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Abstract The study area is located in Tupi field in Santos Basin. It is one of the largest Brazilian maritime basins. They were formed during the Neocomian period as a result of the process of separation of the supercontinent Gondwana. Detailed description work was carried out on plug samples from the five wells in the Tupi oil field to understand carbonate facies and their distribution better. The samples were obtained from the Exploration and Production Database (BDEP/ANP). The facies analysis followed the classification standards proposed by Gomes et al. (2020). The results showed the diversity of facies, with significant variability along the depth of each well, which are related to different depositional environments. In situ, facies with a higher proportion of mud indicate conditions with lower flow energy. At the same time, a greater abundance of spherulites and shrubs may signal shallow water environments, providing carbonate precipitation for forming these structures. Reworked facies indicate environmental conditions with high flow energy, wave and wind action. Introduction The study area is located in Tupi field in Santos Basin, in the southeastern part of the Brazilian continental margin, occupying an area of nearly 352,000 km and water depths of up to 3,000 m. It is one of the largest maritime basins in Brazil, and, being situated approximately 230 km from the Brazilian coast, it extends along the coasts of the states of Rio de Janeiro, São Paulo, Paraná and Santa Catarina (Moreira et al., 2007) (Fig. 1). The formation process of Brazilian marginal basins had its origins during the rupture of the Gondwana Supercontinent in the Neocomian period, approximately 135 Ma. ago, and the supercontinent rifting resulted in the separation of the African and South American continents and the opening of the South Atlantic Ocean. During the evolution of Brazilian marginal basins, large lacustrine carbonate deposits were covered by an extensive evaporite layer that served as a trap for significant quantities of hydrocarbons, known as the Pre-salt section. The carbonate deposits received worldwide attention and became relevant due to the economic discovery of this considerable accumulation of oil in the Santos Basin and the confirmation of the exploratory viability of these new oil reservoirs.
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean (1.00)
- South America > Brazil > Brazil > South Atlantic Ocean (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- Geology > Structural Geology > Tectonics > Salt Tectonics (0.75)
- Geology > Sedimentary Geology > Depositional Environment > Continental Environment > Lacustrine Environment (0.58)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Tupi Field > Lula Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Tupi Field > Guaratiba Formation (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Santos Basin > Block BM-S-11 > Tupi Field > Cernambi Formation (0.99)
- (5 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Decoding Contaminants. A Case study to Understand Source, Origin, and Distribution of H2S and CO2 off the Coast of Sarawak, Offshore Malaysia
Masoudi, Rahim (PETRONAS) | Nayak, Satyabrata (PETRONAS) | Patrick Panting, Alexander Tarang (PETRONAS) | A Hamid, Nuril Anwar Ahba (PETRONAS) | M Diah, M Amri (PETRONAS) | Samsuri, Muhammad Nazam (PETRONAS) | Hoesni, Jamaal (Beicip-Franslab Asia)
Abstract In the shallow offshore region off the coast of Sarawak, Malaysia, exploration, development activities, and oil and gas production have been significantly affected by the presence of high concentrations of contaminants, mainly H2S and CO2. This has led to stranded hydrocarbon discoveries in the central Luconia area. The primary aim of this research was to uncover the origins of these contaminants and predict their distribution throughout the basin. To achieve this objective, an integrated regional petroleum system modeling approach was undertaken in the study area. The focus was on identifying the sources, origins, and distribution patterns of CO2 and H2S. By employing advanced modeling techniques and incorporating isotope analysis, this study provides valuable insights into the sources and distribution patterns of the contaminants. Based on the analysis of geochemical data and petroleum system modeling, it is suggested that the CO2 in the Sarawak basin may have originated from calcareous shale (Pre-Cycle I), coaly shale (Cycle I), and a magmatic source. Meanwhile, preliminary analysis indicates that the amount of H2S encountered in the study area could have been generated from various sources and processes. Overall, this research sheds light on the complex nature of these contaminants and lays the groundwork for a more comprehensive understanding of their origins and distribution patterns in the region.
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.58)
- Asia > China > South China Sea > Yinggehai Basin (0.99)
- Asia > China > South China Sea > Vung May Basin (0.99)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Health, Safety, Environment & Sustainability > Health > Noise, chemicals, and other workplace hazards (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (0.90)
Site Specific Joint Spacing Distribution of Roadcut Slopes in a Selected Stretch of National Highway in Indian Garhwal Himalayas
Hruaikima, Lal (Indian Institute of Technology Roorkee, India) | Singh, Mahendra (Indian Institute of Technology Roorkee, India) | Pradhan, Sarada Prasad (Indian Institute of Technology Roorkee, India) | Singh, Jaspreet (Simon Fraser University, Canada)
ABSTRACT: Due to extensive road widening project in the Himalayas, the roads experience huge instability problems especially during monsoon season. For the present study, 50 rock slope sites were considered over a stretch of 35 km on a national highway. The various attributes of discontinuities governing the slope failure were observed and the joint spacing in the stretch of the national highway is studied in detail. Detailed scanline survey was carried out and a database comprising more than about 6000 datapoints was generated. It is observed that the joints are spaced between 1 cm to 60 cm for the stretch of road. Statistical analysis of the joint spacing shows that most of the joint sets follow Exponential distribution, Weibull distribution, and lognormal distribution. Slope stability analysis was performed using the joint spacing data for all the slopes. It was observed that 50% of the slopes were susceptible to failure. INTRODUCTION Engineering designs for rock slopes sometimes include discontinuities as a source of uncertainty and variable. The strength and geometric characteristics of the discontinuities are liable to change inside a rock slope, which is frequently observed in difficult and challenging terrains such as hilly regions (Basahel & Mitri, 2019). Spacing of discontinuities is one of the indispensable parameters of rock slopes which is used to determine the block size, the hydrogeological permeability, deformability, and strength of the rock masses (Wong et al., 2018). Joint spacing in rocks have been studied by a number of researchers, and have reported to follow the Lognormal Distribution (Becker & Gross, 1996; Pascal et al., 1997; Wong et al., 2018), the Gamma Distributions (Castaing et al., 1996; Gross, 1993), the Negative Exponential Distribution (Hudson & Priest, 1983; Priest & Hudson, 1976, 1981), the Weibull Distribution (Wong et al., 2018) and the Normal Distribution (Ji & Saruwatari, 1998). In the present study, 50 different rock slope sites were considered over a stretch of 35 km on a national highway. Detailed scanline survey was done to assess the spacing of the joints and a database which comprises of more than 6000 joints were generated.
- Asia > Middle East > Yemen (0.95)
- Asia > Middle East > Saudi Arabia (0.95)
- Africa > Sudan (0.95)
- (3 more...)
- Geology > Geological Subdiscipline > Geomechanics (0.72)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.49)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Well Drilling > Drillstring Design > Drill pipe selection (0.40)
Two-Way Coupling Model for Dynamic Seabed Response Around Twin Pipelines Under Combined Wave and Current Loading
Zhang, Jia Yi (School of Civil Engineering, Qingdao Technology Innovative Center for Ocean Dynamic Environmental Simulations, Qingdao University of Technology) | Cui, Lin (School of Civil Engineering, Qingdao Technology Innovative Center for Ocean Dynamic Environmental Simulations, Qingdao University of Technology / Engineering Research Center of Concrete Technology under Marine Environment, Ministry of Education) | Zhai, Hualing (School of Civil Engineering, Southwest Jiaotong University) | Jeng, Dong-Sheng (School of Civil Engineering, Qingdao Technology Innovative Center for Ocean Dynamic Environmental Simulations, Qingdao University of Technology / School of Engineering & Built Environments, Griffith University Gold Coast Campus)
ABSTRACT Although twin pipelines in series have been used to transport hydrocarbons in existing engineering practice, previous studies have mostly focused on the dynamic response of the seabed around a single pipeline. In this study, we adopted the two-way coupling algorithm of fluid-structure-seabed interaction to investigate the wave-induced soil response around twin pipelines with different pipe diameters. The present model integrated the wave model and the seabed response model in a two-way coupling algorithm by introducing a boundary condition of velocity continuity in addition to the continuity of pressures at seabed surface, which overcome the contradiction between physical phenomena and existing theoretical models. Numerical results demonstrated the difference between the present two-way coupling model and existing one-way coupling model. INTRODUCTION Offshore pipeline is one of the key components in offshore oil and gas industry for the transportation of oil and gas products. The wave–pipeline–seabed interaction has be recognised as one of the important factors in the evaluation of the seabed stability around pipelines. The existence of submarine pipeline will not only change the flow morphology nearby, but also enhance the instability of the seabed around the pipeline, and further causes the destruction of the pipeline (Sumer, 2014). Based on the field measurements and laboratory experiments, the wave-induced soil response can be divided into two mechanisms. The first is the transient or oscillatory mechanism. It is generally believed that the transient liquefaction occurs due to the interaction between waves and the unsaturated seabed. The pore water pressure, effective stress and soil particle displacement generated in the seabed soil under the action of waves change periodically (Yamamoto et al., 1978). The second mechanism is residual mechanism with the accumulation of excess pore pressure in a saturated seabed caused by soil shrinkage under cyclic loading (Seed and Rahman, 1978; Sumer and Fredsøe, 2002). In this study, we focus on the oscillatory mechanism.
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Offshore pipelines (1.00)
Uncertainty Quantification for Transport in Porous Media Using Parameterized Physics Informed Neural Networks
Fraces, Cedric G. (Department of Energy Resources Engineering, Stanford University, Stanford, CA) | Tchelepi, Hamdi (Department of Energy Resources Engineering, Stanford University, Stanford, CA)
Abstract We present a Parametrization of the Physics Informed Neural Network (P-PINN) approach to tackle the problem of uncertainty quantification in reservoir engineering problems. We demonstrate the approach with the immiscible two phase flow displacement (Buckley-Leverett problem) in heterogeneous porous medium. The reservoir properties (porosity, permeability) are treated as random variables. The distribution of these properties can affect dynamic properties such as the fluids saturation, front propagation speed or breakthrough time. We explore and use to our advantage the ability of networks to interpolate complex high dimensional functions. We observe that the additional dimensions resulting from a stochastic treatment of the partial differential equations tend to produce smoother solutions on quantities of interest (distributions parameters) which is shown to improve the performance of PINNS. We show that provided a proper parameterization of the uncertainty space, PINN can produce solutions that match closely both the ensemble realizations and the stochastic moments. We demonstrate applications for both homogeneous and heterogeneous fields of properties. We are able to solve problems that can be challenging for classical methods. This approach gives rise to trained models that are both more robust to variations in the input space and can compete in performance with traditional stochastic sampling methods.
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Neural networks (1.00)
Abstract Unconventional shales reservoirs are complex in terms of composition, variable scales of analysis (from centimeter to nanometer) and petrophysical properties. To characterize these reservoirs, detailed analyses are required, including studies of rock samples in a wide range of scales. Extracted from a shale gas well (El Mangrullo Field, southwest of Neuquén Basin), the studied core involves a 123 m thick section within the lower enriched section (informally subdivided into Cocina, Parrilla, Orgánico Inferior y Orgánico Superior intervals) of Vaca Muerta Formation. This study consists in processing, interpreting, and integrating all the information from routine petrophysical laboratory studies (Tight Rock Analysis - TRA), well logs and high-resolution rock analysis (Digital Rock Analysis - DRA) using a customized and tailored workflow that provides quantitative and qualitative results. Permeability, total and effective porosity, organic porosity, and their distribution and another petrophysical properties (like pore size distribution, etc.) are characterized. The integration of the laboratory and DRA results allows the elaboration of a permoporous properties model. This model allowed us to integrate petrophysical model with the production of horizontal wells drilled in different sections of Vaca Muerta Formation.
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.46)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- South America > Argentina > Neuquen > Neuquen Basin > El Mangrullo Field (0.99)
- North America > United States > South Dakota > Williston Basin > Bakken Shale Formation (0.99)
- (2 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Improving Prediction of Fracture Distribution Using Microseismic Data and Acoustic Logging Measurements
Liu, Yilin (Cooperative Innovation Center of Unconventional Oil and Gas, Yangtze University (Ministry of Education & Hubei Province)) | Gao, Guozhong (College of Geophysics and Petroleum Resources, Yangtze University)
Summary The complex fracture network from hydraulic fracturing can significantly improve oilwell productivity, so it is widely used in the field of unconventional reservoir development. However, accurate evaluation of the fracture spatial distribution remains a challenge. As a result, how to combine a variety of data to avoid data islands and identify and predict the space of fracture zone is of great importance. In this paper, we present a method and workflow based on the microseismic (MS) data combined with shear wave velocity data to estimate the physical parameters of subsurface media and improve the description and prediction accuracy for hydraulic fractures. The method analyzes MS events to construct the fracture spatial distribution and uses acoustic logging measurements to correct the magnitude of MS events and enhance the resolution. The corrected MS magnitude is mapped to the MS event space for Kriging interpolation analysis to predict the improved spatial distribution of fractures, which is available in the format of a 3D cloud image. Introduction Effective shale gas production requires reservoir modification through volumetric fracturing technology, which generates complex fracture networks to improve productivity (Shang et al. 2021). In recent years, industry experts have made progress using core data, well logs, seismic measurements through numerical simulation, and other means to conduct geological modeling to understand underground conditions to assist in improving the effects of fracturing (Wang et al. 2016; Shi and Lin 2021; Li et al. 2021). At present, reservoir modeling mainly focuses on the reservoir matrix, natural fractures, and hydraulic fractures. Hydraulic fractures occur when fracturing fluid is injected into horizontal or vertical wells to perforate and rock tensile strength and minimum formation stress are insufficient to resist fluid pressure (Chen et al. 2021b).
- Asia > China (0.93)
- North America > United States > Texas (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Plate Tectonics (0.48)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.36)
- Geophysics > Seismic Surveying > Passive Seismic Surveying > Microseismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Marcellus Shale Formation (0.99)
- (4 more...)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Insights on the Origin and Distribution of CO2 in Malay Basin, Offshore Peninsular Malaysia: A Petroleum System Modelling approach
Nayak, Satyabrata (PETRONAS) | Masoudi, Rahim (PETRONAS) | Tarang Patrick Panting, Alexander (PETRONAS) | B M Diah, M Amri (PETRONAS) | B Roslan, Mohd Razeif (PETRONAS) | B M Amin, M Farid (PETRONAS) | R Iyer, Subramania (Halliburton) | Aarssen, Ben Van (Halliburton) | Fun, Sook (Halliburton) | Mishra, Somen (Halliburton)
Abstract High concentration of CO2 in various fields of Malay basin, offshore Peninsular Malaysia pose major challenges in monetizing the resources in a sustainable way. Focused study to understand the source, origin and distribution of CO2 is essential to make informed decisions on developing the fields. This paper is part of the basin scale study to address the distribution of CO2 and its risk assessment. Modelling of the petroleum system including CO2 contaminant was adopted to validate the fluid accumulations in the basin with observed results from fields. An Earth Model was built using maps generated from an integrated study of seismic and 65 key wells. The depth to basement and depth to Moho were incorporated from previous gravity modelling study. The CO2 content and isotope data compiled from reports facilitated in building the knowledge on the source, origin, and distribution over the study area. Play segments identified based on tectonic features were used to divide the basin into subset areas for analysis.
- Asia > Malaysia > South China Sea > Malay Basin (0.99)
- Asia > China > South China Sea > Penyu Basin (0.99)
- North America > United States > Gulf of Mexico > Gulf Coast Basin (0.97)
- Europe > Norway (0.89)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (0.90)
An Integrated Approach for History Matching of Complex Fracture Distributions for Shale Oil Reservoirs Based on Improved Adaptive Particle Filter
Zhao, Guoxiang (State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum (Beijing) and Department of Chemical & Petroleum Engineering, Schulich School of Engineering, University of Calgary) | Yao, Yuedong (State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum (Beijing) (Corresponding author)) | Zhang, Tao (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University) | Wang, Lian (State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum (Beijing)) | Adenutsi, Caspar Daniel (Department of Petroleum Engineering, Faculty of Civil and Geo-Engineering, Kwame Nkrumah University of Science and Technology) | Nassar, Nashaat N. (Department of Chemical & Petroleum Engineering, Schulich School of Engineering, University of Calgary (Corresponding author))
Summary The application of horizontal well drilling technology and volume fracturing technique makes the economic development of shale oil reservoirs feasible. The unknown fracture networks lead to severe nonlinearity and high uncertainty during fracture characterization. Therefore, the key challenges for history matching in fractured shale oil reservoirs are effectively representing the fracture network and coping with the non-Gaussian distribution of reservoirmodel parameters. In this work, a new characterization method for complex fracture networks is established, in which the distribution of connected fractures of the reservoir domain is represented by some statistical parameters such as fracture dip angle, fracture azimuth, and fracture half-length and some deterministic parameters such as the coordinates of fracture center points. In the uncertainty quantification and history-matching process, an integrated approach that combines the particle filter and an improved kernel density estimation (KDE) based on its Shannon entropy (SE) for estimating fracture distributions and physical parameters is presented. An adaptive mechanism based on Kullback-Leibler divergence (KLD) is introduced in the proposed history matching workflow, which automatically adjusts the number of particles to reduce the computational burden. Two examples of 3D shale oil production were constructed to validate the efficiency and accuracy of the proposed method. Results showed that the method was capable of capturing the main features of the fracture distributions in the reference cases. The proposed method has the potential to be applied in more complex cases such as multiple wells and multiphase flow. Introduction The effective development of shale oil reservoirs has attracted a lot of interest as energy demand around the world increases. The costeffective production of shale oil reservoirs can be attributed to the wide applications of horizontal well technology and hydraulic fracturing technique. The production performance of shale oil is strongly affected by the distribution and geometry of fractures due to the nature of its high fracture conductivity (Dachanuwattana et al. 2018).
- Asia (0.67)
- North America > United States > Texas (0.46)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- South America > Argentina > Patagonia > Neuquén > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- North America > United States > Texas > Permian Basin > Janice Field > Wolfcamp Formation (0.99)
ABSTRACT We have developed a 2D anisotropic magnetotelluric (MT) inversion algorithm that uses a limited-memory quasi-Newton (QN) method for bounds-constrained optimization. This algorithm solves the inverse problem, which is nonlinear, by iterative minimization of linearized approximations of the classic Tikhonov regularized objective function. The QN approximation for the Hessian matrix is only implemented for the data-misfit term of the objective function; the part of the Hessian matrix for the regularization is explicitly computed. This adjustment results in a better approximation for the data-misfit term in particular. The inversion algorithm considers arbitrary anisotropy, and it is extended for special cases including azimuthal and vertical anisotropy. The algorithm is shown to be stable and converges rapidly for several simple anisotropic models. These synthetic tests also confirm that the anisotropic inversion produces a correct anomaly with different but equivalent anisotropic parameters. We also consider a complex 2D anisotropic model; the successful results for this model further confirm that the inversion algorithm presented here, which uses the novel modified limited-memory QN approach, is capable of solving the 2D anisotropic MT inverse problem. Finally, we have evaluated a practical application on MT data collected in northern Tibet to demonstrate the effectiveness and stability of our algorithm.
- North America (0.92)
- Asia > China > Tibet (0.25)
- Asia > China > Qinghai > Qaidam Basin (0.99)
- Africa > South Africa > Western Cape Province > Indian Ocean > Bredasdorp Basin > Block 9 > EM Field (0.99)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Cross-well tomography (0.86)