New methods to evaluate impacts of osmotic pressure and surfactant on fracturing fluid loss and effect of contact angle on spontaneous imbibition data scaling in unconventional reservoirs

Pan, Bin; Clarkson, Christopher R.; Younis, Adnan; Song, Chengyao; Debuhr, Chris; Ghanizadeh, Amin; Birss, Viola I.

doi:10.1016/j.fuel.2022.125328

Cited by 17 publications

(22 citation statements)

References 48 publications

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“…Further, a more water-wet state leads to more snap off events [44,45], and therefore a more serious H2 loss and a smaller 𝐻 2−𝑊𝐹 . Moreover, during well shut-in, discontinuous H2 bubbles can exert strong resistance for the spontaneous imbibition of in-situ formation brine [46,47] -therefore, if RPH is present, the initial H2 concentration is higher around the wellbore region (which again results in a larger 𝐻 2−𝑊𝑃 at the beginning of each H2 withdrawal cycle). The observed 𝐻 2−𝑊𝐹 and 𝐻 2−𝑊𝑃 response to the withdrawal cycle is because 1) at the end of each H2 injection cycle, more H2 will be in place than the earlier injection cycle; and 2) at the end of each H2 withdrawal cycle, more H2 will be lost to the subsurface than the earlier withdrawal cycle [28].…”

Section: Impact Of Relative Permeability Hysteresis and Wettabilitymentioning

confidence: 99%

Impacts of relative permeability hysteresis, wettability, and injection/withdrawal schemes on underground hydrogen storage in saline aquifers

Pan

Li²,

Ren³

et al. 2023

Fuel

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Section: Impact Of Relative Permeability Hysteresis and Wettabilitymentioning

confidence: 99%

Impacts of relative permeability hysteresis, wettability, and injection/withdrawal schemes on underground hydrogen storage in saline aquifers

Pan

Li²,

Ren³

et al. 2023

Fuel

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“…The water–rock interaction between soluble minerals in the rock and water will affect the SI of water. More specifically, the soluble minerals in the rock are partially dissolved by the reaction with water, which has a certain effect on the SI of water, − and the previous studies’ results show that the salinity of water also has a great influence on SI. − In addition, clay minerals typically swell to a certain extent when in contact with water, complicating the pore structure of shale (e.g., blocking pores and throats) and sometimes reducing fluid migration rates. , For homogeneous porous media, the greater the tortuosity of the connected pore system, the longer the migration path of solute molecules through the same linear distance in the porous medium and the smaller the imbibition slope . Due to the strong heterogeneity and complex pore structure of shale with the coexistence of organic matter pores and inorganic pores, shale reservoirs often exhibit mixed wettability (Dalmatian wettability), which in turn affects the SI behavior. , The wettability and pore connectivity of shale reservoirs were previously evaluated by SI experiments. , However, the application of SI on the enrichment mechanism of hydrocarbons is quite limited.…”

Section: Introductionmentioning

confidence: 99%

Using Spontaneous Imbibition to Evaluate the Hydrocarbon Migration and Accumulation Potential of Shale Reservoirs: A Case Study of the Permian Fengcheng Formation in the Mahu Sag, Junggar Basin

Wang

Gao

et al. 2022

Energy Fuels

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Spontaneous imbibition (SI) has been used widely to characterize shale wettability and pore structures, which can significantly affect the migration and accumulation processes of shale oil. However, the application of SI in the enrichment mechanism of shale oil is quite limited. Therefore, focusing on the Permian Fengcheng Formation shale deposited in an alkaline lake environment in the Mahu Sag of Junggar Basin, this study conducts systematic SI experiments with complementary experiments such as contact-angle measurement, optical microscopy, field emission scanning electron microscopy, micro-CT, high-pressure mercury intrusion porosimetry, and N 2 adsorption to clarify the controlling factors of SI behavior of different fluids in shale and attempts to evaluate the migration and accumulation potential of shale reservoirs using SI. The results show that the more hydrophobic the sample is, the stronger the absorption of n-decane is, and the SI of n-decane reaches equilibrium quickly. The development of an alkaline mineral layer that is several millimeters thick in Fengcheng Formation shale could promote hydrocarbon migration due to the large particles of alkaline minerals (200−400 μm) and more development of intergranular microfractures, which can be indicated by the higher SI slope and imbibed oil volume. Using SI parameters, the shale hydrocarbon migration−accumulation index H m was proposed in this study; the greater the H m of the shale reservoir is, the more conducive to the migration and accumulation of shale oil the shale reservoir is. Four migration−accumulation patterns were established for different lithofacies in the study area, and the migration and accumulation potential of different lithofacies of shale from strong to weak is in the order of siltstone, shale with an alkaline mineral layer, laminated shale, and then massive shale, which is generally in line with the order of shale oil content. The validity of the proposed shale hydrocarbon migration−accumulation index is also confirmed using data from the literature.

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“…43 This phenomenon is typically achieved by injecting brine solutions with different salinity compared to the formation brine. 44 The injection-induced osmotic pressure triggers the migration of water molecules from the formation water toward the injected brine, resulting in a water flow into the porous media. The influx of water displaces the oil, improves fluid mobility, and ultimately leads to enhancing oil recovery.…”

Section: ■ Introductionmentioning

confidence: 99%

Effect of pH on the Dominant Mechanisms of Oil Recovery by Low Salinity Water in Fractured Carbonates

Kashiri,

Garapov,

Pourafshary

2023

Energy Fuels

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The spontaneous imbibition process involves the fluid flow driven by gravity and capillary forces between the matrix and fractures, which is a critical mechanism in oil production in naturally fractured reservoirs (NFRs). Previous studies have explored how various rock and fluid parameters, such as temperature, permeability, connate water saturation, and initial wettability, impact the performance of low salinity water in NFRs using spontaneous imbibition tests. In this particular study, we aimed to investigate the influence of pH on wettability alteration and oil recovery in carbonate-fractured porous media through imbibition at high temperatures. To accomplish this, we utilized a combination of imbibition tests, ion chromatography analysis, contact angle study, and ξ-potential and pH value measurements to verify changes in fluid–rock interactions and evaluate the driving mechanisms of incremental oil recovery by low salinity water at different pH conditions. Our test results have demonstrated that the ultimate recovery factor for each brine remains consistent regardless of the pH levels of the brine solution. However, we observed a significant variation in the oil recovery rate by imbibition. This suggests that the pH of the contacted brine has an impact on the dominant recovery mechanism. Our analysis of ion chromatography and data on the contact angle, ξ-potential, and pH variation has indicated that calcite dissolution and the alkali effect are the primary mechanisms at different pH values. At high pH conditions, the production rates are initially low due to the alkali effect, but they increase as calcite dissolution becomes active. In contrast, under low pH conditions, the recovery rate decreases during production due to the activation of the alkali effect.

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New methods to evaluate impacts of osmotic pressure and surfactant on fracturing fluid loss and effect of contact angle on spontaneous imbibition data scaling in unconventional reservoirs

Cited by 17 publications

References 48 publications

Impacts of relative permeability hysteresis, wettability, and injection/withdrawal schemes on underground hydrogen storage in saline aquifers

Impacts of relative permeability hysteresis, wettability, and injection/withdrawal schemes on underground hydrogen storage in saline aquifers

Using Spontaneous Imbibition to Evaluate the Hydrocarbon Migration and Accumulation Potential of Shale Reservoirs: A Case Study of the Permian Fengcheng Formation in the Mahu Sag, Junggar Basin

Effect of pH on the Dominant Mechanisms of Oil Recovery by Low Salinity Water in Fractured Carbonates

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