenges, and Perspectives

Laboratory Testing of Fracture Conductivity Damage by Foam-Based Fracturing Fluids in Low Permeability Tight Gas Formations

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