3D static reservoir modeling by geostatistical techniques used for reservoir characterization and data integration

Soleimani, Mehrdad; Shokri, Behshad Jodeiri

doi:10.1007/s12665-015-4130-3

Cited by 27 publications

(4 citation statements)

References 27 publications

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“…The irreducible water saturation in UHS according to capillary curve analysis was below 20% in the measured range of pressure. For comparison, in another tight sandstone sample, Swir was 18% at a porosity of 5.7% and a permeability of 5.6 mD [32,33].…”

Section: Factors Leading To Low Resistivitymentioning

confidence: 99%

Matching of Water Breakthrough in Low Resistivity Oil Reservoir Using Permeability Anisotropy

Rudyk,

Al Musalhi,

Taura

et al. 2024

Preprint

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Uncertainties in initial water saturation and early water breakthroughs of un-known sources and paths, which occurred in the low resistivity Lower Haushi sand-stone (LHS) reservoir at the beginning of oil production, imply that the bypassed oil can yet remain in the reservoir. In addition, the upper part of LHS is a tight oil reser-voir, which can still contain a significant amount of unrecovered oil. This opens the opportunity to produce the remaining oil instead of abandoning this reservoir. Low resistivity can exaggerate water saturation, leading to misinterpretation and premature water flooding due to inadequate oil-water contrast. Our analysis revealed a correlation between low resistivity and robust porous network connectivity, along-side elevated formation water salinity in highly porous layers. In regions of high po-rosity, sufficient oil-water contrast facilitates precise water saturation determination, affirming oil presence in all wells. However, within tight oil zones, near-complete wa-ter saturation contradicts actual oil presence. Factors contributing to saturation un-certainty and water breakthroughs were reassessed. Utilizing a 1:1 verti-cal-to-horizontal permeability ratio derived from core data enhanced simulation alignment with water production rates. Investigation into the impact of relative per-meabilities on water production was conducted. Water saturation maps were gener-ated to pinpoint remaining oil reserves. Depletion around wells is evident in lower po-rous regions, while oil persists across the entire tight reservoir, notably in two unex-plored sections.

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Section: Factors Leading To Low Resistivitymentioning

confidence: 99%

Matching of Water Breakthrough in Low Resistivity Oil Reservoir Using Permeability Anisotropy

Rudyk,

Al Musalhi,

Taura

et al. 2024

Preprint

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“…The irreducible water saturation (Swir) in UHS according to capillary curve analysis was below 20% in the measured range of pressure. For comparison, in another tight sandstone sample, Swir was 18% at a porosity of 5.7% and a permeability of 5.6 mD [32,33].…”

Section: Factors Leading To Low Resistivitymentioning

confidence: 99%

Matching of Water Breakthroughs in a Low-Resistivity Oil Reservoir Using Permeability Anisotropy

Rudyk,

Al-Musalhi,

Taura

et al. 2024

Applied Sciences

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In a mature middle and lower Gharif field in Oman, uncertainties surrounding initial water saturation and early water breakthroughs of unknown sources and paths suggest the presence of significant bypassed oil. In order to determine the areas with remaining oil, petrophysical and logging data of seven wells were processed using Techlog software and imported into Petrel software for modelling and simulation. Porosity was calculated using the Electric Propagation Time log and was utilized to evaluate the presence of oil, particularly in the upper tight zone of the formation. Despite the low resistivity readings in the highly porous layers, caused by good network connectivity and high formation water salinity, the resistivity contrast was sufficient to differentiate them from the oil zone. However, the calculated water saturation (Sw) in the tight top oil zone was high, consistent with the observed water production in the field. To improve the match between production data and simulation results, sensitivity analyses were conducted on various permeability anisotropy and relative permeability values within the model. The analyses showed that core-derived permeability anisotropy (vertical to horizontal ratio of 1:1) yielded a better history match for water production compared to the conventionally used value of 1:10. Water saturation maps were generated at the start and the end of production to highlight saturation distribution within the reservoirs. The maps revealed that in the lower porous part, the oil was fully depleted around the wells but remained trapped in the undrilled areas.

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“…Within the Salma Field, the clastic late Messinian Abu Madi Formation is considered as the primary gas-producing interval (Figure 1). Previous studies include comprehensive reservoir analysis, property modeling of petrophysical parameters of the reservoir, and identifying various facies of the flow [19][20][21][22][23]. Calculating water saturation variability within the model based on reservoir flow units can reduce the uncertainty in reservoir flow performance and volumetric evaluation in the Salma Field.…”

Section: Introductionmentioning

confidence: 99%

An Integrated Approach for Saturation Modeling Using Hydraulic Flow Units: Examples from the Upper Messinian Reservoir

El-Gendy,

Mabrouk,

Waziry

et al. 2023

Water

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The Upper Messinian reservoirs located in the Salma Field of the Nile Delta area contain variable facies. The key reservoir interval of the Abu Madi Formation was deposited in fluvial to deltaic environments. These fine-grained facies form significant reservoir heterogeneity within the reservoir intervals. The main challenges in this study are reservoir characterizing and predicting the change in reservoir water saturation (SW) with time, while reservoir production life based on the change in reservoir capillary pressure (Pc). This work applies petrophysical analysis to enable the definition and calculation of the hydrocarbon reserves within the key reservoir units. Mapping of SW away from the wellbores within geo-models represents a significant challenge. The rock types and flow unit analysis indicate that the reservoir is dominated by four hydraulic flow units. HFU#1 represents the highest flow zone indicator (FZI) value. Core analysis has been completed to better understand the relationship between SW and the reservoir capillary pressure above the fluid contact and free water level (FWL), which is used to perform saturation height function (SHF) analysis. The calculated SW values that are obtained from logs are affected by formation water resistivity (Rw) and log true resistivity (RT), which are influenced by the volume of clay content and mud salinity. This study introduces an integrated approach, including evaluation of core measurements, well log analysis covering cored and non-cored intervals, neural analysis techniques (K-mode algorithm), and permeability prediction in non-cored intervals. The empirical formula was predicted for direct calculation of dynamic SW profiles and predicted within the reservoir above the FWL based on the change in reservoir pressure.

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3D static reservoir modeling by geostatistical techniques used for reservoir characterization and data integration

Cited by 27 publications

References 27 publications

Matching of Water Breakthrough in Low Resistivity Oil Reservoir Using Permeability Anisotropy

Matching of Water Breakthrough in Low Resistivity Oil Reservoir Using Permeability Anisotropy

Matching of Water Breakthroughs in a Low-Resistivity Oil Reservoir Using Permeability Anisotropy

An Integrated Approach for Saturation Modeling Using Hydraulic Flow Units: Examples from the Upper Messinian Reservoir

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