Summary Preferential fluid flow remains a major challenge in subsurface energy production and gas storage operations, resulting in excessive water production in mature oil fields, reduced heat extraction in geothermal reservoirs, and low sweep and storage efficiency in CO2-EOR projects. Polymer gels are widely used to mitigate high-permeability channels; however, conventional systems exhibit limited plugging efficiency and short lifetimes in ultra-high-temperature reservoirs due to poor thermal stability. This study presents a novel ultra-high-temperature-resistant preformed particle gel (UHT-PPG) developed for conformance control in reservoirs with temperatures of 150–275 °C and severe super-K or channeling problems. The material was evaluated in terms of swelling behavior, re-crosslinking capability, long-term hydrothermal stability, and plugging performance under ultra-high temperature reservoir conditions. UHT-PPG exhibits no swelling at room temperature and delayed swelling up to 20 days at 150 °C. UHT-PPG can re-crosslink to form a strong gel at temperatures above 180 °C. Arrhenius analysis predicts long-term hydrothermal stability exceeding 650 days at 250 °C and more than 9,000 days at 225 °C. Core flooding tests confirmed effective plugging performance in super-K models. Overall, the developed UHT-PPG demonstrates strong potential for improving conformance in ultra-high-temperature reservoirs by combining reliable placement, exceptional thermal durability, and effective plugging of preferential flow paths.

This study explores additive manufacturing of carbon fiber-reinforced thermoplastic composites using Composite Based Additive Manufacturing process. The objective of this work is to additively manufacture Carbon/PEEK and Carbon/Nylon 12 thermoplastic composites and then to evaluate performance of the resultant materials. Compression, tension, flexural and impact test were performed to characterize mechanical properties of the additively manufactured Carbon/PEEK and Carbon/Nylon 12 composites. Thermal characterization, specifically differential scanning calorimetry and thermogravimetric analysis, were both performed on each Carbon/PEEK and Carbon/Nylon 12 composites. From experimental testing Carbon/PEEK outperformed Carbon/Nylon for all the mechanical tests conducted. From DSC/TGA tests, degradation of Carbon/Nylon began around 298°C while Carbon/PEEK was stable until 350°C. Both samples had similar onset temperature for decomposition, around 370°C.

Although recrosslinkable preformed particle gel (RPPG) has been successfully evaluated in the literature for mitigating conformance problems in open- fracture applications, there are no studies that have examined the transportation and plugging performance of microsized RPPGs (micro- RPPG) in high- permeability channels. We systematically evaluated a novel micro- RPPG and its transportation mechanism in matrix- like media. The micro- RPPG can recrosslink to form a bulk gel after being placed in the reservoir, combining the advantages of both in situ and preformed particle gel (PPG) systems. This recrosslinking ability prevents the gel from being washed out easily, ensuring sustained performance under reservoir conditions. In this study, the micro- RPPG characterization, self- healing process, transportation behavior, and plugging performance were investigated. A sandpack model with multipressure taps was utilized to assess the micro- RPPG suspension's transport behavior and plugging efficiency. In addition, micro- optical visualization of the gel particles was deployed to study the particle size changes before and after the swelling process. Bottle tests showed that micro- RPPG could be dispersed and remain as separate particles in water with a concentration below 8,000 ppm, which is a favorable concentration for particle gel pumping. However, during the flooding test, the amount of micro- RPPG can be entrapped in the sandpack, resulting in a higher microgel concentration (higher than 8,000 ppm), endowing the gel particles with recrosslinking ability even with excessive water. The micro- RPPG could propagate through the sandpack model, and the required pressure gradient mainly depends on the average particle/pore ratio and gel concentration. The gel suspension significantly reduced channel permeability, providing sufficient resistance to post- waterflooding (more than 99.97% permeability reduction). In addition, the evaluation of micro- RPPG retention revealed that it is primarily affected by both gel concentration particle/pore ratios. We have demonstrated that the novel recrosslinkable micro- RPPG can transport through large channels, and it can also provide effective plugging due to its unique recrosslinking property. However, by this property, the new microgel exhibits enhanced stability and demonstrates resistance to being flushed out in such high- permeability environments. Furthermore, with the help of novel technology, it is possible to overcome the inherited problems commonly associated with in- situ gel treatments, including chromatographic issues, low- quality control, and shearing degradation.

This study explores additive manufacturing of carbon fiber-reinforced thermoplastic composites using the Composite-Based Additive Manufacturing (CBAM) process. Carbon/Nylon 12 and Carbon/PEEK composites were fabricated and evaluated through mechanical (compression, tensile, flexural, and impact) and thermal (DSC and TGA) tests. Carbon/PEEK exhibited superior mechanical performance, with 97.5

To understand the applicability of high-temperature preformed particle gel(HT-PPG)for control of short-circuiting in enhanced geothermal systems(EGSs),core flooding experiments were conducted on fractured granite cores under varying fracture widths,gel particle sizes and swelling ratios.Key parameters such as injection pressure,water breakthrough pressure,and residual resistance factor were measured to evaluate HT-PPG performance.The gel exhibited strong injectability,entering granite fractures at pressure gradients as low as 0.656 MPa/m;HT-PPG yields a superior sealing performance by significantly reducing the permeability;and dehydration occurs during HT-PPG propagation,with a dehydration ratio ranging from 4.71％to 11.36％.This study reveals that HT-PPG can be injected into geothermal formations with minimal pressure yet provides strong resistance to breakthrough once in place.This balance of injectability and sealing strength makes HT-PPG effective for addressing thermal short-circuiting in EGS reservoirs.

Re-crosslinkable preformed particle gel (RPPG) has been considered to be one of the most promising gels for dealing with fracture and void space conduit (VSC) conformance problems. However, the dehydration of RPPG during its propagation in the fracture-type features and its effect on gel properties remains unclear. This paper investigates the dehydration behavior during RPPG propagating in an open fracture using matrix-free fracture model. Then the results were verified using real fractured sandstone core model. Moreover, the gel properties after extruding a fracture were studied in detail including gel dehydration and gel strength. Results reveal that the RPPG properties changed significantly with increasing propagation distance, which correlated with the gel injection rate. At high gel injection rates, the dehydration and gel strength (G(y)) decrease with increasing propagation distance. In contrast, the opposite result was found at low injection rates. Based on the study of the different gel injection rates, it is found that dehydration time is another key factor affecting dehydration behavior. Results also indicate that the fracture width affects gel dehydration at different locations. Dehydration was more pronounced at narrow fractures but only in the inlet section, while in the outlet section, RPPG contains more water than the initial condition. This study has profound implications for field applications. It provides new insights into the transport of RPPG in fractures and helps field engineers to optimize the gel injection operations. (c) 2025 The Authors. Publishing services by Elsevier B.V. on behalf of KeAi Communications Co. Ltd. This is an open access article under the CC BY license (http://creativecommons.org/licenses/by/4.0/).

Abstract This paper surveys the role of re-crosslinkable preformed particle gels (RPPG) in addressing conformance challenges within mature oilfields. Despite widespread preformed particle gel (PPG) application in 15,000+ wells, their limitations in sealing fractures and conduits prevalent in mature reservoirs have driven the development of RPPG formulations. Synthesized in various sizes from micrometer to millimeter levels, these environmentally friendly RPPGs are tailored for diverse reservoir conditions. Findings showcase the successful laboratory-scale creation and upscaling of RPPG products, offering adaptability to temperatures from 20 to 175°C, customizable sizes, swelling ratios (5 to 40 times), and re-crosslinking times spanning minutes to days. Field applications, notably in Alaska's West Sak field, demonstrate the efficacy of RPPG in resolving Wormhole/Void Space Conduit issues. The paper outlines preferred functionality, properties, evaluation methods, application conditions, and field outcomes, emphasizing RPPG's amalgamation of PPG advantages and in-situ gels into a singular composition, mitigating uncertainties while markedly improving plugging efficiency in fractures and conduits through a rubber-like bulk gel formation. This comprehensive review presents RPPG as a pivotal innovation, poised to revolutionize conformance strategies in many mature oilfields, offering a promising solution to prevailing reservoir challenges

A recrosslinkable CO2-resistant branched preformed particle gel (CO2-BRPPG) was developed for controlling CO2 injection conformance, particularly in reservoirs with super-permeable channels. Previous work focused on a millimeter-sized CO2-BRPPG in open fractures, but its performance in high-permeability channels with pore throat networks remained unexplored. This study used a sandpack model to evaluate a micro-sized CO2-BRPPG under varying conditions of salinity, gel concentration, and pH. At ambient conditions, the equilibrium swelling ratio (ESR) of the gel reached 76 times its original size. This ratio decreased with increasing salinity but remained stable at low pH values, demonstrating the gel’s resilience in acidic environments. Rheological tests revealed shear-thinning behavior, with gel strength improving as salinity increased (the storage modulus rose from 113 Pa in 1% NaCl to 145 Pa in 10% NaCl). Injectivity tests showed that lower gel concentrations reduced the injection pressure, offering flexibility in deep injection treatments. Gels with higher swelling ratios had lower injection pressures due to increased strength and reduced deformability. The gel maintained stable plugging performance during two water-alternating-CO2 cycles, but a decline was observed in the third cycle. It also demonstrated a high CO2 breakthrough pressure of 177 psi in high salinity conditions (10% NaCl). The permeability reduction for water and CO2 was influenced by gel concentration and salinity, with higher salinity increasing the permeability reduction and higher gel concentrations decreasing it. These findings underscore the effectiveness of the CO2-BRPPG in improving CO2 sweep efficiency and managing CO2 sequestration in reservoirs with high permeability.

AbstractHydraulic fracturing treatments in unconventional infill (or "child") wells can be significantly affected by depletion from existing parent-well, resulting in asymmetrical fracture growth. These issues may lead to excessive load-water production, proppant deposition, casing deformation in the parent well, and unbalanced stimulation of infill wells. To mitigate these effects, various strategies have been proposed, including the use of far-field diverters in child wells and repressurization of parent wells. Additionally, an increasingly popular strategy involves injecting near-wellbore diverters to temporarily plug entry points into the parent wellbores during frac operations on infill wells. To achieve better application, a novel low-cost, self-degradable, re-crosslinkable preformed particle gel (RPPG) has been developed and evaluated. Preliminary characterization results indicate that this RPPG exhibits sufficient thermal stability and self-degrading performance at 150°C during the required timeframe, with minimal residues. It also demonstrates good injectivity and plugging efficiency.

Enhanced Geothermal System (EGS) reservoirs represent a vital frontier in clean energy production. However, short-circulation flow within these reservoirs can significantly affect their immediate efficiency and long-term viability. Injected cold fluids moving through wide fractures or direct channels between injection and production wells reduce thermal production temperatures, disrupting energy output. Preformed Particle Gels (PPGs) have proven effective in controlling preferential fluid flow in oil and gas reservoirs, effectively regulating fluid movement. This work explores the potential of a novel High-Temperature Preformed Particle Gel (HT-PPG), designed for geothermal applications, to plug fractures in a simulated geothermal reservoir. Core flooding experiments in coated and uncoated sandstone models were conducted under varying HT-PPG sizes, swelling ratios, and fracture widths to determine gel plugging efficiency. Variations in the HT-PPG injection pressure, breakthrough pressure, and residual resistance factor (Frr) were evaluated. Water breakthrough pressures can reach 464.10 psi/ft. While the stable injection pressure of HT-PPG decreased with increasing swelling ratio and fracture width, it was higher in uncoated cores. The HT-PPG significantly sealed the fractures, drastically reducing conductivities to millidarcy levels. This work validates HT-PPG a robust solution to mitigate fluid diversion challenges in sandstone EGS reservoirs, enhancing performance and advancing sustainable geothermal energy production.

In-situ crosslinking gel known for its cost-effectiveness, has been employed for decades to plug high-permeability features in subsurface environments. However, some commonly used crosslinkers are being phased out due to the increasingly rigorous environmental regulations. As a newly discovered environmentally friendly crosslinker, lysine can crosslink the partially hydrolyzed polyacrylamide through transamidation reaction. The present work aimed to study the effect of polymer composition and concentration on the gelation behavior of lysine and high molecular weight acrylamide-based polymers. Several commercial high molecular weight polymers with different contents of 2-Acrylamido-2-methyl-1-propane sulfonic acid (AMPS) including AN -105/125, SAV-55/ 37/28, and SAV-10 were deployed in this work. High-temperature/pressure-resistant glass tubes were used to study the crosslinking behavior. The plugging efficiency test used a high permeability sandstone core (1600 mD). Besides, the effect of salinity and pH on the crosslinking behavior, gel strength, and long-term thermal stability was also studied. Results showed that increasing the AMPS content could prolong the gelation time, but the polymer and lysine mixture failed to form gels when the AMPS content was excessively high. Additionally, increasing the AMPS content negatively affects the gel strength but positively impacts long-term thermal stability. Polymer gel with a relatively high content of AMPS could be stable in 0.5 % CaCl2 solution at 130 degrees C for over 200 days. The polymer/lysine gel system can efficiently plug the high permeability matrix, and the plugging efficiency is higher than 99 %. The polymer/lysine gel system is a promising green leakage control system in treating the high conductivity features in geothermal and oil reservoirs.

Preformed particle gel (PPG) treatment is a cost-effective technology for controlling excessive water production. However, PPG exhibits limited plugging efficiency when dealing with open fractures at high temperatures. This paper reports a novel environmentally friendly, high-temperature resistant re-crosslinkable PPG (EF-HT-RPPG). The polymer backbone of EF-HT-RPPG is methylene bisacrylamide crosslinked poly (acrylamide-co N-vinylpyrrolidone). The secondary crosslinker is pre-embedded during the synthesis process, and the hydrated gel particles can reform a bulk gel at high temperatures through chemical re-crosslinking between polymer chains and the secondary crosslinker which is lysine. This study investigated the swelling, re-crosslinking behavior, hydrolytic thermal stability, and plugging performance of the EF-HT-RPPG. Bottle tests were conducted to determine the swelling kinetics, re-crosslinking time, and thermal stability data. The plugging efficiency was assessed using a fracture model. EF-HT-RPPG could re-crosslink at 80-130 degrees C within a reasonable time. The storage modulus (G ') of the re-crosslinked gel with a swelling ratio of 10 was measured at 477 Pa. Additionally, gels prepared in Ekofisk formation water remained stable at 130 degrees C for over 350 days. The plugging test demonstrated that EF-HT-RPPG could be readily injected into the fracture, with a water breakthrough pressure gradient of 70 psi/ft.

Recrosslinkable Preformed Particle Gel (RPPG), a novel preformed particle gel of which particles can bond together to form a strong bulk gel system after being placed inside the target formation, has been successfully applied to control conformance problems for water flooding projects. However, no research has been conducted about whether RPPG is feasible in improving gas flooding performance in mature reservoirs. The study presents a systematic evaluation of acrylamide (AM) and 2-acrylamide-2-methylpropane sulfonate acid (AMPS) based RPPG including phase stability under different gel-gas kinetics and plugging performance to natural gas and water. Different experimental apparatuses were designed to quantify and visualize the RPPG phase stability under static and dynamic gel-gas interactions. The RPPG phase stability was evaluated under a different range of injection pressure, gas exposure time and swelling ratio. Also, the RPPG stability was compared to the in-situ gel system HPAM/Cr (III) which has been applied in oilfields to control gas injection conformance. The RPPG plugging efficiency was evaluated using open fractured cores with different apertures. The results showed that the RPPG was stable under both static and dynamic gel-natural gas interactions and was stable when being exposed to an acidic environment with an insignificant total percentage weight loss (< 3%). Additionally, the strength of the RPPG was further improved with the longevity of the gas exposure. Furthermore, different from the in-situ gel system HPAM/Cr(III), which exhibited high degree of dehydration under natural gas and exhibited substantial syneresis under acidic conditions, the microstructure of the RPPG remained stable after the dynamic gas exposure. The results of the coreflooding experiments demonstrated that the RPPG had excellent plugging efficiency, which was closely related to the swelling ratio and the fracture aperture. This is the first study where a polymer gel system has been systematically assessed through varied testing methodologies using natural gas as opposed to other studies where Nitrogen was used to simulate natural gas behavior. The robustness of the RPPG system makes it a viable candidate for improving the gas flooding processes in mature reservoirs dominated by conformance problems such as void space conduits, fractures, and high permeability channels.

As one of the most widely used technology to ameliorate the reservoir's heterogeneity, polymer gels have been applied for more than 60 years. However, how to plug fractured reservoirs with significant abnormal features, high temperature and high salinity, especially the divalent cations, is still a challenging target. This work sys-tematically evaluated a novel salt-resistant re-crosslinkable preformed particle gel (SR-RPPG) designed for fractured reservoirs with excellent salt resistance (up to 5 % CaCl2). We evaluated the swelling kinetics, thermal stability and plugging efficiency of this SR-RPPG. We assessed the swelling kinetic and re-crosslinking behavior of the SR-RPPG through the bottle test method. High temperature-resistant glass tubes with thermally stable O -rings were employed to evaluate the long-term thermal stability of the SR-RPPG product, and the testing lasted for over 200 days. A fractured model was used to assess the plugging efficiency of the SR-RPPG product. Results showed that the SR-RPPG could swell more than 30 times its original volume in 5 % CaCl2 and a middle east formation water. Besides, the SR-RPPG gel slurry can re-crosslink to form a rubber-like elastic bulk gel at 80-100 degrees C, and the elastic modulus of the re-crosslinked bulk gel can reach up to 1350 Pa with a swelling ratio of 10. The SR-RPPG prepared in 1 % NaCl, 2 % KCl, middle east formation water and 5 % CaCl2 with a swelling ratio of 10 have been stable for over 200 days at 100 degrees C. The core flooding test demonstrated that the SR-RPPG could efficiently block the open fractures, and the water breakthrough pressure gradient reached 927.30 psi/ft (20.98 MPa/m).

Summary Recrosslinkable preformed particle gels (RPPGs) have been used to treat the problem of void space conduits (VSC) and repair the “short-circuited” waterflood in Alaska’s West Sak field. Field results showed a 23% increase in success rates over typical preformed particle gel (PPG) treatments. In this paper, we evaluated whether adding fiber into RPPGs can increase the RPPG plugging efficiency and thus further improve the success rate. We designed open fracture models to represent VSC and investigated the effect of swelling ratio (SR), fracture size, and fiber concentration on gel injection pressure, water breakthrough pressure, and permeability reduction. Results show that fiber can increase RPPG strength and delay its initial swelling rate, but an optimized fiber concentration exists. Beyond that, the fiber entangling problem can result in the recrosslinked bulk gel inhomogeneously and impact gel quality. The injection pressure of fiber-assisted RPPGs increased with the SR and fracture width. During post-injection water process, the breakthrough pressure and residual resistance factor increased when the RPPG SR and fracture width decreased. Fiber-assisted RPPGs can dramatically reduce the permeability of the fractured core up to 1.8×106 times. It is observed that the fiber-assisted RPPGs used in the experiment remain in a bulk form in the fracture when we open the fracture after water injection. Not only does the addition of fiber improve the plugging efficiency, but it also prevents particle precipitation along vertical fractures or conduits.

Acrylamide-based polymer gels have been applied to control the preferential flow in the subsurface for decades. However, some commonly used crosslinkers, such as Cr (III) and phenol-formaldehyde, are highly toxic and are being phased out because of stringent environmental regulations. This work uses l-lysine as the green crosslinker to produce acrylamide-based polymer gels. This article systematically studied the effect of lysine and polymer concentration, salinity, pH, and temperature on gelation behavior and thermal stability. Besides, the gelation mechanism and crosslinking density were elucidated in this work. A high-permeability sandstone core was used to test the plugging efficiency of this novel green gel system. This polyacrylamide/lysine system has a controllable gelation time. It can form gels at temperatures higher than 80 °C, with the gelation time from hours to days, and the elastic modulus of the gel can reach over 400 Pa. In addition, the crosslinked gels have been stable at 80 to 130 °C for over 200 days. This novel gel system could decrease rock permeability by over 1000 times. Besides, the Frrw is two times higher than the Frro, confirming that the current gel system can reduce the permeability to water more than that to oil. As a green gel system, this novel polymer gel system could replace the current toxic gel systems for the preferential fluid control for water management projects in oil and gas reservoirs, enhanced geothermal systems, and carbon capture and sequestration projects.

Microspheres have been proposed to be applied in controlling wastewater production for mature oilfields and migrating leakage for gas and nuclear waste storage. However, it remains challenging for stacked microspheres to maintain strong blocking ability in micron-sized small pores or fractures. In this study, a novel microsphere was developed with comprehensive properties including high deformability and long re-crosslinking time upon tunable swelling ratio for the applications. A dual covalent and physical crosslinking strategy was used to develop novel microspheres reinforced by a hydrogen bond (H-bond, between pyrrole ring and amide group) and coordination bond (between chromium acetate (CrAc) and carboxyl group via hydrolysis process). The microspheres were fabricated via radical suspension copolymerization of acrylamide (AM) and N-vinylpyrrolidone (NVP) in the presence of N, NMODIFIER LETTER PRIME-methylene-diacrylamide (MBA) with subsequent introduction of CrAc. MBA induced the strong crosslinking through a chemical covalent bond and H-bond triggered the weak crosslinking which was anticipated to prohibit the hydrolysis of the amide group. The H-bond delayed the formation of CrAc coordination bond by delaying the formation of carboxyl groups, resulting in achieving the re-crosslinking of the microspheres. As a result, the microspheres exhibit the tunable initial size (8-165 mu m) and swelling ratio (30-630 mu m), with controllable network parameters. The microspheres showed high migration ability (can transport through pores with 1/16 size of microsphere itself), and long re-crosslinking time (up to 16.5 days). The re-crosslinked gel demonstrated dual network structure with districted mesh size zeta distribution.

During drilling through highly permeable or fractured formations, the entire drilling fluid or most of it might be lost into formations; this phenomenon is called lost circulation. Lost circulation can cause serious issues during drilling, such as challenging well control operations, and in some cases, complete loss of the well. In this paper, a Low-Temperature Recrosslinkable Preformed Particle Gel (LT-RPPG) was evaluated in the presence of various conventional additives to control drilling fluid loss in fractured formations. The additives tested in the study included mica, walnut shell and bentonite. Different factors were investigated, including mica concentrations, mica particle size, walnut shell concentrations and bentonite. Core flooding experiments were conducted to evaluate the LT-RPPG with the various additives plugging performance utilizing open fractured cores. The results showed that by mixing the LT-RPPG with the drilling fluid, a stronger material, reflected in a higher elastic modulus and sealing pressure, was obtained as compared by solely hydrating the LT-RPPG with brine. Also, the addition of mica and walnut shell further improved the LT-RPPG strength. While the mica particle size selection influenced the LT-RPPG rheological properties, the results from the core flooding experiments indicated the mica particle size had insignificant impact on the sealing pressure as compared with the mica concentration. Among the different tested addtivies, the optimum improvement on the LT-RPPG plugging performance was obtained by introducing 1.00% walnut shell. The mixture achieved a sealing pressure up to 5685.41 psi/ft for 3.0 mm fracture width. Furthermore, the core flooding results exhibited that the LT-RPPG combined with the additives effectivility reduced the fracture permeability to more than 108 times even after the gel rupture by subsequent drilling fluid circulation.

Gel treatment has been widely applied to control conformance for improving oil recovery and control water production in mature oil fields. However, most of the hydrogel systems are limited when being applied in the harsh environments of high temperatures. A systematic evaluation was conducted in this study to evaluate a modified PPG product, the high temperature resistant re-crosslinkable preformed particle gel (HT-RPPG) which can re-crosslink to form a bulky material and keep thermostable in the large-opening features after placement. This material was developed to overcome the limitations of conventional PPGs in the reservoirs with large-opening features such as open fractures, void conduits, wormholes, and so on. The HT-RPPG can swell up to 18 times of its original size at room temperature (23 degrees C), and the swelling ratio is independent of brine concentration and types. We conducted a series of experiments to evaluate the effect of particle size, temperatures, swelling ratios, brine types on re-crosslinking time, as well as the gel strength, blocking performance and thermostability after re-crosslinking. Smaller particle sizes result in the HT-RPPGs swell and re-crosslink much faster. Higher temperatures increase the swelling and re-crosslinking rate, while the larger swelling ratios (more feeding brine) can slow down the re-crosslinking time. HT-RPPG re-crosslinking process can be delayed when the particles contact with Ca2+. Additionally, the re-crosslinking of HT-RPPG is a temperature-responsive reaction which can only start after reaching the target temperature of 100 degrees C or above. The HT-RPPG has kept its volume and strength stable at 100 to 130 degrees C for over 10 months so far. A blocking performance test was conducted by using the tubing model to simulate void-space conduit (VSC), and breakthrough pressure reached to 427 psi/ft.

One of the most prevalent, expensive, and time-consuming problems during drilling operations is the loss of circulation. Uncontrolled lost circulation of drilling fluids may lead to dangerous well control difficulties and, in some cases, complete loss of the well. In this paper, the ability of a low-temperature recrosslinkable preformed particle gel (LT- RPPG) has been evaluated to determine the extent to which it can be used to control drilling fluid losses during drilling operations. The RPPG consists of swellable gel particles that can self-crosslink to form a strong bulk gel in fractures to form strong plugging after being placed in the loss zones. We investigated the effect of the LT-RPPG swelling ratio and fracture width on its plugging efficiency to fractures through core flooding tests. Results showed that its sealing pressure can reach up to 1,381 psi/ft and permeability reduction more than 99.99% when the RPPG swelling ratio is five for the fracture with a width of 2.00 mm. LT- RPPG is a good candidate that can be used to control the severe or total loss during drilling operations.