Fracturing Fluid for Extreme Temperature Conditions is Just as Easy as the Rest

Gupta, D.V. Satya; Carman, Paul

doi:10.2118/140176-ms

Cited by 25 publications

(11 citation statements)

References 3 publications

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“…Gupta and Carman (2011) have reported using sodium bromate as a breaker for an acrylamide-based fluid at 300°F and using encapsulated sodium bromate as the breaker at 400°F. These breakers worked well with the nano-based fracturing fluid.…”

Section: Breakermentioning

confidence: 99%

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Reduced Polymer Loading, High Temperature Fracturing Fluids using Nano-crosslinkers

Liang

Al-Muntasheri

et al. 2015

Day 2 Tue, November 10, 2015

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In the quest to discover more natural gas resources, considerable attention has been devoted to finding and extracting gas locked within tight formations with permeability in the nanoto microdarcy range. The main challenges associated with working in such formations are the intrinsically high temperature and high pressure bottom hole conditions. For formations with bottom hole temperatures around 350-400°F, traditional hydraulic fracturing fluids that use crosslinked polysaccharide gels, such as guar and its derivatives, are not suitable because of significant polymer breakdown in this temperature range. Fracturing fluids that can work at these temperatures require thermally stable synthetic polymers such as acrylamide-based polymers. However, such polymers have to be employed at very high concentrations in order to suspend proppants. The high polymer concentrations make it very difficult to completely degrade at the end of a fracturing operation. As a consequence, formation damage by polymer residue can block formation conductivity to gas flow. This paper addresses the shortcomings of the current state-of-the-art high temperature fracturing fluids, and focuses on developing a less damaging, high-temperature stable fluid that can be used at temperatures up to 400°F. A laboratory study was conducted with this novel system which is comprised of a synthetic acrylamide-based copolymer gelling agent and is capable of being crosslinked with a nano-sized particulate crosslinker (nano-crosslinker). The laboratory data has demonstrated that the temperature stability of the crosslinked fluid is much better than a similar fluid lacking the nano-crosslinker. The nano-crosslinker allows the novel fluid system to operate at significantly lower polymer concentrations (25 to 45 pptg) when compared to current commercial fluid systems (50 to 87 pptg) designed for temperatures from 350°F to 400°F. This paper presents results from rheological studies which demonstrate superior crosslinking performance and thermal stability in this temperature range. This fracturing fluid system has sufficient proppant carrying viscosity, and allows for efficient cleanup using an oxidizer-type breaker. Low polymer loading and little or no polymer residue are anticipated to facilitate efficient cleanup, reduced formation damage, better fluid conductivity and enhanced production rates. Laboratory results from proppant-pack regained conductivity tests are also presented.

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Section: Breakermentioning

confidence: 99%

“…This polymer can be crosslinked with metal crosslinkers as well. Gupta and Carman (2011) reported on using a terpolymer of acrylamide, AMPS and vinyl phosphonate. This system uses a zirconium based crosslinker as well and uses sodium bromate as a breaker.…”

Section: Introductionmentioning

confidence: 99%

Reduced Polymer Loading, High Temperature Fracturing Fluids using Nano-crosslinkers

Liang

Al-Muntasheri

et al. 2015

Day 2 Tue, November 10, 2015

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“…Furthermore, metal crosslinking agents, such as zirconium, were used to increase the viscoelasticity of the solution. The modified polymer was reported to be used in fracturing fluids for formations at over 200 °C [22,23,24,25,26]. However, this crosslinking technology needs to be carried out under specific pH conditions, for example, pH usually is 3–5 when adopting zirconium-based crosslinkers, which increases the operation difficulty and equipment requirements.…”

Section: Introductionmentioning

confidence: 99%

Improving the Thermal Stability of Hydrophobic Associative Polymer Aqueous Solution Using a “Triple-Protection” Strategy

et al. 2019

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Because of their high viscoelasticity, Hydrophobic Associative Water-Soluble Polymers (HAWSPs) have been widely used in many industrial fields, especially in oilfield flooding and fracturing. However, one major problem which limits the wide applications of HAWSPs is their weak resistance to high temperatures. Once the temperature increases over 100 °C, the viscosity of the fracturing fluid decreases rapidly, because high temperatures reduce fluid viscosity by oxidizing the polyacrylamide chains and weakening the association of hydrophobic groups. To improve the high temperature resistance of one HAWSP, a triple-protection strategy was developed. First, rigid N-vinyl-2-pyrrolidone moiety was introduced into the polymer chains. Second, an environmentally-friendly deoxidizer, carbohydrazide, was selected to prevent polymer oxidization by scavenging dissolved oxygen. Results showed that both the rigid groups and the deoxidizer improved the temperature resistance of the polymer and helped it maintain high viscosity under high temperature and shear rate. Using these two protection strategies, the resistant temperature of the polymer could reach 160 °C. However, the polymer network still got severely damaged at further elevated temperatures. Therefore, as the third protection strategy, the pre-added high temperature responsive crosslinking agent was applied to form new networks at elevated temperatures. The results have shown that the optimized polymer solution as a kind of fracturing fluid showed good temperature resistance up to 200 °C.

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“…• Effectiveness and pressure during injection of the fluid • Percentage content of clay in a deposit rock • Potential possibility of creation of both silicate and organic particles • Solubility of a rock in an acid • Microbiological activeness • Potential possibility of non-organic sediments forming • Difficulties with injected fluid collection (receiving) [1,[5][6][7][8].…”

Section: Introductionmentioning

confidence: 99%

“…The lattice formed in the entire volume of fluid by the micelles of surfactants increases the viscosity. Such fluids cause less damage to conductivity of the fracture compared to fluids prepared on the basis of polymers [5][6][7]10].…”

Section: Introductionmentioning

confidence: 99%

Analysis of Chemical and Toxicological Properties of Fluids for Shale Hydraulic Fracturing and Flowback Water

Steliga

Kluk

Jakubowicz

2015

Pol. J. Environ. Stud.

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Hydraulic fracturing of non-conventional (tight and shale) deposits is a controlled process of technological fluid injection into a deposit. The fluid consists mainly of water and chemical components ( Fig. 1) and the injection is done with high effectiveness (6-20 m 3 /min) with high pressureup to 100 MPa, which cracks rocks in a deposit and creates chains of cracks, or clefts.Further injecting the fluid results in propagation of cracks to a size determined in a technological project. After opening the crack, a proppant material (sand of proper granulation and mechanical strength) is added to the technological fluid and gets into the cracks and stops their closure. Simultaneously, it creates access for gas flowing to an excavation slot [1][2][3][4].Compositions of technological fluids used in hydraulic fracturing depend on the geological formation of a deposit and on the type of well (vertical or horizontal).During development of a fracturing fluid and selection of additives, the following factors should be taken into account: Pol. J. Environ. Stud. Vol. 24, No. 5 (2015), [2185][2186][2187][2188][2189][2190][2191][2192][2193][2194][2195][2196] AbstractAn analysis of environmental threats showed that the complete influence of shale gas production on the environment is bigger than in the case of gas production from a traditional oilfield. Hydraulic fracturing of shale, done on a much larger scale, results in huge amounts of liquid waste that must be managed in a rational way. An optimum solution to this problem is reusing flowback water to develop fluids for later fracturing. This article discusses the composition of the fluids used in hydraulic fracturing of non-conventional deposits as well as the flowback water. In the case of the examined liquids, toxicological tests have been carried out using microbiotests of ToxKit types Microtox, MARA, Daphtoxkit F magna, and Thamnotoxkit F. The research was done on a sample of fluids for hydraulic fracturing, and on flowback water obtained in hydraulic fracturing of shale formations in Poland. The tests are essential for correctly managing flowback waters after fracturing.

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Fracturing Fluid for Extreme Temperature Conditions is Just as Easy as the Rest

Cited by 25 publications

References 3 publications

Reduced Polymer Loading, High Temperature Fracturing Fluids using Nano-crosslinkers

Reduced Polymer Loading, High Temperature Fracturing Fluids using Nano-crosslinkers

Improving the Thermal Stability of Hydrophobic Associative Polymer Aqueous Solution Using a “Triple-Protection” Strategy

Analysis of Chemical and Toxicological Properties of Fluids for Shale Hydraulic Fracturing and Flowback Water

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