Schlumberger Technology Corporation

Yenny Christanti

Philip F Sullivan

Bruno Drochon

Gary John Tustin

Gregory Kubala

Trevor Lloyd Hughes

Syed Afaq Ali

Yiyan Chen

Carlos Abad

Balkrishna Gadiyar

Paul R Howard

Marie Noelle Dessinges

Diankui Fu

Richard Donald Hutchins

Golchehreh Salamat

Bernhard Lungwitz

Marieliz Garcia-Lopez De Victoria

Alhad Phatak

Valerie Gisele Helene Lafitte

Jian Zhou

Samuel Danican

Isabelle Couillet

Arthur Milne

Zhijun Xiao

Stephen Davies

Changsheng Xiang

Alexander Martin Wilson

Brent Busby

Konstantin Viktorovich Vidma

Emilio Jose Miquilena

Manuel Jose Lastre Buelvas

A wellbore treatment fluid is disclosed herein, the fluid comprising a butenediol vinyl alcohol copolymer. Also, a wellbore treatment fluid comprises a dissolvable material capable of forming a gel upon hydration, the dissolvable material having a cylindrical cross-sectional shape. Methods of treating a subterranean formation includes introducing a treatment fluid comprising a butenediol vinyl alcohol copolymer, and creating a plug with the treatment fluid.

Methods and compositions using dissolvable gelled materials for diversion

A water-free slurry may include a non-aqueous carrier fluid; a suspension agent including a mineral clay mixture; a crosslinking agent; and a hydratable polymer. A method of treating a subterranean formation may include injecting a water-free slurry into a wellbore penetrating the subterranean formation, the water-free slurry including: a non-aqueous carrier fluid; a suspension agent comprising a mineral clay mixture; a crosslinking agent; and a hydratable polymer.

Hydratable polymer slurry and method for water permeability control in subterranean formations

A method of treating a producing well that includes the introduction of a treatment fluid to the producing well from a surface above the subterranean formation, the treatment fluid comprised of at least PPG particles to enhance the oil rate and reduce the water rate of the producing well.

Swellable polymer particles for producing well treatments

This invention relates to compositions and methods for treating subterranean formations, in particular, oilfield stimulation compositions and methods using water-in-water polymer emulsions to uniformly dissolve a rheologically active polymer, such as a thickener or friction reducer, in the treatment fluid. The emulsions have a low viscosity and are easily pumped for mixing into a treatment fluid, where upon dilution with an aqueous medium, the polymer is easily hydrated without forming fish-eyes. The partitioning agent in the water-in-water emulsion does not generally affect the rheology of the treatment fluid. The invention also relates to further processing of the emulsion by wet grinding, high shear mixing and/or heating to enhance the hydration rate in the preparation of the well treatment fluid.

Polymer delivery in well treatment applications

A method includes providing a treatment fluid that is a viscous fluid. The viscous fluid may be greater than 0.01 Pa-s, greater than 0.1 Pa-s, and/or a cross-linked polymer based fluid. The method further includes determining a fines migration composition soluble in an aqueous phase of the treatment fluid that is compatible with the treatment fluid, and that interacts to secure fines in an earth formation intersecting a wellbore within a fines reaction time. The method further includes adding an amount of the fines migration composition to the treatment fluid, and treating the earth formation with the treatment fluid. The method includes leaking off a portion of the treatment fluid into the earth formation, and providing a residence time of the leaked off portion of the treatment fluid in the earth formation, where the residence time meets or exceeds the fines reaction time.

System, method and treatment fluid for controlling fines migration

A thickened aqueous composition is delivered to a subterranean location accessible via a wellbore by steps of i. providing a biphasic aqueous mixture comprising two aqueous solutions which, at surface temperature and pressure, are able to co-exist as separate aqueous phases in contact with each other, ii. pumping said biphasic aqueous system down the wellbore to the subterranean location, and iii. converting the biphasic mixture below ground so that its phases combine into a single aqueous phase which is more viscous than the biphasic mixture. The two phases of the aqueous biphasic mixture contain dissolved solutes which segregate between the two phases such that at least one first solute is present at a greater concentration in the first aqueous phase than in the second aqueous phase while at least one second solute is present at a greater concentration in the second aqueous phase than in the first aqueous phase. The solute in the first phase may be a thickening polymer or other thickening material such as viscoelastic surfactant. The solute in the second phase may be a different polymer, surfactant or salt. Conversion to a single phase may be carried out in various ways including dilution, change in pH, change in salinity, increase in temperature and adsorption of one solute onto formation rock.

Provision of viscous compositions below ground

A method includes providing a wellbore treatment fluid having a divalent brine and an amount of polymer and lowering a pH value of the treatment fluid. The method further includes retaining the treatment fluid at the lower pH value until the polymer achieves a primary hydration value. The method further includes adding a cross-linking agent and a cross-linking delay agent to the treatment fluid. The cross-linking agent includes zirconium and/or titanium, and the cross-linking delay agent is a polyol. The method further includes performing a wellbore treatment with the treatment fluid.

System, method, and apparatus for utilizing divalent brines in viscosified well treatment fluids

A low viscosity wellbore polymer fluid gelling system comprising an aqueous medium and a water-in-water emulsion comprising a plurality of polymers or oligomers, including at least one removable polymer or oligomer, and at least one gelling polymer or oligomer, wherein said fluid has a low viscosity when injected, and the gelling polymer forms a gel downhole which has a storage modulus of at least about 60 Pa after the removable polymer is removed from the fluid. A method of isolating at least one zone of a subterranean formation penetrated by a wellbore includes the steps of preparing a water-in-water emulsion comprising a plurality of polymers or oligomers including at least one removable polymer or oligomer, and at least one gellable polymer or oligomer; and combining the water-in-water emulsion with an aqueous medium to prepare a low viscosity polymer fluid.

Aqueous two-phase emulsion gel systems for zone isolation

A method is described for treating a subterranean formation with a low viscosity fluid system that contains a surfactant or mixture of surfactants that does not divert fluid flow in the formation, but that develops the ability to divert flow as the fluid flows through the formation. The fluid optionally contains a formation-dissolving agent. The fluid is used in matrix acidizing, acid fracturing, and diversion.

Self diverting matrix acid

Compositions are given that have high viscosities at one pH range and low viscosities at another pH range. Methods are given for using such compositions in oilfield treatments. In particular CT wellbore cleanout compositions and methods are given in which a viscous fluid is injected into a wellbore; the fluid entrains particles and carries them to the surface; the viscosity of the fluid is reduced by reducing or increasing the pH; the particles settle from the fluid; the viscosity of the fluid is increased by increasing or reducing the pH; and the fluid is re-injected into the wellbore. Suitable surfactants are anionic surfactants, or mixtures of surfactants containing anionic surfactants, that aggregate into three-dimensional structures that substantially increase the viscosity at high pH but not at low pH. Other suitable surfactants are cationic surfactants with co-surfactants that aggregate below a certain pH but not above.

Fluid having recyclable viscosity

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.

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Houston, TX, United States of America

Yenny Christanti