A system for improved oil extraction through in-situ generation of surfactants

Abstract

A system (100) for improved oil recovery through in-situ surfactant generation, comprising: a) a unit (102) for the preparation of an alkaline solution, configured to prepare an alkaline solution using three alkaline agents, namely Na 2 CO 3, NaOH and KOH; b) an injection unit (104) comprising a high-precision Quizix pump (104a) configured to inject the alkaline solution into a reservoir at controlled rates; c) a monitoring unit (106) configured to measure the interfacial tension (IFT) between oil and water phases; and d) a production unit (108) configured to pump mobilised oil.

Description

FIELD OF THE INVENTION

[0001] The present disclosure relates to a system for enhanced oil recovery through in-situ generation of surfactants. More specifically, the present invention relates to a system that facilitates the in-situ generation of surfactants by alkaline agents to enhance oil recovery. BACKGROUND OF THE INVENTION

[0002] Chemical oil recovery (EOR) methods, particularly surfactant flooding and surfactant-based techniques, are widely used to enhance oil recovery by reducing interfacial tension (IFT) and altering reservoir wettability. Conventional approaches use high concentrations of external surfactants, typically up to 5 wt%, along with strong bases such as NaOH and KOH. While these methods demonstrate the ability to reduce IFT and alter wettability, they have several critical limitations.

[0003] First, the required high surfactant concentration significantly increases operating costs. Second, significant surfactant adsorption on reservoir rocks reduces their effectiveness, necessitating even higher dosages. Third, the reaction between strong alkalis and reservoir minerals leads to precipitate formation, which reduces permeability and impedes fluid flow. Furthermore, the use of low-viscosity solutions leads to unstable displacement fronts, causing fingering effects and poor sweep efficiency.

[0004] The present invention overcomes these limitations with a system configured for in-situ surfactant generation. By using low-cost alkaline agents (Na2CO3, NaOH, and KOH) at significantly reduced concentrations of 0.1 wt.%, the invention enables the generation of surfactants directly at the oil-water interface by reacting with the acidic components of crude oil. This eliminates the need for expensive external surfactants and minimizes problems with surfactant adsorption, while increasing displacement efficiency through improved viscosity control. SUMMARY OF THE INVENTION

[0005] The present disclosure relates to a system for enhanced oil recovery through in-situ generation of surfactants. The present invention provides an innovative enhanced oil recovery (EOR) system that utilizes in-situ generation of surfactants using low-cost alkaline agents. The system uses Na2CO3, NaOH, and KOH at minimal concentrations (0.1 wt%) to react with the acidic components of crude oil and generate surfactants directly at the oil-water interface. This process produces RCOO-Na+ surfactants that effectively reduce interfacial tension while forming water-in-oil emulsions that stabilize the displacement front and prevent fingering effects.

[0006] The present disclosure is intended to provide a system for enhanced oil recovery through on-site surfactant generation. The system comprises: an alkaline solution preparation unit configured to produce an alkaline solution using three alkaline agents, namely Na2CO3, NaOH, and KOH; an injection unit comprising a high-precision Quizix pump and configured to inject the alkaline solution into a reservoir at controlled rates; a monitoring unit configured to measure the interfacial tension (IFT) between oil and water phases; and a production unit configured to extract mobilized oil.

[0007] An objective of the present disclosure is to provide a system for enhanced oil recovery through on-site surfactant generation.

[0008] Another object of the present disclosure is to provide a cost-effective EOR system by in-situ generation of surfactants using low concentration alkaline agents.

[0009] Another objective of the present disclosure is to minimize surfactant adsorption losses to reservoir rock by generating surfactants directly at the oil-water interface.

[0010] Another objective of the present disclosure is to improve sweep efficiency by stabilizing the displacement front by increasing emulsion viscosity.

[0011] To further clarify the advantages and features of the present disclosure, a more detailed description of the invention will be given with reference to specific embodiments thereof, which are illustrated in the accompanying drawings. It should be noted that these drawings represent only typical embodiments of the invention and are therefore not to be considered limiting its scope. The invention will be described and explained in additional detail and in greater detail with reference to the accompanying drawings. SHORT DESCRIPTION OF THE FIGURE

[0012] These and other features, aspects, and advantages of the present disclosure will be better understood when the following detailed description is read with reference to the accompanying drawings, in which like characters represent like parts throughout. Where: Fig. 1 shows a block diagram of a system for enhanced oil recovery through in-situ surfactant generation according to an embodiment of the present disclosure.

[0013] Furthermore, those skilled in the art will appreciate that elements in the drawings are shown for convenience and may not necessarily be drawn to scale. For example, the flowcharts illustrate the method by key steps to enhance understanding of aspects of the present disclosure. Furthermore, with respect to device construction, one or more components of the device may have been represented in the drawings by conventional symbols, and the drawing may show only the specific details relevant to understanding embodiments of the present disclosure in order not to clutter the drawings with details that would be readily apparent to those skilled in the art who would benefit from the description herein. DETAILED DESCRIPTION:

[0014] To facilitate an understanding of the principles of the invention, reference will now be made to the embodiment illustrated in the drawings and described in specific language. It is to be understood, however, that no limitation on the scope of the invention is intended thereby, since such changes and further modifications of the illustrated system, and such further applications of the principles of the invention as illustrated therein, are contemplated as would normally occur to one skilled in the art to which the invention pertains.

[0015] It will be understood by one skilled in the art that the foregoing general description and the following detailed description are exemplary and explanatory of the invention and are not intended to be limiting thereof.

[0016] References in this specification to "one aspect," "another aspect," or similar language mean that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the present disclosure. Therefore, occurrences of the phrase "in one embodiment," "in another embodiment," and similar language throughout this specification may or may not all refer to the same embodiment.

[0017] The terms "comprises," "comprising," or other variations thereof are intended to cover non-exclusive inclusion, such that a process or method comprising a list of steps not only includes those steps, but may also include other steps not expressly listed or inherent in such process or method. Likewise, one or more devices or subsystems or elements or structures or components preceded by "comprises...a" does not preclude, without further limitation, the existence of other devices or other subsystems or other elements or other structures or other components or additional devices or additional subsystems or additional elements or additional structures or additional components.

[0018] Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs. The system, methods, and examples provided herein are for illustrative purposes only and should not be considered limiting.

[0019] Embodiments of the present disclosure will be described in detail below with reference to the accompanying drawings.

[0020] Fig. 1 shows a block diagram of a system for enhanced oil recovery through in-situ surfactant generation according to an embodiment of the present disclosure.

[0021] With reference to Fig.1, the system (100) comprises an alkaline solution preparation unit (102) configured to prepare an alkaline solution using three alkaline agents, namely Na2CO3, NaOH and KOH; an injection unit (104) comprising a high-precision Quizix pump (104a) and configured to inject the alkaline solution into a reservoir at controlled rates; a monitoring unit (106) configured to measure the interfacial tension (IFT) between the oil and water phases; and a production unit (108) configured to extract mobilized oil.

[0022] In one embodiment, the alkaline solution preparation unit (102) is configured to maintain the concentration of the alkaline agent at 0.1% by weight.

[0023] In one embodiment, the monitoring unit (106) is further configured to monitor the formation of water-in-oil emulsions and to measure the emulsion viscosity, and wherein the monitoring unit (106) further monitors the mobilization of trapped oil droplets in the reservoir caused by the reduction in IFT.

[0024] In one embodiment, the system (100) further comprises a reaction monitoring unit (110) configured to monitor the formation of surfactants at the oil-water interface.

[0025] In one embodiment, the system (100) further comprises a displacement efficiency measuring unit (112) configured to measure the sweep efficiency of the oil displacement process and to monitor fingering effects during the displacement process.

[0026] In one embodiment, the system (100) further comprises a precipitation control unit (114) configured to control the formation of Ca (OH) 2- to suppress precipitation in the reservoir.

[0027] In one embodiment, the system (100) further comprises an analysis unit (116) configured to measure the percentage of oil recovery relative to the original oil supply (OOIP) and to compare the recovery efficiency with the conventional flooding technique.

[0028] In one embodiment, the monitoring unit (108) is configured to check for a reduction in interfacial tension from 12 mN / m to less than 0.01 mN / m.

[0029] The present invention relates to a system for enhanced oil recovery through on-site surfactant generation. The system consists primarily of an alkaline solution preparation unit and a precision Quizix pump injection system. The system includes monitoring units for measuring interfacial tension, tracking emulsion formation, and analyzing oil recovery, as well as special units for controlling precipitate formation and measuring displacement efficiency.

[0030] The present invention addresses the challenges of enhanced oil recovery (EOR) by introducing an innovative system that utilizes on-site surfactant generation. This system uses low-cost alkaline agents such as sodium carbonate (Na2CO3), sodium hydroxide (NaOH), and potassium hydroxide (KOH) at reduced concentrations (0.1 wt%). These agents react with the acidic components in crude oil to generate surfactants directly at the oil-water interface, eliminating the need for expensive external surfactants. Generating surfactants in this way reduces chemical costs while minimizing surfactant adsorption to reservoir rocks, thereby improving its efficiency. Emulsification also increases the viscosity of the displacement fluid, stabilizes the displacement front, and reduces the occurrence of fingering effects. For example, the chemical reaction between a carboxylic acid (RCOOH) and NaOH forms a surfactant (RCOO).- N / a + ), which reduces interfacial tension (IFT) and improves oil recovery.

[0031] This invention offers significant advantages by reducing dependence on external surfactants and lowering chemical costs to less than 0.1 wt% of the solution. Surfactants formed at the oil-water interface not only improve recovery but also minimize adsorption, making them more effective. Emulsification of water in oil further increases the viscosity of the displacement fluid and improves displacement stability. Careful selection of alkaline concentrations prevents the formation of precipitates that can otherwise impair reservoir permeability. For example, reactions that lead to precipitates, such as the formation of calcium hydroxide (Ca(OH)2) from calcium ions and hydroxide ions, are suppressed by controlling alkali concentrations.

[0032] Previous laboratory tests have demonstrated the effectiveness of this method. By using 0.1 wt% sodium carbonate, the interfacial tension could be significantly reduced from 15 mN / m to 0.01 mN / m within 30 minutes, enabling better oil mobilization. Core flooding experiments showed that this technique could recover up to 58% of the original oil present (OOIP), compared to only 35% with the conventional technique. Furthermore, breakthrough times remained stable, indicating improvements in both microscopic displacement efficiency and macroscopic sweep efficiency. Micromodel observations also showed that emulsification stabilized the displacement process and reduced fingering effects.The microscopic displacement efficiency (Ed), calculated as the ratio of produced oil to original oil volume, reached 72% for alkaline flooding, compared to 45% for water flooding. A post-experiment scanning electron microscopy analysis confirmed minimal formation damage with no significant clay swelling or precipitation.

[0033] This invention overcomes the limitations of conventional EOR techniques by combining low-cost alkaline agents with on-site surfactant generation. It improves overall production efficiency, reduces formation damage, and provides a sustainable, economical solution for oil production from challenging reservoirs, particularly those containing heavy oils with high acidity.

[0034] Enhanced oil recovery (EOR) techniques aim to increase the efficiency of oil production from decommissioned reservoirs through primary and secondary recovery techniques. This invention improves oil production by generating surfactants directly in the reservoir. The process improves oil displacement and mobilizes residual hydrocarbons, particularly in challenging reservoirs where conventional techniques fail. By emulsifying water in oil, the viscosity of the displacing fluid increases, creating a more stable front that minimizes bypassing oil-rich zones. This ensures more uniform displacement and significantly improves production efficiency, especially in reservoirs with severe viscous fingering or residual oil that cannot be reached with conventional techniques.

[0035] One of the main advantages of this approach is the significant reduction in operating costs. Conventional EOR techniques rely on high concentrations of surfactants and cosurfactants, which drive up costs. This invention reduces the need for external surfactants by generating them in situ at the oil-water interface, even at very low concentrations (as low as 0.1 wt%). This results in significant savings in chemical costs, handling, and storage, making the process more cost-effective. Furthermore, the logistical burden of handling large quantities of chemicals is minimized, further improving the economics of the technique.

[0036] Efficiency is a critical factor in maximizing oil recovery. Conventional techniques often struggle with uneven displacement, bypassing portions of the reservoir. By generating surfactants in situ through the interaction of alkaline agents and acidic crude oil components, this technique improves microscopic displacement efficiency and increases the viscosity of the displacement fluid. This results in a more uniform and effective fluid front, allowing oil to be displaced from a wider area and diverse pore spaces, even in reservoirs with complex geological features.

[0037] The adsorption of surfactants onto reservoir rock is a major challenge in conventional chemical flooding techniques because it reduces the surfactant concentration in the displacement fluid. This invention solves this problem by generating surfactants at the oil-water interface, limiting the dependence on external surfactants and minimizing adsorption. This ensures more efficient oil mobilization and reduces interfacial tension, improving flooding efficiency while reducing the frequency of chemical injections.

[0038] The proposed system is also highly adaptable to different reservoir conditions. By using cost-effective alkaline agents such as sodium carbonate, sodium hydroxide, and potassium hydroxide, the process can be adapted to reservoirs with different oil types, rock compositions, pressures, temperatures, and permeabilities. These agents react with acidic crude oil components to generate surfactants, optimizing the process for different geological conditions. This flexibility makes the system particularly suitable for heavy oil reservoirs and fields with high acidity, providing a reliable solution for a wide range of conditions.

[0039] This invention offers several advantages. It significantly reduces costs by minimizing dependence on expensive surfactants and cosurfactants. In-situ surfactant generation reduces chemical adsorption and enhances oil mobilization, thereby improving displacement efficiency. Furthermore, the use of low concentrations of alkaline agents helps prevent formation damage, preserve reservoir integrity, and maintain fluid flow. In heavy oil reservoirs, where high viscosity is a challenge, the emulsification of the oil by this system facilitates displacement and improves production efficiency.

[0040] Despite its advantages, the system has certain limitations. Its effectiveness depends on the presence of acidic components in the crude oil. In reservoirs with low-acid crude oil, surfactant generation may be less effective. Furthermore, varying reservoir conditions such as temperature and pressure can affect reaction rates and overall efficiency. Excessive use of alkaline agents can also lead to the formation of precipitates, potentially impairing reservoir permeability.

[0041] These limitations can be addressed through advanced reservoir characterization and modeling to identify areas of high acidity. The use of alternative alkaline agents or additives can improve surfactant production in low-acid reservoirs. Real-time monitoring systems and controlled chemical injection processes can optimize surfactant production, prevent formation damage, and ensure consistent performance.

[0042] Conventional chemical flooding techniques such as surfactant / micellar / polymer flooding rely heavily on external surfactants and polymers, resulting in high costs and challenges such as adsorption. Gas injection techniques such as CO2 flooding are less effective in reservoirs with low permeability or heavy oil. The proposed invention offers a cost-effective alternative by overcoming these challenges through efficient on-site surfactant generation, thus providing a more practical and economical solution for enhanced oil recovery.

[0043] The invention represents an advanced system for enhanced oil recovery (EOR) based on the in-situ generation of surfactants, offering an economical and efficient alternative to conventional EOR techniques. This innovative system uses low-cost alkaline agents such as sodium carbonate (Na2CO3), sodium hydroxide (NaOH), and potassium hydroxide (KOH) in minimal concentrations of only 0.1 wt.%. These alkaline agents interact with the acidic components of crude oil, primarily carboxylic acids (RCOOH), directly at the oil-water interface to form surfactants. The chemical process underlying this system can be described by the reaction RCOOH + NaOH → RCOO - N / a + + H2O, where RCOO - acts as a surfactant, effectively reducing interfacial tension (IFT) and facilitating the mobilization of residual oil.

[0044] Unlike conventional systems that rely on expensive external surfactants in concentrations of up to 5% by weight, this technique utilizes in-situ surfactant generation, significantly reducing costs. Furthermore, the system minimizes problems such as surfactant adsorption to reservoir rock and ensures that the effective surfactant concentration in the displacement fluid remains constant. This reduction in adsorption losses improves the overall efficiency of chemical flooding. By stabilizing the displacement front, the system achieves greater uniformity in oil recovery. Furthermore, the natural emulsification of water in oil increases the viscosity of the displacement fluid, thus preventing fingering and promoting uniform oil displacement. The improved viscosity of the emulsified system (µ-emulsion) exceeds that of the alkaline solution and contributes to the stability and efficiency of the system.

[0045] The system is carefully designed to prevent formation damage by controlling alkaline concentrations and thus avoiding undesirable reactions that can lead to precipitation. For example, the reaction Ca 2+ + 2OH -→ Ca(OH)2, which forms precipitates, is effectively suppressed, ensuring the operational integrity of the system. This design is particularly effective in reservoirs containing high-acid heavy oil, where conventional flooding techniques often fail due to severe finger formation or insufficient IFT reduction. Experimental evidence shows that the introduction of Na2CO3 at a concentration of 0.1 wt% reduces the IFT from 12 mN / m to less than 0.01 mN / m, resulting in significantly improved oil recovery rates. Laboratory core flooding tests further confirm the effectiveness of the system, demonstrating an increase in oil recovery of up to 60% of the original oil in place (OOIP), compared to less than 40% OOIP achieved with conventional techniques.

[0046] The invention also includes micromodel studies to provide valuable insights into microscale displacement mechanisms, such as pore emulsification and the dynamics of capillary forces. These findings enable the optimization of the system for different reservoir conditions and ensure its adaptability and effectiveness. By addressing the high costs, inefficiencies, and adsorption losses of existing techniques, this system advances the scientific understanding and practical application of chemical EOR.

[0047] Overall, this system offers a sustainable, cost-effective, and highly efficient solution for oil recovery, especially under challenging reservoir conditions. It represents a significant advance in the field of chemical EOR by combining innovative chemical interactions with a comprehensive understanding of displacement dynamics, making it a groundbreaking tool for enhanced oil recovery applications.

[0048] The Enhanced Oil Recovery (EOR) system generates surfactants on-site to maximize oil recovery from reservoirs. The system is configured to produce an alkaline solution using cost-effective agents such as sodium carbonate (Na2CO3), sodium hydroxide (NaOH), and potassium hydroxide (KOH). This prepared solution serves as the primary chemical medium required for surfactant generation in subsequent steps.

[0049] Quizix precision pump injects the alkaline solution into the reservoir, ensuring uniform distribution within the reservoir and optimal interaction with the existing fluids. Upon reaching the oil-water interface in the reservoir, the alkaline solution reacts with the acidic components of the crude oil, particularly carboxylic acids (RCOOH). This reaction leads to the formation of surfactants on site, as shown by the chemical reaction: RCOOH + NaOH → RCOO - N / a + + H2O. These surfactants play a crucial role in reducing the interfacial tension (IFT) between the water and oil phases.

[0050] The reduction in interfacial tension caused by the generated surfactants facilitates the mobilization of residual oil trapped in pore spaces. By reducing interfacial tension, the oil droplets detach more effectively from rock surfaces, increasing their mobility. Furthermore, the interaction of the generated surfactants with the crude oil leads to the formation of a water-in-oil emulsion. This emulsion increases the viscosity of the displacement front, stabilizes the flow, and improves the mobility ratio, which is essential for effective displacement.

[0051] The increased viscosity and stability of the displacement front prevent undesirable flow phenomena such as fingering, which can lead to uneven displacement. By minimizing these effects, the system improves recovery efficiency and ensures that the reservoir is displaced evenly. The mobilized oil is then directed toward the production well due to the combined effects of reduced interfacial tension and an optimized mobility ratio. The system's balanced pressure gradient, created during the injection process, facilitates this displacement.

[0052] In the final step, the displaced oil reaches the production well, where it is efficiently extracted. This extraction represents the culmination of the process and demonstrates a comprehensive and cost-effective oil recovery enhancement technique. Each step of the system is critical for efficient oil mobilization and extraction through on-site surfactant generation, providing a robust solution for enhanced oil recovery applications.

[0053] The present invention presents a novel system for the in-situ generation of surfactants designed to increase the efficiency of oil recovery (EOR) while minimizing the risk of formation damage. This system operates on the principle of injecting an alkaline solution into the reservoir, where it reacts with the acidic components present in the crude oil to generate surfactants directly at the oil-water interface. These surfactants play a crucial role in significantly reducing the interfacial tension (IFT) between oil and water, thus facilitating the mobilization and displacement of trapped oil. By utilizing this innovative approach, the system eliminates the need for high concentrations of expensive surfactants, thus providing a cost-effective solution. Furthermore, the process ensures minimal formation damage, a common problem with conventional EOR techniques.

[0054] In one embodiment, a micromodel of the proposed system is fabricated, comprising a fabricated reservoir measuring 60 mm × 60 mm × 0.085 mm. This micromodel replicates reservoir conditions at the microscale and exhibits a porosity of 52.48% and a permeability of 1600 millidarcy (mD). These properties are representative of typical reservoir rocks and allow detailed observation of fluid dynamics, surfactant generation, and oil displacement processes. The model also includes an injection mechanism that uses a high-precision Quizix pump to ensure a uniform and accurate delivery of the alkaline solution into the micromodel. This injection system replicates real reservoir conditions and maintains precise control over fluid flow, thereby improving the reliability of experimental observations.The micromodel investigates the mechanism of in-situ surfactant generation and its influence on oil recovery. The results show that in-situ surfactant generation effectively reduces interfacial tension (IFT), a crucial factor in improving oil displacement efficiency. Reducing IFT enables better oil movement and makes the displacement process more efficient. Furthermore, the system promotes the formation of stable emulsions, which increases the viscosity of the displacement fluid. This increased viscosity plays an important role in preventing fingering, a common problem that leads to uneven oil production. By reducing fingering, the system ensures more consistent and efficient oil production from the reservoir.These observations confirm the functionality and efficiency of this innovative enhanced oil recovery (EOR) technique, especially under challenging reservoir conditions. The controlled conditions of the micromodel experiments provide a reliable framework for analyzing the system's impacts and underscore its potential to improve oil recovery results in real-world applications.

[0055] The system uses three alkaline agents—sodium carbonate (Na2CO3), sodium hydroxide (NaOH), and potassium hydroxide (KOH)—as part of the surfactant generation process. These agents react with the acidic components of crude oil to produce surfactants directly in the reservoir. This reaction significantly reduces the IFT between oil and water, thus enabling improved oil displacement and recovery.

[0056] Overall, this invention provides an innovative and efficient on-site surfactant generation device that ensures enhanced oil recovery while addressing common challenges such as formation damage and high operating costs. By replicating reservoir conditions through a carefully designed system, it offers a reliable and scalable solution for the oil industry.

[0057] The system operates in a sequence of interconnected phases designed to enhance oil recovery by generating surfactants on-site. In the first phase, the injection phase, an alkaline solution is precisely prepared at the surface. This solution contains controlled concentrations of sodium carbonate (Na2CO3), sodium hydroxide (NaOH), and potassium hydroxide (KOH). A Quizix pump is used to inject this solution into the reservoir with high precision, ensuring consistent production and optimal interaction with the crude oil in the reservoir.

[0058] Once the alkaline solution is introduced into the reservoir, it enters the reaction zone. Here, the solution reacts with acidic components present in the crude oil, such as carboxylic acids (RCOOH). This chemical interaction leads to the formation of surfactants at the oil-water interface according to the reaction: RCOOH + NaOH → RCOO - N / a ++ H2O. The resulting surfactants significantly reduce the interfacial tension (IFT) between the oil and water phases, thus facilitating the mobilization of the trapped oil.

[0059] This is followed by the mobilization phase, in which the reduced IFT generated by the surfactants releases the previously immobile oil droplets in the reservoir pores. This process significantly improves the efficiency of oil displacement and enhances the production process. Furthermore, the surfactants promote the formation of water-in-oil emulsions, which contribute to a further reduction in IFT and increase the viscosity of the displacement fluid. This viscosity increase is crucial because it stabilizes the displacement front and prevents fingering, a phenomenon in which the displacement fluid bypasses large portions of the reservoir, leaving oil unused. The stabilized displacement ensures more consistent oil production from the reservoir.

[0060] Finally, during the production phase, the mobilized oil is displaced to the production wells, where it is extracted for subsequent processing. The system's ability to generate surfactants on-site ensures high production efficiency at low operating costs. Furthermore, the technology minimizes formation damage, making it an effective and sustainable solution for enhanced oil production.

[0061] The experimental results confirm the efficiency of the proposed system for the in-situ surfactant generation process. The system works by increasing the concentration of alkaline agents, which directly improves oil recovery rates. This improvement is achieved by more effectively reducing the interfacial tension (IFT) between oil and water, enabling better oil mobilization. Importantly, the use of low alkaline concentrations, particularly around 0.1 wt. %, ensures minimal risk of formation damage. This precaution preserves reservoir permeability and ensures that the system maintains high recovery efficiency without compromising the reservoir structure. The technique demonstrates improved microscopic displacement efficiency by significantly lowering the IFT between the oil and water phases.Furthermore, it improves macroscopic sweep efficiency due to the viscosity increase resulting from emulsification. This viscosity increase reduces the mobility ratio between the water, which acts as the displacement fluid, and the oil, which serves as the displaced fluid. By stabilizing the displacement front and preventing fingering, the system achieves a more consistent and efficient recovery process. Overall, this system offers significant potential for improving oil recovery while reducing operating costs and associated risks. The integration of low alkaline concentrations combined with effective IFT reduction and improved displacement dynamics makes this technique a viable solution for improving production performance in oil reservoirs.

[0062] The drawings and the foregoing description provide examples of embodiments. Those skilled in the art will recognize that one or more of the described elements may well be combined into a single functional element. Alternatively, certain elements may be separated into multiple functional elements. Elements from one embodiment may be added to another embodiment. For example, orders of the processes described herein may be changed and are not limited to the manner described herein. Furthermore, the actions of any flowchart need not be implemented in the order shown; nor do all actions necessarily need to be performed. Also, those actions that are not dependent on other actions may be performed in parallel with the other actions. The scope of the embodiments is in no way limited by these specific examples.Numerous variations, whether explicitly stated in the specification or not, such as differences in structure, dimensions, and material use, are possible. The scope of the embodiments is at least as broad as indicated in the following claims.

[0063] Advantages, other benefits, and solutions to problems have been described above with reference to specific embodiments. However, the advantages, benefits, solutions to problems, and any components that may cause an advantage or solution to occur or become more apparent are not to be construed as a critical, required, or essential feature or component of any or all of the claims. REFERENCES 100 Block diagram of a system for enhanced oil recovery through in-situ surfactant generation. 102 Plant for the production of alkaline solutions 104 Injection unit 106 Monitoring Unit 108 production units 110 Reaction Monitoring Unit 112 displacement power measurement unit 114 Rainfall Control Unit 116 Analysis Unit

Claims

[1] A system (100) for enhanced oil recovery by in-situ surfactant generation, comprising: a) an alkaline solution preparation unit (102) configured to prepare an alkaline solution using three alkaline agents, namely Na 2 CO 3, NaOH and KOH; b) an injection unit (104) comprising a high-precision Quizix pump (104a) configured to inject the alkaline solution into a reservoir at controlled rates; c) a monitoring unit (106) configured to measure the interfacial tension (IFT) between oil and water phases; and d) a production unit (108) configured to produce mobilized oil. [2] The system according to claim 1, wherein the alkaline solution preparation unit (102) is configured to maintain the concentration of the alkaline agent at 0.1% by weight. [3] The system of claim 1, wherein the monitoring unit (106) is further configured to monitor the formation of water-in-oil emulsions and to measure the emulsion viscosity, and wherein the monitoring unit (106) further monitors the mobilization of trapped oil droplets in the reservoir caused by the reduction in IFT. [4] The system of claim 1, further comprising a reaction monitoring unit (110) configured to monitor the formation of surfactants at the oil-water interface. [5] The system of claim 1, further comprising a displacement efficiency measuring unit (112) configured to measure the sweep efficiency of the oil displacement process and to monitor finger effects during the displacement process. [6] The system of claim 1, further comprising a precipitation control unit (114) configured to suppress the formation of Ca(OH)2 precipitates in the reservoir. [7] The system of claim 1, further comprising an analysis unit (116) configured to measure the percentage of oil recovery relative to the original oil level in place (OOIP) and compare the recovery efficiency with conventional flooding methods. [8] The system of claim 1, wherein the monitoring unit (108) is configured to check for a reduction in interfacial tension from 12 mN / m to less than 0.01 mN / m.

Images