Waterless stimulation: a new liquid CO2 based gel fracturing fluid with cylinder micelles structure

2016 ◽  
Author(s):  
Weixiang Cui ◽  
Chunpeng Wang ◽  
Mingyue Cui ◽  
Jun Yan
Keyword(s):  
Fracturing Fluid ◽  
Liquid Co2

Effect of foam quality on flow behavior of liquid CO2-based foam fracturing fluid stabilized by hydrofluoroether

2017 ◽  
Vol 159 ◽  
pp. 710-716 ◽  
Author(s):  
Zefeng Jing ◽  
Chenchen Feng ◽  
Shuzhong Wang ◽  
Donghai Xu ◽  
Guixi Xu
Keyword(s):  
Flow Behavior ◽  
Fracturing Fluid ◽  
Liquid Co2

Study and Application of Shallow Water Fracturing Fluid in High Temperature Deep Carbonate Reservoir

2013 ◽  
Author(s):  
Mingguang Che ◽  
Yonghui Wang ◽  
Xingsheng Cheng ◽  
Yongjun Lu ◽  
Yongping Li ◽  
...  
Keyword(s):  
High Temperature ◽  
Shallow Water ◽  
Carbonate Reservoir ◽  
Fracturing Fluid

A new approach to the hydraulic fracture geometric dimensions determination

2017 ◽  
Vol 12 (1) ◽  
pp. 126-134
Author(s):  
A.M. Ilyasov
Keyword(s):  
Exact Solution ◽  
Hydraulic Fracture ◽  
Pressure Gauge ◽  
Hyperbolic Type ◽  
Fluid Injection ◽  
Fracturing Fluid ◽  
New Approach ◽  
Gauge Data ◽  
Bottomhole Pressure ◽  
Half Length

Based on the generalized Perkins-Kern-Nordgren model (PKN) for the development of a hyperbolic type vertical hydraulic fracture, an exact solution is obtained for the hydraulic fracture self-oscillations after terminating the fracturing fluid injection. These oscillations are excited by a rarefaction wave that occurs after the injection is stopped. The obtained solution was used to estimate the height, width and half-length of the hydraulic fracture at the time of stopping the hydraulic fracturing fluid injection based on the bottomhole pressure gauge data.

Fracturing fluid retention in shale gas reservoirs:mechanisms and functions

2019 ◽  
Vol 12 (24) ◽  
Author(s):  
Lijun You ◽  
Yang Zhou ◽  
Yili Kang ◽  
Bin Yang ◽  
Zhongyu Cui ◽  
...  
Keyword(s):  
Shale Gas ◽  
Fluid Retention ◽  
Fracturing Fluid

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

Energies ◽  
2021 ◽  
Vol 14 (6) ◽  
pp. 1783
Author(s):  
Klaudia Wilk-Zajdel ◽  
Piotr Kasza ◽  
Mateusz Masłowski
Keyword(s):  
Hydraulic Fracturing ◽  
Guar Gum ◽  
Polymer Concentration ◽  
Laboratory Research ◽  
Damage Effect ◽  
Tight Gas ◽  
Fracturing Fluid ◽  
Fracture Conductivity ◽  
Fracturing Fluids ◽  
Sandstone Rock

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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