To address challenges associated with excessive water production in mature oil reservoirs, this study introduces a carboxymethyl cellulose (CMC)-based material as a novel preformed particle gel (PPG) designed to plug excessive water pathways and redistribute the subsequent injected water toward unswept zones. Through microwave-assisted grafting copolymerization of CMC with acrylamide (AM), we successfully generated multi-sized dry particles within the range of 250-800 µm. Comprehensive analyses, including Fourier-transform infrared spectroscopy (FTIR) and scanning electron microscopy (SEM), have confirmed the chemical composition and morphology of the resulting carboxymethyl cellulose-grafted crosslinked polyacrylamide (CMC/PAMBA). Swelling kinetics and rheology tests were conducted to confirm the ability of this novel PPG system to perform at different reservoir conditions. The results of core flooding experiments showed that the CMC/PAMBA PPG is capable of plugging open fractures with a water breakthrough pressure gradient of up to 144 psi/ft. This preformed particle gel (PPG) system was designed specifically for application in Middle East reservoirs, which are distinguished by high salinity and elevated temperature levels. This PPG system is able to swell up to 10 times its original size in seawater and maintain a strength of about 1300 Pa at a temperature of 80 °C. Further optimization is conceivable to enhance injection efficiency and achieve superior plugging outcomes.

Evaluation of Novel Preformed Particle Gel System for Conformance Control in Mature Oil Reservoirs.

Reducing water production from hydrocarbon wells is one of the major requirements to prolong the life span of production wells. Gel treatment is commonly regarded as one of the traditional cost-effective methods for water shut-off applications. Different gel systems have been developed to overcome the challenges of performing a successful water shut-off treatment. Each gel system has its advantages and disadvantages. A new proposed technology is to enhance the gel performance by utilizing nanomaterials in its composition. Nanomaterials such as nanosilica, nanoclay, and graphene can significantly modify gel properties to improve plugging efficiency. This paper provides a brief review of the added value of using nanomaterials in the structure of polymer in situ gel, preformed particle–gel, and nanosilica-based fluid. Nanomaterials such as nanoclay, nanosilica, and nanographene are capable of adjusting the properties of in situ gel, such as control of gelation time (9–10) hours and enhancing gel strength up to 4.5 times. Nanomaterials also improved the swelling ratio of the preformed particle–gel by up to 400%, accompanied by increased gel strength. Notably, nanosilica-based gels exhibit an exceptional plugging efficiency (100%). Additionally, the paper discusses how modeling can be used to overcome operational challenges in terms of placement and plugging performance.

A Review of Recent Developments in Nanomaterial Agents for Water Shutoff in Hydrocarbon Wells

Modern oil and gas extraction faces challenges, notably from the surplus of produced water, hampering hydrocarbon recovery and raising environmental and economic concerns. A promising solution is the injection of preformed particle gels (PPGs) into the reservoir's fractures and high permeability zones, facilitating production processes. This study introduces a novel class of inorganically cross-linked PPGs with exceptionally high swelling capacities, comprising sulfonated polyacrylamide cross-linked with aluminum attached to acetate, nitrate, sulfate, and lactate anions individually. These PPGs function as superabsorbents, capable of absorbing water at a ratio of 100–700 times their dry weight while maintaining adequate gel strength up to 2709 Pa. The study examines the influence of anionic groups attached to the aluminum on the swelling ratio, kinetics, and strength of the developed PPGs. It also reveals the impact of reservoir conditions, including temperature, salinity, and pH. The research explores the chemical compositions and cross-linking mechanisms by employing Fourier transform infrared spectroscopy (FTIR) spectroscopy and scanning electron microscopy (SEM) techniques. Thermogravimetric analysis (TGA) experiments further examine thermal stability. Results highlight the significant influence of anionic groups on PPG performance, with aluminum lactate providing the most robust and stable network structure, followed by aluminum sulfate, aluminum nitrate, and aluminum acetate, which offer the highest swelling PPG but are most sensitive under saline and diverse conditions. Notably, aluminum-based PPGs exhibit slow swelling kinetics, taking over 5 h. Furthermore, results showed that high cross-linker concentrations and increased salinity are associated with decreased PPG swelling ratios but enhanced mechanical strength. It is worth noting that PPG swelling and strength thrive within the pH range of 5–9 and below temperatures exceeding 75 °C, as conditions beyond these thresholds compromise their intricate three-dimensional (3D) network structures. 

Development of Inorganically Cross-Linked Sulfonated Polyacrylamide Preformed Particle Gels for Conformance Control: Impact of Anionic Groups

Carboxymethyl Cellulose-based Preformed Particle Gels for Water Management in Oil and Gas Reservoirs

Abstract Effective water management in oil reservoirs is crucial for maximizing hydrocarbon recovery while minimizing environmental degradation. This paper investigates the potential of innovative chemical techniques to control water production in oil reservoirs and compares these methods with traditional mechanical strategies. By reviewing over 70 case studies extensively, this research provides a detailed evaluation of different approaches to managing water cut. The study reveals that chemical methods, particularly those utilizing advanced polymer-based gels, are generally more effective than mechanical techniques. These methods are especially advantageous in settings with high water cuts and geologically complex reservoirs. Chemical treatments provide greater adaptability and cost-efficiency, significantly reducing the environmental impact compared to mechanical approaches. The primary aim of this research is to analyze the sources of water cut and evaluate common water shutoff operations to enhance reservoir management based on specific challenges, reservoir characteristics, and economic considerations. Our findings suggest using a two-step strategy: starting with mechanical control methods and then applying chemical treatments specifically designed for the reservoir’s unique physical properties. This not only improves oil recovery rates but also enhances economic efficiency by extending the reservoirs’ lifespan. Future research should focus on developing cost-effective, environmentally friendly chemical solutions suitable for various geological settings. Such advancements could significantly refine water management practices in oil fields, leading to better economic and environmental outcomes. 

Using new chemical methods to control water production in oil reservoirs: comparison of mechanical and chemical methods

Oil and gas extraction frequently produces substantial volumes of produced water, leading to several mechanical and environmental issues. Several methods have been applied over decades, including chemical processes such as in-situ crosslinked polymer gel and preformed particle gel, which are the most effective nowadays. This study developed a green and biodegradable PPG made of PAM and chitosan as a blocking agent for water shutoff, which will contribute to combating the toxicity of several commercially used PPGs. The applicability of chitosan to act as a crosslinker has been confirmed by FTIR spectroscopy and observed by scanning electron microscopy. Extensive swelling capacity measurements and rheological experiments were performed to examine the optimal formulation of PAM/Cs based on several PAM and chitosan concentrations and the effects of typical reservoir conditions, such as salinity, temperature, and pH. The optimum concentrations of PAM with 0.5 wt% chitosan were between 5–9 wt%, while the optimum chitosan amount with 6.5 wt% PAM was in the 0.25–0.5 wt% range, as these concentrations can produce PPGs with high swellability and sufficient strength. The swelling capacity of PAM/Cs is lower in high saline water (HSW) with a TDS of 67.2976 g/L compared with fresh water, which is related to the osmotic pressure gradient between the swelling medium and the PPG. The swelling capacity in freshwater was up to 80.37 g/g, while it is 18.73 g/g in HSW. The storage moduli were higher in HSW than freshwater, with ranges of 1695–5000 Pa and 2053–5989 Pa, respectively. The storage modulus of PAM/Cs samples was higher in a neutral medium (pH = 6), where the fluctuation behavior in different pH conditions is related to electrostatic repulsions and hydrogen bond formation. The increase in swelling capacity caused by the progressive increment in temperature is associated with the amide group’s hydrolysis to carboxylate groups. The sizes of the swollen particles are controllable since they are designed to be 0.63–1.62 mm in DIW and 0.86–1.00 mm in HSW. PAM/Cs showed promising swelling and rheological characteristics while demonstrating long-term thermal and hydrolytic stability in high-temperature and high-salinity conditions.

https://www.mdpi.com/2073-4360/15/8/1961/pdf?version=1681998600

Biodegradable Preformed Particle Gel (PPG) Made of Natural Chitosan Material for Water Shut-Off Application

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Biodegradable Preformed Particle Gel (PPG) Made of Natural Chitosan Material for Water Shut-Off Application