<p>Carbonate acidizing is a well stimulation technique used to enhance the connectivity between the well and the reservoir. Simulating the acidizing process at the laboratory scale is a common strategy to estimate treatment performance. However, incorporating heterogeneities from real carbonate rocks can be challenging to represent in a numerical framework. This study proposes a methodology for simulating carbonate acidizing experiments using a high-resolution micro-CT image to derive the initial porosity field. The goal is to improve the representation of pore-scale heterogeneity and its effect on dissolution dynamics. A two-scale numerical model is employed, with fluid flow governed by the Navier–Stokes–Brinkman equation to account for transport in porous media. The results demonstrate that the model implemented successfully reproduces characteristic rock dissolution patterns, such as face dissolution, dominant, and ramified wormhole. The <InlineEquation ID="IEq1"> <InlineMediaObject> <ImageObject Color="BlackWhite" FileRef="40430_2025_5888_Article_IEq1.gif" Format="GIF" Height="16" Rendition="HTML" Resolution="72" Type="Linedraw" Width="43" /> </InlineMediaObject> <EquationSource Format="TEX">$PV_{BT}$</EquationSource> <EquationSource Format="MATHML"><math> <mrow> <mi>P</mi> <msub> <mi>V</mi> <mrow> <mi mathvariant="italic">BT</mi> </mrow> </msub> </mrow> </math></EquationSource> </InlineEquation> curve exhibits the expected U-shaped profile. Simulated pore volume to breakthrough (<InlineEquation ID="IEq2"> <InlineMediaObject> <ImageObject Color="BlackWhite" FileRef="40430_2025_5888_Article_IEq1.gif" Format="GIF" Height="16" Rendition="HTML" Resolution="72" Type="Linedraw" Width="43" /> </InlineMediaObject> <EquationSource Format="TEX">$PV_{BT}$</EquationSource> <EquationSource Format="MATHML"><math> <mrow> <mi>P</mi> <msub> <mi>V</mi> <mrow> <mi mathvariant="italic">BT</mi> </mrow> </msub> </mrow> </math></EquationSource> </InlineEquation>) values closely aligns with experimental data at low flow rates, while larger deviations occur at higher injection rates. These results highlight the importance of including realistic heterogeneity when modeling reactive flow.</p>

2-D numerical simulation of carbonate acidizing experiments using a micro-CT image-based model

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发表日期：

2025年9月26日

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Beatriz dos Santos Santana,
Bruno José Vicente,
Caio Cézar Góes Pereira,
Jair Rodrigues Neyra,
Daniel Nobre da Silva Nunes,
Cláudio Regis dos Santos Lucas,
Pedro Tupã Pandava Aum

摘要

Carbonate acidizing is a well stimulation technique used to enhance the connectivity between the well and the reservoir. Simulating the acidizing process at the laboratory scale is a common strategy to estimate treatment performance. However, incorporating heterogeneities from real carbonate rocks can be challenging to represent in a numerical framework. This study proposes a methodology for simulating carbonate acidizing experiments using a high-resolution micro-CT image to derive the initial porosity field. The goal is to improve the representation of pore-scale heterogeneity and its effect on dissolution dynamics. A two-scale numerical model is employed, with fluid flow governed by the Navier–Stokes–Brinkman equation to account for transport in porous media. The results demonstrate that the model implemented successfully reproduces characteristic rock dissolution patterns, such as face dissolution, dominant, and ramified wormhole. The $PV_{BT}$ $P V_{BT}$ curve exhibits the expected U-shaped profile. Simulated pore volume to breakthrough ( $PV_{BT}$ $P V_{BT}$ ) values closely aligns with experimental data at low flow rates, while larger deviations occur at higher injection rates. These results highlight the importance of including realistic heterogeneity when modeling reactive flow.