Saudi Arabian Oil Company

Vikrant Bhavanishankar Wagle

Abdullah Saleh Al-Yami

Hussain Albahrani

Zainab Alsaihati

Rajendra Arunkumar Kalgaonkar

Abdulaziz Ibrahim Alhelal

Ali Safran

Ali Mohammed Alsafran

Khawlah A Alanqari

Nasser AlHareth

Abdullah Saleh Hussain Al-Yami

Ali Al-Safran

Jothibasu Ramasamy

Sara Alkhalaf

Abdulla H Awadh

Abdullah Al-Awadh

Saleh A Haidary

Sara Abdulaziz Alkhalaf

Omprakash Pal

Abdulaziz A Ba Hamdan

Ali Mohammed Hussain Al Safran

Abdullah AlYami

Antonio A Santagati

Nasser Salem Alalhareth

Mohammad Al-Alqam

Mohammad Alharthi

Ayman Mohammed Almohsin

Hussain Al-Bahrani

Abdullah Awadh

Md Amanullah

Jin Huang

Pratyush Singh

Nassar Al-Hareth

Mohammad Abdullah Al-Harthi

Tushar Mukherjee

Ali BinAli

Ali Alqahtani

Naser AlHareth

Ali Al Safran

Abdulaziz Alhehal

Nassar Al-Alhareth

Abdulwahab Aljohar

Abrar Alshaikh

Mohammad Aljubran

Mohammed Murif Al-Rubaii

Abdulaziz Salah Bubshait

Amjad O Shaarawi

Carl Daniel Lindahl

Mohammed Alsheikh

Faramak Almassi

Salem Alshammari

Abdulla Hussein Al-Awadh

Ziad Abdullrahman Saleh AlAbdullatif

Nassar Alhareth

Mohammad Alawami

Nasser Al-Alhareth

Abdulwahab Al-Joher

Ahmad A Omair

Husain A Buwaidi

Mohammed Alawami

Mohammad A Otaibi

Noktan Mohammed AlYami

Abdulla Al-awadh

Nasser Alhareth

Described is a method for quantifying and tracking an amine-based shale inhibitor in a drilling fluid through UV-visible spectroscopy. A correlation is determined between varying concentrations of an amine-based shale inhibitor in a water-based drilling fluid sample and an ultraviolet (UV)-visible absorption intensity. A calibration plot is generated based on the correlations. Samples of a circulating drilling fluid having an unknown concentration of amine-based shale inhibitor are obtained. Using the calibration plot, the concentration of amine-based shale inhibitor in the samples of the circulating drilling fluid is estimated.

Methods for quantifying and tracking amine-based shale inhibitors in drilling fluids

A composition of an invert emulsion oil-based drilling fluid formulation includes an invert emulsion of an oil phase and an aqueous phase. The oil phase includes an oleaginous fluid and a liquid viscosifier that is a polyhedral oligomeric silsesquioxane (POSS). A method includes introducing an invert emulsion oil-based drilling fluid formulation including an oil phase, an aqueous phase, and a liquid viscosifier including POSS downhole through the wellbore and maintaining wellbore conditions such that the invert emulsion oil-based drilling fluid formulation provides a stable rheological property including one or more of viscosity, yield point, plastic viscosity, gel strength, and electrical stability for a period up to about 96 hours.

Organoclay-free invert emulsion oil-based drilling fluids with polyhedral oligomeric silsesquioxane

An insulating fluid system includes an acidic nanosilica dispersion and an alkaline activator. The acidic nanosilica dispersion includes silica nanoparticles and a stabilizer, such as a carboxylic acid. The alkaline activator includes an alkanolamine, such as a monoalkanolamine. A mixture of the acidic nanosilica dispersion and the alkaline activator forms an insulating fluid having a pH greater than 7 and less than or equal to 12, and the insulating fluid forms an insulating gel when heated to a temperature in a range between 100° F. and 300° F. The insulating gel may be formed in an annulus between an inner conduit and an outer conduit. The inner and outer conduits may be positioned in a subterranean formation. Forming an insulating gel may include combining the acidic nanosilica dispersion with the alkaline activator to yield the insulating fluid, and heating the insulating fluid to form the insulating gel.

Insulating fluid for thermal insulation

Compositions may include a calcium lignosulfonate salt having a chemical structure (I), wherein a total number of syringyl groups is 2 to 10. The compositions may further include an alcohol, an aldehyde, and water. Cement slurries may include a lignosulfonate-based cement dispersant including a calcium lignosulfonate salt having a chemical structure (I), an alcohol, an aldehyde, and water, wherein a total number of syringyl groups in the chemical structure (I) is 2 to 10. The cement slurries may further include a cement and water. Methods may include introducing a cement slurry into a wellbore penetrating a subterranean formation, wherein the cement slurry comprises a lignosulfonate-based cement dispersant, a cement, and water, and allowing the cement slurry to set to a concrete in a downhole zone of interest.

Compositions and methods for branched calcium lignosulfonate cement dispersants

Methods for making and using an invert-emulsion drilling fluid, and the invert-emulsion drilling fluid are provided. An exemplary invert-emulsion drilling fluid includes a C-36 dimer diamine dihydrochloride salt (CDDH), an aqueous solvent, a non-aqueous solvent, an emulsifier, and calcium chloride.

C-36 dimer diamine hydrochloride salt as primary viscosifier for invert-emulsion drilling fluids

A method of reducing water production in a wellbore may include introducing an alkaline nanosilica dispersion to the wellbore such that it contacts a water producing zone of the wellbore, introducing a sodium bicarbonate activator to the wellbore such that it contacts the alkaline nanosilica dispersion in the water producing zone, and forming a gelled solid from the water shutoff material in the water producing zone, thereby reducing water production in the wellbore.

Methods to use water shutoff material composition comprising alkaline nanosilica dispersion and sodium bicarbonate in downhole conditions

A cement spacer fluid and a method for making and a method for using the cement spacer fluid are provided. The cement spacer fluid includes a polyethyleneimine hydrochloride (PEI HCl) salt, an aqueous solvent, a viscosifier, and a weighting agent.

Cement spacer fluid with polyethyleneimine hydrochloride salt as a shale inhibitor

A tool for use in a wellbore includes an annular body having an inner flow passage extending axially therethrough, at least one gripping member positioned around an outer perimeter of a retainer section of the annular body, and a gate member positioned in the inner flow passage. When the gate member is in a closed configuration, an upstream portion of the inner flow passage is sealed from a downstream portion of the inner flow passage by the gate member. When the gate member is in an open configuration, the upstream portion of the inner flow passage is fluidly connected to the downstream portion of the inner flow passage. At least one static mixing blade extends through the downstream portion of the inner flow passage to mix fluid when it flows through the open gate member.

Method and apparatus for downhole in-situ mixing using dual, concentric flow channels

A composition of an invert emulsion oil-based drilling fluid is provided. The composition may include an oil phase and an aqueous phase. The oil phase may include an oleaginous fluid, an organophilic clay-based solid viscosifier, and a liquid viscosifier including a POSS. Further provided is a method of introducing the composition including the POSS into a wellbore. After introduction of the composition into the wellbore, the method includes maintaining wellbore conditions to provide a stable rheological property for a period up to about 96 hours in an HPHT section of a wellbore.

Polyhedral oligomeric silsesquioxane as rheology booster for invert emulsion oil-based mud

A wellbore fluid composition is provided that includes an aqueous base fluid and at least one ethylene ammonium salt having a number average molecular weight in a range of 250 to 500 grams per mole. A method of drilling a wellbore is also provided. the method includes circulating an aqueous drilling fluid into the wellbore while drilling, wherein the aqueous drilling fluid includes at least one ethylene ammonium salt. The aqueous drilling fluid further includes a pH value from 6.5 to 7.5. The method of drilling a wellbore further includes recovering shale cuttings while maintaining wellbore stability.

Ethylene amine hydrochloride based shale inhibitor for aqueous drilling fluids

A method for mitigating loss circulation zones in a wellbore is provided. The method includes synthesizing a carbamate from an amine-curing agent, and the carbamate is mixed with an epoxy resin from the loss control composition. The loss control composition is pumped into a wellbore with a loss circulation zone, wherein the loss control composition flows into the loss circulation zone. The carbamate of the loss control composition is allowed to decompose at wellbore temperatures, wherein the carbamate releases COgas and the amine-curing agent. The COgas foams the epoxy resin, expanding the epoxy resin to fill voids in the loss circulation zone, and the amine-curing agent cures the foamed epoxy resin, forming a loss control material that seals the loss circulation zone.

Loss circulation material

Methods and compositions including introducing a lost circulation material to a zone of interest in a subterranean formation via a wellbore, the zone of interest comprising depleted zones, zones of low pressure, lost circulation zones, fractured zones, and any combination thereof; wherein the lost circulation material comprises an epoxidized linear α-olefin; a surfactant; a curing agent; and a carbon dioxide gas-generating compound comprising sodium bicarbonate; heating the lost circulation material; and allowing the epoxidized linear α-olefin to polymerize to a resin and the carbon dioxide gas-generating compound to produce a gas to form a foamed resin in the zone of interest, thereby mitigating a flow of fluids from the wellbore into the subterranean formation.

Methods and compositions for carbon dioxide-foamed lost circulation materials

This disclosure relates to a foamable resin composition containing a nitrogen gas-generating compound and methods of using the composition for loss circulation control.

Foamable resin composition for controlling loss circulation

Cement compositions of the present disclosure include a cement precursor, water, and a cement retarder that includes hydrocarboxylic acid derivatives. In particular, the cement compositions include from 10 wt. % to 70 wt. % cement precursor, from 5 wt. % to 70 wt. % water, and from 0.1 percent by weight of cement (BWOC) to 10 percent BWOC cement retarder comprising the hydrocarboxylic acid derivatives. The hydrocarboxylic acid derivatives provide increased thickening time to the cement compositions at downhole temperatures of greater than or equal to 50° C. The present disclosure further includes methods of cementing a wellbore using the cement compositions with the cement retarder comprising the hydrocarboxylic acid derivatives.

Hydrocarboxylic acid derivative as a retarder additive for oil and gas wells cementing

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Abqaiq, Saudi Arabia

Vikrant Bhavanishankar Wagle