Patent application number | Description | Published |
20120264658 | Methods to Characterize Fracture Plugging Efficiency for Drilling Fluids - 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 N | 10-18-2012 |
20120316088 | Method to Characterize Fracture Plugging Efficiency for Drilling Fluids - A method for determining a Plug Normal Stress Difference (ΔN | 12-13-2012 |
20120316089 | Methods to Characterize Fracture Plugging Efficiency for Drilling Fluids - A drilling fluid may include a base drilling fluid and a plurality of particulates, wherein a concentration of the particulates in the base drilling fluid provides for ΔN | 12-13-2012 |
20140083703 | Triggerable Lost Circulation Material and Method of Use - Methods for preventing or alleviating the loss of drilling fluids and other well treatment fluids into a subterranean formation during drilling or construction of boreholes therein include a drilling fluid including a lost circulation material. The lost circulation material includes a suspension of swelled particles of a pH sensitive polymeric material, the swelled particles capable of reversibly attaching to other swelled particles of the polymeric material. The pH of the aqueous solution is such that each particle of the swelled pH sensitive polymeric material is not attached to other swelled particles, and wherein upon lowering the pH of the suspension, the swelled particles attach to each other. | 03-27-2014 |
20140155300 | OIL OR GAS TREATMENT FLUID CONTAINING A CHELATE OR COORDINATION COMPLEX THAT SETS - A treatment fluid comprises: a metal oxide, wherein the metal oxide is capable of forming a chelate complex or coordination complex with a ligand, wherein the chelate complex or coordination complex has a setting time of less than 90 minutes at a temperature of 71° F. and a pressure of 1 atmosphere. A method of treating a portion of a subterranean formation comprises: introducing the treatment fluid into the subterranean formation; allowing or causing a chelate complex or coordination complex to form between the metal oxide and a ligand; and allowing or causing the chelate complex or coordination complex to set. | 06-05-2014 |
20140231086 | METHODS AND COMPOSITIONS FOR TREATING SUBTERRANEAN FORMATIONS WITH SWELLABLE LOST CIRCULATION MATERIALS - Methods of treating a fluid loss zone in a wellbore in a subterranean formation including providing swellable particles having an initial unswelled volume, wherein the swellable particles upon swelling adopt a specific shape; introducing the swellable particles into the wellbore in the subterranean formation; and swelling the swellable particles so as to adopt a swelled volume beyond the initial unswelled volume; and sealing at least a portion of the fluid loss zone. | 08-21-2014 |
20140338912 | THERMALLY-ACTIVATED GELLANT FOR AN OIL OR GAS TREATMENTFLUID - A treatment fluid for treating a portion of a subterranean formation comprises: a base fluid, wherein the base fluid comprises a hydrocarbon liquid; and a gellant, wherein the gellant: is a polymer; and is activated at an activation temperature, wherein the thermal activation of the gellant causes the treatment fluid to become a gel. A method of treating a portion of a subterranean formation includes introducing the treatment fluid into the portion of the subterranean formation, wherein the subterranean formation is penetrated by a well, wherein at least a portion of the well has a bottomhole temperature greater than or equal to the activation temperature, and wherein the step of introducing comprises introducing the treatment fluid into the portion of the well. | 11-20-2014 |
20150144332 | MODELING THE SUSPENDABILITY OF FIBERS IN A TREATMENT FLUID USING EQUATIONS - A method of predictive modeling of a treatment fluid comprises: determining the value of properties of a base fluid and insoluble particulates; providing a proposed suspending agent; performing a first calculation of the suspendability of the proposed suspending agent as determined by a yield gravity function equation; evaluating if the result from the first calculation indicates a stable treatment fluid comprising the base fluid, the insoluble particulates, and the proposed suspending agent, or if the result does not indicate a stable treatment fluid, then: modifying the value of at least one of the properties of the proposed suspending agent, base fluid, and/or insoluble particulate; and performing a second calculation, wherein the same or different property values are continued to be modified and the calculation is continued to be performed until the result indicates a stable treatment fluid; and introducing the stable treatment fluid into a wellbore. | 05-28-2015 |