Halliburton Energy Services, Inc.

Bmic LLC

Xiangnan Ye

Dale E Jamison

Cato Russell McDaniel

Li Gao

Katerina V Newman

Narongsak Tonmukayakul

HsinChen Chung

B Raghava Reddy

Samuel Jason Lewis

Jay Paul Deville

Peter James Boul

Lee Jeremy Hall

Xueyu Pang

Vivek S Goel

Hsinchen Chung

Shih-Ruey Tom Chen

Sandeep D Kulkarni

Sharath Savari

Michael A McCabe

Kevin W Frederick

Chesnee Lae Davis

Aaron Gene Russell

Timothy Neal Harvey

Randy J Loeffler

Adam Dotson

Trissa Joseph

Jonathan Paul Walker

Yuntao Thomas Hu

Marek Kozikowski

Cato R Mcdaniel

Cato Russell Mcdaniel

Michael A Mccabe

Kevin Walter Frederick

Randy Jack Loeffler

Michael Thomas Pelletier

Rajesh Kumar Saini

William Walter Shumway

James William Ogle

Dipti Singh

Jeremy A Holtsclaw

Andrew David Vos

Denis Muki Tibah

Sorin Gabriel Teodorescu

Robert Lynn Williams

Kenneth William Pober

Jason Maxey

Ramil Marcelo L Mercado

Lucas Kurtis Fontenelle

Jarod L Krajca

Eli Allen Schnoor

Pinmanee Boontheung

Lalit N Mahajan

Lisa Brzezinski

Timothy N Harvey

Adam R Dotson

Polymer modified asphalt compositions for roofing applications and related systems and methods are provided. A polymer modified asphalt composition comprises at least 80% by weight of an asphalt based on a total weight of the polymer modified asphalt composition, a polyolefin having a number average molecular weight of at least 25 kDa, and an ethylene vinyl acetate copolymer.

Polymer modified asphalt compositions and related methods

Characterizing the decay of the microstructure of a drilling fluid gel using a model based on two exponential functions. Based on the model, identify at least two components of the decay model comprising a fast decay component and a slow decay component, wherein the fast decay component decays more quickly than the slow decay component. The decay of the microstructure of the gel over a time period can be determined using a rheometer or viscometer. Wellbore processes, including start up and tripping operations can be optimized based on the determination of the fast decay component and/or a slow decay component of the drilling fluid gel.

Fragile and normal viscoelastic components of drilling fluid gels

Systems and methods to determine a characteristic of a drilling fluid are presented. A method to determine a characteristic of a drilling fluid includes obtaining a measurement of a mud density of a drilling fluid formed from a mixture of a plurality of components. The method also includes obtaining a measurement of a thermal conductivity of the drilling fluid and determining an error function of a calculation of characteristics of the drilling fluid, where the error function is indicative of a threshold difference between the calculation of the characteristics of the drilling fluid and the characteristics of the drilling fluid obtained from retort data of a fluid distillation process. The method further includes determining, based on the error function, an oil water ratio of the drilling fluid and an average specific gravity of the drilling fluid.

Systems and methods to determine a characteristic of a drilling fluid

The present disclosure relates to downhole fluid additives including a clay, a hydroxylated polymer, a cation, and water. The disclosure further relates to downhole fluids, including drilling fluids, spaces, cements, and proppant delivery fluids containing such as downhole fluid additive and methods of using such fluids. The downhole fluid additive may have any of a variety of functions in the downhole fluid and may confer any of a variety of properties upon it, such as salt tolerance or desired viscosities even at high downhole temperatures.

Downhole fluids and methods of use thereof

Fiber additives that may be useful as lost circulation materials for mitigating fluid loss and/or as bridging agents or diverting agents in subterranean treatment fluids such as drilling fluids. In some embodiments, the fiber additives include a fiber and calcium carbonate disposed on at least a portion of the outer surface of the fiber. In some embodiments, the methods include providing a treatment fluid that includes the base fluid and the fiber additives, and introducing the treatment fluid into at least a portion of a subterranean formation.

Calcium carbonate / fiber additives for use in subterranean operations

A method of treating a wellbore in a subterranean formation including introducing a first fluid into a formation, wherein the first fluid comprises: a first water soluble salt and a carrier; placing a second fluid into the formation, wherein the second fluid comprises: a second water soluble salt and a carrier, wherein the first fluid and second fluid produce a solid precipitate upon contact; and allowing the solid precipitate to form in-situ in the formation. An acid may be added to the wellbore after formation of the precipitate. The method may be also used for stabilizing a wellbore during drilling, and shutting off and reopening a region in a formation.

Consolidation and wellbore strength enhancement with CaCOprecipitation

Methods including precipitated and mined calcium carbonate lost circulation materials for use in subterranean formation operations. The precipitated calcium carbonate lost circulation materials are formed under a chosen set of precipitation conditions, including in situ in a subterranean formation. The mined calcium carbonate lost circulation materials are obtained in a desired morphological form under naturally occurring mined conditions. The precipitated and mined calcium carbonate lost circulation materials may be needle-shaped aragonite having an aspect ratio of about 1.4 to about 15.

Calcium carbonate lost circulation material morphologies for use in subterranean formation operations

Systems and methods are described herein. The method generally includes generating frequency responses of one or more sample fluids having known fluid properties, selecting an equivalent circuit model for modeling the frequency responses, the equivalent circuit model including one or more model elements, calculating an equivalent impedance of the equivalent circuit model, generating a correlation between the one or more model elements and the known fluid properties, measuring an impedance of a drilling fluid, and determining at least one property of the drilling fluid based on the correlation between the one or more model elements and the known fluid properties.

Application of electrochemical impedance spectroscopy in drilling fluid composition measurements

Systems and methods for determining the composition of a drilling fluid using electro-rheology.

Analyzing average specific gravity of solids in drilling fluids

The disclosure presents a technique for predicting the composition of a borehole mud using a thermal conductivity parameter of the mud and a dilution liquid. The mud can be altered by conditions within the borehole, such as material, fluid, and temperature affecting the original mud composition pumped into the borehole location. The mud can be an oil-based, water-based, or another type of mud of a well system. The technique can extract a measured quantity of mud and place it into a mud container. A first thermal conductivity parameter can be calculated for the extracted mud. A dilution liquid can be mixed into the extracted mud in the mud container and a second thermal conductivity parameter calculation can be performed. From the calculated first and second thermal conductivity parameters, the composition of the mud, as well as the fractional proportions of the major components of the mud, can be predicted and computed.

Determining borehole mud composition

Drilling fluid can be monitored throughout a drill site and at various stages of drilling operations. The drilling fluid may be analyzed to identify components that make the drilling fluid as well as the volume of each of the components, The volume of each component can be used, for example, to determine a percentage of water in a water-based drilling fluid and the average specific gravity of the water-based drilling fluid without further decomposition of the drilling fluid. The percentage of water and the average specific gravity can then be used to modify the drilling fluid, in real-time, based on conditions in the wellbore.

Dynamic formulation of water-based drilling fluids

Compressed lost circulation materials for use in subterranean formations are provided. In some embodiments, the methods include: introducing a treatment fluid that includes a base fluid and a compressed lost circulation material into a wellbore penetrating at least a portion of a subterranean formation including a loss zone, the compressed lost circulation material including a binding material and a compressed material; allowing the binding material to at least partially degrade or dissolve; and allowing the compressed lost circulation material to at least partially expand in the subterranean formation.

Compressed lost circulation materials

Insulating fluids for use in drilling, production, and other applications are provided, the insulating fluids containing a porous medium (such as a sponge or foam) to limit the mobility of the liquid phase of the insulating fluid. The porous medium in the insulating fluid provides a mechanical means for reducing convective heat transfer, as the small pore spaces within the porous media create tortuous paths for the liquid moving therethrough. Methods include introducing the insulating fluid into an annulus of a drilling, riser, production, packer, or pipeline assembly to reduce heat transfer therethrough.

Insulating fluids containing porous media

Systems and methods for this disclosure describe systems and methods that are directed to monitoring active clay in water-based drilling fluid may be provided. A method for monitoring active clay concentration while drilling may be provided. The method may include providing a sample of water-based drilling fluid. The method may further include adding methylene blue to the sample in a methylene blue titration. The method may further include performing an impedance measurement on the sample during the methylene blue titration. The method may further include determining an endpoint of the methylene blue titration using a phase angle measurement from the impedance measurement. The method may further include correlating the endpoint to the active clay concentration of the sample. The method may further include determining a treatment for the water-based drilling fluid based on the active clay concentration.

Real-time monitor and control of active clay in water-based drilling fluids

Systems and methods for measurement of the oil content in oil-based drilling may be provided in accordance with embodiments of the present disclosure. A method for measuring oil content of an oil-based drilling fluid may include providing a sample of the oil-based drilling fluid. The method may further include performing electro impedance spectroscopy on the sample by a process that comprises applying an alternating electric current to the sample and measuring a response of sample to obtain electro impedance spectroscopy measurements. The method may further include determining an estimate of the oil content of the sample based, at least partially on the electro impedance spectroscopy measurements.

Measuring the oil content in oil-based drilling fluids

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Cypress, TX, United States of America

Xiangnan Ye