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Petroleum Engineering, University of Houston, 2. Metarock Laboratories, 3. Department of Earth and Atmospheric Sciences, University of Houston) 16:00-16:30 Break and Walk to Bizzell Museum 16:30-17:30 Tour: History of Science Collections, Bizzell Memorial Library, The University of Oklahoma 17:30-19:00 Networking Reception: Thurman J. White Forum Building
- Research Report > New Finding (0.93)
- Overview (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Mineral (0.72)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
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- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
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- Research Report > New Finding (0.93)
- Overview (0.88)
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- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.68)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.47)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
All material in this report, with accompanying figures, is property of SEG Advanced Modeling Corporation (SEAM). License to use the data and models can be obtained through SEAM. This document contains contributions from many different individuals and has been reviewed for accuracy. Reported errors will be fixed on a timely basis. The SEAM Carbonate model is the petroleum industry's first field-scale, digital model of a carbonate reservoir to be openly available.
- Geology > Rock Type > Sedimentary Rock (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Well Drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
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- Geology > Structural Geology > Tectonics > Plate Tectonics (1.00)
- Geology > Rock Type > Sedimentary Rock (1.00)
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- Energy > Oil & Gas > Upstream (1.00)
- Education > Educational Setting (1.00)
- Materials > Metals & Mining (0.92)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Block V > Urengoyskoye Field > Achimov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Block IV > Urengoyskoye Field > Achimov Formation (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Purovsky District > West Siberian Basin > Nadym-Pur-Taz Basin > Block 5A > Urengoyskoye Field > Achimov Formation (0.99)
- (4 more...)
The 11th Society of Petroleum Engineers Comparative Solution Project: Problem Definition
Nordbotten, Jan M. (Department of Mathematics, University of Bergen) | Ferno, Martin A. (Norwegian Research Center (NORCE) (Corresponding author)) | Flemisch, Bernd (Department of Physics and Technology, University of Bergen) | Kovscek, Anthony R. (Norwegian Research Center (NORCE)) | Lie, Knut-Andreas (Institute for Modelling Hydraulic and Environmental Systems, University of Stuttgart)
Summary This article contains the description of, and call for participation in, the 11th Society of Petroleum Engineers Comparative Solution Project (the 11th SPE CSP, ). It is motivated by the simulation challenges associated with CO2 storage operations in geological settings of realistic complexity. The 11th SPE CSP contains three versions: Version 11A is a 2D geometry at the laboratory scale, inspired by a recent CO2 storage forecasting and validation study. For Version 11B, the 2D geometry and operational conditions from 11A are rescaled to field conditions characteristic of the Norwegian Continental Shelf. Finally, for Version 11C, the geometry of Version 11B is extruded to a full 3D field model. The CSP has a two-year timeline, being launched at the 2023 SPE Reservoir Simulation Conference and culminating at the 2025 SPE Reservoir Simulation Conference. A community effort is run in parallel to develop utility scripts and input files for common simulators to lower the threshold of participation; see the link to supplementary material on the CSP website. At the time of writing, complete input decks for one simulator are already ready for all three versions.
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (9 more...)
Application of Physics-Informed Neural Networks for Estimation of Saturation Functions from Countercurrent Spontaneous Imbibition Tests
Abbasi, Jassem (Department of Energy Resources, University of Stavanger (Corresponding author)) | Andersen, Pรฅl รstebรธ (Department of Energy Resources, University of Stavanger)
Summary In this work, physics-informed neural networks (PINNs) are used for history matching data from core-scale countercurrent spontaneous imbibition (COUCSI) tests. To our knowledge, this is the first work exploring the variation in saturation function solutions from COUCSI tests. 1D flow was considered, in which two phases flow in opposite directions driven by capillary forces with one boundary open to flow. The partial differential equation (PDE) depends only on a saturation-dependent capillary diffusion coefficient (CDC). Static properties such as porosity, permeability, interfacial tension, and fluid viscosities are considered known. In contrast, the CDC or its components [relative permeability (RP) and capillary pressure (PC)], are considered unknown. We investigate the range of functions (CDCs or RP/PC combinations) that explain different (synthetic or real) experimental COUCSI data: recovery from varying extents of early-time and late-time periods, pressure transducers, and in-situ saturation profiles. History matching was performed by training a PINN to minimize a loss function based on observational data and terms related to the PDE, boundary, and initial conditions. The PINN model was generated with feedforward neural networks, Fourier/inverse-Fourier transformation, and an adaptive tanh activation function, and trained using full batching. The trainable parameters of both the neural networks and saturation functions (parameters in RP and PC correlations) were initialized randomly. The PINN method successfully matched the observed data and returned a range of possible saturation function solutions. When a full observed recovery curve was provided (recovery data reaching close to its final value), unique and correct CDC functions and correct spatial saturation profiles were obtained. However, different RP/PC combinations composing the CDC were calculated. For limited amounts of recovery data, different CDCs matched the observations equally well but predicted different recovery behavior beyond the collected data period. With limited recovery data, when all points were still following a square root of time trend, a CDC with a low magnitude and peak shifted to high saturations gave the same match as a CDC with a high magnitude and peak shifted to low saturations. Recovery data with sufficient points not being proportional to the square root of time strongly constrained how future recovery would behave and thus which CDCs could explain the results. Limited recovery data combined with an observed in-situ profile of saturations allowed for accurate determination of CDC and prediction of future recovery, suggesting in-situ data allowed for shortened experiments. With full recovery data, in-situ PC data calibrated the PC toward unique solutions matching the input. The RPs were determined, where their phase had much lower mobility than the others. The CDC is virtually independent of the highest fluid mobility, and RPs could not be matched at their high values. Adding artificial noise in the recovery data increased the variation of the estimated CDCs.
- Europe (1.00)
- North America > United States (0.93)
- Health & Medicine (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- (2 more...)
Summary The centrifuge experiment is used to measure capillary pressure in core plugs by forced displacement (imbibition or drainage): Strong gravitational forces (imposed by rotation) displace fluid held in place by capillary forces. This setup is also used to measure and establish residual saturation, the saturation where a fluid loses connectivity and can no longer flow. Obtaining this saturation is challenging as the capillary end effect causing outlet fluid accumulation theoretically only vanishes at infinite rotation speed. First, we derive a novel โintercept methodโ to estimate residual saturation with a centrifuge: Plotting steady-state average saturation data against inverse squared rotation speed gives a straight line at high speeds where the intercept equals the residual saturation. The linear behavior starts once the core saturation profile contains the residual saturation. The result is theoretically valid for all input parameters and functions, derived assuming uniform gravity along the core at a given speed. Then the saturation profile near the outlet is invariant and compresses at a higher speed. The method was, however, demonstrated numerically to be highly accurate even for extremely nonuniform gravity: The saturation data are linear and the correct residual saturation value is estimated. This is because when the residual saturation enters, most of the end effect profile is located in a narrow part of the core and thus uniformly compressed. Several experimental and numerical data sets validated the method. Second, an analytical solution (using all relevant input) is derived for transient production toward equilibrium after the rotation speed is increased starting from an arbitrary initial state. For this result, we assume the outlet (or initial) profile compresses also transiently. The displacing and displaced regions have fixed mobilities but occupy different lengths with time. Time as a function of production has a linear term and logarithmic term (dominating late time behavior). Production rate can thus be constant most of the time or gradually reducing, resulting in very distinct profiles. The correlation could fit experimental data well and confirmed the possible profile shapes. A time scale was derived analytically that scales all production curves to end (99.5% production) at same scaled time. The solution predicted similar time scales and trends in time scale with rotation speed and viscosity as numerical simulations. Numerical simulations indicated that the saturations near the residual saturation traveled slowly, which caused production to tail and span 5 log units of time (the analytical solution predicted 2โ3). The correlation better matched low-speed data where the residual saturation had not entered.
- Europe (1.00)
- North America > United States (0.93)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- (3 more...)
Real-Time Ultra-Deep Azimuthal Resistivity Inversion Helps to Maximize Asset Value in West Kuwait by Locating Oil-Water Contact Below the Target Well Trajectory
Gezeery, T. (Kuwait Oil Company) | Halawah, Y. (Kuwait Oil Company) | Al Haddad, M. (Kuwait Oil Company) | Al Sabea, S. (Kuwait Oil Company) | Abdulkarim, A. (Halliburton)
Abstract The Burgan sandstone reservoir in the Minagish field of Kuwait is a complex depositional sequence that makes targeting Upper Burgan sands unpredictable due to channeling limiting the reservoir exposure. The area is complicated further by oil-water contact (OWC) uncertainty due to the long history of oil production. The objective of the well was real-time OWC mapping to provide reservoir insight, maximize pay zone exposure and extend the well life through optimizing the completion and production regime. Recent production pulsed-neutron capture (PNC) logging in an offset well showed watering in the Upper Burgan reservoir. This might indicate a change in the level of the OWC or water coning. Utilization of an ultra-deep azimuthal resistivity (UDAR) mapping service was planned to help locate the OWC below the well trajectory and simultaneously identify and track the desired target sandstone sequence. UDAR has proven its capability to map reservoir boundaries and the OWC in real time, during drilling, earlier than with traditional methods. This facilitates real-time geosteering to drill the well in a single run in the productive zone. The wellbore was placed in the desired zone by using UDAR real-time 1D inversion services. While drilling it had been discovered that the OWC was deeper than expected. The reservoir management team obtained important information to update the oilfield development. UDAR services helped to increase reservoir exposure of the well in the Burgan sand of the Minagish oilfield and enhanced the understanding of the sand deposition structure. It was evident that PNC results in the producing offset well do not represent the OWC level throughout the field; instead, localized measurements may be affected by water coning in that specific area. This information led to a change in the field development strategy. The UDAR real-time 1D inversion enabled optimization of the completion design and perforation intervals, and the understanding of the reservoir potential has been improved. The accurate OWC level evaluation will allow to place more production wells in this location.
- Geology > Sedimentary Geology (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Mineral (0.95)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.90)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (0.68)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Upper Marrat Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sargelu Formation (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > Sabriyah Field > Marrat Formation > Sabiriyah Mauddud (SAMA) Formation (0.99)
- (24 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- (2 more...)
Members of the editorial board and their respective employers are not responsible for the opinions, content, and viewpoints of articles appearing in The Way Ahead. Aman Srivastava is the Editor in Chief of TWA. He is Product Owner for Halliburton-Landmark. With a bachelor's degree in mechanical engineering from National Institute of Technology, Surat, India, and a master's degree in petroleum engineering from the University of Oklahoma, and more than 15 years of experience in on-field and off-field drilling activities, Srivastava holds a special interest in well construction engineering and energy/sustainability. Aman received the SPE Mid-Continental Regional Award for 2023, is a reviewer of two peer-reviewed journals, and holds a patent for his design of internal combustion engine. In his free time, he loves watching movies and reading books when he is not busy playing with his daughter and spending time with family. James Blaney is the Deputy Editor in Chief of TWA. He is an Application Engineer for Chevron's MidCon Business Unit, holding a bachelor's in economics from Georgetown University and a bachelor's in Petroleum Engineering from the Colorado School of Mines. He cut his teeth in the Permian Basin as a field engineer for Liberty Energy before progressing to a software development role working on pump control software, integrating their new electric DigiFrac and natural gas powered DigiPrime pumps. He sees plenty of room for the role of tech in industry to grow and firmly believes if you're going to do anything twice you should automate it once. A former PetroBowl contestant, he is also a lover of all things trivia.
- Asia > India (1.00)
- North America > United States > Texas (0.90)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (23 more...)
- Well Completion (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- (9 more...)
Simulation of Hydrate Particles Aggregation and Deposition in Gas-Dominated Flow
Wang, Zhiyuan (China University of Petroleum (East China) (Corresponding author)) | Li, Zeqin (China University of Petroleum (East China)) | Pei, Jihao (China University of Petroleum (East China)) | Ma, Nan (China University of Petroleum (East China)) | Zhang, Jianbo (China University of Petroleum (East China)) | Sun, Baojiang (China University of Petroleum (East China))
Summary Owing to low-temperature and high-pressure production environments, hydrate generation, accumulation, and deposition are prone to occur in deepwater oil and gas production wells and transportation pipelines, leading to pipeline blockage and threatening the safety of oil and gas production. To explore the aggregation mechanism and deposition law of hydrate particles in the main gas diversion pipeline, this study considered the adhesion effect of hydrate particles and established a hydrate particle aggregation and deposition model based on theory and experiments. The coupled computational fluid dynamics-discrete element method (CFD-DEM) is used in the simulation calculation. The simulation results were compared with the relevant experimental results, and maximum and average errors of 9.48% and 4.56% were observed, respectively. It was found that the main factor affecting the aggregation of hydrates is the adhesion between particles. As the subcooling temperature increased, the aggregation and adhesion of the hydrate particles increased to varying degrees. The tangential adhesion force between the hydrate aggregate particles was significantly greater than the normal adhesion force, and the adhesion force between the particles gradually increased from the surface to the interior of the aggregates. The coordination number of the hydrate particles can quantitatively characterize the degree of aggregation and is affected by many factors, such as adhesion. By studying the particle coordination number, the evolution of hydrate accumulation and deposition under different conditions can be summarized. Based on the simulation results, the mathematical relationship between different dimensionless numbers and hydrate deposition ratio (HDR) was calculated, and an expression that can predict the HDR was obtained, with an average relative error of 10.155%. This study provides a theoretical basis for predicting the aggregation and deposition of hydrate particles in gas-dominated systems and a reference for the development of hydrate prevention and control plans.
- North America > United States (0.46)
- Asia > China (0.28)
- North America > Canada (0.28)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
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