A fast method of waterflooding performance forecast for large-scale thick carbonate reservoirs

Li, Yong; Zhang, Qi; Wang, Daigang; Song, Benbiao; Liu, Pengcheng

doi:10.1016/j.petrol.2020.107227

Cited by 9 publications

(5 citation statements)

References 22 publications

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“…(Kr) is affected by temperature change and the rocks and liquids relative wetting phase [14]. The temperature will be more effective on relative permeability when water, oil, and rock in the system become more humid when the temperature rises [15,16]. Three liquids (gas, oil, and water) may exist and move in the rock system and at a definite saturation, so three-phase relative permeabilities must be taken into consideration [17].…”

Section: Relative Permeabilitymentioning

confidence: 99%

Effect of Heterogeneity on Capillary Pressure and Relative Permeability Curves in Carbonate Reservoirs. A Case Study for Mishrif Formation in West Qurna/1 Oilfield, Iraq

Al-Dujaili

Shabani

Al-Jawad

2023

IJCPE

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The special core analysis tests were accomplished on a set of core plugs for Mishrif Formation (mA, mB1, and mB2cde/mC units) in West Qurna/1 oilfield, southern Iraq. Oil relative permeability (Kro) data and the Corey-type fit of the data as functions of the brine saturation at the core outlet face for individual samples in the water-oil imbibition process to estimate relative permeability measurements by the centrifuge method were utilized. Identical correlations for oil and water relative permeabilities were extracted by steady-state and unsteady-state methods. For the mA samples, the gas-water capillary pressure curves were within a narrow range (almost identical) indicating that mA is a homogeneous unit. Kro curves for three mB2ab plugs were practically identical, that is referring to the homogeneity in the upper portion of the unit. The mB2 unit has a more solid‐phase concentration than other units. In addition, the general trend of low residual oil saturation is related to the raising in porosity but no reliable correlation between the residual oil saturation to water drive (Sorw) and Klinkenberg-corrected permeability (Kinf). Based on the correlation between the effective oil permeability at the initial water saturation [ko(Swi)] and (Kinf/f)1/2 for the high-permeability lithofacies mB1 plugs, ko(Swi) is approximately equal to or exceeds Kinf. While ko(Swi) was below Kinf for the other samples. New good empirical equations were obtained for effective gas permeability at final water saturation versus Kinf, as well as, for Kro and Krw versus saturation for all lithofacies.

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Section: Relative Permeabilitymentioning

confidence: 99%

Effect of Heterogeneity on Capillary Pressure and Relative Permeability Curves in Carbonate Reservoirs. A Case Study for Mishrif Formation in West Qurna/1 Oilfield, Iraq

Al-Dujaili

Shabani

Al-Jawad

2023

IJCPE

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“…Figures [14][15][16] show that constant-pressure bottom water significantly affected the recovery percentage of double-vug reservoirs. Under connection type I, the recovery percentage of fractured-vuggy reservoirs with constant-pressure bottom water could uniformly exceed 17% at all three production rates.…”

Section: Production Characteristics Under Connection Type Imentioning

confidence: 99%

“…Liu et al [15] carried out two-dimensional physical simulation experiments on the production performance of vuggy reservoirs with bottom water and found it to be closely related to the connection type and energy of bottom water. Wang et al [16] performed visual physical simulation experiments on fractured-vuggy reservoirs and found that injecting water into the bottom of a reservoir effectively improves the development effect of the reservoir; moreover, the intensity of water injection affects both water breakthrough time and recovery percentage.…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on Production Characteristics of Bottom Water Fractured-Vuggy Reservoir

Cai

Jiang

2022

Geofluids

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To assess the high-pressure production characteristics of double-vug reservoirs with bottom water in the Tahe Oilfield, in this study, a high-pressure physical simulation experiment apparatus is built for double-vug reservoirs with bottom water. The high-pressure production characteristics of “vug-fracture-vug” reservoirs under different bottom water characteristics are studied experimentally, and fracture-vug relationship and oil recovery rates are explored. According to the findings, the oil recovery rate significantly affects the development effect of double-vug reservoirs with bottom water, and bottom water provides sufficient energy for reservoir development. Furthermore, considering the possible occurrence of water invasions, the production rate control must receive close attention in the development process to avoid strong water channeling. Constant-pressure bottom water has sufficient energy and can quickly replenish vug energy. Therefore, the recovery percentage and bottom water invasion and retention volume of fractured-vuggy reservoirs with constant-pressure bottom water are higher than those of fractured-vuggy reservoirs with constant-volume bottom water. Under the appropriate control of production factors, the presence of bottom water can noticeably improve the development effect of fractured-vuggy reservoirs.

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“…Water injection is a vital method for improving oil recovery in carbonate reservoirs in the Middle East (Bisweswar G et al, 2020; Barros E G D et al, 2023;Ghalib H B et al, 2023;Farnetano R P et al, 2023;Wu Y and Hu D et al, 2023). However, challenges such as premature water breakthrough pose significant obstacles to achieving optimal oil recovery (Li Y et al, 2020;AL-Otaibi B et al, 2021;Dewever B et al, 2021;Yang C and Yang S et al, 2022;Wei C et al, 2022).…”

Section: Introductionmentioning

confidence: 99%

Research on water-out mode and differential perforation in thick carbonate reservoir

Junshuai,

Peiyuan,

Jian

et al. 2024

Front. Energy Res.

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The development of anti-rhythmic carbonate reservoirs in the Middle East often encounters challenges such as water hold-up and reverse coning during the water injection process, leading to premature water breakthrough and various water-out issues. The unclear understanding of these phenomena, attributed to strong reservoir heterogeneity, results in a relatively low recovery degree in water injection development. This paper investigates the mechanisms behind water hold-up and reverse coning phenomena, offering detailed solutions. Numerical models of the oil reservoirs were developed, and an extensive study of influencing factors, including reservoir types, Kv/Kh, water injection pressure differential, wettability, and perforation position, was conducted to unveil the underlying mechanisms. Key findings indicate that the water hold-up phenomenon is influenced by capillary force barriers due to wettability and high-perm streaks, while the reverse coning phenomenon depends on the combined forces of gravity, capillary force and downward production differential among which downward production differential is the dominant factor compared to capillary force and gravity. The study also proposes a differential perforation principle tailored to different water-out types to enhance vertical sweep efficiency. The differential perforation principle is as follows: the optimal perforation position is at top layer and the optimal perforation length approximately accounts for 1/4 of the total oil layer thickness for water-out in bottom; the avoidance perforation height in top accounts for 1/6 of the total oil layer thickness and the optimal perforation length approximately accounts for 1/2 of the total oil layer thickness for water-out in top; the avoidance perforation height in top and bottom accounts for 1/5 and 2/5 of the total oil layer thickness respectively for water-out in both top and bottom.

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A fast method of waterflooding performance forecast for large-scale thick carbonate reservoirs

Cited by 9 publications

References 22 publications

Effect of Heterogeneity on Capillary Pressure and Relative Permeability Curves in Carbonate Reservoirs. A Case Study for Mishrif Formation in West Qurna/1 Oilfield, Iraq

Effect of Heterogeneity on Capillary Pressure and Relative Permeability Curves in Carbonate Reservoirs. A Case Study for Mishrif Formation in West Qurna/1 Oilfield, Iraq

Experimental Study on Production Characteristics of Bottom Water Fractured-Vuggy Reservoir

Research on water-out mode and differential perforation in thick carbonate reservoir

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