Laboratory study of Fracturing Fluid Migration due to Spontaneous Imbibition in Fractured Tight Formations

Dutta, Riteja

doi:10.2118/160915-stu

Cited by 7 publications

(4 citation statements)

References 6 publications

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“…Handy [65] defined it as the process in which a fluid is displaced by another fluid within a porous medium due to the effect of capillary forces alone. Other researchers like Bear [66], Bennion et al [67], Hoffman [68] and Dutta [69] have also interrogated the mechanisms of hydration imbibition.…”

Section: Hydration Imbibition and Fluid Retentionmentioning

confidence: 99%

Review of Geochemical and Geo-Mechanical Impact of Clay-Fluid Interactions Relevant to Hydraulic Fracturing

Awejori¹,

Radonjic²

2022

Emerging Technologies in Hydraulic Fracturing and Gas Flow Modelling

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Shale rocks are an integral part of petroleum systems. Though, originally viewed primarily as source and seal rocks, introduction of horizontal drilling and hydraulic fracturing technologies have essentially redefined the role of shale rocks in unconventional reservoirs. In the geological setting, the deposition, formation and transformation of sedimentary rocks are characterised by interactions between their clay components and formation fluids at subsurface elevated temperatures and pressures. The main driving forces in evolution of any sedimentary rock formation are geochemistry (chemistry of solids and fluids) and geomechanics (earth stresses). During oil and gas production, clay minerals are exposed to engineered fluids, which initiate further reactions with significant implications. Application of hydraulic fracturing in shale formations also means exposure and reaction between shale clay minerals and hydraulic fracturing fluids. This chapter presents an overview of currently available published literature on interactions between formation clay minerals and fluids in the subsurface. The overview is particularly focused on the geochemical and geomechanical impacts of interactions between formation clays and hydraulic fracturing fluids, with the goal to identify knowledge gaps and new research questions on the subject.

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Section: Hydration Imbibition and Fluid Retentionmentioning

confidence: 99%

Review of Geochemical and Geo-Mechanical Impact of Clay-Fluid Interactions Relevant to Hydraulic Fracturing

Awejori¹,

Radonjic²

2022

Emerging Technologies in Hydraulic Fracturing and Gas Flow Modelling

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“…Dutta et al [9] reported the quantitative characterization of the heterogeneity of rocks, tracking fracturing fluid migration with time and space, and an investigation on the effects of capillary pressure on fluid migration and retention in low-permeability sandstone cores utilizing CT scanning technology. Shi et al [10] explored the damage mechanism of guar gum fracturing fluids in the Sulige gas field through nuclear magnetic resonance (NMR) and core flooding experiments.…”

Section: Introductionmentioning

confidence: 99%

Study on the Imbibition Damage Mechanisms of Fracturing Fluid for the Whole Fracturing Process in a Tight Sandstone Gas Reservoir

Chen

Chen³

et al. 2022

Energies

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Tight sandstone gas is a significant unconventional natural gas resource, and has been exploited economically mostly through the application of hydraulic fracturing technology in recent decades. However, formation damage occurs when fracturing fluid percolates into the pores inside sandstones through imbibition driven by capillary pressure during fracturing operations. In this work, the formation damage resulting from the whole operation process composed of fracturing, well shut-in and flowback, and the degree of damage at different moments were investigated through core flow experiments and the low-field Nuclear Magnetic Resonance (NMR) technique. The results show that imbibition damage occurs starting from the contact surface between the formation and the fracturing fluid, which penetrates into an increasingly deep position with time down to a certain depth. The T2 spectra of NMR at different moments indicates that fracturing fluid initially enters the small pores, followed by the large pores due to the larger capillary pressure in the former. Thus, the sandstone cores with low permeability incur a higher degree of damage due to their stronger capability of retaining fracturing fluid compared to high-permeability cores. The front position of the fracturing fluid imbibition at different moments, along with the degree of damage, were characterized through the one-dimensional encoding processing of the NMR signal. These results underlie the effective strategy to relieve formation damage resulting from imbibition during hydraulic fracturing operations.

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“…The processes of displacement and imbibition are carried out at the same time and interact with each other. Especially for small pores (25 nm < pore diameter ≤100 nm), whose capillary force and displacement pressure difference are relatively balanced, so it is difficult to distinguish the effects of imbibition and displacement [29][30][31]. (2) There is a big deviation in the definition of capillary force effect.…”

Section: Introductionmentioning

confidence: 99%

Imbibition Retention in the Process of Fluid Replacement in Tight Sandstone Reservoir

Yan

2022

Geofluids

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“Fracture network stimulation and oil-water infiltration and replacement” are recent attempts to effectively produce oil from tight reservoirs. On the one hand, the formation can be fractured by the fracturing fluid, which can carry proppant into fractures. On the other hand, the fracturing fluid can spontaneously infiltrate into the pores under the action of capillary pressure to displace the oil phase, thereby enhancing the oil recovery. To distinguish imbibition and displacement processes during fluid replacement in tight reservoirs is difficult, and the effect of these two processes is also vaguely defined. In this study, an experimental method that can visualize the imbibition and displacement process is proposed by combining the core slice displacement experiment. Based on this method, the process of imbibition and displacement can be effectively distinguished, and imbibition retention rate can be quantitatively characterized. The effectiveness of this method is proved by taking the core of Chang 7 tight sandstone reservoir in the Ordos Basin as the research object. The results show that the force direction of the fluid under imbibition is related to the wettability, and it is always from the wetting phase to the nonwetting phase, while the force direction of fluid under displacement is mainly related to the directivity of displacement pressure difference. Based on the difference of force action, imbibition and displacement can be quantitatively characterized, respectively. During the imbibition process, the peak value of the NMR curve corresponding to the small pore throat shifts to the left, and the signal amplitude increases. During the displacement process, the peak value of the NMR curve corresponding to the small pore throat has no obvious shift, nor signal amplitude change, but the peak value of the curve corresponding to the large pore throat shifts to the right. The results also indicate that there is an exponential negative correlation between imbibition retention rate and gas permeability. The greater the gas permeability is, the smaller the imbibition retention rate is.

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Laboratory study of Fracturing Fluid Migration due to Spontaneous Imbibition in Fractured Tight Formations

Cited by 7 publications

References 6 publications

Review of Geochemical and Geo-Mechanical Impact of Clay-Fluid Interactions Relevant to Hydraulic Fracturing

Review of Geochemical and Geo-Mechanical Impact of Clay-Fluid Interactions Relevant to Hydraulic Fracturing

Study on the Imbibition Damage Mechanisms of Fracturing Fluid for the Whole Fracturing Process in a Tight Sandstone Gas Reservoir

Imbibition Retention in the Process of Fluid Replacement in Tight Sandstone Reservoir

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