History matching of naturally fractured reservoirs based on the recovery curve method

Ghaedi, Mojtaba; Masihi, Mohsen; Heinemann, Z.E.; Ghazanfari, Mohammad Hossein

doi:10.1016/j.petrol.2014.12.002

Cited by 14 publications

(2 citation statements)

References 40 publications

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“…Other approaches are: artificial neural networks (Al-Anazi and Babadagli, 2009), Markov Chain Monte Carlo (Ginting et al, 2011), probability perturbation method (Suzuki et al, 2007), recovery curve method (Ghaedi et al, 2015), Discrete Fracture Network flow simulator (Lange, 2009), Ensemble Kalman Filter (Lu and Zhang, 2015;Nejadi et al, 2015), and Kernel principal component analysis (Paico, 2008).…”

Section: Literature Reviewmentioning

confidence: 99%

A new methodology to reduce uncertainty of global attributes in naturally fractured reservoirs

Costa

Maschio

Schiozer

2018

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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Accurately characterizing fractures is complex. Several studies have proposed reducing uncertainty by incorporating fracture characterization into simulations, using a probabilistic approach, to maintain the geological consistency, of a range of models instead of a single matched model. We propose a new methodology, based on one of the steps of a general history-matching workflow, to reduce uncertainty of reservoir attributes in naturally fractured reservoirs. This methodology maintains geological consistency and can treat many reservoir attributes. To guarantee geological consistency, the geostatistical attributes (e.g., fracture aperture, length, and orientation) are used as parameters in the history matching. This allows us to control Discrete Fracture Network attributes, and systematically modify fractures. The iterative sensitivity analysis allows the inclusion of many (30 or more) uncertain attributes that might occur in a practical case. At each uncertainty reduction step, we use a sensitivity analysis to identify the most influential attributes to treat in each step. Working from the general history-matching workflow of Avansi et al. (2016), we adapted steps for use with our methodology, integrating the history matching with geostatistical modeling of fractures and other properties in a big loop approach. We applied our methodology to a synthetic case study of a naturally fractured reservoir, based on a real semi-synthetic carbonate field, offshore Brazil, to demonstrate the applicability in practical and complex cases. From the initial 18 uncertain attributes, we worked with only 5 and reduced the overall variability of the Objective Functions. Although the focus is on naturally fractured reservoirs, the proposed methodology can be applied to any type of reservoir.

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Section: Literature Reviewmentioning

confidence: 99%

A new methodology to reduce uncertainty of global attributes in naturally fractured reservoirs

Costa

Maschio

Schiozer

2018

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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“…The method itself was presented by Mittermeir (2015) and its application to the Sabah field by Heinemann et al (2014) and Gharsalla et al (2014). Ghaedi et al (2015aGhaedi et al ( , 2015bGhaedi et al ( , 2015c used the recovery curve method for history matching and in-situ wettability determination of naturally fractured reservoirs.…”

Section: Field Applicationmentioning

confidence: 99%

Generally Applicable Method For Calculation Of The Matrix-fracture Fluid Transfer Rates

Heinemann

Mittermeir

2016

SPE Europec Featured at 78th EAGE Conference and Exhibition

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The paper presents a practical method for calculating the matrix-fracture fluid transfer correctly, applicable under expansion, solution gas, capillary and gravitational drives and their combinations, considering water, gas and oil as displacing agents. The method is an improvement of the Reiss (1973) formulation based on time-depending recovery functions. Reiss could not consider depletion drive in combination with water and gas displacement. Kazemi et al. (1976) extended the Warren-Root shape factor approach to multi-phase cases, but without satisfying the conditions under which the single-phase solution is correct. Since that continuous efforts were made for improvement including diversification and making the shape factor time-dependent. Many publications demonstrated that these efforts are futile. Su et al. (2013) clearly postulated Љa change of focus to the improvement of the transfer function would be a path to exploreЉ. The paper is an attempt in this sense with encouraging results. The suggested approach determines on fine gridded single matrix block (SMB) models recovery curves. Those are used directly in dual continuum models.

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Using the Recovery‐Curve Method for In Situ Wettability Determination in a Fractured Porous Medium

et al. 2015

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This work presents a new method based on the recovery‐curve method to evaluate the in situ rock wettability in naturally fractured reservoirs. The recovery‐curve method uses recovery curves to describe more realistically the matrix–fracture interactions. The capability of the proposed method was shown in two models, namely a simple column model and a realistic naturally fractured reservoir. Appropriate recovery curves were determined by history matching the movement of the water–oil contact. The slopes of the obtained recovery curves were analyzed with the method presented by Mirzaei‐Paiaman et al.,12 which is referred to as the MPMS method in this study. The MPMS method has many advantages over other methods. Proper indices describing in situ rock wettability states were determined. The results are in very good agreement with those obtained from conventional methods.

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History matching of naturally fractured reservoirs based on the recovery curve method

Cited by 14 publications

References 40 publications

A new methodology to reduce uncertainty of global attributes in naturally fractured reservoirs

A new methodology to reduce uncertainty of global attributes in naturally fractured reservoirs

Generally Applicable Method For Calculation Of The Matrix-fracture Fluid Transfer Rates

Using the Recovery‐Curve Method for In Situ Wettability Determination in a Fractured Porous Medium

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