Integration of mud logging and wire-line logging to detect overpressure zones: a case study of middle Miocene Kareem Formation in Ashrafi oil field, Gulf of Suez, Egypt

Abass, Ali E.; Teama, Mostafa A.; Kassab, Mohamed A.; Elnaggar, Ahmed A.

doi:10.1007/s13202-019-00781-8

Cited by 4 publications

(1 citation statement)

References 27 publications

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“…The Gulf of Suez basin is classified as one of the challenging basins in terms of drilling due to complex tectonic and structural settings (Radwan, 2018;Abass et al, 2019;Radwan et al, 2019b;Radwan et al, 2020a;Radwan, 2021b). However, to date, overpressure generation mechanisms have not been studied before in the Gulf of Suez basin, despite their importance and implications for drilling activity.…”

Section: Figurementioning

confidence: 99%

A multi-proxy approach to detect the pore pressure and the origin of overpressure in sedimentary basins: An example from the Gulf of Suez rift basin

Radwan

2022

Front. Earth Sci.

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The pore pressure gradient and fracture gradient (PPFG) are critical parameters for drilling mud weight design in the energy industry. Successful drilling operations can be achieved successfully through the understanding of the pore pressure and fracture pressure in the subsurface succession. The scope of this research is to use an integrated approach that encompasses well-logging, basin modeling, drilling-based interpretations, and reservoir measurement methods to gain a reasonable PPFG model and decrease the drilling uncertainties in the El Morgan oil field in the Gulf of Suez. Moreover, it investigates the overpressure generation mechanisms in the basin, which have not been studied before in this area. In this work, PPFGs of more than 16 km of cumulative thick sedimentary succession were modeled and evaluated using an integrated approach. This study utilizes Eaton’s sonic and resistivity-based methods for pore pressure evaluation, while vertical stress was calculated based on the composite density profile. The study revealed that the top geo-pressure was detected at a depth of 1,030 m of Tortonian sediments. Late Miocene sediments reveal hard over-pressure with a maximum gradient of 0.55 PSI/feet, while Middle Miocene sediments exhibit mildly over-pressured, normal, and sub-normal pore pressure zones. The lowest pore pressure values were measured in the Langhian-Serravalian Kareem reservoir with a gradient of 0.29 PSI/feet. With the exception of a slight difference in the reservoir section, the pore pressure profiles in the northern and southern parts of the El Morgan oil field are relatively similar. Reservoir connectivity is believed to be the main reason behind pore pressure magnitude differentiation in the Middle Miocene reservoirs. The key mechanism for generating overpressure has been identified as disequilibrium compaction, and reservoir overcharging may contribute as an excess-pressure generation mechanism at the reservoir level. The presented approach can be applied in PPFG studies for both development and exploratory geomechanical studies in other areas of the Gulf of Suez basin or elsewhere in the world.

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Section: Figurementioning

confidence: 99%

A multi-proxy approach to detect the pore pressure and the origin of overpressure in sedimentary basins: An example from the Gulf of Suez rift basin

Radwan

2022

Front. Earth Sci.

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Synthesizing Missing Travel Time of P-Wave and S-Wave: A Two-Stage Evolutionary Modeling Approach

Wong

Juwono

Nuwara³

et al. 2023

IEEE Sensors J.

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Predicting Rock Properties from Formation Fluid Measurements: Examples, Challenges, and Future Possibilities

Anifowose,

Mezghani,

Torlov

et al. 2024

Day 2 Tue, April 23, 2024

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Digital transformation is unleashing unprecedented potentials to maximize subsurface data utility and explore various possibilities. The petroleum industry has witnessed for a long time the prediction of reservoir rock properties from wireline data. Recent efforts have explored the same with drilling surface parameters. While basic and advanced mud gas data have been used extensively for reservoir fluid characterization, there is the question of whether their utility could be extended to reservoir rock characterization. There is currently no empirical correlation or established relationship between mud gas measurements and rock properties. This gave us the motivation to embark on this research effort. In this paper, we will review the physics behind the relationship between mud gas measurements and reservoir properties especially porosity, and how the measurements are carried out. We will also discuss a number of research questions on the need to extend the utility of mud gas data beyond the traditional reservoir fluid typing. A physics-based workflow that follows the machine learning modeling approach will be presented and discussed. Example results of two successful applications of predicting porosity and hydrocarbon volume fraction from only mud gas data and a combination of drilling surface parameters and mud gas data respectively will be discussed. The applications are based on state-of-the-art machine learning methods including random forest and support vector machines. We used correlation coefficient, mean squared error, and mean percentage error as the models’ performance evaluation metrics. All the metrics indicate that the models gave acceptable results, proved the feasibility of this proposal, and gave impetus for exploring more possibilities. The challenges faced while implementing the proposed methodology and answering the research questions will be shared. Moving forward, other possibilities of predicting various rock properties and their respective implications will be discussed. There is immense value in utilizing only mud gas data or using it to complement drilling surface parameters to predict reservoir rock properties, especially in real time. With dedicated research, incorporating the physics of the problem, and leveraging the power of machine learning, the industry could be witnessing the emergence of a new era of "real-time reservoir characterization".

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Integration of mud logging and wire-line logging to detect overpressure zones: a case study of middle Miocene Kareem Formation in Ashrafi oil field, Gulf of Suez, Egypt

Cited by 4 publications

References 27 publications

A multi-proxy approach to detect the pore pressure and the origin of overpressure in sedimentary basins: An example from the Gulf of Suez rift basin

A multi-proxy approach to detect the pore pressure and the origin of overpressure in sedimentary basins: An example from the Gulf of Suez rift basin

Synthesizing Missing Travel Time of P-Wave and S-Wave: A Two-Stage Evolutionary Modeling Approach

Predicting Rock Properties from Formation Fluid Measurements: Examples, Challenges, and Future Possibilities

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