Saudi Arabian Oil Company

Zuhair AlYousif

Subhash Chandrabose Ayirala

Muhammad Majid Almajid

Ali Abdullah Al-Taq

Abdulaziz S Al-Qasim

Mustafa Alkhowaildi

Deena Tayyib

Hana AlMatouq

Ali Abdallah Al-Yousef

Sunil Kokal

Moataz Abu AlSaud

Hamoud Alqahtani

Afnan Mashat

Abdulkarem Algadrah

Mohammed Alabbad

Mustafa Alsaffar

Othman Alswaie

Amin Alabdulwahab

Abdulaziz AlQasim

Described is a method for enhanced carbon dioxide (CO) sequestration in geological formations. The method includes dissolving COin a low salinity fluid to form a CO-brine solution. The low salinity fluid includes sodium (Na) ions and sulfate (SO) ions. The CO-brine solution is injected into a geological formation, and the COreacts with the geological formation to produce solid carbonate minerals for COsequestration.

Method for enhanced storage of carbon dioxide in geological formations

A method for sealing a high permeability region in a reservoir is provided. The method includes injecting a gel precursor solution into a high permeability region in a reservoir, injecting a sodium nitrite solution proximate to the high permeability region, and injecting an ammonium chloride solution proximate to the high permeability region. The ammonium chloride solution and the sodium nitrite solution are mixed proximate to the high permeability region. The ammonium chloride solution and the sodium nitrite solution are allowed to react, increasing the temperature of the reservoir proximate to the high permeability region. The gel precursor solution is allowed to react to form a solid gel in the high permeability region.

Gel formation from reaction heating

Methods and systems for producing oil from a subsurface reservoir include drilling a horizontal production well into the subsurface reservoir and drilling a horizontal injection well into the subsurface reservoir below the horizontal production well. Carbon dioxide and a second gas are mixed to form a gas mixture with a density more than a density of reservoir fluids between the horizontal production well and the horizontal injection well. The gas mixture is injected into the subsurface formation through the horizontal injection well and fluid is produced from the subsurface reservoir through the horizontal production well.

Sweep efficiency of carbon dioxide gas injection

An aqueous wellbore fluid may include a surface active agent package in an amount ranging from 1 to 20 gpt, a thickener in an amount ranging from 0.01 to 0.3 wt. %, and an aqueous base fluid. The surface active agent package may include an &#x3b1;-olefin sulfonate, a terpenoid, and isopropyl alcohol. The thickener may include a biopolymer.

Enhancing foam rheological properties using water-soluble thickener

A foam for hydrocarbon recovery includes a gas phase and a liquid phase. The liquid phase includes a foaming mixture, and the foaming mixture includes an aqueous solution, one or more surfactants, and an oil mixture. At least 2 wt. % of the liquid phase includes the oil mixture. Also described are methods of recovering hydrocarbons from a deposit reservoir using such a foam, as well as a hydrocarbon well including such a foam.

Foams for hydrocarbon recovery, wells including such, and methods for use of such

Foaming fluid composition and methods for enhanced oil recovery are provided with enhanced foaming properties. The foaming composition may include a surfactant andoil whereoil may be included in an amount ranging from 20 to 75 vol % in respect to the total volume of the surfactant and theoil. Methods of enhancing recovery of oil from an oil containing formation are also provided. Methods may include injecting a foaming composition into the oil containing formation, where the foaming composition may include a surfactant andoil. Methods may also include the foaming composition that includesoil in an amount ranging from 20 to 75 vol % in respect to the total volume of the surfactant and theoil.

Enhancing foam stability using allium sativum oil

A method for enhanced oil recovery from a hydrocarbon bearing subterranean formation includes withdrawing hydrocarbons from a production well extending into the formation, identifying a high permeability streak in the formation, and injecting a dense COcomposition from an injection well into the high permeability streak. The dense COcomposition includes dense COand a thickener soluble in the dense CO. The thickener includes copolymer. The method includes, after injecting the dense carbon dioxide composition into the high permeability streak, injecting an aqueous treatment fluid into the formation. The dense COcomposition blocks the high permeability streak to divert at least a portion of the aqueous treatment fluid into bypassed regions of the formation during the injecting of the aqueous treatment fluid, and the injecting of the aqueous treatment fluid into the hydrocarbon bearing subterranean formation drives hydrocarbons in the hydrocarbon bearing subterranean formation towards the production well.

Methods of enhanced oil recovery using dense carbon dioxide compositions

A method for increasing CO2 sequestration efficiency in depleted reservoirs by increasing injectivity is provided. This method includes the steps of introducing a surfactant solution into an upper portion of the reservoir through an injection well and introducing CO2 to a lower portion through another injection well such that the CO2 and surfactant solution migrate away from the wells and intimately intermingle to form CO2-based foam in situ. The surfactant solution and CO2 may also be introduced through the same injection well, where the surfactant solution is introduced to an upper portion of the reservoir and the CO2 is introduced into a lower portion. The pressure may be maintained at a value less than the fracture pressure of the reservoir utilizing a pressure relief well.

Methodology to increase CO2 sequestration efficiency in reservoirs

A method for reducing water production from a hydrocarbon bearing subterranean formation includes identifying a high permeability zone in the formation and injecting a dense COcomposition from a production well into the high permeability zone. The dense COcomposition includes dense COand a thickener soluble in the dense CO. The thickener includes a copolymer that is the polymerized reaction product of monomers that include at least one alkenyl ether or dialkenyl ether monomer, at least one acrylate or methacrylate monomer, at least one structural monomer, and at least one allyl ester monomer. After injecting the dense COcomposition into the high permeability zone, the method includes withdrawing hydrocarbons from the hydrocarbon bearing subterranean formation through the production well. The dense COcomposition blocks pores in the high permeability zone to reduce or prevent flow of water from the high permeability zone into the production well.

Methods of controlling water production from hydrocarbon bearing subterranean formations using dense carbon dioxide compositions

A surfactant foam for enhanced oil recovery (EOR) gas injection that includes a surfactant andgel. The surfactant may be a methanol surface active agent foamer. The surfactant foam may be generated in-situ from an injected gas (such as air or nitrogen), water (such as seawater), a surfactant, andgel. A process for enhancing oil recovery in a hydrocarbon reservoir using the surfactant foam and for manufacturing the foam are also provided.

Enhancing rheological properties of foam using aloe-barbadensis gel

A method of remediation of a water-bearing formation is disclosed. A first solution containing a nitrogen-containing compound and a second solution containing a nitrite-containing compound are introduced into the water-bearing formation. The two solutions intermix within the formation such that a foam is generated within the formation.

Method for improving aquifer remediation using in-situ generated nitrogen foam

Treatment fluids of the present disclosure may comprise an aqueous base fluid and a surfactant composition. The surfactant composition may comprise a sulfonate surfactant in an amount of from 0.01 wt. % to 2 wt. % based on the total weight of the treatment fluid composition, a plant-based oil in an amount of from 0.01 wt. % to 2 wt. % based on the total weight of the treatment fluid composition, and a zwitterionic co-surfactant in an amount of from 0.01 wt. % to 2 wt. % based on the total weight of the treatment fluid composition. The plant-based oil may comprise from 65 mol. % to 85 mol. % species comprising one or more gondoic acid moieties. Methods for recovering hydrocarbons from a subterranean formation with the treatment fluid are also disclosed.

Treatment fluids and methods for recovering hydrocarbons from a subterranean formation

A method for treating a hydrocarbon-containing formation includes injecting an aqueous solution that contains an alkali nitrite, an ammonium halide, and a foaming agent into the formation, injecting supercritical carbon dioxide into the formation, allowing a portion of the carbon dioxide to dissolve in the aqueous solutions, causing the alkali nitrite and ammonium halide to react and generate nitrogen gas, and allowing a foam to form by the interaction of the nitrogen gas with the foaming agent.

Method for modifying well injection profile and enhanced oil recovery

The application discloses foam compositions, methods to produce foam compositions, and methods to increase hydrocarbon production by displacing a hydrocarbon product with a foam composition. The foam composition includes an aqueous phase that typically includes an amphoteric surfactant and inorganic ions.

Stabilized foams with tailored water chemistry for mobility control in gas injection processes

A method for improving oil recovery within a subterranean formation that includes forming a barrier within the formation to isolate at least a portion of a first region from a proximate second region. The barrier is formed by introducing a first solution including an ammonium containing compound and a second solution including a nitrite containing compound into the formation. The first solution, the second solution, or both, further include a foaming agent. The compounds react to generate nitrogen gas in the presence of the foaming agent to generate a foam within a first region. The foam provides the barrier. Water is introduced into the formation. The barrier diverts the water away from the first region and into the second region. The water operates to displace at least a portion of a hydrocarbon present in the second region and discharge the hydrocarbon from the formation.

Growing community of inventors

Saihat, Saudi Arabia

Zuhair AlYousif