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A paper presents laboratory research conducted to evaluate technological properties of the nanoparticle-induced water shut-off agent and to assess its potential for gas recovery enhancement in geo-physically complicated reservoir conditions. The studied water shut-off agent is an inverse emulsion generated through the synergy of physico-chemical reactions between natural and artificial surfactants with silicon dioxide nanoparticles (NPs). Ultra-hydrophobicity and stability of the nanoparticle-based emulsion (nano-emulsion) conveys game-changing technological properties, resulting in a high performance of the water shut-off agent. Introduced in this paper research program was specifically developed to meet an inquiry of gas-condensate fields operator for an efficient physico-chemical or chemical water shut-off technology with zero secondary damage to reservoir. Therefore, the research program aimed to evaluate technological properties of the emulsion system with nanoparticles (ESN) in the tight sandstone formation conditions 8990 psi and 230°F. Firstly, rheometric study and tests in an autoclave were conducted to measure rheology, stability, compatibility and floating property of the ESN water shut-off agent under heavier polymer-clay fluid. Secondly, core flooding tests were conducted on four sets of natural low-permeable sandstone core columns to assess reversibility feature of the ESN water shut-off agent and a threshold pressure of the gas-condensate breakthrough. Rheology of the investigated water shut-off agent characterized by the share thinning behavior, i.e., viscosity drops under rise of the share rate and the other way around. The pseudoplastic behavior of the ESN perfectly suits applications in gas wells because it improves processes of preparing and pumping the water shut-off fluid downhole, does not float under heavier process fluids and self-controllable in-situ. It was learned that the ESN is compatible with reservoir and process fluids, and stable at reservoir conditions 230°F and 8990 psi. The ESN's blockage reversibility feature was confirmed in core floods. Overall, the research results confirmed innovative properties of the ESN water shut-off technology with its wide-range compatibility and high stability properties.
A paper presents laboratory research conducted to evaluate technological properties of the nanoparticle-induced water shut-off agent and to assess its potential for gas recovery enhancement in geo-physically complicated reservoir conditions. The studied water shut-off agent is an inverse emulsion generated through the synergy of physico-chemical reactions between natural and artificial surfactants with silicon dioxide nanoparticles (NPs). Ultra-hydrophobicity and stability of the nanoparticle-based emulsion (nano-emulsion) conveys game-changing technological properties, resulting in a high performance of the water shut-off agent. Introduced in this paper research program was specifically developed to meet an inquiry of gas-condensate fields operator for an efficient physico-chemical or chemical water shut-off technology with zero secondary damage to reservoir. Therefore, the research program aimed to evaluate technological properties of the emulsion system with nanoparticles (ESN) in the tight sandstone formation conditions 8990 psi and 230°F. Firstly, rheometric study and tests in an autoclave were conducted to measure rheology, stability, compatibility and floating property of the ESN water shut-off agent under heavier polymer-clay fluid. Secondly, core flooding tests were conducted on four sets of natural low-permeable sandstone core columns to assess reversibility feature of the ESN water shut-off agent and a threshold pressure of the gas-condensate breakthrough. Rheology of the investigated water shut-off agent characterized by the share thinning behavior, i.e., viscosity drops under rise of the share rate and the other way around. The pseudoplastic behavior of the ESN perfectly suits applications in gas wells because it improves processes of preparing and pumping the water shut-off fluid downhole, does not float under heavier process fluids and self-controllable in-situ. It was learned that the ESN is compatible with reservoir and process fluids, and stable at reservoir conditions 230°F and 8990 psi. The ESN's blockage reversibility feature was confirmed in core floods. Overall, the research results confirmed innovative properties of the ESN water shut-off technology with its wide-range compatibility and high stability properties.
Water production management is a common concern for oil fields adopting water flooding. Water shut-off (WSO) technologies: both mechanical and chemical methods have been investigated to mitigate increasing water production. Mechanical methods like cementing or shut-off by completion types work within the wellbore. Crosslink polymer gels as chemical method penetrate by maximum 10 ft from the wellbore in most cases. Hence, the crossflow inside the reservoir is considered as a potential risk to deteriorate the WSO impact on production improvement. This paper focuses on an advanced nano-chemical WSO technology, which is emulsion system with supercharged nanoparticles (ESN®). The ESN® has unique features to overcome several difficulties which conventional chemical methods face frequently. Furthermore, the ESN® has a strong advantage that can selectively block water zone and penetrate in maximum 50 ft from the wellbore. A pilot test of chemical water shut off using ESN® is planned in an offshore carbonate oil field (Field-A) in Abu Dhabi. The Field-A has been developed under continuous water injection more than 25 years and suffers from the resultant high water production. Well-1 was selected as a candidate well for pilot test because this well had been unable to flow due to high water cut. As the first step of pilot preparation, the effectiveness of ESN® was evaluated using the numerical simulation model compared with conventional WSO methods. In the simulation model, local grid refinement (LGR) was applied at the grids including wellbore to replicate the penetration feature of each WSO. According to this model, the ESN® expected significant benefit on the well life extension by water cut reduction and increase in oil production compared with the conventional gels. For further detailed evaluation by the numerical model, the uncertainty of reservoir properties affecting crossflow was evaluated through sensitivity study. In the upper part of reservoir in the Field-A, there is high permeability streak which acts as a main flow path for injected water from injectors to producers. For vertical and deviated oil producers, the perforation was conducted below the high permeability streak to avoid early water breakthrough. With consideration of these specifications, a sensitivity study of vertical permeability and high permeability streak was conducted. As a result of sensitivity study, improvement of well performance by ESN® was expected with consideration of parameter uncertainty range, though incremental oil production is dependent on parameter value. As the next step of pilot preparation, this sensitivity study outcomes were also utilized to select such pilot well which can expect maximum incremental recovery by applying this technology.
Results of laboratory research conducted in the framework of laboratory program developed jointly by a technology provider and an offshore oil-gas fields operator are presented in this paper. The laboratory program included optimal list of experiments for testing physical and technological properties of the physico-chemical water shut-off agent, resulting in a ready-for-pilot solution at minimum cost and time. The studied water shut-off agent is an emulsion system with nanoparticles (ESN), which is an inverse emulsion augmented by the synergy of natural and artificial surfactants with supercharged silicon dioxide nanoparticles. The ESN consists of three liquid components: sea water, diesel and nanoparticle-based surfactant. One of the main tasks of this research was to study such features of the ESN as selectivity of blocking impact to water-bearing zones and reversibility of blocking effect in the oil-bearing zones of sandstone reservoirs in the Lower Miocene (2950 psi and 91°C) and Late Oligocene (3900 psi and 107°C) hydrocarbon formations. As a basic requirement from the operator, the ESN had to be stable at the said reservoir conditions and compatible with reservoir and process fluids. Besides that, the operator wanted to confirm that the ESN is an easy-to-handle water shut-off agent in the offshore environment, meaning that it can be prepared with ordinary equipment available at the vessel, all components are liquids easily mixed to each other at ambient conditions and ready-to-use composition properties do not change in time within the operation offshore. Thus, the laboratory program was executed in three successive stages, divided based on the experiment conditions: ambient; pressure & temperature; modeled reservoir conditions. In result, the ESN performed as stable and compatible water shut-off agent and met all requirements of the operator. In the series of core floods, conducted on eight sandstone cores of different permeability and saturation, it was confirmed that the ESN selectively and fully blocks water-saturated cores, while the oil-saturated cores permeability decreased slightly with clear tendency to full recovery under the flow of hydrocarbons.
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