Preparation and evaluation of acryloyl morpholine modified emulsion fracturing fluid thickener with high temperature resistance and salt resistance

Abstract

To prepare the thickener of fracturing fluid with temperature resistance, salt resistance and quick dissolution, an emulsion thickener (ASC) was synthesized by acrylamide, acrylic acid, 2-acrylamide-2-methylpropanesulfonic acid, and acryloyl morpholine. The dissolution, salt resistance and drag reduction of ASC, and the viscoelasticity, temperature resistance and shear resistance and gel breaking properties of fracturing fluid formed by ASC and zirconium crosslinker were investigated. The results showed that the sticky time of ASC was less than 60 s and the drag reduction rate was 72.5% in 100,000 mg/L brine, showing that ASC had thickening ability in high salinity brine and satisfied the requirements of continuous fluid preparation on the fracturing process.The viscosity of ASC fracturing fluid was 98 mPa s after shearing at 200 C and 170 s À1 for 150 min when the salinity was 100,000 mg/L. When the ammonium persulfate concentration was 400 mg/L, the viscosity of the broken fluid was 4.0 mPa s. The temperature resistance, salt resistance and shear resistance of ASC emulsion fracturing fluid could be significantly improved by the introduction of acryloyl morpholine, ASC fracturing fluid had the characteristics of high elasticity and low viscosity, which could meet the application requirements under ultra-high temperature reservoirs.

Investigation on the influence of sulfonic substitution in polyacrylamides for minimizing drag in turbulent flow of slickwater fluids

“…36 The literature also highlighted that the functional substitution other than ATBS also yielded with better %DR performance when compared to nonfunctionalized PAMs in similar conditions. 44,45,56 The observed increase in %DR in the SPAM-brine systems with the rise in sulfonic substitution (i.e., charge density) in the SPAMs of equivalent MW was in-contrast with Eshrati et al 96 ; these researchers have observed the increase in charge density, in fact, reduced the drag reduction ability of the polymers in oil-water multiphase flow systems. The %DR values of all the studied polymers in various brine systems are mentioned in Table 5.…”

“…These salts tend to impede the %DR performance of PAMs by causing the linear structure of polymers to coil. 40 To increase salt tolerance of these polymers, chain modification with various functional group substitutions have been reported from various studies, for example, polymer substitutions with styrene, 41 acrylamide tertiary butyl sulfonic acid (ATBS), 14,33,40,42,43 triblock-polymer of polyethylene oxide (PEO), and polypropylene oxide (PPO), 44 acryloyl morpholine (ACMO) 45 have been reported in the literature. Functional substitution with ATBS comonomer during polymerization of base acrylamide monomers have also resulted in increase in the viscosity of the polymer solution in the brine systems.…”

Effect of Chemical Composition of Metal–Organic Crosslinker on the Properties of Fracturing Fluid in High-Temperature Reservoir

“…Zirconium oxychloride (ZrOCl 2 ·8H 2 O, AR 98%), aluminum chloride (AlCl 3 , AR 98%), lactic acid (LA, AR 98%), ethanediamine (ESD, AR 98%), sorbitol (SOR, AR 98%), sodium chloride (NaCl, AR 99.5%), calcium chloride (CaCl 2 , AR 98%), sodium hydroxide (NaOH, AR 98%), and ammonium persulfate (APS, AR 98%) were purchased from Shanghai Aladdin BioChem Technology Co., Ltd. (Shanghai, China) The thickener (a copolymer of AM, AA, AMPS and ACMO, denoted as ASC) was synthesized in the laboratory, as depicted in Figure 10 [ 39 ]. Thickener 2 is a biopolymer; CMHPG (industrial grade, molecular weight of 1.36 × 10 6 g/mol) polymer powder is made by Shandong AK Biotech Co., Ltd., (Dongying, China) and its chemical composition is presented in Figure 11 .…”

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

“…Hydraulic fracturing is an effective technique for stimulating low-permeability and ultralow-permeability oil and gas reservoirs. − A large amount of fracturing fluid is pumped to the bottomhole under high pressure to form the induced fractures, and the proppant is carried and transported into the fractures. The proppant located in the fractures will prevent the fractures from fully closing after fracturing operation, , resulting in a channel with permeability several orders of magnitude higher than the permeability of the formation itself. − The viscosity and elastic properties of the fracturing fluid are crucial for creating the designed fracture geometry and controlling the suspension efficiency of proppants. − Therefore, a reasonable selection of fracturing fluid is very important in hydraulic fracturing treatment.…”