Halliburton Energy Services, Inc.

General Electric Company

Betz Laboratories, Inc.

Chevron U.s.a. Inc.

Bl Technologies, Inc.

Cato Russell McDaniel

Dale E Jamison

William Walter Shumway

Xiangnan Ye

Timothy Neal Harvey

Katerina V Newman

Jay Paul Deville

Charles R Landis

Alan E Goliaszewski

Sharath Savari

David Birenbaum Engel

Eric Davidson

Edmund J Bockowski

Pubudu Gamage

William Wade Samec

Rui Shen

Karl Douglas Kuklenz

Kurt Jason Ginsel

Hui Zhou

Paul V Roling

Chesnee Lae Davis

Kenneth William Pober

Adam Dotson

Donald Curtis Van Slyke

Jonathan Paul Walker

Shawn Lynn Broussard

Steven P Sherwood

Truc K Nguyen

Songhua Chen

Carl Joseph Thaemlitz

Sandeep D Kulkarni

Lee Jeremy Hall

Catherine Martin Santos

J Michael Brown

Roberto Gutierrez

Nimeshkumar Kantilal Patel

Sherif Eldin

Dwight P Davis

Bruce E Wright

Magdalena Sandor

Jason Glen Bell

Patric L Friend

Maria Celeste Rellamas Tria

Anita Gantepla

Mary King

Harold James Eggert

Ramyakrishna Kothamasu

W John Delaney

Venkatesan Mani

Mohan Kr

Thomas K Brow

Frank Denison

Earl E Siders

Kevin S Solomon

Karl Kuklenz

Kurt Ginsel

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

Methods for resolving emulsions in a hydrocarbon stream by contacting the hydrocarbon stream with a demulsifying composition are disclosed. Demulsifying compositions for treating a hydrocarbon stream are also disclosed, wherein the demulsifying composition comprises at least one C4-C12 alkyl phenol-formaldehyde resin alkoxylate.

Demulsifying compositions and methods of use

Systems, methods and devices for analyzing a sample of fluid extracted from a hydrocarbon-producing geological formation to detect a quantitative amount of hydrogen sulfide or disclosed. The systems methods and devices involve including a scavenger within a sample compartment to react with the hydrogen sulfide therein. The concentration of hydrogen sulfide in the sample may be derived as a function of the amount of scavenger remaining in the sample after reaction with hydrogen sulfide, an amount of byproduct of a reaction between the scavenger and the hydrogen sulfide, or an amount of hydrogen sulfide as measured following a secondary reaction that releases the hydrogen sulfide from the scavenger.

Sampling chamber with hydrogen sulfide-reactive scavenger

A sag-resistant fluid, such as a drilling fluid, a completion fluid, or a spacer fluid, including a colloidal suspension that includes a continuous liquid phase and a solid phase suspended in the continuous liquid phase. The solid phase includes a plurality of particles, having an average diameter of the plurality of particles less than about 1000 nm. The sag-resistant fluid has a density of from about 7 to about 30 lbm/gal, and exhibits a density variation of less than about 0.5 lbm/gal over a time period of at least about 16 hours. A method including circulating the sag-resistant fluid through a well.

Colloidal dispersions (sols) for weighting agents in fluids

The physical properties of a fluid may be used in deriving the compositional properties of the fluid, which may, in turn, be used to influence an operational parameters of a drilling operation. For example, a method may include drilling a wellbore penetrating a subterranean formation with a drilling fluid as part of a drilling operation; circulating or otherwise containing the drilling fluid in a flow path that comprises the wellbore; measuring at least one physical property of the drilling fluid at a first location and a second location along the flow path; deriving a compositional property of the drilling fluid at the first location and the second location based on the at least one physical property that was measured; comparing the compositional property of the drilling fluid at the first location and the second location; and changing an operational parameter of the drilling operation based on the comparison.

Drilling operations that use compositional properties of fluids derived from measured physical properties

A wellbore treatment fluid comprising: a base fluid; and a water-soluble salt, the salt comprising: a cation; and an anion, wherein the anion is selected from phosphotungstate, silicotungstate, phosphomolybdate, and silicomolybdate. The treatment fluid can have a density greater than or equal to 13 pounds per gallon. A method of treating a portion of a subterranean formation penetrated by a well comprising: introducing the treatment fluid into the well.

Thermally-stable, non-precipitating, high-density wellbore fluids

The disclosure relates to an electrocrushing drilling fluid with an electrocrushing drilling base fluid including a polar oil, a non-polar oil, or a combination thereof and glycerine carbonate. The electrocrushing drilling fluid or base fluid may further include water or glycerin. The electrocrushing drilling fluid may further contain at least one additive. The electrocrushing drilling fluid may have a dielectric constant or dielectric strength of at least a set amount, an electric conductivity less than a set amount, or a combination of these properties. The disclosure further relates to an electrocrushing drilling system containing the electrocrushing drilling fluid and an electrocrushing drill bit.

Drilling fluid for downhole electrocrushing drilling

Various embodiments disclosed relate to weighted compositions for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include placing in the subterranean formation a coated weighting agent. The coated weighting agent can include a weighting agent and an inorganic coating material on the weighting agent.

Weighted composition for treatment of a subterranean formation

Various embodiments disclosed relate to clay stabilizers. In various embodiments, the present invention provides a method of treating a subterranean formation, including obtaining or providing a composition including a clay stabilizer having the structure Y&#x2014;R&#x2014;(O&#x2014;R)&#x2014;Y. The variable Rcan be a substituted or unsubstituted (C-C)hydrocarbylene. At each occurrence, Rcan independently be a substituted or unsubstituted (C-C)hydrocarbylene. At each occurrence, Y can be independently selected from a substituted or unsubstituted amino group, a substituted or unsubstituted ammonium group, a nitro group, a substituted or unsubstituted amine oxide group, and a substituted or unsubstituted (C-C)hydrocarbyloxy group, wherein at least one terminal group Y is a substituted amino group, a substituted or unsubstituted ammonium group, a substituted or unsubstituted amine oxide group, or a nitro group. The variable x can be an integer between 1 and 200,000. The method also includes placing the composition in a subterranean formation.

Clay stabilizers

A method for monitoring the oleophilic fluid to aqueous fluid ratio of a drilling fluid includes selecting a sample of the drilling fluid that has been recirculated, measuring the NMR response of the sample of the drilling fluid and determining the oleophilic fluid to aqueous fluid ratio of the drilling fluid based at least in part on the NMR response.

Determining the oleophilic to aqueous phase fluid ratio for drilling fluids

Systems and methods for separation of oleaginous fluids, aqueous fluids, and solids from drilling or other oilfield emulsions by solvent extraction. A method for separation of oilfield emulsions comprising: providing an oilfield emulsion prepared for use in a wellbore and/or recovered from a wellbore; mixing the oilfield emulsion with at least a solvent to form at least a mixture; and separating the mixture to at least partially recover an oleaginous phase of the oilfield emulsion.

Solvent-induced separation of oilfield emulsions

Methods and compositions for the use of treatment fluids comprising metalate-based additives to treat subterranean formations are provided. In one embodiment, the methods comprise providing a treatment fluid comprising a non-aqueous base fluid and at least one metalate-based additive comprising: an anion selected from the group consisting of: a tungstate, a molybdate, a vanadate, a manganate, and any combination thereof, and an organic cation; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

Metalate-based additives for use in subterranean formations

Growing community of inventors

The Woodlands, TX, United States of America

Cato Russell McDaniel