Schlumberger Technology Corporation

Cameron International Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Alice Chougnet-Sirapian

Christian Stoller

Simon James

Sylvaine Le Roy-Delage

Fadhel Rezgui

Slaheddine Kefi

Matthew David Givens

Gérard Daccord

Mickael Allouche

Ray Zonoz

Bernard Dargaud

Anthony Loiseau

Nicolas Droger

Marie-Laure Mauborgne

Mauro Manclossi

Quentin Barral

Sebastien Catheline

Elena Tomilina

Remi Robutel

Nora Bennani

Dominique Zamora

Olivier Amsellem

Sébastien Catheline

Methods for cementing a subterranean well and maintaining zonal isolation involve preparing a cement slurry that contains water, an inorganic cement and an expanding agent. The slurry is placed in the annular region between casing and the formation or between two casing strings. After the cement sets, the expanding agent reacts and causes the set cement to be in a state of compression within the annular region. The casing dimensions may fluctuate in response to a temperature change, a pressure change, a mechanical disturbance resulting from a well intervention, or mud contamination or a combination thereof. The expanding agent may further react and maintain a state of compression within the annular region. The state of compression in the annular region may be monitored by acoustic impedance measurements.

Compositions and methods for well cementing

The service life of a packer element, an annular BOP, is estimated using one pressure sensor below the elastomer seal or two pressure sensors positioned above and below the elastomer seal. The pressure variations below the elastomer are monitored versus piston position and used to detect elastomer wear with time/pressure cycles. The pressure variations above the elastomer can be used to detect potential leakage, as well as leak characteristics such as leaking rate or leak geometry.

BOP elastomer health monitoring

A method for evaluating cement in a cased wellbore in a geological formation includes placing a downhole tool into the cased wellbore, where the cased wellbore has been cased using a cement that contains a particular material. The method includes emitting neutrons using the downhole tool, wherein the neutrons interact with the particular material via inelastic scattering or capture of neutrons and cause the material to emit an energy spectrum of the gamma rays associated with the material or wherein the time-based measurement of gamma rays or neutrons is influenced by the presence of the material. The method includes using the downhole tool to detect radiation radiation, such as the energy spectrum of the gamma rays, or a die-away pattern of the gamma rays or neutrons that indicates a presence of the particular material and enable to estimate a parameter of the cement.

Cement evaluation using neutron tool

A dried latex emulsion coating on a surface of a metal member is used as a thin bond layer on well tubular joints, on tubular strings in wells, and on other metal members. The bond layer promotes adhesion to cement members formed from hardening a cement slurry in contact with the bond layer. The bond layer can be used in bonded cement structures, on well tubular joints, on tubular strings in a well, on tubular strings cemented in a well, in methods of making the cement structures and the tubular strings, and in methods of placing and cementing a tubular string in a well.

Latex-bonded metal and cement members

Incorporation of carbonaceous materials in a cement slurry increases the linear thermal-expansion coefficient of the set cement. When placed in a subterranean well having at least one casing string, cement sheaths with linear thermal-expansion coefficients similar to that of the casing will be subjected to lower compressive and tensile stresses during downhole-temperature changes. Such cement slurries are particularly advantageous in the context of thermal-recovery wells.

Compositions and methods for well completions

An apparatus may be used to test the ability of a first fluid to remove a second fluid from a surface. The apparatus comprises a reservoir that contains the first fluid and a testing cell that contains the second fluid. The testing cell also contains a rotor within. The first fluid is pumped into the testing cell, thereby displacing the second fluid. The displaced second fluid flows to a collection vessel. The apparatus is particularly useful for determining the ability of a chemical wash or a spacer fluid to remove non-aqueous drilling fluids from a metallic surface.

Apparatuses and methods for testing wellbore fluids

Methods for servicing subterranean wells are disclosed. Particularly, the use of a fiber-laden fluid to separate and prevent the commingling of two stationary process fluids after placement in the borehole of a subterranean well, or in a tubular body installed in a subterranean well. The fiber-laden fluids prevent the cement plug from descending through drilling fluid to the bottom of the well. It obviates the need for mechanical devices such as packers, or special adjustment of the process fluids' rheological properties.

Methods and compositions for suspending fluids in a wellbore

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Elancourt, France

Alice Chougnet-Sirapian