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公开(公告)号：US12259517B2
公开(公告)日：2025-03-25
申请号：US18717453
申请日：2022-05-20
Inventor： Gong Li Wang , Wael Abdallah , Shouxiang Ma , Sherif Ghadiry
Abstract: Methods and systems are provided for characterizing connate water salinity and resistivity of a subsurface formation. Well log data including resistivity and spontaneous potential (SP) log data are measured by at least one downhole tool disposed within a borehole. The resistivity and SP log data are inverted to determine a resistivity model and an SP model, which are used to determine connate water resistivity. The connate water resistivity is used to determine connate water salinity. The connate water salinity derived from the inversion of resistivity log data and SP log data (or derived from a trained ML system supplied with such log data) can be used as a baseline measure of connate water salinity, and this baseline measure can be evaluated together with the connate water salinity estimates derived from pulsed neutron tool measurements over time-lapsed periods of production to monitor variation in connate water salinity due to production.
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2.发明申请公开(公告)号：US20250076221A1
公开(公告)日：2025-03-06
申请号：US18457717
申请日：2023-08-29
IPC: G01N23/046 , G01N1/40 , G01N23/083 , G01N33/24 , G06F30/20
Abstract: Systems and methods are described for correcting ambient condition capillary pressure curves. In an example, the capillary pressure curve of a porous medium can be measured in non-reservoir conditions. Samples of the porous medium can be scanned at various confining pressures, and digital models of the scans can be created by a computing device. The computing device can simulate a porous plate experiment on the digital models to create a capillary pressure curve for each model. The computing device can calculate fitting equations for each capillary pressure curve according to capillary pressure points. The fitting equations can be averaged together and applied to the capillary pressure curve of the porous medium to correct for the non-reservoir conditions.
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3.发明公开公开(公告)号：US20240201414A1
公开(公告)日：2024-06-20
申请号：US18553628
申请日：2021-04-28
Inventor： Ping Zhang , Gong Li Wang , Wael Abdallah , Dean Homan , Shouxiang Ma
CPC classification number: G01V3/38 , E21B44/00 , E21B49/00 , G01V3/30 , E21B2200/20
Abstract: A method for characterizing a subterranean formation is provided that involves obtaining resistivity log data measured by a logging-while-drilling electromagnetic tool operated while drilling a wellbore that traverses the subterranean formation, and calculating at least one of a first data value representing water saturation of the subterranean formation and a second data value representing cation exchange capacity (CEC) of the subterranean formation from the resistivity log data. In embodiments, the method can further involve storing at least one of the first data value and the second data value in computer memory, and/or outputting at least one of the first data value and the second data value as part of a log for well placement, formation evaluation. geological modeling, or reservoir management. The first data value and/or the second data value can also be used for geo-steering the drilling of the wellbore.
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公开(公告)号：US11892581B2
公开(公告)日：2024-02-06
申请号：US16984210
申请日：2020-08-04
Inventor： Ping Zhang , Wael Abdallah , Shouxiang Ma , Chengbing Liu
CPC classification number: G01V1/306 , E21B49/005 , E21B49/0875 , G06N20/00
Abstract: Methods and systems are provided that determine or estimate total clay volume fraction in a formation for well log data of the formation using machine learning are described. Methods and systems are also provided that employ computation models to determine amounts or concentrations of at least one clay mineral in the formation from total clay volume fraction of the formation.
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公开(公告)号：US11796710B2
公开(公告)日：2023-10-24
申请号：US16940479
申请日：2020-07-28
Inventor： Ping Zhang , Shouxiang Ma , Wael Abdallah , Chengbing Liu
CPC classification number: G01V3/38 , E21B49/00 , E21B49/0875 , G01N27/221 , G01N33/18 , G01N33/24 , G01V3/28
Abstract: Methods and systems are provided for characterizing formation water salinity of subsurface formation using multifrequency permittivity data over a range of frequencies below 1 MHz. The multifrequency permittivity data is processed to determine salinity of formation water contained in the subsurface formation. Other useful formation properties (such as formation water saturation) can be determined based on the formation water salinity.
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Patent Agency Ranking
公开(公告)号：US11280191B2
公开(公告)日：2022-03-22
申请号：US14373019
申请日：2013-01-17
Applicant: Schlumberger Technology Corporation
Inventor： Youxiang Zuo , Oliver C. Mullins , Francois Xavier Dubost , Cosan Ayan , Wael Abdallah , Andrew E. Pomerantz , Dingan Zhang
Abstract: A methodology that performs fluid sampling within a wellbore traversing a reservoir and fluid analysis on the fluid sample(s) to determine properties (including asphaltene concentration) of the fluid sample(s). At least one model is used to predict asphaltene concentration as a function of location in the reservoir. The predicted asphaltene concentrations are compared with corresponding concentrations measured by the fluid analysis to identify if the asphaltene of the fluid sample(s) corresponds to a particular asphaltene type (e.g., asphaltene clusters common in heavy oil). If so, a viscosity model is used to derive viscosity of the reservoir fluids as a function of location in the reservoir. The viscosity model allows for gradients in the viscosity of the reservoir fluids as a function of depth. The results of the viscosity model (and/or parts thereof) can be used in reservoir understanding workflows and in reservoir simulation.
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7.发明授权公开(公告)号：US11237292B2
公开(公告)日：2022-02-01
申请号：US16663636
申请日：2019-10-25
Inventor： Shouxiang Ma , Ping Zhang , Wael Abdallah , Chengbing Liu
Abstract: Methods and systems are provided for clay detection, clay typing, and clay volume quantification using downhole electromagnetic measurements conducted by a downhole logging tool on a formation at a low frequency less than 5000 Hz. The downhole electromagnetic measurements are used to determine permittivity data that characterizes permittivity of the formation at the low frequency less than 5000 Hz. The downhole low frequency electromagnetic measurements are nondestructive, and the results indicate it is with high sensitivity to the existence of clays.
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8.发明授权Measurement of surface energy components and wettability of reservoir rock utilizing atomic force microscopy 有权利用原子力显微镜测量储层岩石的表面能量成分和润湿性公开(公告)号：US09110094B2
公开(公告)日：2015-08-18
申请号：US14158359
申请日：2014-01-17
Applicant: SCHLUMBERGER TECHNOLOGY CORPORATION , SAUDI ARAMCO
Inventor： Ahmed Gmira , Wael Abdallah , Mikhail Stukan , Johannes J. M. Buiting
CPC classification number: G01Q60/38 , G01Q30/04 , G01Q30/14 , G01Q60/24 , G01Q60/28 , G01Q70/02 , G01Q70/08 , G01Q70/14 , G01Q70/16
Abstract: An instrument (and corresponding method) performs AFM techniques to characterize properties of a sample of reservoir rock. The AFM instrument is configured to have a probe with a tip realized from reservoir rock that corresponds to the reservoir rock of the sample. The AFM instrument is operated to derive and store data representing adhesion forces between the tip and the sample at one or more scan locations in the presence of a number of different fluids disposed between the tip and the sample. The AFM instrument is further configured to perform computational operations that process the data representing the adhesion forces for a given scan location in order to characterize at least one property of the rock sample at the given scan location. The properties can include total surface energy of the rock sample as well as wettability of the rock sample.
Abstract translation: 仪器（和相应的方法）执行AFM技术来表征储层岩石样品的性质。 AFM仪器被配置为具有从储层岩石实现的具有对应于样品的储层岩石的尖端的探针。 操作AFM仪器以在存在位于尖端和样品之间的许多不同流体的情况下在一个或多个扫描位置导出和存储表示尖端和样品之间的粘附力的数据。 AFM仪器还被配置为执行计算操作，其处理表示给定扫描位置的粘附力的数据，以便表征给定扫描位置处的岩石样品的至少一个性质。 这些性质可以包括岩石样品的总表面能以及岩石样品的润湿性。
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公开(公告)号：US20240418623A1
公开(公告)日：2024-12-19
申请号：US18744264
申请日：2024-06-14
Applicant: Schlumberger Technology Corporation
Inventor： Jun Tao Ma , Lin Liang , Muyang Zhang , Mohammed Fadhel Al-Hamad , Marie Van Steene , Wael Abdallah , Shouxiang Mark Ma
IPC: G01N15/08 , E21B44/00 , E21B49/00 , G01N23/2251
Abstract: Process for determining rock permeability. In some embodiments, the process can include determining a volume-based aspect ratio distribution of pores in a rock sample from a digital image of the sample, grouping the volume-based aspect ratio distribution into two or more pore types, selecting an initial pore type from the two or more pore types, obtaining mercury injection capillary pressure (MICP) data of the sample, creating a volume forward model and a frequency forward model using the MICP data, deriving an initial volume-based pore size distribution and an initial frequency-based pore size distribution for the initial pore type using the volume and the frequency forward models, respectively, selecting either the initial volume-based or the initial frequency-based distribution based on the forward models, and optimizing the selected distribution using an inversion of the MICP data with combinations of two or more pore type distributions to create an optimized distribution.
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公开(公告)号：US20240301791A1
公开(公告)日：2024-09-12
申请号：US18596714
申请日：2024-03-06
Applicant: Schlumberger Technology Corporation
Inventor： Wael Abdallah , Nestor Herman Cuevas , Andrew J. Speck
CPC classification number: E21B49/087 , G01V3/26 , G01V3/30
Abstract: Systems and methods are described for locating hydrocarbons near a wellbore, determining petrochemical properties of a reservoir, and assessing hydrocarbon saturation between reservoirs. The nanoparticles can be positively charged and have properties that make them explode upon contacting crude oil. Sensors can be strategically placed near the wellbore to measure micro tremors caused by nanoparticle explosions. When the fluid is pumped into the wellbore, the fluid is forced into the surrounding rock formations. The fluid can contact crude oil in the rock formations, and the nanoparticles can attract to the fluid/oil interface due to negatively charged particles in the crude oil. When the nanoparticles reach the fluid/oil interface, they can contact the crude oil and explode. The seismic sensors can detect micro tremors caused by the nanoparticle explosions. The seismic sensor readings can be superimposed to identify the location of the crude oil and assess hydrocarbon saturation.
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