Saudi Arabian Oil Company

Dong Kyu Cha

Ali Abdallah Al-Yousef

Subhash Chandrabose Ayirala

Mohammed Badri Alotaibi

Mohammed Al Otaibi

Muhammad Majid Almajid

Mohammed Badri Al-Otaibi

Salah H Alsaleh

Mohammed Badri AlOtaibi

Ahmed Gmira

Zuhair AlYousef

Ming Han

Zuhair Al-Yousif

Sultan Muhammad Al Enezi

Sultan M Enezi

Subhash Ayirala

Abdulaziz S Al-Qasim

Hyung Tae Kwak

Hassan Sakar Alqahtani

Moataz Abu AlSaud

Ali Abdullah Al-Yousef

Atul Godbole

Ali AlYousef

Mohammed Abbad

Mohammed Badri AIOtaibi

Ali Abdullah Altaq

Tareq Ghamdi

Naif J Alqahtani

A method and system for labeling and identifying a sample, including a rock core sample, after determining a physical primary label has been compromised is provided. The method includes labeling the sample by placing a physical primary label on the sample or sample container, creating a first rollout image of the sample for a secondary label, and storing the first rollout image in a secondary label digital database with a sample identifier. The method continues for identifying the sample after determining the physical primary label has been compromised by creating a secondary rollout image of the sample and searching the secondary label digital database using the second rollout image to create a plurality of matching scores using a machine learning or deep learning image matching technique. The matching scores are then evaluated to determine an identify of a sample and the sample is re-labelled using a replacement primary label.

Sample labeling method using image-matching

Enhanced hydrocarbon recovery methods may utilize aqueous flooding. For example, such aqueous flooding methods may include: desalinating, at least partially, a first portion of a saline aqueous fluid through a reverse osmosis system to produce a desalinated aqueous fluid; mixing the desalinated aqueous fluid with a second portion of the saline aqueous fluid at a first ratio to produce an aqueous flooding fluid; and introducing the aqueous flooding fluid to a subterranean reservoir.

Advanced waterflooding methods for enhanced hydrocarbon recovery

Provided is a coreflood apparatus that comprises a housing, an inlet, an outlet, and two chambers positioned within the housing that are configured to retain porous media. The apparatus includes a partition coupled to an inner surface of the housing between the two chambers and a sensor mounting location. Provided is a method of introducing a fluid into the coreflood apparatus and allowing fluid to pass through chambers in the apparatus having a sensor mounting location there between. Further provided is a coreflood system comprising a coreflood apparatus, a calcium ion sensor, and a data processing device. Provided is a method of introducing fluid into the coreflood system and allowing fluid to pass through chambers in the system having a calcium ion sensor there between. The method further comprises detecting calcium ions in the fluid and determining calcium ion concentration data.

Dynamic in-situ measurement of calcium ion concentration in porous media experiments

Systems and methods for preparing a nanofluidic LCTEM cell are provided. An exemplary method includes coating a photoresist layer onto a top surface of a silicon nitride substrate; etching channels into the photoresist layer; depositing calcite into the etched channels; removing the photoresist; placing the cell on a holder; connecting a first end of an inlet line to the cell; connecting a second end of the inlet line to an ultrasound transducer configured to generate nanobubbles; and connecting an outlet line to the cell.

Fabrication of in situ HR-LCTEM nanofluidic cell for nanobubble interactions during EOR processes in carbonate rocks

A method for recovering hydrocarbons from a hydrocarbon bearing formation includes introducing a first solution having a first salt into the hydrocarbon bearing formation. A second solution is also introduced into the hydrocarbon bearing formation, wherein the second solution has a second salt and a foaming agent. The first salt and the second salt produces a nitrogen gas, and the nitrogen gas and the foaming agent produces a foam formed in-situ within the formation. The foam forms a foam barrier, and carbon dioxide is introduced into the formation to form a gas cap, wherein the carbon dioxide gas cap has a gas front that is separated from the hydrocarbons by the foam barrier.

Insitu foam generation to fasten and increase oil production rates in gravity drainage COgas injection

A method and a system for oil recovery are provided. An exemplary method includes injecting thickened carbon dioxide (CO) into the top of a reservoir containing oil. An interface is formed between the thickened COand the oil. The oil is mobilized by the thickened CO. The mobilized oil is recovered with a recovery well drilled below the reservoir.

Thickened COin gravity drainage gas injection processes

A method for enhancing productivity of a stratified subterranean wellbore includes introducing a mixture including water and a first set of nanoparticles reactive to high frequency acoustic waves having a size ranging from about 10 to 100 nm to a first target zone, located in a high permeability layer of the stratified subterranean wellbore. A first stimulation including acoustic waves having a frequency range of 1 kHz to 10 kHz is provided to the first set of nanoparticles to promote reacting. Then, a mixture including water and a second set of nanoparticles having a size ranging from about 1 to 10 nm is introduced to a second target zone, located in a medium permeability layer of the stratified subterranean wellbore. A second stimulation including acoustic waves having a frequency range of 100 Hz to 1 kHz is provided to the second set of nanoparticles to promote reacting.

Enhanced recovery method for stratified fractured reservoirs

Methods for fabricating a sensor module for detecting carbon dioxide leakage from a subsurface reservoir are disclosed. The methods include attaching anodic aluminum oxide porous membrane onto a first conductive electrode to form an anodic aluminum oxide template; initiating growth of a plurality of TiOnanotubes inside the AAO template using an atomic layer deposition process; removing the anodic aluminum oxide template from the first metal electrode leaving the plurality of TiOnanotubes on the first conductive electrode; attaching a second conductive electrode to the plurality of TiOnanotubes; connecting the first and the second conductive electrodes with an electric line to form a sensor; providing a rollable sheet of non-conductive material; and attaching a plurality of sensors to the rollable sheet of non-conductive material forming the sensor module.

Detecting carbon dioxide leakage in the field

A method of making a portion of a microfluidic channel includes lithographically patterning a first pattern into a first layer of photoresist disposed on a substrate, the first pattern representative of morphology of a reservoir rock; etching the first pattern into the substrate to form a patterned substrate; disposing a second layer of photoresist onto the patterned substrate; lithographically patterning a second pattern into the second layer of photoresist to reveal portions of the patterned substrate; and depositing calcite onto the exposed portions of the patterned substrate.

Calcite channel structures with heterogeneous wettability

A method to improve the efficiency of a gravity drainage CO2 gas injection process includes the steps of: (a) injecting a slug proximate to an underground reservoir, wherein the slug comprises a polymer component and an inorganic metal ion type crosslinking agent that are configured to form an in situ weak gel in the reservoir to block high permeability channels in a pay zone of the reservoir; and (b) continuously injecting COgas at a top of the pay zone to form a gas cap at the top of the reservoir and to cause the gas cap to advance rapidly towards a producing well located below to provide a uniform sweep of the gas cap.

Methodology to improve the efficiency of gravity drainage CO2 gas injection processes

A pressure cell for sum frequency generation spectroscopy includes: a metal pressure chamber; a heating stage that heats a liquid sample; an ultrasonic stage that emulsifies the liquid sample; a chamber pump that pressurizes an interior of the metal pressure chamber; and a controller that controls the chamber pump, the ultrasonic stage, and the heating stage to control a pressure of the interior of the metal pressure chamber, an emulsification of the liquid sample, and a temperature of the liquid sample, respectively. The metal pressure chamber includes: a liquid sample holder that retains the liquid sample; a removable lid that seals against a base; a window in the removable lid; a sample inlet that flows the liquid sample from an exterior of the metal pressure chamber to the liquid sample holder at a predetermined flow rate; and a sample outlet.

High temperature high pressure (HTHP) cell in sum frequency generation (SFG) spectroscopy for oil/brine interface analysis with reservoir conditions and dynamic compositions

A method includes flowing an inlet solution having an inlet salinity and an inlet ion concentration from an inlet to a membrane filtration system, dynamically adjusting the salinity or ion concentration of the inlet solution in situ as the inlet solution flows to an inlet of a microfluidic cell, and determining a wettability alteration in situ while dynamically adjusting the salinity or ion concentration of the inlet solution. A system includes a fluid inlet, a microfluidic cell fluidly coupled to the fluid inlet, the microfluidic cell having a surface representative of a reservoir rock, and a membrane filtration system coupled between the microfluidic cell and the fluid inlet.

In-situ salinity and ionic concentration control for calcite coated microfluidic cell

Provided is a coreflood system that comprises a housing including an inlet end and an outlet end, an inlet positioned at the inlet end, and an outlet positioned at the outlet end. The system includes two chambers positioned within the housing between the inlet and the outlet, configured to retain porous media. The two chambers are in series along a fluid flow pathway through the coreflood system. The system includes a partition extending from an inner surface of the housing between the inlet and the outlet, and a pH sensor provide in a sensor mounting location in the housing having access to the fluid flow pathway. Further provided is a method that comprises directing a fluid into a coreflood system, and using a data processing device coupled to the pH sensor to collect hydrogen ion data and determine hydrogen ion concentration and pH within the fluid.

PH monitoring in porous media during waterflooding experiments

A pressure cell includes a metal pressure chamber, a heating stage, disposed in the interior of the metal pressure chamber, that heats the liquid sample, a chamber pump, connected to the interior of the metal pressure chamber, that pressurizes the interior of the metal pressure chamber, a salinity control system including a membrane coupled to the sample inlet, where the membrane is configured to reduce a salinity level of the liquid sample, and a controller that controls the chamber pump, the salinity control system, and the heating stage to control a pressure of the interior of the metal pressure chamber, a salinity level of the liquid sample, and a temperature of the liquid sample, respectively. The metal pressure chamber includes a liquid sample holder, a removable lid, a window in the removable lid, a sample inlet, and a sample outlet.

High temperature high pressure (HTHP) cell in sum frequency generation (SFG) spectroscopy for oil/brine interface analysis with salinity control system

Described is a method for treating hydrocarbons in a reservoir. A foaming surfactant solution and a foaming gas are introduced into the upper portion of a reservoir such that barrier foam bubbles form. Then, super/critical carbon dioxide is introduced such that a CO2 cap forms. The CO2 cap is formed above a foam barrier of aggregated barrier foam bubbles positioned at an interface between hydrocarbons to be treated in the reservoir and the CO2 cap. The super/critical carbon dioxide is introduced into the reservoir at an injection rate that is greater than a pre-treatment critical gas injection rate. Hydrocarbons are recovered from a lower portion of the reservoir.

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Dhahran, Saudi Arabia

Dong Kyu Cha