Patent application number | Description | Published |
20130248251 | Mathematical Modeling of Shale Swelling in Water Based Muds - A method of servicing a wellbore comprises determining a cation exchange capacity of a sample of a shale, determining a swelling characteristic of the shale using the cation exchange capacity in an equation comprising a term of the form: | 09-26-2013 |
20130318019 | METHODS AND APPARATUSES FOR MODELING SHALE CHARACTERISTICS IN WELLBORE SERVICING FLUIDS USING AN ARTIFICIAL NEURAL NETWORK - An apparatus and method for determining a formation/fluid interaction of a target formation and a target drilling fluid is described herein. The method may include training an artificial neural network using a training data set. The training data set may include a formation characteristic of a source formation and a fluid characteristic of a source drilling fluid and experimental data on source formation/fluid interaction. Once the artificial neural network is trained, a formation characteristic of the target formation and fluid characteristic of target drilling fluid may be input. The formation characteristic of the target formation may correspond to the formation characteristic of the source formation. The fluid characteristic of the target drilling fluid may correspond to the fluid characteristic of the source drilling fluid. A formation/fluid interaction of the target formation and the target drilling fluid may be determined using a value output by the artificial neural network. | 11-28-2013 |
20130324442 | Compositions and Method for Treating Out Hydrogen Sulfide and Preventing Settling of Precipitate in an Environmentally Responsible Drilling and Packer Fluid - An environmentally responsible iron chelating additive and method for removing hydrogen sulfide or sulfide ions from drilling and packer fluids and preventing settling of precipitates. Iron chelating agents selected from the group consisting of ferrous lactate, ferrous gluconate, ferrous bis glycinate, ferrous citrate, ferrous acetate, ferrous fumarate, ferrous succinate, ferrous sacchrate, ferrous tartarate, ferrous glycine sulfate, ferrous glutamate, ferrous ascorbate, ferrous polymaltose, or a combination thereof, may be used. When the fluids are oil based, the iron chelating agents are added to the water phase of an emulsion, and the emulsion is added to the fluid. Viscosifiers may also be added to the drilling fluid with the emulsion. | 12-05-2013 |
20130332089 | Methods for Predicting Dynamic Sag Using Viscometer/Rheometer Data - A method for quantitatively determining dynamic barite sag in drilling fluids includes measuring rheological properties with viscometers and/or rheometers, and introducing the parameters into an equation to obtain the sag rate. | 12-12-2013 |
20140202772 | DRILLING A WELL WITH PREDICTING SAGGED FLUID COMPOSITION AND MUD WEIGHT - Methods of drilling or treating a well including the steps of: designing a fluid with high-gravity solids (e.g., barite); calculating the sagged fluid mud weight after allowing for sag according to formulas; forming a fluid according to the sagged fluid mud weight; and introducing the fluid into the well. The methods can be used to help control the well or to avoid excessive drilling torque or pressure, kick, or lost circulation due to sag of high-gravity solids such as barite. | 07-24-2014 |
20140262281 | Methods of Designing a Drilling Fluid Having Suspendable Loss Circulation Material - Methods including providing a wellbore in a subterranean formation having at least one pore opening; providing a proposed wellbore operation; providing a proposed treatment fluid; providing proposed FLCM particulates; calculating the suspendability of the proposed FLCM particulates in the proposed treatment fluid as determined by a yield gravity function based on properties of the proposed treatment fluid and properties of the proposed FLCM particulates or as determined by an experimental FLCM function; manipulating at least one of the properties of the proposed treatment fluid, the properties of the proposed FLCM particulates, or the proposed wellbore operation based on the yield gravity function or the experimental FLCM function so as to produce a FLCM-suspension treatment fluid; and introducing the FLCM-suspension treatment fluid into the wellbore in the subterranean formation so as to contact the at least one pore opening. | 09-18-2014 |
Patent application number | Description | Published |
20110214864 | Invert drilling fluids having enhanced rheology and methods of drilling boreholes - An invert emulsion drilling fluid, and a method of drilling with such fluid, having improved rheology at low mud weights and high temperatures. The improved rheology is effected with addition of hydrophobic amines, most preferably dimer diamines. | 09-08-2011 |
20120097403 | Invert Drilling Fluids Having Enhanced Rheology and Methods of Drilling Boreholes - An invert emulsion drilling fluid, and a method of drilling with such fluid, having improved rheology at low mud weights and high temperatures. The improved rheology is effected with addition of hydrophobic amines, most preferably dimer diamines. | 04-26-2012 |
20130310282 | Wellbore Servicing Fluids and Methods of Making and Using Same - A method of servicing a wellbore comprising placing an invert emulsion drilling fluid having an oleaginous continuous phase, a non-oleaginous discontinuous phase, and a fluid loss additive into a wellbore wherein the fluid loss additive comprises a quaternary ammonium compound containing at least one ester linkage. A method of servicing a wellbore comprising introducing a clay-free invert emulsion drilling fluid comprising distearoylethyl dimonium chloride to the wellbore. A wellbore servicing fluid comprising an invert emulsion drilling fluid having an oleaginous continuous phase, a non-oleaginous discontinuous phase, and a fluid loss additive into a wellbore wherein the fluid loss additive comprises an esterquat characterized by Structure A: | 11-21-2013 |
20140374099 | Invert Emulsion for Swelling Elastomer and Filtercake Removal in a Well - A treatment fluid and method for simultaneously swelling an oil-swellable elastomer and breaking a filtercake in a well. The treatment fluid includes an emulsion comprising: (i) a continuous oil phase, wherein the oil phase comprises: (a) an oil; and (b) an emulsifier; and (ii) an internal aqueous phase, wherein the aqueous phase comprises: (a) water; and (b) a water-soluble hydrolyzable ester of a carboxylic acid; wherein the emulsion is stable to hydrolysis of the water-soluble hydrolyzable ester of the carboxylic acid. A method of treating a well includes the steps of: (A) forming the treatment fluid; and (B) introducing the treatment fluid into the portion of the wellbore, wherein: (i) a filtercake has been previously formed in the portion of the wellbore, wherein the filtercake comprises an acid-soluble or an acid-degradable material; and (ii) an oil-swellable elastomer has been previously deposited or positioned in the portion of the wellbore. | 12-25-2014 |