Schlumberger Technology Corporation

Stephen Davies

Trevor Lloyd Hughes

Wayne W Frenier

Murtaza Ziauddin

Frank F Chang

Jean-Louis Pessin

Philip F Sullivan

Diankui Fu

John W Still

Mohan Kanaka Raju Panga

Frank F Espinosa

Keith Ingram Dismuke

Yenny Christanti

Isabelle Couillet

Alexander Martin Wilson

Henk Lekkerkerker

Hassan Chaabouni

Xuehao Tan

Michel Van Bruggen

Arnaud Van Der Beken

Courtney Payne

Chidi Eugene Nwafor

Ann Wattana

Methods of treating a subterranean formation penetrated by a well bore, by diverting treatment fluid stages from zones of higher permeability to zones of lower permeability with an acid precursor material and fibers. The acid precursor material has an average particle size less than 1000 microns.

Well treatment

Methods for creating packers at a desired location or locations within a wellbore for use in specific wellbore applications. A slurry of fluid medium and hydrolysable particulate matter is flowed to a downhole position and dehydrated. At this location, the particulate matter is released from the fluid medium and accumulated. The continual accumulation of the slurry and consequent deposition of particulate matter creates a degradable packer at the desired location within the wellbore. The particulate matter may be formed of an acid particle which may be removable, degradable, or hydrolysable under certain conditions of temperature, time, hydration, pH, and/or pressure. Either simultaneous with or subsequent to a wellbore activity, the packer is partially or completely removed from the wellbore.

Methods of forming acid particle based packers for wellbores

An aqueous oilfield treatment fluid containing a chelating agent and an HF source is described. This fluid is effective at dissolving siliceous materials such as clays and keeping the dissolved materials in solution. In particular it is effective at preventing re-precipitation of initially-dissolved silicon as silica and therefore reduces damage to sandstones with which it is contacted. Methods are given for using this fluid for sandstone matrix stimulation, removal of clay-containing drilling fluid components and filter cakes from wellbores, sandstone acid fracturing, and gravel pack and proppant pack cleaning.

Composition comprising a fully dissolved non-HF fluoride source and method for treating a subterranean formation

The invention concerns an aqueous delayed-gelation solution and a method of selectively placing a delayed-gelation solution in a hydrocarbon well. According to the invention, the aqueous delayed-gelation solution a dissolved metal salt which, in use, hydrolyses to form a gel, wherein the solution contains suspended inorganic particles and the method comprises the steps of&#x2014;providing the aqueous delayed-gelation solution, and&#x2014;injecting the solution into the hydrocarbon well, whereby the suspended inorganic particles reduce or block the flow of the delayed-gelation solution to relatively low permeability formation zones thereby selectively placing the solution in a relatively high permeability formation zone. Applications of the invention relate to the treatment of hydrocarbon wells.

Delayed-gelation solution

The present invention relates to viscoelastic fluids that contain nanotube structures that may be used advantageously as oilfield stimulation fluids in many different applications, most particularly as a fracturing fluid. Viscoelastic fluid compositions of the present invention include an aqueous medium, a viscoelastic surfactant, an organic or inorganic acids, or salt thereof, organic acid salts, inorganic salts, and a nanotube component. The invention is also called to a methods of treating a subterranean well bores in which the viscoelastic fluid is injected into the wellbore to perform operations such as fracturing, drilling, acid fracturing, gravel placement, removing scale, matrix acidizing, and removing mud cake. Further, a method of preparing a nanotube viscoelastic fluid comprising the steps of effectively mixing a carbon nanotube component into a viscoelastic fluid, and sonicating the mixture in order to incorporate the carbon nanotube component is claimed.

Viscoelastic fluids containing nanotubes for oilfield uses

Composition and method for treating a subterranean formation

Disclosed are methods of treating subterranean formations by first providing a suspension of colloidal particles prior to the injection of viscoelastic based treatment fluid, and injecting the treatment fluid into a well. The colloidal particles reduce fluid loss into the formation. According to a second embodiment, the treating fluid includes a hydrophobically-modified polymer, said hydrophobically-modified polymer being present at a concentration between approximately its overlap concentration c* and approximately its entanglement concentration c. The method is particularly useful for fracturing operations in medium to high permeability formations.

Methods for controlling the fluid loss properties of viscoelastic surfactant based fluids

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Sugar Land, TX, United States of America

Stephen Davies