bluuebunny/crossref_metadata_2025_split huggingface dataset:
Nonlinear Modal Responses of Damaged Shell Structures: Numerical Prediction and Experimental Validation
Authors: Kumar Vikash , Panda Subrata Kumar , Dwivedi Madhuresh , Mahmoud S. R. , Balubaid Mohammed 
Published: February 2023

The nonlinear finite element (FE) modeling approach has been adopted to model and predict the modal responses of the combined damaged (crack and delamination) layered shell structures. The damaged panel structure has been constructed mathematically using a circular meshing approach of the FE technique to include the crack. Similarly, the sublaminate approach has being used to introduce delamination of the layered structure on a mutual center. The structural distorted geometry and the deformations were modeled through the full geometrical nonlinear strain-displacement (Green–Lagrange) relations in association with higher-order polynomial functions. The modal responses of the damaged structure were obtained through an iterative method in association with the nonlinear FE technique. The predicted response accuracies were established with two-step verifications: that is, the numerical solution stability (elemental sensitivity) and the degree of deviation with published data. The maximum deviation between the developed numerical model and the reference result (first-order shear deformation theory) was 8.3%. The model’s competence and responses were compared with experimental data, with and without damages. Finally, new examples have been solved for different structural geometry-dependent parameters (shell configurations, delamination shapes, crack positions/lengths, end boundaries, etcetera) affecting final modal values. A detailed in-depth understanding of the damage and curvature (unequal/equal curvature) effects on modal responses will be discussed.
Shifting Focus to Electrical Submersible Pump (ESP) Technology to Enhance Well Productivity and Recovery in Malaysia Fields
Authors: Ho Yeek Huey , Fazilah Siti Rodhiah , Nava Bastidas Jesus , Amsidom Amirul Adha , Rosland Eadie Azahar , Idris Khairul Nizam , Masoudi Rahim , Trjangganung Kukuh , Mohd Khair Zahrah , majid Mohamad Syafiq , Subandi Ahmad Nabil , Chandaran Tharushana 
Published: February 2023

AbstractMore than 50% of Malaysia fields are matured or at its late life stage. These fields are mostly highly dependent on gas lift as the artificial lift method to maximize well potential and reserves recovery. Many of these fields are presently facing matured field operational challenges such as high water cut, shortage of gas lift supply, reservoir pressure depletion and aging facilities.As host authority for all hydrocarbon resources in Malaysia, PETRONAS Malaysia Petroleum Management (MPM) has initiated a Malaysia- wide effort to improve the production rate and recovery of hydrocarbon by expanding the usage of Electric Submersible Pump (ESP) as an alternative artificial lift method. ESP is an alternative artificial lift method that has been successfully pilot deployment.This paper focuses on the strategy of ESP replications at Malaysia to address production decline and extending well life through various enabler to support the target. PETRONAS has identified 10% of producing wells in Malaysia that will benefit from ESP technology, resulting in 6% incremental production. Subsequently, PETRONAS embarking ESP Feasibility Study with Solution Partner to mature ESP opportunities basket in integrated approach surface and subsurface and acts as an enabler for PAC to evaluate future fields for ESP replications.There are four main scopes in Feasibility Study which are, (i) Data Gathering and Well Screening, (ii) Potential Candidate Identification, (iii) Maturation of Opportunities Proposal and (iv) cost effective solution for ESP implementation. At the same time, ESP Integrated Contract which will serve as end-to-end solution for all PACs, is being developed by MPM as a key enabler to enhance ESP replications via more volume of work, lower cost, and improved lifecycle efficiency.There were five fields were under the ESP Feasibility Studies where comprehensive of subsurface and surface study were conducted. More than 500 strings were evaluated. A 50 well proposals were completed and the ESP opportunities to be implemented by phases to address production decline and to increase well life, leveraging on ESP Integrated Contract to create more value to PETRONAS and PAC. The feasibility study has also guided PETRONAS in candidate prioritization. Long term roadmap on ESP replications was developed to fully capitalize on ESP Technology to enhance Malaysia production and reserves monetization by creating the right ESP eco-system for the Oil & Gas Industry. The feasibility Studies approach enable future ESP studies in Malaysia fields.
Integrated Multiscale Carbonate Rock Types Prediction Using Multiscale Data and Kohonen Self-Organising Maps in E11 Field, Central Luconia Province, Malaysia
Authors: Jimenez Soto Grisel , Abdul Latiff Abdul Halim , Ben Habel Wael , Poppelreiter Michael 
Published: February 2023

AbstractA crucial role that significantly affects carbonate field development for hydrocarbon and carbon sequestration (CCS) projects is reducing uncertainty in rock type prediction. The carbonate reservoirs in Central Luconia Province, Malaysia, are significant economic worldwide reservoirs and are currently considered excellent candidates for Carbon Storage containers. The nature of these carbonate rock properties is visible and notably distinguishable at the core scale.To characterize significant petrophysical and geological factors of the distribution of the rock properties in the E11 carbonate build-up, this work proposes a sequence of processes (workflow) for obtaining spatial information about the organization using Kohonen Self-organizing maps.This work highlights the significant geological and petrophysical constraints on the distribution of rock properties in the E11 field. Using self-organizing maps, the predicted rock types were propagated among wells with no core available.Using this workflow, multiscale data is categorized according to "patterns". The phases include Phase 1: Detailed core description, Phase 2: Microscope sections description, Phase 3: Well logs analysis, Phase 4: Well logs analysis, and Phase 4: Self-organizing maps using IPSOM module in Techlog software. Considering the stratigraphic organization, juxtaposition, and proportions, the anticipated rock type closely resembles the rock types identified by core description manually.The results allow a comprehensive understanding of flow behavior in carbonate tight and reservoir rock types.
Impact Of Cation Exchange On Polymer In-Situ Viscosity: An Experimental Investigation For A Low-Salinity Polymer Flooding Case
Authors: Rousseau David , Salaün Mathieu 
Published: February 2023

AbstractCation exchange occurs when water with a different salinity as the connate brine is injected in a reservoir. During polymer flooding operations, the potential release of divalent cations by the rock can have a detrimental impact on the in-situ viscosity in the polymer bank. The objective of this work was to assess for the risk related to cations exchange in an Argentinian oilfield and to provide guidelines for the injection water design.Reservoir rock samples were first submitted to mineralogical analysis involving scanning-electron microscopy (SEM), X-Ray Diffraction (XRD) and determination of their Cation Exchange Capacities (CEC). Coreflood tests were then performed where the effluents were analyzed for their cations composition. In these experiments, two main scenarios for the composition of the low-salinity injection water (with or without softening) were investigated and the transport properties of the polymer were determined. As a more exploratory approach, polymer was also injected in a 12-meter-long slim tube filled with crushed reservoir rock, to assess if it could be exposed to released cations.The results showed that all reservoir rocks investigated had high CEC, which was consistent with their high clay contents, and that significant cations exchanges took place during low salinity water injection, although no formation damage occurred, showing the stability of the clays. During injection of the softened water, evidences of significant divalent (and monovalent) cations release from the rock were found. During injection of the unsoftened water, a marked and long-term adsorption of the injected calcium cations was observed, corresponding to a depletion in calcium of the injected water. This suggests that, quite counter-intuitively, using unsoftened water as polymer make up water could be interesting in view of economics because the cations exchanges could entail an increase of the in-situ viscosity. The coreflood test results also showed that the presence of polymer in the injected water had no impact on the cations exchanges mechanisms. The partial results from the slim tube injection test suggested, however, that the retardation of the polymer bank caused by polymer adsorption was sufficient to avoid for its viscosity to be affected by the changes in cations distribution.This study illustrates the importance of cation exchange mechanisms and their potential impact for polymer flooding. It also shows that these effects can be investigated in a representative manner at the lab and that practical guidelines for the composition of the polymer injection water can be deduced from the experiments, provided a risk for in-situ viscosity reduction is identified.
Secondary Versus Tertiary Polymer Flooding: A Laboratory Evaluation in Low Permeability HT/HS Carbonate Reservoir Conditions
Authors: Ould Metidji Mahmoud , Juarez Morejon Jose Luis , Garcia Mayoral Maria Flor , Rodriguez Pardo Maria Rosario , Montes Ruiz Jesus , Lereau Damien , Monzon Vazquez Jorge , Dupuis Guillaume 
Published: February 2023

AbstractPolymer flooding is a well-established EOR technique widely implemented in sandstone reservoirs. Sulfonated acrylamide-based copolymers recently proved their potential in harsh HT/HS carbonate reservoirs with pilot tests upcoming in the Middle East. While polymer flooding is often classified as a tertiary recovery method, the present study aims to evaluate EOR efficiencies in secondary and tertiary recovery scenarios. The polymer selection process and characterization in porous media are described in detail.The study was conducted on a lab-scale at a temperature of 120°C. The salinity of seawater used for injection was 42 g/L TDS. The polymer selection was based on a thorough rheology and filterability study. The coreflooding tests were performed on limestone outcrops with permeability in the range of 40 mD. Single-phase experiments were performed to evaluate the impact of a pre-shearing step and study the in-situ rheology. Secondary and tertiary oil recovery experiments were conducted using reservoir dead oil. In all experiments, the tracer method was used to determine dynamic adsorption.The rheology and filterability study identified the best candidate (SAV 10) among three different molecular weight polymers containing the same high-sulfonation level. The target viscosity for the desired mobility ratio was 3 cP at 120°C, achieved with a polymer concentration of 3500 ppm. The single-phase experiments suggested that pre-shearing the polymer reduced the apparent shear thickening at high velocities due to a reduction in viscoelastic properties. The best oil recovery performances were obtained in the secondary mode (polymer flood applied at Swi) with a 15% higher recovery when compared to the tertiary mode (after reaching Sorw). The results correlate with a later breakthrough for the earlier polymer flood case. In both cases the mobility ratio was comparable (0.18-0.20) and much lower than waterflooding (1.5). The polymer dynamic adsorption estimated with the tracer method was about 140 μg/g rock in brine saturated cores, decreasing to ~100 μg/g rock in the presence of residual oil saturation. The in-situ rheology evaluation after stable recovery was reached following polymer flooding (Sorp), evidenced less apparent shear thickening, which could be related to a change in the conformation of the pores in the presence of oil.Most studies reported on secondary and tertiary polymer flooding focused on the case of heavy-oil sandstone reservoirs. The present work introduces new insights on early implementation of polymer flooding to optimize oil production by maximizing the performance of the method in HT/HS carbonate reservoirs. Furthermore, our study provides new insights about sulfonated acrylamide-base copolymer rheology in porous media for low permeability carbonate cores.
Application of Seismic-Geological Integration Anisotropy Modeling and PSDM Technology to Horizontal-Well Group Deployment in New Exploration Field
Authors: Bao Yi , Zhao Haibo , Wang Cheng , Wang Yangyang , Yan Feng , Zhang Zhiming , Guo Shuai , Li Xingyuan , Yao Shunyu 
Published: February 2023

AbstractNew exploration field of Shale-oil located on Songliao Basin in the northeast of China show good prospects has been found very strong anisotropy and varies greatly from location to another through laboratory measurement of drilled cores. But the thickness of high-quality target layer is less than 10m and average vertical depth is 2500m, conventional seismic migration results cannot support accurate geosteering of horizontal-wells. We adopted the result-driven integrated seismic and geological modeling concept to guide the following processing in order to eliminate the structural errors existing in the seismic processing results of Well-X1 and the trajectory calibration of horizontal wells, the fidelity velocity analysis technology based on the combined constraints of rockphysical analysis firstly, the anisotropic forward modeling results is used to obtain accurate isotropic velocity field, and then the "Well-control + Stratification + Fault-control" modeling technology is used to establish a high-precision velocity model. The depth errors of the seismic and geological model and the horizontal well trajectory are directly calibrated quantitatively in the depth domain after the PSDM (Prestack Depth Migration), and the anisotropic model is modified for iterative PSDM. Finally, the structural errors of the horizontal well trajectory and seismic profile in the correlation between the seismic results of the new method and the vertical well synthesis record increased from 79% to 91%. Then, the anisotropy model was updated by quantitative calibration with existing horizontal-well trajectory in the depth domain, so that the final VTI anisotropic PSDM results and the horizontal well construction error in the depth domain was less than 1‰. The anisotropic PSDM results provide accurate guidance for geosteering, and the posterior horizontal-well verifies the high accuracy of the method. The technology can effectively support the deployment of horizontal-well groups in new fields and the beneficial development and utilization of new types of reservoirs in Daqing oilfield, it also demonstrated that the seismic-geological integration anisotropy modeling and PSDM technology can provide reliable support for the deployment of horizontal-wells in the same type of deep, thin, anisotropic reservoirs.
Feasibility Study of Carbon Capture Utilization and Storage (CCUS) in the Gulf of Thailand: Phase I Storage Potential Identification
Authors: Henglai Puntira , Laochamroonvorapongse Rapheephan , Kovitkanit Naruttee , Kunpitaktakun Takonporn 
Published: February 2023

Abstract
With the determination towards sustainable growth, PTTEP has a commitment to achieve Net Zero Greenhouse Gas Emissions by 2050. Therefore, the Carbon Capture Utilization and Storage (CCUS) project in the Gulf of Thailand was initiated to evaluate the CO2 storage capacity in Bongkot and Arthit fields. Three categories of storage potential were considered including shallow aquifers and depleted gas reservoirs together with storage potential in oil rim reservoirs by using CO2 enhanced oil recovery (CO2-EOR) method.
The storage potential in shallow aquifer was targeted on porous rock located between seabed and top producing reservoirs which were identified in seismic and/or well data and reached by existing platforms. For the inventory of depleted gas reservoirs, the cumulative gas production volume was allocated to an individual reservoir, which signified storage size and injectivity of reservoir. The depleted gas reservoirs were focused on ones where a great amount of gas has been produced. For the CO2-EOR candidates, all oil rim reservoirs were reviewed and included in the study. The calculation of oil gain, CO2 injection requirement, and CO2 storage potential were based on the statistical data of Water-Alternating-CO2 fields.
The inventory of CO2 storage potential from three categories were compiled with the information of 1) platform name, 2) remaining reserves, 3) distance from processing platforms, and 4) CO2 storage volume. After considering the CO2 storage potential, two platforms were considered as the most suitable for two fields equipped with CO2 removal units. In addition, the CCS development study considered an option to improve CO2 removal performance of the membrane in order to recover more hydrocarbon from flared gas. After the preliminary technical evaluation, the detailed study with reservoir simulation will be conducted in order to ensure the injectivity at reservoir level, the optimization of injection well number, and the integrity of containment. The injection plan will be formulated, and the investment cost estimation of CCS project can be refined accordingly.
This CCUS study was initiated to reduce the CO2 emission from production fields under PTTEP. Currently, there are more than 20 CCUS projects around the world with only a few projects at the stage of CO2 injection. It requires good collaboration among subsurface and surface teams to increase confidence in storage suitability assessment. This project provides an example of multi-disciplinary integration and robust workflow starting from CO2 storage identification, volume calculation, to candidate ranking for further detail study.
Carbon Storage Leak Detection via Seismic FWI and RTM: Different Surveys Analysis
Authors: Amani Sajjad 
Published: February 2023

AbstractMarine seismic data processing is investigated to monitor possible leakages from the geological Carbon storage. Due to the high importance of storage permanence, a precise leakage monitoring strategy is crucial. Advanced seismic monitoring solutions should be used for this goal. The proficiency of these solutions for monitoring a Carbon storage leakage can be affected by shallower layers due to their structures, seismic wave attenuation, and leak size. Knowing the difficulty of this problem, we investigate the two popular seismic monitoring methods on Seismic data for monitoring Carbon leaks in different scenarios: Full Waveform Inversion (FWI) and Reverse-Time Migration (RTM).Finding the best survey strategy for monitoring carbon leaks is also significant. So, the results of different survey strategies, including vertical seismic profiling (VSP), cross-well, and surface, are compared to demonstrate the pros and cons of each strategy.The synthetic marine seismic data is calculated for different models, including Carbon storage and its leak. We used a set of realistic physical values for sedimentary rocks that are common for such a media. An elastic finite-difference time-domain scheme is used for the simulations. We applied FWI and RTM methods for monitoring Carbon Leaks using the seismic data. The FWI results demonstrate a good detection of the leakage areas that were clearer in the VSP survey than the others. Also, the performance of the FWI method was checked for different sizes of Carbon leaks. The results show the high capability of FWI as a solution to this problem. Besides, the RTM results show the high potential of the z-component of seismic data outperformed in showing the borders of the CO2 leakage. This point is more visible in the VSP results than in others. On the other side, the x-component of seismic data in the RTM results shows that it can demonstrate lateral reflectors better.
Subsurface CCUS Monitoring & Surveillance: Insights on CO2 Resistivity Measurements
Authors: Al-Qasim Abdulaziz , Al-Tayyib Deena , Katterbauer Klemens 
Published: February 2023

AbstractThe topic of carbon dioxide (CO2) enhanced oil recovery (EOR) has received increased attention since five decades for two main applications:Improvement of oil recovery in reservoirs, using miscible CO2 injection as tertiary oil recovery technique. Carbon dioxide can be injected into the reservoir using different injection strategies: injected by itself, simultaneously injected with water or as water-alternating-gas (WAG) mode. CO2 can be found in different phase states: liquid, gas or supercritical, depending on the reservoir conditions (pressure/temperature). CO2 sequestration (geologic storage) as a way to reduce CO2 emission. The realization of the CO2 sequestration into reservoir requires that long term stability of the reservoir seal is ensured.It is considered that measuring electric resistivity is useful to monitor CO2 migration in the reservoir. Resistivity shows a high sensitivity to fluids saturation in reservoirs. Therefore, it is considered that deep electromagnetic technologies (e.g., crosswell EM) can also be useful as a surveillance method in case of CO2 injection. The variation of resistivity due to CO2 injection into a carbonate reservoir is not thoroughly studied, especially in a mixed salinity environment. Thus, the study presented in this paper provides a better understanding of the resisitivity responses in a mixed-salinity carbonate cores during drainange, imbibtion and CO2 injection processes, which may aid in CO2 montiroing.The study addresses the following objectives:Conduct the flooding tests on one carbonate core plug, varying the brine salinity. Conduct the CO2 injection at reservoir conditions. Measure resistivity of cores at different injection rates of CO2 into a carbonate plug, already partially saturated with brine and oil. Monitor a change in the overall resistivity of the rock while CO2 is being injected at different rates and also at a constant rate. Investigate the frequency effect on resistivity response while injecting fluids.