Determination of the Appropriate Value of m for Evaluation of Carbonate Reservoirs With Vugs and Fractures at the Well-Log Scale

Wang, Dahai; Peng, Jun

doi:10.30632/pjv60n3-2019a6

Cited by 1 publication

(3 citation statements)

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“…Wang and Peng [20] used the Monte Carlo method to simulate the random distribution of fractures and vugs in carbonate reservoirs. The method was used as a supplement to the model in the work to make the predicted results more accurate.…”

Section: Resultsmentioning

confidence: 99%

“…For the triple-porosity reservoir with unknown severe heterogeneity, the porosity of different reservoir spaces in the reservoir is first incorporated into Equation (3) for cementation index m. Then, the m value of the triple-porosity media reservoir can be predicted by simulation. As an example, Monte Carlo simulation [20] predicts that the m value of the triple-porosity media reservoir with Φ f = 0:5%, Φ v = 1%, and Φ m = 4% (low-porosity carbonate rock) is equal to 2.01, using the triple-porosity model developed in the work for 10,000 experiments (see Figure 8). Since the dual-porosity medium reservoir is a particular case of the triple-porosity one, this method can be used to obtain the m value.…”

Section: Resultsmentioning

confidence: 99%

“…For serious heterogeneous triple-porosity media reservoirs such as carbonate rocks, traditional petrophysics experiments are limited in understanding due to the artificial selection of core samples. As a result, the electrical characteristics of reservoir rock cannot be fully understood [20]. Especially in low-porosity formations, the relationship between electrical conductivity and porosity is more complicated, and pore-throat ratio, tortuosity, and connectivity are three important influencing factors [21].…”

Section: Methodsmentioning

confidence: 99%

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A New Method for Calculating the Cementation Exponent of Triple-Porosity Media Reservoirs

Wang

Liu

et al. 2022

Geofluids

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The value of a cementation exponent, usually obtained by rock and electricity experiments, significantly affects the calculation of water saturation, thickness of the hydrocarbon reservoir, and recovery rate. The determination of the cementation exponent for porous-media reservoirs has been a challenge because of the limited core sampling. A new method was proposed to determine the value of cementation exponent for complex triple-porosity media reservoirs in the work. Firstly, the work discussed the effects of fractures and nonconnected vugs on the cementation exponent of the reservoir as well as the calculation method of the cementation exponent of the dual-porosity media reservoir. Then, a new model for calculating the cementation exponent of triple-porosity media reservoirs was derived by combining the Maxwell-Garnett theory and series-parallel theory, which matched with the real physical-experiment data of rocks. The results showed that the fractures decreased the cementation exponent of the reservoir but the vugs increased. The mixture of matrix pores, fractures, and vugs made the value of the cementation exponent of the triple-porosity media reservoir vary around 2.0. The conductivity of the triple-porosity media reservoir was the external macroscopic expression of the microscopic conductive network. The new calculation model of the cementation exponent proposed in the work could reasonably predict the cementation exponent of the strongly inhomogeneous triple-porosity media reservoir.

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Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%