Development and Performance Evaluation of a Gel-Based Plugging System for Complex Fractured Formations Using Acrylic Resin Particles

Our plain-English summary of Development and Performance Evaluation of a Gel-Based Plugging System for Complex Fractured Formations Using Acrylic Resin Particles, by L. Yao, X. Quan, J. Ma, et al (Gels, 2025).

The study

• Authors: L. Yao, X. Quan, J. Ma, G. Wang, Q. Feng, H. Jin, J. Yang
• Journal: Gels
• Published: 2025;11(3)
• Cited by: 1 article, as counted by NIH iCite
• Read it: PubMed · Publisher · Free full text

Abstract

The issue of fluid loss in fractured formations presents a significant challenge in petroleum engineering, often leading to increased operational costs and construction risks. To address the limitations of traditional lost circulation materials (LCMs) in oil reservoirs with different fracture sizes, this study developed an acrylic resin gel particle with excellent thermal stability (thermal decomposition temperature up to 314 °C) and compatibility. By employing Box-Behnken design and response surface methodology, the synergistic interaction of calcium hydroxide (Ca(OH)2), asbestos fibers, and cement was optimized to create a novel gel solidification plugging system that meets the requirements of fluid loss control and compressive strength improvement. Experimental results revealed that the gel-based system demonstrated exceptional performance, achieving rapid fluid loss (total fluid loss time of 18~47 s) and forming a high-strength gelled filter cake (24 h compressive strength up to 17.5 MPa). Under simulated conditions (150 °C), the gel-based system provided efficient fracture sealing, showcasing remarkable adaptability and potential for engineering applications. This study underscores the promise of acrylic resin gel particles in overcoming fluid loss challenges in complex fractured formations.

In plain English

This was a laboratory engineering study from the oil industry, not a health study. It did not study asbestos exposure or disease. The authors mixed laboratory-made acrylic resin particles with calcium hydroxide, asbestos fibers and cement into a slurry meant to seal rock cracks where drilling fluid leaks away. The article calls the asbestos only industrial-grade "asbestos fibers" and does not name the fiber type. The resin was thermally stable below 314 degrees Celsius. Single-factor tests and a statistical design method showed acrylic resin and asbestos fibers were the main factors affecting how fast the slurry lost fluid. They settled on 10% acrylic resin, 15% calcium hydroxide, 3% asbestos fibers and 10% cement. At slurry concentrations of 5 to 30%, total fluid loss time was 18 to 47 seconds. The filter cake's 24-hour compressive strength peaked at 17.5 MPa, at 30% dosage. At 150 degrees Celsius the seal held pressure for 30 minutes without breakdown and withstood over 4 MPa. The authors concluded that the system offered a durable, efficient solution to fluid loss in oilfield operations.

We wrote this plain-English summary from the full article with the help of AI, and a second AI model checked each sentence against the article. It is not the authors' wording; the abstract and the article are their own account.

What the study did and found

• Design: laboratory materials-development experiment (petroleum engineering), using single-factor tests and a Box–Behnken response surface design; not a study of human health
• Who was studied: No people were studied. The subjects were laboratory-made acrylic resin particles and plugging slurries, tested in fluid-loss equipment and on quartz sand beds simulating fractured rock.
• Exposure: Asbestos fibers (type not named; industrial grade) were used as an ingredient in a plugging slurry, alongside acrylic resin, calcium hydroxide and cement. Asbestos fiber dosages of 2, 3 and 4% were tested in the response surface design. No human exposure was studied.
• Main results:
  • The acrylic resin particles showed good thermal stability below 314 degrees Celsius
  • In single-factor tests, filtration volume with asbestos fibers fell at low dosages (0 to 3%), was lowest at 3%, and then rose
  • Acrylic resin and asbestos fibers were the primary factors influencing total fluid loss time
  • The final recipe was 10% acrylic resin, 15% calcium hydroxide, 3% asbestos fibers and 10% cement
  • At plugging agent concentrations of 5 to 30%, total fluid loss time was 18 to 47 seconds and fluid loss volume was 44 to 96 mL
  • As the plugging system dosage rose to 30%, the filter cake reached a maximum compressive strength of 17.5 MPa and a thickness of about 18 mm
  • The compressive strength reported was the 24-hour compressive strength of the filter cake
  • At 150 degrees Celsius, cumulative fluid loss was 96 mL. The seal held pressure for 30 minutes without breakdown and withstood over 4 MPa, in a test where pressure was raised by 1 MPa every 2 minutes.
• The authors' conclusion: The authors concluded that the gel-based plugging system offered a durable, efficient solution to fluid loss problems in oilfield operations

Topics

Medical terms in this study, explained in our Lexicon: Thermal Stability.

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