Impact of Fluid Distribution on Scale Inhibitor Squeeze Treatments in Pattern Floods and Fractured Wells

Rakhimov, Arman Zhassanovich; Vazquez, Oscar; Mackay, Eric James

doi:10.2118/131724-ms

Cited by 3 publications

(1 citation statement)

References 25 publications

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“…In a fractured well, the inhibitor is more retarded by contact with rock over a greater distance in comparison to a matrix with radial treatment [25]. In a fractured well, the inhibitor is more retarded by contact with rock over a greater distance in comparison to a matrix with radial treatment [25].…”

Section: Precipitation Squeeze Methodsmentioning

confidence: 94%

Scale inhibitors

2015

Petroleum Engineer's Guide to Oil Field Chemicals and Fluids

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In certain operations in petroleum industries, such as production, stimulation, and transport, there is some risk of scale deposition. Scaling can occur when a solution becomes supersaturated, which occurs mostly if the temperature changes in the course of injection operations.Also, if two chemicals that will form a precipitate are brought together, a scale is formed, for example, if a hydrogen fluoride solution meets calcium ions. From a thermodynamic perspective, there is a stable region, a metastable region, and an unstable region, which are separated by the binodal curve and the spinodale curve, respectively.Scales may consist of calcium carbonate, barium sulfate, gypsum, strontium sulfate, iron carbonate, iron oxides, iron sulfides, and magnesium salts [1]. In the literature some monographs, for example, Corrosion and Scale Handbook [2], as well as reviews [3] on scale depositions are available. Case studies have been presented for North Sea carbonate reservoirs [4, 5] and Gulf of Mexico [6]. A more recent work focuses on green systems [7]. SCALE PREDICTIONAn overview of scale prediction and control has been presented [8]. The challenges of scale prediction at high temperature, high pressure, and high total dissolved solids and an accurate model to predict pH, scale indices, density, and inhibitor needs at these conditions have been discussed and reviewed. CLASSIFICATION AND MECHANISMThe problem is basically similar to preventing scale inhibition in washing machines. Therefore similar chemicals are used to prevent scale deposition. Scale inhibition can be achieved either by adding substances that react with potential scale forming substances so that from the view of thermodynamics the stable region is reached or by adding substances that suppress crystal growth.Petroleum Engineer's Guide to Oil Field Chemicals and Fluids. http://dx.

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Section: Precipitation Squeeze Methodsmentioning

confidence: 94%

Scale inhibitors

2015

Petroleum Engineer's Guide to Oil Field Chemicals and Fluids

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Scale inhibitors

Fink

2021

Petroleum Engineer's Guide to Oil Field Chemicals and Fluids

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Improving Scale Inhibitor Squeeze Design for Naturally Fractured Reservoirs

Spooner¹,

Stalker²,

Wright³

et al. 2014

Day 2 Thu, May 15, 2014

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Scale Inhibitor (SI) squeeze treatments continue to be an important method for delivering chemical to the production system. However, while SI squeeze treatments in unfractured reservoirs can generally be readily simulated in matrix flow models, designing such treatments for application in fractured reservoirs is less routine, and resulting field treatment lifetimes can be disappointing. One reason for this is that the flow process and transport mechanisms by which the inhibitors are retained in fractured formations differs considerably from simple matrix flow. In this paper we expand upon previously published work examining the impact of squeeze treatment design on the outcome of a SI squeeze treatment for a fractured well using a novel fractured well squeeze model. In previous papers, we highlighted the importance of diffusion-controlled transport of SI in low permeability tight matrix fractured reservoirs where little matrix flow is possible. In this paper, we report continuing developments of the fracture squeeze model and demonstrate how differences between advection and diffusion-controlled inhibitor transport can significantly alter the predicted squeeze treatment lifetimes, and suggest appropriate treatment design modifications to improve SI squeeze treatments in such fractured reservoirs. This paper will demonstrate that such differences in transport mechanisms directly impacts the distribution of scale inhibitor within the near-wellbore region during the treatment phase. In fractured systems, this SI distribution is affected both by the extent of propagation of injection fluid through the fracture network and rate of diffusion into the surrounding matrix rock. This work examines the influence of factors such as injection rate, soak time, inhibitor diffusivity and retention/release properties on the matrix material. By adjusting injection parameters such as injection rate and soak time in the treatment design, a more desirable distribution of scale inhibitor can be obtained, resulting in improved predicted treatment lifetimes. Thus, using the fracture squeeze model to provide a fuller simulation of the inhibitor transport, retention and release mechanism active in a fractured reservoir, we highlight potential placement issues for such reservoirs and demonstrate methods to improve squeeze design for fractured wells.

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Impact of Fluid Distribution on Scale Inhibitor Squeeze Treatments in Pattern Floods and Fractured Wells

Cited by 3 publications

References 25 publications

Scale inhibitors

Scale inhibitors

Scale inhibitors

Improving Scale Inhibitor Squeeze Design for Naturally Fractured Reservoirs

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