Unified relative permeability model and waterflooding type curves under different levels of water cut

Feng, Qihong; Zhang, Jin; Wang, Sen; Wang, Xiang; Cui, Ronghao; Wang, Duanping; Bing, Shaoxian; Rui, Zhenhua

doi:10.1016/j.petrol.2017.04.031

Cited by 17 publications

(10 citation statements)

References 37 publications

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“…Numerous researchers [18,19] discovered the formula (1) the approximate exponential relationship between K rw /K ro and S w exists only when S w is near the center of the oil-water two-phase infiltration zone (single well or Oilfield block production to medium-high water cut period). Non-exponential bending, on the other hand, will occur during the early and late stages of production in waterflooding oil fields.…”

Section: Characterization Of New Phase Permeability Mathematical Modelmentioning

confidence: 99%

Application of New Water Flooding Characteristic Curve in the High Water-Cut Stage of an Oilfield

Zhang¹,

Wang²,

Wang³

et al. 2022

Fluid Dynamics &Amp; Materials Processing

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The oil production predicted by means of the conventional water-drive characteristic curve is typically affected by large deviations with respect to the actual value when the so-called high water-cut stage is entered. In order to solve this problem, a new characteristic relationship between the relative permeability ratio and the average water saturation is proposed. By comparing the outcomes of different matching methods, it is verified that it can well reflect the variation characteristics of the relative permeability ratio curve. Combining the new formula with a reservoir engineering method, two new formulas are derived for the water flooding characteristic curve in the high water-cut stage. Their practicability is verified by using the production data of Mawangmiao and Xijiakou blocks. The results show that the error between the predicted cumulative oil production and production data of the two new water drive characteristic curves is less than the error between the B-type water drive characteristic curve and the other two water drive characteristic curves. It is concluded that the two new characteristic curves can be used to estimate more accurately the recoverable reserves, the final recovery and to estimate the effects of water flooding. KEYWORDSWater flooding characteristic curve; high water cut period; production dynamic prediction; recoverable reserves; water flooding Nomenclature WOR Water-oil ratio; Q w Water production, t/day; Q o Oil production, t/day; K rw , K ro Relative permeability of water phase and oil phase; μ w , μ o Water, oil viscosity, mPa⋅s; B w , B o Water and oil volume coefficient, m 3 /m 3 ; a, b, c Constants influenced by reservoir and fluid properties; A, B, C, C 1 Constants; S w Water saturation, %; S w Average water saturation, %; S we Outlet end water saturation;

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Section: Characterization Of New Phase Permeability Mathematical Modelmentioning

confidence: 99%

Application of New Water Flooding Characteristic Curve in the High Water-Cut Stage of an Oilfield

Zhang¹,

Wang²,

Wang³

et al. 2022

Fluid Dynamics &Amp; Materials Processing

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“…Yao et al (2001Yao et al ( , 2009 established a fine reservoir geological model and obtained accurate current formation pressure distribution through history matching. Feng et al (2017), Xu et al (2018), Zhu et al (2011) used the numerical simulation theory of the reservoir to analyze the change of pore pressure of the reservoir by using the dynamic and static parameters of the oilfield production and established a set of basic feasible theory and method for adjusting the formation pressure of the wells. Prediction of formation pore pressure and collapse pressure are used as an important basis for determining wellbore structure and drilling fluid density.…”

Section: Introductionmentioning

confidence: 99%

Design method and application of accurate adjustment scheme for water injection wells around adjustment wells

Hao

Zhong

Liu

et al. 2021

J Petrol Explor Prod Technol

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Affected by the surrounding injection and production wells, the formation near the infill adjustment well is in an abnormal pressure state, and drilling and completion operations are prone to complex situations and accidents such as leakage and overflow. The conventional shut-in method is to close all water injection wells around the adjustment well to ensure the safety of the operation, but at the same time reduce the oil field production. This paper proposes a design method for shut-in of water injection wells around adjustment wells based on injection-production data mining. This method uses water injection index and liquid productivity index as target parameters to analyze the correlation between injection and production wells. Select water injection wells with a high correlation and combine other parameters such as wellhead pressure and pressure recovery speed to design accurate adjustment schemes. Low-correlation wells do not take shut-in measures. This method was applied to 20 infill adjustment wells in the Penglai Oilfield. The correlation between injection and production wells was calculated using the data more than 500 injection wells and production wells. After a single adjustment well is drilled, the surrounding injection wells can increase the water injection volume by more than 5000 m3. This method achieves accurate adjustment for water injection wells that are high correlated with the adjustment well. Under the premise of ensuring the safety of drilling operations, the impact of drilling and completion on oilfield development is minimized, and oilfield production efficiency is improved. It has good application and promotion value.

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“…Waterflooding is by far the most widely applied method in improving oil recovery. − However, large-scale and long-term water injection will cause reservoirs to enter the high water-cut stage, even the extra-high water-cut stage, and the yield will seriously drop in the meantime. − For decades, the oilfield development industry in China has gradually formed a technology series featuring water injection technology . Meanwhile, most oilfields in China have entered the stage of high water-cut and high oil recovery.…”

Section: Introductionmentioning

confidence: 99%

Novel Method for Inverted Five-Spot Reservoir Simulation at High Water-Cut Stage Based on Time-Varying Relative Permeability Curves

et al. 2020

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After large-scale and long-term waterflooding, reservoir physical properties such as the pore throat structure and rock wettability may change. In this paper, the relative permeability curves under different water injection volumes through core-flood experiments were used to characterize the comprehensive changes of various reservoir physical properties at high water-cut stage. The novel concept of "water cross-surface flux" was proposed to characterize the cumulative flushing effect on the reservoir by injected water, and a novel method for inverted five-spot reservoir simulation at high water-cut stage based on time-varying relative permeability curves was established. From the relative permeability curves measured through two cores from the X oilfield under different water injection volumes (100, 500, 1000, 1500, and 2000 PV), it is found that with the increase of injected water volume, the two-phase co-flow zone becomes wider, the water permeability under residual oil saturation increases, and the residual oil saturation decreases. A waterflooding core model was established, simulated, and verified by the method proposed in this paper. It is found that using time-varying permeability curves for simulation, the highest oil recovery factor (61.58%) can be obtained with injected water volume up to 2000 PV, and the purpose of improved oil recovery (IOR) can be achieved by high water injection volume, but the increment is only approximately 10%. Besides, a waterflooding model of an inverted five-spot reservoir unit based on the X oilfield was also established, simulated, and analyzed. Simulation results have shown that no matter which set of core permeability curves measured from 100 to 2000 PV is directly used alone, the oil recovery factor will be simulated inaccurately. The findings of this study can help in better understanding the quantitative description of the oil recovery changes with time-varying reservoir physical properties in high water-cut reservoirs during waterflooding.

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Unified relative permeability model and waterflooding type curves under different levels of water cut

Cited by 17 publications

References 37 publications

Application of New Water Flooding Characteristic Curve in the High Water-Cut Stage of an Oilfield

Application of New Water Flooding Characteristic Curve in the High Water-Cut Stage of an Oilfield

Design method and application of accurate adjustment scheme for water injection wells around adjustment wells

Novel Method for Inverted Five-Spot Reservoir Simulation at High Water-Cut Stage Based on Time-Varying Relative Permeability Curves

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