An Experimental Approach of a Robust Polymer Gels for Water Shutoff Applications in Carbonate Formations

Alabdrabalnabi, Mohammed; Almohsin, Ayman; Busaleh, Ahmed Sami; Alharbi, Bader

doi:10.2118/214168-ms

Cited by 3 publications

(2 citation statements)

References 12 publications

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“…Gelation time (GT) is one of the essential parameters for designing successful water shutoff treatments. Most mathematical models for polymer gels fundamentally include one dependent variable, “GT,” and three independent variables, temperature, polymer concentration, and crosslinker concentration. , To study the gelation kinetics of water shutoff in-situ gels, steady shear rate measurements have been widely used. − …”

Section: Utilizing Nanomaterials For Enhancing Gel Treatmentsmentioning

confidence: 99%

“…Most mathematical models for polymer gels fundamentally include one dependent variable, “GT,” and three independent variables, temperature, polymer concentration, and crosslinker concentration. 142 , 143 To study the gelation kinetics of water shutoff in-situ gels, steady shear rate measurements have been widely used. 144 − 147 …”

Section: Utilizing Nanomaterials For Enhancing Gel Treatmentsmentioning

confidence: 99%

See 1 more Smart Citation

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

Ali,

Alabdrabalnabi,

Ramadan

et al. 2024

ACS Omega

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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 shutoff 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.

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Section: Utilizing Nanomaterials For Enhancing Gel Treatmentsmentioning

confidence: 99%

Section: Utilizing Nanomaterials For Enhancing Gel Treatmentsmentioning

confidence: 99%

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

Ali,

Alabdrabalnabi,

Ramadan

et al. 2024

ACS Omega

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A gel system with long‐term high‐temperature stability for deep profile modification of high‐temperature oil and gas reservoirs

Tian,

Liu,

Liu

et al. 2023

J of Applied Polymer Sci

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Profile modification is the key for efficient development of oil and gas reservoirs, especially high‐temperature reservoirs, which requires the system to have good high‐temperature resistance. According to the characteristics of high‐temperature reservoir, a high temperature gel composed of terpolymer, modified phenolic resin, aromatic amine curing agent and thiourea was developed. The effects of different components on the properties of the gel system were clarified. Then, the long‐term thermal stability under high‐temperature conditions was studied. In addition, the plugging performance of gel system under different permeability and injection volume was studied. Finally, the gelation properties and plugging properties of gel system with the flow distance were studied by simulating the flow of porous media. The results show that the gel system has high strength and suitable gelation time, and it can be adjusted in real time according to different oilfield requirements. In the range of 75–150°C, the gel system had excellent long‐term stability. When the temperature was 75°C, no free water after 120 days, and the viscosity only decreased from 13,131 to 11,254 mPa·s. Even at 150°C, the viscosity was as high as 8350 mPa·s after 120 days, and the free water was only 5.5%. The gel system had good adhesion ability on the porous media surface and strong anti‐flooding properties. When the injection volume was 0.1 pore volume (PV in short), the plugging rate to the sand packed tube was 72.7%. When the injection volume was 0.5 PV, the plugging rate was as high as 97.6%. The plugging rate of the gel system for the sand packed tube with permeability of 500 mD was 98.7% when the injection volume was 0.5 PV. When the permeability increased to 3000 mD, the plugging rate still reached 92.3%. The gel system also had an excellent deep profile control ability, and the viscosity retention of at 60 cm was as high as 96%. When the flow distance was 2 m, the viscosity retention also reached 75%. The rheological properties also shown that the gel system had excellent shearing resistance and adsorption resistance. Finally, combined with the state of the gel system on the surface of the porous media, there was no cementation between the formation sand before the injection, and the sand particles did not stick to each other. After the gel was injected, the adhesion of gel system on the porous media surface was very strong. The 3D network structure was also very dense, the sand particles could have good cementation effect under the adhesion of gel system.

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From Lab to a Successful Field Operation: In-Situ Polymer Gel with Adsorption System for Water Shutoff Application

Almohsin,

Sharma,

Alabdrabalnabi

et al. 2024

Day 1 Mon, February 12, 2024

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Robust and cost-effective water shutoff technologies are required to improve oil recovery and avoid challenges such as undesired water production. Herein, we present a new chemical water shutoff technology: A composite polymer gel system for carbonate substrate formation, from research work to successful field implementation. The composite gel with controlled gelation time was developed to isolate water production zones over various parameters, including temperature, pressure, injectivity duration, and flow rate. The rheological property of matured gels was investigated, such as the storage modulus (G'). In addition, a robust process was implemented based on rigorous job design and preparation, precise execution with real-time downhole monitoring, and thorough post-job analysis. Indeed, production logging and a noise tool were run to confirm the water entry and ensure good cement isolation behind the casing across the target zone. Laboratory results revealed that the gelation time can be controlled by varying the amount of fluid component, allowing a predictable pumping time at the given temperature between minutes to more than 10 hours. The gel system showed a significant pressure increase after the treatment, with good durability and effective water shut-off during the extended core flooding experiment. Thus, it is in alignment with gel strength testing. Hence, during the job mix adequate formulations based on the real-time downhole temperature, recorded while simulating the formation cooldown during treatment squeeze between retrievable plug and inflatable packer. The bottom hole circulating temperature and pressure were then measured in real time to adjust the water shutoff fluid formulations and to avoid exceeding the differential pressure limitation of the inflatable packer. After squeezing and waiting on the gelation of the water shutoff fluid in three stages, a successful pressure test demonstrated that the high water cut zone is reduced. Analysis of the pre and post job through rate test using downhole production logging tool (PLT); confirmed the success of treatment with a significant reduction in water production for more than 60%. The new trend of using in-situ composite gel incorporated with adsorption system is a breakthrough water shutoff technology. Utilizing laboratory coupled with field data collected before, during, and after gel injection along with proper diagnostic are the key elements to increase the success rate.

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An Experimental Approach of a Robust Polymer Gels for Water Shutoff Applications in Carbonate Formations

Cited by 3 publications

References 12 publications

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

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

A gel system with long‐term high‐temperature stability for deep profile modification of high‐temperature oil and gas reservoirs

From Lab to a Successful Field Operation: In-Situ Polymer Gel with Adsorption System for Water Shutoff Application

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