Compatibility: A Key To An Efficient Matrix Acidizing Fluid Design

Ok, Dankwa; Appah, Dulu; Joel, OF; Ek, Asiam

doi:10.4172/2157-7463.1000274

Cited by 2 publications

(3 citation statements)

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“…The complex mineral composition of sandstone reservoirs, coupled with the complex pore structure in the formation, has caused the complexity of the acid rock reaction process in sandstone reservoirs. 11 In more than half a century of research, experts at home and abroad have been devoted to constructing mathematical models that can truly reflect the acid rock reaction process in sandstone reservoirs. 1 Most of the existing sandstone acid rock reaction mathematical models are based on the study of sandstone reaction kinetics, 12 and according to the treatment of sandstone reservoir mineral composition, the acid rock reaction mathematical models can be roughly classified into four major categories: set total parameter model, 13 one acid and two minerals model, two acids and three minerals model, 14 and geochemical model.…”

Section: Introductionmentioning

confidence: 99%

“…Sandstone matrix acidizing has been widely used in the field since the 1960s. The complex mineral composition of sandstone reservoirs, coupled with the complex pore structure in the formation, has caused the complexity of the acid rock reaction process in sandstone reservoirs 11 . In more than half a century of research, experts at home and abroad have been devoted to constructing mathematical models that can truly reflect the acid rock reaction process in sandstone reservoirs 1 .…”

Section: Introductionmentioning

confidence: 99%

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Research on high efficiency and retarded autogenous mud acid for plugging removal in a sandstone reservoir—Example of Bai 823 well area

Li,

Yang,

et al. 2023

Energy Science & Engineering

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Acidification, as an effective measure to remove blockages and restore oil well productivity, has received widespread concern. However, conventional acid systems can only be used to unblock near‐wellbore zones and are difficult to act on far‐wellbore reservoirs. In this article, scanning electron microscope, energy‐dispersive X‐ray spectroscope, and X‐ray diffractometer were used to analyze the blockages in the Bai 823 well area, and it was determined that their main components were CaCO3 and FeCO3, which provided the basis for the construction of the unblocking formula. Then, the acid dissolution experiments on the plugging materials showed that the dissolution rate of 10% HCl can reach more than 85% for the scale sample; the acid dissolution experiments on the rock sample showed that the autogenous mud acid has better dissolution performance and better retardation performance for the rock sample, and the effective action time is longer, so it can be used for deeper unplugging of the reservoir. Finally, the process parameters such as the optimal acid concentration, acid dosage, and discharge volume were optimized by establishing the fracture‐matrix acid flow reaction model. Research results indicate that the autogenous mud acid can act on the blockage in the far‐wellbore area to improve the acidification effect.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Research on high efficiency and retarded autogenous mud acid for plugging removal in a sandstone reservoir—Example of Bai 823 well area

Li,

Yang,

et al. 2023

Energy Science & Engineering

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“…Stimulation treatments, such as HF [4,5,6], matrix acidizing, acid fracturing [7,8,9], or EOR [6,10,11,12] are common techniques used to increase the extraction productivity. In all aforementioned cases, the stimulation (injection) fluid is a crucial element and must meet special requirements depending on the goal of the application [13,14,15]. After stimulation treatment, a part of this fluid remains within fractures, causing damage to the formation and reducing the stimulation effectiveness [16,17,18].…”

Section: Introductionmentioning

confidence: 99%

Impact of Nitrogen Foamed Stimulation Fluids Stabilized by Nanoadditives on Reservoir Rocks of Hydrocarbon Deposits

2019

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The first objective of this experiment was to improve the stabilization of N2 based foam with nanoparticles as an alternative to typical fracturing fluid, which consists of a gelling agent (HPG—hydroxypropyl guar). The second objective of the project was to investigate the damage caused by nanoparticle–based nitrogen foamed fracturing fluids (F.F) on a reference sandstone, using permeability and porosity tests, optical microscope with a Profilometer, and a scanning electron microscope (SEM). The properties of F.F with two types of SiO2 nanoparticles (hydrophilic fumed silica Areosil 300 and silica sol U-2 obtained by the sol-gel method), such as rheology and core damage, were investigated. The discussion of this research results is based on the stability tests carried out with the use of rheology and the foam half-life, formation damage ratio, and observation of exposed samples using SEM and the Profilometer. The permeability and porosity damage ratios of the damaged core samples were found to decrease when nitrogen foamed fluids were used. These results were confirmed with the Profilometer and SEM images. The experimental data showed that the foam stability increased when silica (SiO2) nanoparticles were added. SiO2 nanoparticle-surfactant-stabilized foam for fracturing is superior to traditional water-based fracturing fluids and causes lower core permeability damage than a traditional F.F.

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Compatibility: A Key To An Efficient Matrix Acidizing Fluid Design

Cited by 2 publications

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Research on high efficiency and retarded autogenous mud acid for plugging removal in a sandstone reservoir—Example of Bai 823 well area

Research on high efficiency and retarded autogenous mud acid for plugging removal in a sandstone reservoir—Example of Bai 823 well area

Impact of Nitrogen Foamed Stimulation Fluids Stabilized by Nanoadditives on Reservoir Rocks of Hydrocarbon Deposits

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