Geochemical, mineralogical and petrographical characteristics of the domanik formation from north samara region in the volga-ural basin, Russia: Implication for unconventional tight oil reservoir potential

Saeed, Shadi A.; Hakimi, Mohammed Hail; Al‐Muntaser, Ameen A.; Khamieva, Aliia N.; Varfolomeev, Mikhail A.; Vladimir, Morozov P.; Lashin, Aref; Abdelaal, Mohamed A.; Suwaid, Muneer A.; Mustapha, Khairul Azlan; Djimasbe, Richard; Kadyrov, Rail; Гареев, Б. И.; Kwofie, Michael

doi:10.1016/j.petrol.2022.111240

Cited by 16 publications

(3 citation statements)

References 45 publications

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“…As global economic development accelerates and industrial technology advances, the consumption of oil and gas is steadily rising, surpassing the capacity of conventional resources to meet society’s energy demands. − Currently, China possesses substantial tight oil resources distributed widely, boasting recoverable reserves amounting to 40% × 10 8 tons, primarily concentrated in Xinjiang Oilfield, Changqing Oilfield, and other regions, offering significant potential for exploration and development. − Tight oil reservoirs differ from conventional ones due to abundant nanoscale pores, intricate pore structures, elevated capillary resistance, and hindered crude oil flow. , Utilizing depletion mining in tight oil reservoirs can result in rapid pressure depletion, leading to shortened development cycles, diminished recovery rates, and elevated residual oil content. − Therefore, the implementation of appropriate stimulation measures following elastic mining is essential. At the same time, tight oil reservoirs generally have strong water sensitivity, making water injection production difficult and prone to irreversible damage to the formation.…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on Ethane-Dimethyl Ether Assisted CO₂ Displacement to Improve Crude Oil Recovery in Tight Reservoirs

Wang,

Su,

Wang

et al. 2024

Energy Fuels

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The difficulty to carry out water injection production in tight reservoirs is high, and this is easy to cause irreversible damage to the formation. Thus, increasing the recovery rate of tight oil through gas injection is gradually attracting attention. This article studies the saturation pressure and viscosity changes of CO 2 and composite gas (CO 2 −C 2 H 6 -dimethyl ether (DME)) in crude oil through PVT experiments. Finally, it reveals the degree of crude oil utilization under the context of different gas media and displacement pressures, through high-temperature and high-pressure core experiments. The results show that the ethane/ DME in the composite gas enhances the gas−liquid two-phase mixing ability of crude oil, improves the CO 2 viscosity reduction and dissolution ability, and significantly increases the fluidity of crude oil. With the increase of C 2 H 6 -DME mole fraction in the composite gas, the saturation pressure of crude oil increases by 25.81% from 13.83 to 17.41 MPa. The viscosity of crude oil decreases from 23.68 to 8.76 mPa•s. When the injection PV number is greater than 3 PV, the recovery rate of the three types of cores is stable in all regions, with the composite gas (CO 2 −C 2 H 6 -DME) having the best effect on improving the crude oil recovery rate.

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Section: Introductionmentioning

confidence: 99%

Experimental Study on Ethane-Dimethyl Ether Assisted CO₂ Displacement to Improve Crude Oil Recovery in Tight Reservoirs

Wang,

Su,

Wang

et al. 2024

Energy Fuels

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“…Many attempts have been made to improve the performance of hydrothermal treatment (HTT) of heavy oil with chemical additives, particularly surfactants. , Sasaki et al proposed a new process, which couples surfactants with SAGD. The authors carried out 2D scaled model experiments and evaluated the influence of surfactants on steam chamber growth in a thermal simulator: CMG.…”

Section: Introductionmentioning

confidence: 99%

Influence of Anionic and Amphoteric Surfactants on Heavy Oil Upgrading Performance with Nickel Tallate under Steam Injection Processes

Kholmurodov

Vakhin

Aliev

et al. 2023

Ind. Eng. Chem. Res.

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Steam-based thermal enhanced oil recovery techniques are widely applied methods to unlock heavy oil and natural bitumen resources. In this paper, two oil-soluble surfactants, as a subset of chemical additives, are introduced to favor the in situ catalytic hydrothermal upgrading of heavy oil. The solubility, salt tolerance, and thermal stability of both surfactants are experimentally investigated. The surfactant-assisted catalytic hydrothermal treatment of heavy oil was carried out in a batch reactor with a stirrer coupled with a gas chromatography device. The outputs of heavy oil upgrading processes were evaluated by comprehensive analysis of SARA fractions and elemental and structural changes of crude oil. Moreover, the distribution of low-molecular-weight alkanes in saturates and alkyl benzenes in aromatics are examined by gas chromatography−mass spectroscopy (GC−MS). The results confirmed the synergistic effect of catalytic nanoparticles and surfactants on the destructive hydrogenation of fused polynuclear aromatic rings such that the contents of resins and asphaltenes were reduced by 12.5 and 43.3%, respectively. In addition, surfactants contributed to hydrogen addition and inhibition of carbon rejection processes such that the H/C ratio increased from 1.32 to 1.72 with improving hydrodesulfurization and hydrodenitrogenation processes. Moreover, the amphoteric surfactant significantly enhanced the emulsification potential of the steam phase by decreasing the interfacial tension (IFT) between heavy crude oil and the steam phase, which positively affects the steam chamber propagations and hence leads to the incremental oil recovery in case of field-scale applications. On the basis of the achieved laboratory-scale results, the surfactant is a promising steam additive for improving heavy oil production.

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“…Tight oil reservoirs are characterized by their low permeability and complex pore network, which severely hampers the flow of hydrocarbons and impedes conventional production methods. − A combination of horizontal drilling and hydraulic fracturing is used to create multiple fractures and increase production. − Despite the benefits of hydraulic fracturing, there are challenges to maintaining production levels, such as rapid declines, instability, and low primary recovery rates of 5–10%, with a significant portion of the oil remaining trapped in the reservoir matrix. − …”

Section: Introductionmentioning

confidence: 99%

Investigating Recovery Potential through Depletion Development of Tight Oil Reservoirs via NMR Technology

He,

Shang,

et al. 2023

Energy Fuels

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Tight oil reservoirs have emerged as a vital component of the global energy landscape, offering both promising prospects and intricate challenges in their exploitation. Overcoming challenges to maintain sustainable production levels, including rapid declines, instability, and low primary recovery rates, is imperative. However, understanding the mechanisms behind production declines during the depletion development of tight oil reservoirs remains elusive. In this study, we employ nuclear magnetic resonance (NMR) online monitoring technology to quantitatively assess oil recovery on the pore scale and investigate the impacts of depletion development on tight oil reservoirs. Our experimental findings reveal a bimodal pore distribution within the target reservoir, characterized by a significant proportion of micronano pore throats measuring less than 0.1 μm in radius. A noteworthy nonlinear relationship exists between the T 2 relaxation time and pore throat radius within the tight reservoir core, enabling the derivation of rock pore distribution from T 2 spectra. Within these tight reservoirs, the recovery rate achieved solely through the utilization of formation energy during depletion development ranges from 7 to 10%. This finding underscores the substantial untapped potential for future oil recovery, with a significant volume of oil remaining trapped within the matrix. Our analysis indicates that primary oil extraction primarily targets macropores during depletion development, leaving the crude oil within the micropores largely undisturbed.

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Geochemical, mineralogical and petrographical characteristics of the domanik formation from north samara region in the volga-ural basin, Russia: Implication for unconventional tight oil reservoir potential

Cited by 16 publications

References 45 publications

Experimental Study on Ethane-Dimethyl Ether Assisted CO₂ Displacement to Improve Crude Oil Recovery in Tight Reservoirs

Experimental Study on Ethane-Dimethyl Ether Assisted CO₂ Displacement to Improve Crude Oil Recovery in Tight Reservoirs

Influence of Anionic and Amphoteric Surfactants on Heavy Oil Upgrading Performance with Nickel Tallate under Steam Injection Processes

Investigating Recovery Potential through Depletion Development of Tight Oil Reservoirs via NMR Technology

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Geochemical, mineralogical and petrographical characteristics of the domanik formation from north samara region in the volga-ural basin, Russia: Implication for unconventional tight oil reservoir potential

Cited by 16 publications

References 45 publications

Experimental Study on Ethane-Dimethyl Ether Assisted CO2 Displacement to Improve Crude Oil Recovery in Tight Reservoirs

Experimental Study on Ethane-Dimethyl Ether Assisted CO2 Displacement to Improve Crude Oil Recovery in Tight Reservoirs

Influence of Anionic and Amphoteric Surfactants on Heavy Oil Upgrading Performance with Nickel Tallate under Steam Injection Processes

Investigating Recovery Potential through Depletion Development of Tight Oil Reservoirs via NMR Technology

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Product

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Experimental Study on Ethane-Dimethyl Ether Assisted CO₂ Displacement to Improve Crude Oil Recovery in Tight Reservoirs

Experimental Study on Ethane-Dimethyl Ether Assisted CO₂ Displacement to Improve Crude Oil Recovery in Tight Reservoirs