Schlumberger Technology Corporation

Hemant K J Ladva

Carlos Abad

Yiyan Chen

Manuel P Marya

Lijun Lin

Christopher Alan Sawdon

Paul R Howard

John E Edwards

Anthony Loiseau

A degradable composition including magnesium-based materials doped with metals, metalloids, and/or compounds, where the composition has a hardness in excess of 80 BHN, and methods of using the same (for example, as a constituent of a treatment fluid of a subterranean formation) are described. The degradable composition may be a shaped composition that degrades in environments typically encountered downhole, such as oilfield environments/conditions and/or fluids. Compositions including magnesium-based materials and various manufacturing processes to produce a composition including the magnesium-based materials in a desired shape are also described.

Compositions and methods for treating a subterranean formation

A thickened composition comprising a polymer, a divalent ions source, water and cement is disclosed. Such composition enables fluid loss reduction and higher gel strength. This may be useful for treating a well for example as a fluid spacer or a scavenger; this may also be used a hydraulic fracturing fluid.

Subterranean treatment fluid composition and method of treatment

The toughness of set cement may be enhanced by incorporating partially cured waterborne resins in the cement matrix. A hardening agent is added to the waterborne resin, and the mixture is allowed to react for periods between about 1 min and 15 min. The waterborne resin with hardening agent is then combined with an inorganic cement to form a pumpable slurry.

Compositions and methods for improving the toughness of set cements

A method includes performing a chemical process to create a chemical product and an amount of heat, and transferring the heat to a first fluid. The method further includes hydrating a polymer in the first fluid, and adding the chemical product from the chemical process to the first fluid to create a treatment fluid. The method further includes diluting the treatment fluid with respect to at least one constituent of the treatment fluid. The method includes treating a formation of interest in a wellbore with the treatment fluid. The method includes changing a formulation of the treatment fluid during the treating. The method also includes extending the treating beyond a design amount, or ending the treatment before the design amount and preserving some reagents of the chemical process.

System, method and apparatus for enhancing wellbore treatment fluid flexibility

The use of time-lapsed NMR diffusivity measurements in an observation well is disclosed. The observation well is cased in the zone of interest with non-magnetic and non-conductive casing that is invisible to the NMR tool. Second, because NMR measurements have a dead zone in front of the antenna depending on the spatial variation of the fixed magnet strength, for example about 2.7 inches, a distance between the casing and the formation is reduced to less than the dead zone length by drilling the observation well at small deviation of about 5&#xb0; and running the casing without centralizers. Both the casing and the pad-type NMR tool will follow the low side of the borehole, ensuring the measurement volume of the NMR tool is inside the formation and beyond the annulus. With the appropriate observation well completion, time-lapse diffusivity measurements with pad-type NMR tools can address several shortcomings in the current practice of monitoring EOR processes that rely upon changes in density and hydrogen index (HI). Various uses of NMR imaging in wells cased with non-metallic casing are also disclosed.

Time-lapsed diffusivity logging for monitoring enhanced oil recovery

A low molecular weight, high melting point, crystalline, oil soluble additive for use in wellbore fluids is provided that is preferably a ground crystalline material of melting point over 80&deg; C., preferably over 100&deg; C. which is readily soluble in produced hydrocarbons such as crude oil and lighter condensates, and which exhibits a molecular weight of less than 1000, and preferably less than 500, and more preferably less than 300. Its particle size can be adjusted to bridge efficiently across different pore size formations and control its solubility rate.

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Missouri City, TX, United States of America

Hemant K J Ladva