Saudi Arabian Oil Company

King Fahd University of Petroleum and Minerals

Abdullah Saleh Al-Yami

Vikrant Bhavanishankar Wagle

Hussain Albahrani

Zainab Alsaihati

Ali Safran

Abdulaziz Ibrahim Alhelal

Khawlah A Alanqari

Ali Mohammed Alsafran

Nasser AlHareth

Sara Alkhalaf

Rajendra Arunkumar Kalgaonkar

Ali Al-Safran

Abdulla H Awadh

Abdullah Al-Awadh

Jothibasu Ramasamy

Saleh A Haidary

Abdulaziz A Ba Hamdan

Sara Abdulaziz Alkhalaf

Nasser Salem Alalhareth

Mohammed Murif Al-Rubaii

Antonio A Santagati

Mohammad Al-Alqam

Hussain Al-Bahrani

Salaheldin Elkatatny

Abdulwahab Aljohar

Abdulwahab S Al-Johar

Amjad O Shaarawi

Omprakash Pal

Pratyush Singh

Mohammad Alharthi

Nassar Al-Alhareth

Nassar Al-Hareth

Mohammad Abdullah Al-Harthi

Tushar Mukherjee

Ali BinAli

Ali Alqahtani

Naser AlHareth

Ali Al Safran

Abdulaziz Alhehal

Md Amanullah

Chinthaka Pasan Gooneratne

Abdullah M Al-Dhafeeri

Ali Radhwan

Abrar Alshaikh

Ahmad Mohammad Al-AbdulJabbar

Mohammad Aljubran

Mohammed Alsheikh

Carl Daniel Lindahl

Salem H Al Gharbi

Mahmoud Abughaban

Bader Ghazi Alharbi

Ahmad Saleh Al-Humaidi

Bader M Otaibi

Mohammed Ali Al-Malki

Maxim Orlov

Bandar Almalki

Odai A Elyas

Salem Alshammari

Abdulla Hussein Al-Awadh

Madina Baltaeva

Abdulla Al-awadh

Nassar Alhareth

Mohammad Alawami

Nasser Al-Alhareth

Abdulwahab Al-Joher

Ahmad A Omair

Husain A Buwaidi

Mohammed Alawami

Abdulla F Dossary

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

Microcapsule encapsulated microcapsule (MIM) material compositions and methods for preparing the same are provided for self-repairing cements that include a plurality of first microcapsules where each of the first microcapsule comprises a first core and a first shell and a plurality of second microcapsules that each comprise a second core and a second shell where the plurality of second microcapsules are dispersed within a continuous phase comprised within the first core of each of the first microcapsules. The MIM material may be prepared such that the first and second shell comprise a cross-linked material. Compositions for self-healing cement slurries are also provided and include cement, sand, water, and microcapsule encapsulated microcapsules (MIM) materials.

Self-repairing cement including microcapsule-in-microcapsule material and designed swellable rubber and methods for fabricating same

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

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 pipe section is disclosed. The pipe section includes a tubular body with a wall defining an interior flow path extending axially through the tubular body and a turbine assembly assembled to a first portion of the wall. The turbine assembly includes a link rod extending through the wall, from an interior of the tubular body to an exterior of the tubular body, an inner turbine mounted on the link rod in the interior of the tubular body, wherein the inner turbine is rotatable about the link rod, and an outer impeller mounted on the link rod at the exterior of the tubular body, wherein the outer impeller is rotatable about the link rod. The pipe section further includes a protective shield disposed around the outer impeller.

Hydraulically driven cement downhole mixing enhancer apparatus

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

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

A method may include obtaining, in real-time, well data regarding a wellbore and drilling fluid data regarding drilling fluid circulating in the wellbore. The method may further include determining, based on the drilling fluid data, a plastic viscosity (PV) value and a yield point (YP) value regarding the drilling fluid. The method may further include determining, based on the well data and the drilling fluid data, an equivalent circulating density (ECD) value of an annulus of the wellbore. The method may further include determining a hole cleaning efficiency (HCE) value based on a hole cleaning model, the PV value, the YP value, and the ECD value. The method may further include determining an adjusted rate of penetration (ROP) value for a drilling operation in the wellbore based on the HCE value and a current ROP value. The method may further include transmitting a command to a drilling system that produces the adjusted ROP value in the drilling operation.

Method and system for real-time hole cleaning using a graphical user interface and user selections

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

A method of automatic optimization of ROP. The method obtains a plurality of drilling surface parameters for a field of interest, and determines an UCS data and a MSE data for a targeted formation based on well logs. The method further trains a ML model using the drilling surface parameters as inputs, and outputs a plurality of weights for drilling parameters in a ROP equation and in a Teale's MSE equation for the field of interest. The method further combines the ML ROP equation with the Teale's MSE equation to determine a plurality of optimum drilling parameters by simultaneously solving the set of ML ROP equation and the Teale's MSE equation. Furthermore, the method generates a work order to adjust the drilling parameters and cause display of the work order and the determined optimum drilling parameters in a user interface of a client device.

Method and system for rate of penetration optimization using artificial intelligence techniques

A corrosion inhibiting cement composition for reducing corrosion of wellbore casings is disclosed that includes from 10 weight percent to 70 weight percent cement precursor, from 5 weight percent to 70 weight percent water, from 0.1% to 60% by weight of cement amine corrosion inhibitor, where the amine corrosion inhibitor comprises a polyethylene polyamine. A method for reducing corrosion of wellbore casings includes dispensing the corrosion inhibiting cement compositions into the annulus and allowing the corrosion inhibiting cement composition to cure to form a hardened cement, where the corrosion inhibiting cement composition includes a cement composition and the amine corrosion inhibitor.

Methods and cement compositions for reducing corrosion of wellbore casings

Lost circulation material (LCM) compositions may include a resin; an emulsifier selected from the group consisting of ethoxylated phenol, sodium salt of modified tall oil fatty amide, carboxylic acid terminated fatty polyamide, modified amidoamine, tall oil fatty acid, oxidized tall oil fatty amidoamine, ether carboxylic acid, and combinations thereof; a crosslinker, a cementitious and/or weighting agent; a retarder; a dispersant; and a silicon-based defoamer. The LCM compositions may have a thickening time of from about 3 hours than about 6 hours by reaching a Bearden consistency of 100 Bc. Methods of eliminating or reducing lost circulation in a lost circulation zone from a well may include introducing these LCM compositions into the well.

Loss circulation materials for high pressure formations

The present disclosure concerns a cement dispersant for cement compositions wherein the cement dispersant is a polynaphthalene sulfonate salt having a weight average molecular weight of from 2500 g/mol to 3000 g/mol. The cement compositions are of from 10 weight percent to 70 weight percent of a cement precursor based on the total weight of the cement composition, from 5 weight percent to 70 weight percent water based on the total weight of the cement composition, and from 0.001 percent by weight of cement (BWOC) to 1.0 percent BWOC the cement dispersant. The cement dispersant provides improved rheological properties, allowing for good cement dispensing and increased presence of weighting agents.

Polymer dispersant for well cementing

A method for cementing a wellbore having a lost circulation zone includes installing a cement basket around a casing string having a casing diameter, and running and setting the casing string in the wellbore. The cement basket is set in proximity of and up hole from the lost circulation zone. The method includes pumping a cement slurry, through the casing string, to a first depth downhole from the cement basket, running a first tubing, having a tubing diameter, into an annulus between the casing string and the wellbore, and pumping the cement slurry, through the first tubing, to a second depth up hole from the cement basket. The tubing diameter is less than the casing diameter.

Cement top job with non-retrievable tubing

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries have, among other attributes, an extended thickening time, leading to improved retardation, flowability, and pumpability and may be used, for instance, in the oil and gas drilling industry. The cement slurry includes water, microfine cement material, and bisphenol-F diglycidyl ether resin.

Cement slurries, cured cement and methods of making and use thereof

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Dhahran, Saudi Arabia

Abdullah Saleh Al-Yami