Innovative Encapsulating Acid with Release Dually Controlled by the Concentration of Hydrogen Ions and Temperature

Luo, Zhifeng; Zhang, Nanlin; Liu, Hongtao; Luo, Pandeng; Liu, Ju

doi:10.1021/acs.energyfuels.9b00673

Cited by 16 publications

(6 citation statements)

References 33 publications

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“…The experimental results indicate that the size of TRIGP could be controlled by the change of the reservoir temperature. For example, by optimizing the amount of injected prelinear gel to keep the reservoir temperature at 60, 90, or 120 °C, 30 TRIGP with a different size was generated.…”

Section: Resultsmentioning

confidence: 99%

Thermoresponsive in Situ Generated Proppant Based on Liquid–Solid Transition of a Supramolecular Self-Propping Fracturing Fluid

et al. 2019

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A thermoresponsive in situ generated proppant based on liquid−solid transition of a supramolecular selfpropping fracturing fluid was developed. At lower temperatures (below gas/oil reservoir temperature), the supramolecular fracturing fluid is in the liquid state; with the increase of temperature, the self-propping fracturing fluid becomes a solid proppant during the phase transition. This particular conversion was characterized by scanning electron microscopy, nuclear magnetic resonance, viscosity, viscoelasticity, leak-off, friction, mechanical properties, and conductivity tests. All test results indicated that noncovalent interactions between the components led to the supramolecular proppant generated. These scientific findings showed that the self-propping fracturing fluid is a proppant solid-particle-free liquid with good fluidity at lower temperatures. After injection to a fracture in reservoir formation, the self-propping fracturing fluid gradually transformed into solid proppant particles with good mechanical strength stimulated by the reservoir high temperature. The critical phase transformation temperature and time could be adjusted by a change in the composition. This novel self-propping fracturing fluid is solid ceramsite and quartz proppant free, and there is no need to add thickeners and cross-linkers. Comparisons with existing proppant-carrying fluid mixture of a solid proppant and high viscosity fracturing fluid, damage by fracturing fluid gel residues, abrasion of the pumping equipment and tubes are reduced. Besides, the self-propping fracturing fluid could enter any narrow fracture, increasing the effective propped area. All experimental results proved that the novel fracturing fluid has potential use in conventional reservoir fracturing and unconventional reservoir network fracturing.

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Section: Resultsmentioning

confidence: 99%

Thermoresponsive in Situ Generated Proppant Based on Liquid–Solid Transition of a Supramolecular Self-Propping Fracturing Fluid

et al. 2019

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“…These results underscore the substantial influence of specific crucial variables, especially inherent factors that are challenging to control. Effectively addressing factors like rock-gel friction in diverse reservoirs becomes essential for enhancing fracture conductivity and projecting fracture pressure to achieve desired operational results [19,26,40]. The findings reveal substantial variations between scenarios, notably indicating a heightened failure rate in the fourth scenario.…”

Section: Calculation Of Indicesmentioning

confidence: 98%

“…Particularly, the model focuses on the propagation of Pressure Wave Peaks (PWPs) within coal rock fissures during hydraulic fracturing, as illustrated in Figure 8. The utilization of MATLAB software for modeling estimates the likelihood probability of high permeability zones and near-wellbore friction, showcasing the BBN model's predictive capabilities in this intricate process [24][25][26].…”

Section: A Bbn For Hydraulic Fracturingmentioning

confidence: 99%

“…For instance, it might indicate that 90% of the output is due to the interaction between two inputs, with one contributing 8% of the variance and the other 2% (see Figure 9). This approach is applied to characterize the dynamic system of the environment impacted by hydraulic fracturing, incorporating changes and developments expressed within the BBN model for shale gas reservoir hydraulic fracturing [21,25,26]. The variance-based Sobol sensitivity method explores the multidimensional space of the unknown input parameters X with a certain number of Monte Carlo samples.…”

Section: Finding Sensitivity Parametersmentioning

confidence: 99%

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A Bayesian Network Model for Risk Management during Hydraulic Fracturing Process

Badjadi,

Zhu,

Zhang

et al. 2023

Water

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The escalating production of shale gas and oil, witnessed prominently in developed nations over the past decade, has sparked interest in prospective development, even in developing countries like Algeria. However, this growth is accompanied by significant opposition, particularly concerning the method of extraction: hydraulic fracturing, or ‘fracking’. Concerns regarding its environmental impact, water contamination, greenhouse gas emissions, and potential health effects have sparked widespread debate. This study thoroughly examines these concerns, employing an innovative approach to assess the risks associated with hydraulic fracturing operations in shale gas reservoirs. Through the integration of diverse data sources, including quantitative and qualitative data, observational records, expert judgments, and global sensitivity analysis using the Sobol method, a comprehensive risk assessment model, was developed. This model carefully considered multiple condition indicators and extreme working conditions, such as pressures exceeding 110 MPa and temperatures surpassing 180° F. The integration of these varied data streams enabled the development of a robust Bayesian belief network. This network served as a powerful tool for the accurate identification of process vulnerabilities and the formulation of optimal development strategies. Remarkably, this study’s results showed that this approach led to a notable 12% reduction in operational costs, demonstrating its practical efficacy. Moreover, this study subjected its model to rigorous uncertainty and sensitivity analyses, pinpointing the most severe risks and outlining optimal measures for their reduction. By empowering decision-makers to make informed choices, this methodology not only enhances environmental sustainability and safety standards but also ensures prolonged well longevity while maximizing productivity in hydraulic fracturing operations.

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“…The standard and modified API fracture conductivity device is widely used for acid-etched fracture conductivity evaluation (Chen et al, 2005;Han et al, 2016;Jin et al, 2019;Li et al, 2003;Luo et al, 2008;Luo et al, 2018;Luo et al, 2019;Malagon et al, 2008;Peng et al, 2015;Xue et al, 2018;Yao et al, 2015;Zhao et al, 2017;Peng et al, 2019b;Peng et al, 2020). The influences of closure stress, temperature, injection rate, contact time, acid type, and stimulation technique on fracture conductivity were investigated.…”

Section: Acid-etched Fracture Conductivity Experimentsmentioning

confidence: 99%

Case Study of Successfully Staged Acid Fracturing on the Ultra-Deep Horizontal Well for the Qixia Fm HTHP Tight Carbonate Gas Reservoir in China

Liu¹,

Yang²,

Li³

et al. 2022

Front. Energy Res.

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The lower Permian Qixia formation gas reservoir is characterized by ultra-deep buried, high temperature and high pressure (HTHP), low porosity and permeability, ultra-high closure pressure, and thin thickness in the western Sichuan Basin, China. Acid fracturing has been adopted as the main well stimulation technology. The average test production of the acid-fractured vertical well was 46 × 104 m3/d. The horizontal well with staged acid fracturing is considered a reliable measure to enhance gas production. However, the staged acid fracturing on the ultra-deep horizontal well has been challenged. The reaction rates of conventional, self-diverting, and gelled acid and the acid-etched fracture conductivity experiments under HTHP are measured to optimize the acid fracturing technique. The reaction rate of gelled acid with Qixia Fm limy dolomite at 150°C is 3.4–6.7 times faster than that with dolomite and similar to that with limestone. The gelled acid with better retardation and friction reduction performance is selected as the main acid to increase the effective acid-etched fracture length. The acid-etched fracture conductivity can be greatly enhanced by using gelled acid, increasing acid volume, and closed fracture acidizing (CFA) under a closure stress of 50 MPa. Moreover, the feasibility of staged acid fracturing for ultra-deep horizontal wells is discussed. The first stage is assembled by fracturing sleeve, spared ball drop sleeve, and circulating valve to ensure activation of the fracturing channel. The tested production is significantly enhanced with temporary plugging and open-hole packer and sliding sleeve staged acid fracturing.

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Innovative Encapsulating Acid with Release Dually Controlled by the Concentration of Hydrogen Ions and Temperature

Cited by 16 publications

References 33 publications

Thermoresponsive in Situ Generated Proppant Based on Liquid–Solid Transition of a Supramolecular Self-Propping Fracturing Fluid

Thermoresponsive in Situ Generated Proppant Based on Liquid–Solid Transition of a Supramolecular Self-Propping Fracturing Fluid

A Bayesian Network Model for Risk Management during Hydraulic Fracturing Process

Case Study of Successfully Staged Acid Fracturing on the Ultra-Deep Horizontal Well for the Qixia Fm HTHP Tight Carbonate Gas Reservoir in China

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