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Collaborating Authors
Perth Basin
Standalone museum focused on the Argentinian petroleum heritage. It offers educational program in indoor/outdoor exhibition spaces. The museum stands on the site of the first commercial oil well drilled in Argentina, the Pozo N 2 in 1907. The National University of Patagonia San Juan Bosco manages the museum since its opening in December 13, 1987. The collections of the museum consist mainly of donations from the YPF. Standalone museum mainly focused on the local petroleum exploration. It includes indoor/outdoor exhibition spaces.
- South America (1.00)
- Oceania > Australia (1.00)
- North America > United States > Texas (1.00)
- (6 more...)
- 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)
- (35 more...)
The Best Scenario for Geostatistical Modeling of Porosity in the Sarvak Reservoir in an Iranian Oil Field, Using Electrofacies, Seismic Facies, and Seismic Attributes
Mehdipour, Vali (Department of Petroleum Engineering, Amirkabir University of Technology) | Rabbani, Ahmad Reza (Department of Petroleum Engineering, Amirkabir University of Technology (Corresponding author)) | Kadkhodaie, Ali (Earth Sciences Department, Faculty of Natural Science, University of Tabriz)
Summary The lateral and vertical variations in porosity significantly impact the reservoir quality and the volumetric calculations in heterogeneous reservoirs. With a case study from Iranโs Zagros Basin Sarvak reservoir in the Dezful Embayment, this paper aims to demonstrate an efficient methodology for distributing porosity. Four facies models (based on electrofacies analysis data and seismic facies) with different geostatistical algorithms were used to examine the effect of different facies types on porosity propagation. Both deterministic and stochastic methods are adopted to check the impact of geostatistical algorithms on porosity modeling in the static model. A total of 40 scenarios were run and validated for porosity distribution through a blind test procedure to check the reliability of the models. The studyโs findings revealed high correlation values in the blind test data for all porosity realizations linked to seismic facies, ranging from 0.778 to 0.876. In addition, co-kriging to acoustic impedance (AI), as a secondary variable, increases the correlation coefficient in all related cases. Unlike deterministic algorithms, using stochastic methods reduces the uncertainty and causes the porosity model to have an identical histogram compared with the original data. This study introduced a comprehensive workflow for porosity distribution in the studied carbonate Sarvak reservoir, considering the electrofacies, and seismic facies, and applying different geostatistical algorithms. As a result, based on this workflow, simultaneously linking the porosity distribution to seismic facies, co-kriging to AI, and applying the sequential Gaussian simulation (SGS) algorithm result in the best spatial modeling of porosity.
- Europe (1.00)
- Asia > Middle East > Iran (1.00)
- North America > United States > Texas (0.67)
- Africa > Middle East > Egypt > Nile Delta (0.28)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.46)
- Phanerozoic > Mesozoic > Cretaceous > Lower Cretaceous (0.46)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.93)
- Geology > Sedimentary Geology (0.93)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.46)
- South America > Ecuador > Oriente Basin (0.99)
- South America > Ecuador > Napo > Oriente Basin > Napo Formation > Napo T Formation (0.99)
- Oceania > Australia > Western Australia > Perth Basin (0.99)
- (18 more...)
Understanding the synergistic impact of stress release and cementation on sandstone using sound waves โ Implications for exhumation estimation
Yu, Jiaxin (Norwegian University of Science and Technology) | Duffaut, Kenneth (Equinor) | Avseth, Per (Dig Science, Norwegian University of Science and Technology)
ABSTRACT Exhumation is the process that encompasses uplift and erosion, leading to the removal of overburden and the release of effective stress exerted on rocks. When estimating exhumation magnitude using the compaction trend method, it is commonly assumed that the physical properties of rocks are insensitive to stress reduction. However, recent laboratory evidence has indicated that porosity exhibits weaker sensitivity to stress release compared with velocity that can be significantly affected by stress release. This raises questions regarding the validity of irreversible compaction assumed by compaction trend method. It remains unclear whether the impact of stress release can be observed in real rocks in exhumed areas because there is a lack of methods to directly measure the impact of stress release on field data. In addition, studying real rocks is further complicated by the presence of rock diagenesis and its interaction with stress release. To address these knowledge gaps, this study uses stress-dependent burial and uplift modeling and interprets an extensive well-log data set using the modeling-derived evaluation metrics. Conceptual modeling suggests that methods that neglect the combined effect of cementation and stress release tend to underestimate the exhumation magnitude. Furthermore, we discover that the disparity between porosity sensitivity and velocity sensitivity to stress release can be leveraged to derive a metric we call โporosity inconsistencyโ that can serve as a qualitative and quantitative measure for identifying and evaluating stress release in sandstone using geophysical field measurements. We gather a significant amount of sonic velocity and porosity data from normally compacted and uplifted clean sandstones in the Norwegian Sea and the Barents Sea. Notably, we observe significant porosity inconsistency in the exhumed well 6510/2-1 in the Norwegian Sea. In the Barents Sea, which has experienced extensive Cenozoic exhumation, the well data reveal a varying pattern of porosity inconsistency increasing toward the north and decreasing toward the west. This distribution of porosity inconsistencies in the Barents Sea wells not only aligns with the spatial variation of exhumation reported in various studies but also exhibits a positive correlation with the magnitude of exhumation. Furthermore, the exhumation magnitude derived from velocity-depth trends is considerably lower than the magnitude obtained from porosity/density-depth trends for wells displaying significant porosity inconsistency. These observations provide support for the predictions made by the conceptual modeling. The results of this study enhance our understanding of the synergistic impact of stress release and cementation on sandstone. Moreover, these findings have implications for pore pressure prediction and core evaluation in exhumed areas. They also provide insights into the feasibility and interpretation of time-lapse data of reservoir injection, for which the effective stress is likely to decrease due to pore pressure buildup.
- Europe > Norway > Norwegian Sea (0.68)
- Europe > United Kingdom (0.68)
- Phanerozoic > Cenozoic (1.00)
- Phanerozoic > Mesozoic > Jurassic (0.93)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.48)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
- Geophysics > Borehole Geophysics (0.67)
- Oceania > Australia > Western Australia > Perth Basin (0.99)
- Oceania > Australia > Victoria > Otway Basin (0.99)
- Oceania > Australia > South Australia > Otway Basin (0.99)
- (12 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- (3 more...)
Feasibility Study and LCoE Analysis of Geothermal Energy Production from Depleted Oil Fields and Gas Prospects Onshore Sarawak, Malaysia
Bataee, Mahmood (Curtin University Malaysia) | Carter, Rick (Renewables Consulting Sarawak) | Hamdi, Zakaria (Heriot-Watt University) | Ridha, Syahrir (Universiti Teknologi Petronas)
Abstract Due to regulatorsโ determination to address climate change concerns and the necessity for a global CO2 emissions reduction, renewable energy sources are now seen as preferable options. Geothermal energy has a long history of successful deployment and is a proven, dependable, ongoing, sustainable, and adaptable source of renewable energy that has very low CO2 emissions over its project lifetime. However, there are always uncertainties associated with determining realistic ranges for values of the critical subsurface parameters such as geothermal gradients, aquifer size, transmissivity and geochemistry, when choosing an optimal location for geothermal energy extraction. This project focused on the Baram Basin located in the northern part of the state of Sarawak, Malaysia. Reservoir modelling was used to examine the viability of geothermal energy extraction utilizing publicly available analogue data. For both surface and downhole parameters, published data from existing active fields and recent exploration and appraisal efforts are used. In order to explore the economic feasibility for generating electricity from geothermal heat in this basin, various geothermal development scenarios were investigated both with and without injection wells using the reservoir simulation to determine net heat flow to the surface. The studyโs findings compare the productionโs enthalpy output estimations from simulations and examine how the LCoE is impacted by heat loss of produced fluids to surface. To investigate commercial competitiveness, different economic tools were run and sensitivity analysis was used to examine the major risk factors and indicate the expected thermal energy recovery ranges for profitable projects. The findings indicate that whilst there is significant geothermal potential in this basin, the challenges are to deploy reliable and cost-effective enabling technologies to deliver an economic return for investors.
- North America > United States (1.00)
- Asia > Malaysia > Sarawak > South China Sea (0.28)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.47)
- Oceania > Australia > Western Australia > Perth Basin > Carynginia Shale Formation (0.99)
- North America > United States > New Mexico > San Juan Basin > Basin Field (0.99)
- Asia > China > South China Sea > Vung May Basin (0.99)
The Hydrogen System in the Subsurface: Implications for Natural Hydrogen Exploration
Zhao, Hongwen (Hydrogen Department, PRSB, PETRONAS, Bangi, Malaysia) | Jones, Ernest A. (Hydrogen Department, PRSB, PETRONAS, Bangi, Malaysia) | Singh, Rajput Seemant (Hydrogen Department, PRSB, PETRONAS, Bangi, Malaysia) | Ismail, Hasnol Hady B. (Hydrogen Department, PRSB, PETRONAS, Bangi, Malaysia) | WahTan, Seng (Hydrogen Department, PRSB, PETRONAS, Bangi, Malaysia)
Abstract In the context of global efforts to achieve carbon neutrality, Hydrogen (H2) has emerged as a key solution for reducing greenhouse gases emission. However, current methods of hydrogen production, such as thermochemical and electrochemical processes like electrolysis, methane reforming and pyrolysis, are generally expensive and suffer from issues including intensive carbon dioxide emission and high electricity consumption etc. (Ishaq et al. 2022; Younas et al. 2022). In fact, hydrogen gas can naturally occur in the subsurface which has been manifested by numerous hydrogen seepages found across the world (cf. Zgonnik 2020 and the references therein). Notably, a significant discovery of natural hydrogen was made accidently during drilling a water well (Bougou-1) in Mali in 1987. Subsequent exploration in the vicinity of Bougou-1 confirmed the existence of an active hydrogen system in the area (Prinzhofer et al. 2018), highlighting the possibility of commercial hydrogen accumulation in the subsurface. Moreover, there is a growing consensus that natural hydrogen could be an important alternative for hydrogen production (Zgonnik 2020). In recent years, extensive exploration activities and scientific research focusing on natural hydrogen occurrences, generation mechanisms, and accumulation processes have been conducted, particularly, in Africa (Moretti et al. 2022; Prinzhofer et al. 2018), Australia (Boreham et al. 2021; Frery et al. 2021; Leila eta al. 2022; Rezaee, 2021), Europe (Combaudon et al. 2022; Larin et al. 2015; Lefeuvre et al. 2022; Leila et al. 2021), Brazil (Moretti et al. 2021; Prinzhofer et al. 2019), and the USA (Guรฉlard et al. 2017; Zgonnik et al. 2015). Geological investigations indicate that natural hydrogen is dominantly found on Precambrian cratons, ophiolite belts and mid-oceanic ridges (Rigollet and Prinzhofer, 2022). It occurs as gas leakages on the surface or is associated with other gases in the conventional and unconventional gas plays (Milkov 2022).
- Proterozoic (0.50)
- Archean (0.36)
- Geology > Structural Geology > Tectonics > Plate Tectonics (1.00)
- Geology > Rock Type > Igneous Rock (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- (2 more...)
- Oceania > Australia > Western Australia > Perth Basin > Carynginia Shale Formation (0.99)
- Asia > Malaysia > Kelantan > South China Sea > Gulf of Thailand > Malaysia-Thailand JDA > Block B-17 > Mali Field (0.97)
- Europe > Russia > Northwestern Federal District > Komi Republic > Timan-Pechora Basin > Pechora-Kolva Basin > Usa Field (0.89)
- Africa > Middle East (0.89)
Effects of Fracturing Fluids Imbibition on CBM Recovery: In Terms of Methane Desorption and Diffusion
Sun, Xiaoxiao (School of Energy Resource, China University of Geosciences, Beijing / Beijing Key Laboratory of Unconventional Natural Gas Geological Evaluation and Development Engineering, China University of Geosciences, Beijing) | Yao, Yanbin (School of Energy Resource, China University of Geosciences, Beijing / Frontiers Science Center for Deep-time Digital Earth, China University of Geosciences, Beijing (Corresponding author)) | Liu, Dameng (School of Energy Resource, China University of Geosciences, Beijing / Beijing Key Laboratory of Unconventional Natural Gas Geological Evaluation and Development Engineering, China University of Geosciences, Beijing) | Ma, Ruying (School of Energy Resource, China University of Geosciences, Beijing / Beijing Key Laboratory of Unconventional Natural Gas Geological Evaluation and Development Engineering, China University of Geosciences, Beijing) | Qiu, Yongkai (School of Energy Resource, China University of Geosciences, Beijing)
Summary Hydraulic fracturing technology has been widely used to improve the productivity of the coalbed methane (CBM) reservoir, during which tons of fracturing fluids infiltrate the coal seam. However, the effects of fracturing fluids imbibition on CBM recovery are still unclear. In this study, spontaneous and forced water imbibition experiments in methane-bearing low-volatile bituminous (LVB) coal were conducted at various gas adsorption equilibrium pressures, following which methane desorption and diffusion experiments were performed. These experiments simulated the complete process of fracturing fluid imbibition during well shut-in and subsequent methane production upon reopening, which is helpful in understanding the impact of fracturing fluid imbibition on CBM production. The results show that water imbibition displaces adsorbed methane in the coal matrix, and with reservoir pressure increasing, the displaced effect decreases. Furthermore, the forced imbibition (FI) displaces less methane than the spontaneous imbibition (SI) due to water rapidly filling fractures and blocking methane migration out of the matrix in the FI. In the initial stages of gas production following spontaneous or forced water imbibition, the displaced methane diffuses out of the coal at a rapid rate and then slows down. Furthermore, in the case of FI, a significant amount of residual gas remains after desorption and diffusion due to the water blocking effect. However, the water blocking effect has a minimal impact on coal undergoing SI. In terms of desorption and diffusion, this study provides a comprehensive understanding of the effects of fracturing fluids imbibition on recovery of CBM, which is useful for practical shut-in operations following hydraulic fracturing in LVB coal seams.
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.47)
- Oceania > Australia > Western Australia > Perth Basin (0.99)
- Asia > China > Qinshui Basin (0.99)
- Asia > China > Xinjiang Uyghur Autonomous Region > Junggar Basin (0.94)
- (3 more...)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Coal seam gas (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
A Feasibility Study of Geothermal Energy Extraction in the Baram Basin, Sarawak Using Numerical Reservoir Simulation Based on Analogue Data
Bataee, M. (Department of Chemical and Energy Engineering, Curtin University Malaysia, Miri, Sarawak, Malaysia) | Carter, R. (Renewables Consulting Sarawak, Miri, Sarawak, Malaysia) | Hamdi, Z. (School of Energy, Heriot-Watt University, Putrajaya, Wilayah Persekutuan, Malaysia) | Bennour, Z. (Department of Chemical and Energy Engineering, Curtin University Malaysia, Miri, Sarawak, Malaysia) | Mahmud, H. K. B. (Department of Chemical and Energy Engineering, Curtin University Malaysia, Miri, Sarawak, Malaysia)
Abstract Renewable energy sources are becoming favorable choices nowadays, due to Regulatorsโ desire to respond to the challenges of climate action and meet the need for global reduction of CO2. Geothermal energy is a recognized source of clean, low carbon renewable energy, however, selecting an optimized location for extracting this heat energy from the subsurface depends on many factors, and there are always risks involved with obtaining accurate and realistic values for the key parameters. In this project, the feasibility of geothermal energy extraction was studied using reservoir simulation, based on publicly available analogue data. The investigation focused on the Baram Basin, located in the state of Sarawak, Malaysia. Published data from existing fields and recent exploration and appraisal activities are used for estimating the likely range for both surface and subsurface parameters. Different geothermal development scenarios were run with and without injection wells to investigate the effect of formation pressure on sustainable water production. Results of this study indicate that optimum well spacing of 300m was predicted for maximum sustainable heat extraction. Results of the work compare the amount of enthalpy derived from production with estimates of Levelized Cost of Electricity. Simplified economics were run to explore commercial competitiveness. Sensitivity analysis has explored the key risk factors in this study and reveals the likely ranges for recoverable thermal energy for a profitable project. Geothermal energy sets an example for other energy providers by offering renewable baseload power, reducing emissions, enhancing energy independence, creating jobs, utilizing heat for various applications, and emphasizing long-term resource availability, inspiring greater sustainability, reliability, and environmental stewardship in energy generation practices.
- North America > United States (1.00)
- Asia > Malaysia > Sarawak (0.29)
- Energy > Renewable > Geothermal (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.46)
- Oceania > Australia > Western Australia > Perth Basin > Carynginia Shale Formation (0.99)
- Europe > Russia > Northwestern Federal District > Komi Republic > Timan-Pechora Basin > Pechora-Kolva Basin > Usa Field (0.89)
- Reservoir Description and Dynamics > Non-Traditional Resources > Geothermal resources (1.00)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)
- Health, Safety, Environment & Sustainability > Environment > Air emissions (1.00)
UNDERSTANDING THE SYNERGISTIC IMPACT OF STRESS RELEASE AND CEMENTATION ON SANDSTONE USING SOUND WAVES - IMPLICATIONS FOR EXHUMATION ESTIMATION
Yu, Jiaxin (Norwegian University of Science and Technology) | Duffaut, Kenneth (Equinor) | Avseth, Per (Dig Science, Norwegian University of Science and Technology)
Exhumation is the process that encompasses both uplift and erosion, leading to the removal of overburden and the release of effective stress exerted on rocks. When estimating exhumation magnitude using the compaction trend method, it is commonly assumed that the physical properties of rocks are insensitive to stress reduction. However, recent laboratory evidence has shown that porosity exhibits weaker sensitivity to stress release compared to velocity that can be significantly affected by stress release. This raises uncertainties regarding the assumption of irreversible compaction. It remains unclear whether the impact of stress release can be observed in real rocks in exhumed areas, as there is a lack of methods to directly measure the impact of stress release on field data. Additionally, studying real rocks is further complicated by the presence of rock diagenesis and its interaction with stress release. To address these knowledge gaps, this study employs stress-dependent burial and uplift modeling and interprets an extensive well log dataset using the modeling-derived evaluation metrics. We discover that the disparity between porosity sensitivity and velocity sensitivity to stress release can be leveraged to derive a metric porosity inconsistency which can serve as both a qualitative and quantitative measure for identifying and evaluating stress release in sandstone using geophysical field measurements. We have gathered a significant amount of sonic velocity and porosity data from normally compacted and uplifted clean sandstones in the Norwegian Sea and the Barents Sea. Notably, we observe significant porosity inconsistency in the exhumed well 6510/2-1 in the Norwegian Sea. In the Barents Sea, well data reveals a varying pattern of porosity inconsistency that not only aligns with the spatial variation of exhumation reported in various studies but also exhibits a positive correlation with the magnitude of exhumation. These observations provide support for the predictions made by the conceptual modeling.
- Europe > Norway > Norwegian Sea (0.68)
- Europe > United Kingdom (0.67)
- Phanerozoic > Cenozoic (0.93)
- Phanerozoic > Mesozoic > Jurassic (0.92)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.47)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.93)
- Geophysics > Borehole Geophysics (0.66)
- Oceania > Australia > Western Australia > Perth Basin (0.99)
- Oceania > Australia > Victoria > Otway Basin (0.99)
- Oceania > Australia > South Australia > Otway Basin (0.99)
- (13 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- (3 more...)
ABSTRACT Sand production prediction is essential from the early stages of field development planning for well completion design and later for production management. Unconsolidated and weakly consolidated sandstones are prone to fail at low flowing bottom hole pressures during hydrocarbon production. To predict the sand-free drawdown, a robust sand production prediction model that integrates near-wellbore and in-situ stresses, rock mechanical properties, well trajectory, reservoir pressure, production and depletion trends is required. Sanding prediction models should be calibrated with field data such as production and well tests observation. In the absence of field data, numerical techniques can provide a reliable estimate on potential onset and severity of sanding at various reservoir pressures. In this study, analytical and finite-element numerical models are independently used to predict the onset and extent of sanding in a high-rate gas well with poorly consolidated sandstone reservoir. The analytical method uses a poro-elastic model and core-calibrated log-derived rock strength profiles with an empirical effective rock strength factor (ESF). In the study, the ESF was calibrated against documented field sanding observation from a well test extended flow periods at the initial reservoir pressure at low drawdown pressure. This sanding model ESF was then verified against the sanding observation from another well test with higher drawdown pressure as well as with the sand-free production conditions from two producers that have been on line for several years. The numerical method uses a poro-elasto-plastic model defined from triaxial core tests. The rock failure criterion in the numerical method is based on a critical strain limit (CSL) corresponding to the failure of the inner wall of thick-walled cylinder core tests that can also satisfy the existing wells sanding observations in the production well tests. To validate the onset and severity of sanding predicted by the analytical model, numerical simulations for an identical sandstone interval were developed to investigate the corresponding CSL. Results showed the numerical model is also able to predict the onset of sanding observed during well tests with plastic strains exceeding the CSL defined from TWC test simulations. This combined analytical and numerical modelling calibrated with field data provided high confidence in the sanding evaluation and their application for future well completion and sand management decisions. The analytical model was finally used for sanding assessment over field life pressure condition because of its processing simplicity, speed and flexibility in assessing various pressure and rock strength scenarios with sensitivity analysis over the whole production interval in compared with the numerical method which is more suitable for single-depth and pressure condition modelling.
- North America > United States (0.93)
- Oceania > Australia > Western Australia (0.46)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.97)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
An Efficient and Straightforward Procedure for Rapid Investigation of Reservoir Compartmentalization by Fourier Transform Infrared Spectroscopy of Asphaltenes
Asemani, Morteza (Department of Geology, Faculty of Earth Sciences, Kharazmi University, Tehran, Iran (Corresponding author)) | Rabbani, Ahmad Reza (Department of Petroleum Engineering, AmiKabir University of Technology, Tehran, Iran) | Sarafdokht, Hashem (University of Science and Technology of Mazandaran (Behshar), Behshar, Iran (Corresponding author))
Summary Reservoir compartmentalization is an essential phenomenon in the different life cycles of oilfield production. This concept is crucial for the economic assessment of field development plans because it influences future decisions and designs. Hence, early and fast identification of reservoir compartmentalization is highly appreciated in the oil industry. The routine techniques based on the light-end fraction of crude oil [e.g., gas chromatography (GC) fingerprinting] are relatively time-consuming, high-cost, and sometimes affected by secondary processes. The suggestion of an efficient, straightforward, and rapid technique for obtaining the reservoir architecture, especially in giant and supergiant fields, is an acceptable attempt in the oil industry. Although the concentration of asphaltenes shows a gradient in the reservoir, the chemical composition of these compounds is constant in connected and equilibrated reservoirs. Hence, investigation of the chemical composition of asphaltenes with a precise method for revealing subtle differences comprises the underlying of every efficient method in reservoir continuity assessment. Here, the application of the relative root-mean-square deviation (RMSD) technique on the Fourier transform infrared (FTIR) data was used to compare the structural characteristics of asphaltenes in two case studies (i.e., Ahwaz and Shadegan oil fields) from the Dezful Embayment, southwest Iran. The 12 highest difference characteristic peak ratios were determined in the studied sample suit from the calculated variations in 5 replicates of a sample. The comparison between samples was performed based on these peak ratios, and the RMSD method was used to compare the studied samples. The samples with RMSD values higher than the defined threshold were considered samples with different fingerprints, and these wells will not be communicated during production. Results showed that the Ahwaz and Shadegan fields were subjected to reservoir compartmentalization in the Bangestan reservoir. At least three compartmentalized regions have occurred in the Bangestan reservoir of the Ahwaz field, and two distinct zones are observed in this reservoir from the Shadegan field. The pressure/volume/temperature (PVT) data (i.e., fluid property and composition) and repeat formation tester (RFT) measurements confirmed that these proposed regions in the Ahwaz field are distinct and will not be communicated during production. The FTIR results in the Shadegan field were completely corroborated by PVT and RFT results and indicated two distinct zones with no flow communication during production in the Bangestan reservoir. The obtained results showed that the suggested procedure is robust, trustworthy, simple, rapid, and cost-effective for investigating reservoir compartmentalization.
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (0.93)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.68)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.70)
- Oceania > Australia > Western Australia > Perth Basin (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 127 > Horn Mountain Field (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 126 > Horn Mountain Field (0.99)
- (25 more...)