Accelerated History Matching Through Process Independent Scale-up Techniques in a Giant Carbonate Reservoir

2004 ◽  
Author(s):  
K. Suzuki ◽  
J. Asada ◽  
K. Yoshida ◽  
M. Nomura
Keyword(s):  
History Matching ◽  
Scale Up ◽  
Carbonate Reservoir

scholarly journals Injection-production optimization of carbonate reservoir based on an inter-well connectivity model

2021 ◽  
pp. 014459872199465
Author(s):  
Yuhui Zhou ◽  
Sheng Lei ◽  
Xuebiao Du ◽  
Shichang Ju ◽  
Wei Li
Keyword(s):  
History Matching ◽  
Water Injection ◽  
Field Application ◽  
Carbonate Reservoir ◽  
Production Optimization ◽  
Oil Field ◽  
Carbonate Reservoirs ◽  
Utilization Rate ◽  
Production Volume ◽  
Connectivity Model

Carbonate reservoirs are highly heterogeneous. During waterflooding stage, the channeling phenomenon of displacing fluid in high-permeability layers easily leads to early water breakthrough and high water-cut with low recovery rate. To quantitatively characterize the inter-well connectivity parameters (including conductivity and connected volume), we developed an inter-well connectivity model based on the principle of inter-well connectivity and the geological data and development performance of carbonate reservoirs. Thus, the planar water injection allocation factors and water injection utilization rate of different layers can be obtained. In addition, when the proposed model is integrated with automatic history matching method and production optimization algorithm, the real-time oil and water production can be optimized and predicted. Field application demonstrates that adjusting injection parameters based on the model outputs results in a 1.5% increase in annual oil production, which offers significant guidance for the efficient development of similar oil reservoirs. In this study, the connectivity method was applied to multi-layer real reservoirs for the first time, and the injection and production volume of injection-production wells were repeatedly updated based on multiple iterations of water injection efficiency. The correctness of the method was verified by conceptual calculations and then applied to real reservoirs. So that the oil field can increase production in a short time, and has good application value.

scholarly journals Development of machine learning predictive models for history matching tight gas carbonate reservoir production profiles

2018 ◽  
Vol 15 (5) ◽  
pp. 2235-2251 ◽  
Author(s):  
Eric Thompson Brantson ◽  
Binshan Ju ◽  
Busayo Oreoluwa Omisore ◽  
Dan Wu ◽  
Aphu Elvis Selase ◽  
...  
Keyword(s):  
Machine Learning ◽  
Predictive Models ◽  
History Matching ◽  
Carbonate Reservoir ◽  
Tight Gas

Comprehensive History Matching a Complex Carbonate Reservoir (Maydan MahzamField, Offshore Qatar)

2010 ◽  
Author(s):  
Ahmad Al Ahmed ◽  
Vance Fryer ◽  
Mohammed Javed ◽  
Abdulmalik Al-Abdulmalik ◽  
Patrick Léandri ◽  
...  
Keyword(s):  
History Matching ◽  
Carbonate Reservoir ◽  
Comprehensive History

Streamline-Based History Matching Using Geostatistical Constraints: Application to a Giant, Mature Carbonate Reservoir

2004 ◽  
Author(s):  
H. Gross ◽  
M.R. Thiele ◽  
M.J. Alexa ◽  
J.K. Caers ◽  
A.R. Kovscek
Keyword(s):  
History Matching ◽  
Carbonate Reservoir

Simultaneous Interpretation of Three-Phase Relative Permeability and Capillary Pressure for a Tight Carbonate Reservoir From Wireline Formation Testing

2019 ◽  
Vol 142 (6) ◽  
Author(s):  
Xiangnan Liu ◽  
Daoyong Yang
Keyword(s):  
Capillary Pressure ◽  
Relative Permeability ◽  
History Matching ◽  
Carbonate Reservoir ◽  
Reservoir Rock ◽  
Fluid Saturation ◽  
Three Phase ◽  
Tight Carbonate ◽  
Wet Condition ◽  
Oil Gas

Abstract In this paper, techniques have been developed to interpret three-phase relative permeability and water–oil capillary pressure simultaneously in a tight carbonate reservoir from numerically simulating wireline formation tester (WFT) measurements. A high-resolution cylindrical near-wellbore model is built based on a set of pressures and flow rates collected by dual packer WFT in a tight carbonate reservoir. The grid quality is validated, the effective thickness of the WFT measurements is examined, and the effectiveness of the techniques is confirmed prior to performing history matching for both the measured pressure drawdown and buildup profiles. Water–oil relative permeability, oil–gas relative permeability, and water–oil capillary pressure are interpreted based on power-law functions and under the assumption of a water-wet reservoir and an oil-wet reservoir, respectively. Subsequently, three-phase relative permeability for the oil phase is determined using the modified Stone II model. Both the relative permeability and the capillary pressure of a water–oil system interpreted under an oil-wet condition match well with the measured relative permeability and capillary pressure of a similar reservoir rock type collected from the literature, while the relative permeability of an oil–gas system and the three-phase relative permeability bear a relatively high uncertainty. Not only is the reservoir determined as oil-wet but also the initial oil saturation is found to impose an impact on the interpreted water relative permeability under an oil-wet condition. Changes in water and oil viscosities and mud filtrate invasion depth affect the range of the movable fluid saturation of the interpreted water–oil relative permeabilities.

Ensemble-Based Assisted History Matching With Rigorous Uncertainty Quantification Applied to a Naturally Fractured Carbonate Reservoir

2016 ◽  
Author(s):  
Marko Maucec ◽  
Fabio M. De Matos Ravanelli ◽  
Stig Lyngra ◽  
Shu J. Zhang ◽  
Aymen A. Alramadhan ◽  
...  
Keyword(s):  
Uncertainty Quantification ◽  
History Matching ◽  
Carbonate Reservoir ◽  
Naturally Fractured ◽  
Assisted History Matching ◽  
Fractured Carbonate
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