Halliburton Energy Services, Inc.

Arunesh Kumar

Sharath Savari

Dale E Jamison

Jason T Scorsone

Sandeep D Kulkarni

Matthew Lynn Miller

Robert J Murphy

Donald Lee Whitfill

Rajendra Arunkumar Kalgaonkar

Shadaab Syed Maghrabi

Sandeep Kulkarni

Garima Misra

Mathew L Miller

Generally, assessing the properties of a plug comprising wellbore strengthening materials may enable the design of more efficient wellbore strengthening additives and fluids because the properties of the plug may translate to the near wellbore strengthening effect of the wellbore strengthening materials of the plug. Assessing such properties may involve applying a differential pressure to a plug formed in a passageway of a tool comprising at least one sensor proximal to the passageway plug, and then measuring at least one attribute selected from the group consisting of a normal plug pressure, a normal plug displacement, and any combination thereof with the at least one sensor.

Methods relating to designing wellbore strengthening fluids

A method of treating a well the method including the steps of: (A) forming a fluid including: (i) a shear-thinning aqueous liquid phase; and (ii) an inorganic setting material; wherein the fluid is shear-thinning, pumpable, and settable; and (B) introducing the fluid into the well.

Viscous settable fluid for lost circulation in subterranean formations

A method of wellbore strengthening may include providing a wellbore strengthening fluid comprising a drilling fluid, a particulate, and a fiber; introducing the wellbore strengthening fluid into a wellbore penetrating a subterranean formation; and forming a plug comprising the particulate and the fiber in a void near the wellbore, the plug being capable of maintaining integrity at about 1000 psi or greater overbalance pressure.

Engineered methods and materials for wellbore strengthening in subterranean operations

A treatment fluid comprises: water; a carboxylate; and a corrosion inhibitor, wherein the corrosion inhibitor is a polymer, wherein the polymer comprises silicone, an ether monomer residue, and an amine functional group; wherein a test fluid consisting essentially of the water, the carboxylate, and the corrosion inhibitor, and in the same proportions as in the treatment fluid, is capable of providing a corrosion weight loss to a metal plate of less than 0.05 pounds per square feet (lb/ft) under testing conditions of 200&#xb0; F. (93.3&#xb0; C.), a pressure of 500 psi (3.4 MPa), and a time of 24 hours whereas a substantially identical test fluid without the corrosion inhibitor provides a corrosion weight loss of greater than 0.05 lb/ftunder the testing conditions. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Treatment fluid containing a corrosion inhibitor of a polymer including a silicone and amine group

Of the many compositions and methods provided herein, one method includes providing a drilling fluid comprising a base drilling fluid and a plurality of particulates, wherein the base drilling fluid without the particulates is characterized by Nand wherein the base drilling fluid with the particulates is characterized by N; and adjusting a concentration of the particulates in the drilling fluid by comparing the value of &#x394;Nto &#x394;Nso that &#x394;N&#x2267;&#x394;N, wherein &#x394;N=|N|&#x2212;|N|.

Methods to characterize fracture plugging efficiency for drilling fluids

A method for determining a Plug Normal Stress Difference (&#x394;N) may include providing a test base drilling fluid that is characterized by N; adding a first concentration of a test particulate to the test base drilling fluid; adjusting the concentration of the test particulate in the test base drilling fluid to achieve a minimum concentration of the test particulate in the test base drilling fluid that will substantially plug a tapered slot, wherein the test base drilling fluid with the minimum concentration of the test particulate is characterized by N; and calculating &#x394;N=|N|&#x2212;|N| wherein each First Normal Stress Difference is measured by the same procedure.

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Bihar, India

Arunesh Kumar