Ha Quang Man

Bio: Ha Quang Man is an academic researcher from Petrovietnam. The author has contributed to research in topics: Permafrost & Environmental science. The author has an hindex of 3, co-authored 7 publications receiving 20 citations. Previous affiliations of Ha Quang Man include Hanoi University of Mining and Geology.

Hydraulic Flow Unit Classification and Prediction Using Machine Learning Techniques: A Case Study from the Nam Con Son Basin, Offshore Vietnam

Abstract: The test study area is the Miocene reservoir of Nam Con Son Basin, offshore Vietnam. In the study we used unsupervised learning to automatically cluster hydraulic flow units (HU) based on flow zone indicators (FZI) in a core plug dataset. Then we applied supervised learning to predict HU by combining core and well log data. We tested several machine learning algorithms. In the first phase, we derived hydraulic flow unit clustering of porosity and permeability of core data using unsupervised machine learning methods such as Ward’s, K mean, Self-Organize Map (SOM) and Fuzzy C mean (FCM). Then we applied supervised machine learning methods including Artificial Neural Networks (ANN), Support Vector Machines (SVM), Boosted Tree (BT) and Random Forest (RF). We combined both core and log data to predict HU logs for the full well section of the wells without core data. We used four wells with six logs (GR, DT, NPHI, LLD, LSS and RHOB) and 578 cores from the Miocene reservoir to train, validate and test the data. Our goal was to show that the correct combination of cores and well logs data would provide reservoir engineers with a tool for HU classification and estimation of permeability in a continuous geological profile. Our research showed that machine learning effectively boosts the prediction of permeability, reduces uncertainty in reservoir modeling, and improves project economics.

Integration of core, well logging and 2D seismic data to improve a reservoir rock model: a case study of gas accumulation in the NE Polish Carpathian Foredeep.

Abstract: Geological models play a crucial role in the description and simulation of fluid flow of both hydrocarbon- and water-bearing strata. Methodology, based on the hydraulic flow unit build on the basis of core plug data combined with rock types determined from logs and 3D seismic cubes generated on the basis of 2D seismic sections is presented. It works as a possible exploration tool for the Miocene gas accumulations in the Carpathian Foredeep of Poland. Deterministic and stochastic, geostatistical methods were used to construct a static reservoir model from 2D seismic sections, lithological data and hydraulic flow unit data. A pseudo-3D seismic volume was generated from all of the 2D seismic data available, in order to aid the modelling of hydraulic flow units. This approach is applicable to other reservoirs, where the availability of seismic data is limited. This study demonstrates that even without 3D seismic data and with limited well log data, the proposed hydraulic flow unit approach can be successfully applied to reservoir modelling through the integration of diverse data sets for a wide range of scales

Sediment discharge and storage over the last deglacial highstand period on the central Vietnam shelf off Nha Trang

Abstract: A sediment budget for the central Vietnam shelf off Nha Trang over the last deglacial Holocene highstand period has been investigated on the basis of shallow seismic and sediment core data and empirical equations. The annual suspended sediment discharge to the Nha Trang shelf ranges from: 4.3 to 5.4 Mt/year. Estimates based on published empirical equations suggest that the sediment discharge by three main local mountainous rivers (the Cai, Dinh and Van Phong rivers) that enter the Nha Trang shelf ranges between 1.7 and 4 Mt/year, which implies that the local rivers discharge approximately 75% of the total annual sediment input to the shelf. The annual sediment supply of the Cai River is approximately 2 and 6 times higher than that of the Dinh and Van Phong rivers, respectively. The highstand sediment depocentre of the Nha Trang shelf is mostly attached to the local river outflows, indicating their importance as the principal sediment supply sources to the shelf. Additional sources of sediment supply to the Nha Trang shelf can probably be related to along-shore transport from the nearby shelves. Calculations based on seismic and sediment core data indicate that the net sediment volume storage on the Nha Trang shelf is approximately 2.15 Mt/year. Approximately 50% of the total sediment yield supplied to the shelf is probably transported along-shore to the south. The sediment budget model for highstand deposits on the Nha Trang shelf is typical for a small mountainous river basin, which is significantly different from that of the large river delta systems in Vietnam such as the Mekong and Red rivers where 90% of the river sediments are captured on the delta plain/subaqueous part and only 10% of the river sediments are transported to the nearby shelf. In contrast, most of the sediments supplied by small mountainous rivers off Nha Trang are transported to the mid-shelf, forming a shore-parallel mud depocentre.

Podział skały zbiornikowej na jednostki o jednakowych właściwościach hydraulicznych w celu dokładniejszego wyznaczania przepuszczalności podczas modelowania przepływów w złożu gazu

Abstract: Hydraulic units differentiated in reservoir rock to facilitate permeability determinations for flow modeling in gas deposit. A b s t r a c t. Petrophysical parameters such as porosity and permeability and bulk density are input data for modeling hydrocarbon flow in reservoirs with the use of Eclipse® program (Schlumberger). The modeling is preceded by preliminary works comprising division of reservoir into hydraulic (flow) units, HU, and their characterization by geometrical and geological factors. Flow Zone Index, FZI, is a factor enabling easier description of movement of media in pore space only on the basis of combination of permeability and porosity. Then, HUs are determined on the basis of FZIs. The tested gas deposit belonged to a group of typical Miocene reservoirs from the Polish part of the Carpathian Foredeep. In this deposit, gas accumulations are related to deltaic sediments represented by sandstone and mudstone layers of various thickness, and heterolites with claystone, mudstone and sandstone intercalations. In the case of this deposit, the wealth of laboratory data made possible credible differentiation of FZI and HU. The tested methodology can also be applied to investigations of reservoirs bearing potable, mineral and geothermal water as well as those used for storage of sequestrated carbon dioxide.

Stress state in the Cuu Long and Nam Con Son basins, offshore Vietnam, implications for borehole stability analysis.

Abstract: We analysed in situ stress and pore pressure fields in the Cuu Long and Nam Con Son basins using data from petroleum exploration and production wells to evaluate the stress state. Then we used the obtained in-situ stress data to analyse the stability of two planned wells. The data were obtained from the sea floor to 4300 m burial depth and include both hydrostatic and overpressured sections. Seven data points are located in sediments, and seventeen data points in igneous basement rocks at depths greater than 3000 m. The estimated magnitudes of SH are 70-110% of the Sv magnitudes. Considering the errors in the stress magnitude estimates, their relative magnitudes suggest that a borderline normal/strike-slip stress regime presently exists in normally pressured sequences of the Nam Con Son and Cuu Long basins. Of the twenty-four data points, twenty have effective stress ratios at a critical stress state for faulting on the assumption that there are faults present that are optimally oriented for failure with friction coefficients of 0.5. The results suggest that the stress state in these basins is generally critical. Borehole stability analysis showed that for drilling deviated wells in the highly fractured granite basement in the Cuu Long Basin, mud pressure must be not less than 3 MPa below the pore pressure to avoid breakout and borehole collapse. For drilling in the overpressured and fractured carbonate section in the Nam Con Son Basin, the mud pressure must not exceed the pore pressure by more than 2MPa in order to minimize the risk of blowout or inducing fractures that may lead to mud losses and abandonment of the well.