Baker Hughes Oilfield Operations LLC

Baker Hughes, a Ge Compnay, LLC

Dorianne A Castillo

D V Satyanarayana Gupta

Scott Gregory Nelson

Anna Jensen

Sebastian Mesa

Ajay Kumar Venkata Addagalla

Diego Arias

Erna Kakadjian

Autumn Shepherd

Saniya Syed

Daniel P Vollmer

A method includes: injecting a first spacer fluid into a wellbore that comprises a drilling fluid, the first spacer fluid containing barium sulfate and a first spacer fluid carrier; and injecting into the wellbore a second spacer fluid containing a chelating agent and a second spacer fluid carrier. A spacer fluid system includes: a first spacer fluid containing barium sulfate and a first spacer fluid carrier; and a second spacer fluid containing about 10% to about 30 wt % of a chelating agent based on a total weight of the second spacer fluid, and a second spacer fluid carrier.

Chelating agents for barium sulfate dissolution in displacment spacer systems

A method includes disposing a device into a borehole in proximity to a subterranean formation where a filter cake has been formed adjacent thereto, the device comprising a support structure and a shape-memory article disposed at the support structure, the shape-memory article comprising a shape-memory polymer, wherein the device is disposed when the shape-memory article is in a compacted shape; exposing the shape-memory article to a fluid system to cause the shape-memory article to expand and conform to a surface of the borehole; exposing the filter cake to the fluid system; and removing the filter cake with the fluid system. The fluid system comprises a chelating agent, an activator, a non-emulsifier, and water or a brine.

Fluid systems for expanding shape memory polymers and removing water-based filter cakes

A brine-based viscosified pill including (1) a viscosified brine, (2) a surfactant-solvent blend containing about 5 wt. % to about 40 wt. % of at least one nonionic surfactant; about 5 wt. % to about 20 wt. % of at least one polyglycerol ester, about 20 wt. % to about 60 wt. % of at least one co-solvent; about 20 wt. % to about 25 wt. % water; and optionally about 1 wt. % to about 15 wt. % of at least one hydrophobic solvent, and (3) no solid weighting agent, may be introduced to a wellbore in an effective amount to clean the wellbore or displace fluid in the wellbore at a wide range of temperatures.

Additives for wellbore cleaning and fluid displacement

A method of increasing a solubility of a manganese oxide includes contacting the manganese oxide with an acid component in the presence of a dissolution accelerator that includes at least one of hydrazine, a hydrazine derivative, or a hydrazide. Also disclosed is a drilling fluid containing a carrier; MnO; and at least one of a viscosifier, a rheology modifier, a dispersant, a weighting agent, a defoamer, a fluid loss agent, bentonite, or a lubricant.

Method for manganese oxides dissolution

A method includes disposing a device into a borehole in proximity to a subterranean formation where a filter cake has been formed adjacent thereto, the device comprising a support structure and a shape-memory article disposed at the support structure, the shape-memory article comprising a shape-memory polymer, wherein the device is disposed when the shape-memory article is in a compacted shape; exposing the shape-memory article to a fluid system to cause the shape-memory article to expand and conform to a surface of the borehole; exposing the filter cake to the fluid system; and removing the filter cake with the fluid system. The fluid system comprises (i) an acid component, a chelating agent, or a combination thereof; (ii) an activator, (iii) a viscosifier, (iv) water or a brine, and (v) optionally a surfactant.

Fluid systems for expanding shape memory polymers and removing filter cakes

The flow of a fluid may be diverted from a high permeability zone to a low permeability portion of a subterranean formation by use of particulates comprising dicarboxylic acid, ester or an anhydride of the formula:  or an anhydride thereof, wherein Ris &#x2014;COO&#x2014;(RO)y&#x2014;Ror &#x2014;H; Rand Rare selected from the group consisting of &#x2014;H and &#x2014;COO&#x2014;(RO)y&#x2014;R, provided both Rand Rare &#x2014;COO&#x2014;(RO)y&#x2014;Rwhen Ris &#x2014;H and further provided only one of Ror Ris &#x2014;COO&#x2014;(RO)y&#x2014;Rwhen Ris &#x2014;COO&#x2014;(RO)y&#x2014;R, Ris &#x2014;H or a C-Calkyl group, Ris a C-Calkylene group, and each y isto. The dicarboxylic acid, ester or anhydride may further be admixed with an aliphatic polyester having the general formula of repeating units:  where n is an integer betweenandand R is selected from the group consisting of hydrogen, alkyl, aryl, alkylaryl, acetyl, heteroatoms, and mixtures; thereof.

Well treatment operations using diverting system

The flow of a fluid may be diverted from a high permeability zone to a low permeability portion of a subterranean formation by use of particulates comprising a mixture of (i) at least one aliphatic polyester having the general formula of repeating units: where n is an integer between 75 and 10,000 and R is selected from the group consisting of hydrogen, alkyl, aryl, alkylaryl, acetyl, heteroatoms, and mixtures thereof; and 

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Humble, TX, United States of America

Dorianne A Castillo