Schlumberger Technology Corporation

Cameron International Corporation

Changping Sui

Hui Joyce Zhang

Balakrishnan Panamarathupalayam

Steven Philip Young

Pawilai Chinwangso

William E Foxenberg

Yiyan Chen

Emanuel Stamatakis

Sashikumar Mettath

Paulo Pauferro, Jr

Hui Zhang

Zhipeng Wang

Production chemicals and methods of selecting the production chemicals based on Hansen Solubility Parameters (HSP) are disclosed. The production chemicals selected by the methods mitigate or reduce one or more issues or problems associated with oil and gas productions and transportations. The methods measure HSP values for the production chemicals and/or crude oil and select at least one production chemical for at least one application on the crude oil based on the HSP values of the production chemicals and the crude oil.

Production chemicals and methods of selecting the production chemicals based on Hansen solubility parameters

Sized-bridging agents, wellbore fluid compositions including the agents, and methods utilizing said compositions control, reduce, or prevent fluid losses in wellbores and/or formation damages. One or more divalent organic salts disclosed herein are designed to help mitigate fluid loss by temporarily reducing the permeability of the formation around the wellbore. The sized-bridging agents include sized-divalent organic salts for forming one or more filter cakes to seal one or more portions of the wellbores thereby reducing rates of fluid loss and damages to formations.

Sized bridging agents, low density pill and fluid compositions comprising said agents, and methods of controlling fluid loss and formation damage using said compositions

A wellbore fluid may include a non-oleaginous internal phase, an oleaginous external phase, and an emulsifier having a molecular weight of at least 700 daltons, whereby the emulsifier may include at least one tertiary amine. A method of completing a wellbore operation may include injecting a wellbore fluid downhole, the wellbore fluid including a non-oleaginous internal phase, an oleaginous external phase, and an emulsifier having a molecular weight of at least 700 daltons. The emulsifier may include at least one tertiary amine. The method may further include injecting a wash fluid comprising a protonating agent downhole.

Reversible oil-based mud

A brine viscosifier includes at least one monomer and triethoxyvinylsilane (TEVS) to provide crosslinking among the at least one monomer. A method includes admixing a composition comprising a brine, a thermal stabilizer, a pH buffer, and a polymer. The polymer may include a monomer, an organic crosslinker, an inorganic crosslinker; and an initiator.

Organic-inorganic hybrid polymer based fluids

Emulsion-preventing compositions may contain one or more sorbitan esters; and one or more non-ionic surfactants; where the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants is in the range of 1:1 to 1:5. Methods may include contacting an emulsion with a treatment fluid, the treatment fluid containing one or more sorbitan esters and one or more non-ionic surfactants, where the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants is in the range of 1:1 to 1:5; and separating the emulsion into an aqueous phase and an oleaginous phase.

Emulsion preventer for completion brines

A insulating annular fluid for reducing convective currents in the annular region a wellbore is provided that includes an oleaginous fluid, a silica, and, in some embodiments, organoclay.

Insulating annular fluid

An insulating packer fluid including an oleaginous fluid and a styrenic thermoplastic block copolymer and methods of preparing the packer fluid are provided. Also provided are methods of using the insulating packer fluid that include pumping an insulating packer fluid into an annulus formed between two concentric strings of pipe extending into a wellbore.

High temperature viscosifier for insulating packer fluids

Insulating packer fluids containing colloidal silica inorganic additives may be used in methods that reduce convective currents in a packer fluid. In other aspects, packer fluids containing colloidal silica inorganic additives may be used in methods of insulating production wells and methods for stimulating production of hydrocarbons.

Colloidal silica and polymer system for insulating packer fluids

Non-emulsifying compositions may contain one or more sorbitan esters; one or more non-ionic surfactants; and one or more amphoteric surfactants, wherein the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants to the one or more amphoteric surfactants is in the range of 1:1:1 to 1:5:3. Methods may include contacting an emulsion with a treatment fluid, the treatment fluid containing one or more sorbitan esters, one or more non-ionic surfactants, and one or more amphoteric surfactants, wherein the ratio of the one or more sorbitan esters to the one or more non-ionic surfactants to the one or more amphoteric surfactants is in the range of 1:1:1 to 1:5:3; and separating the emulsion into an aqueous phase and an oleaginous phase.

Non-emulsifier for completion brines to prevent emulsion from forming

Compositions may include a monomer, an organic crosslinker, an inorganic crosslinker, and an initiator. Furthermore, compositions may include at least one monomer and triethoxyvinylsilane (TEVS) to provide crosslinking among the at least one monomer.

Growing community of inventors

The Woodlands, TX, United States of America

Changping Sui