Patent application number | Description | Published |
20090217776 | Real-Time Filtration Apparatus and Associated Methods - A fluid testing apparatus and associated method include a testing chamber, a filter storage device and a filter transfer mechanism. The testing chamber has a sample volume, a filtrate collection reservoir, an opening between the sample volume and the filtrate collection reservoir, and at least one port into the sample volume. The filter transfer mechanism positions at least one filter in the opening. The opening is closed and a sample fluid, introduced into the port, at least partially fills the sample volume. The sample volume is pressurized and a filtrate of the sample fluid flows from the sample volume, through the filter into the filtrate collection reservoir. The volume of filtrate passing into the filtrate collection reservoir is measured and the sample fluid from sample volume is discharged. The filtrate is discharged from the filtrate collection reservoir, and the filter transfer mechanism removes the filter. | 09-03-2009 |
20100139387 | Methods and Systems for Characterizing LCM Particle Plugging and Rheology in Real Time - Methods and systems for characterizing drilling fluids laden with LCM (Lost Circulation Material) and other solid materials are disclosed. A test cell for analyzing a fluid is provided with a first conical inner portion and an axial positioning device positioned along an axis of the test cell. A first conical plug is coupled to the axial positioning device and is movable in and out of the first conical inner portion along the axis of the test cell. A fluid inlet is positioned at a first location on the test cell and a fluid outlet at a second location. | 06-10-2010 |
20110167901 | METHODS TO CHARACTERIZE SAG IN FLUIDS - Systems and methods for direct and indirect measurement of the density of a fluid which exhibits sag characteristics is disclosed. The sag measurement system includes a test container for holding a fluid mixture to be analyzed and a suction port on the test container. A pump is coupled to the suction port for circulating the fluid mixture from the test container through a circulation loop. A measurement device is coupled to the circulation loop and a return port directs the fluid mixture from the circulation loop back to the test container at substantially the same vertical location as the suction port. The fluid mixture flowing through the circulation loop passes through the measurement device before returning to the test container through the return port. The measurement device is operable to monitor the particle distribution of the fluid mixture as it changes due to gravity. | 07-14-2011 |
20110203845 | SYSTEM AND METHOD FOR OPTIMIZING DRILLING SPEED - This invention presents various embodiments, including a system and a method, in which pressure-while-drilling data is gathered at a drilling rig and compared to modeled ECD pressure data related to the bore hole. The actual and modeled data are statistically analyzed to generate standard deviation data, which is used to infer information about how rapid a rate of penetration may safely be employed to optimize drilling results. | 08-25-2011 |
20130053284 | Modular Roller Oven and Associated Methods - A housing may include a test cell being enclosed and having at least one test cell wall and one sealable opening and has a cell central axis defined along the center line of the length of the test cell, a thermal element in thermal communication with the test cell, and an insulation, at least a portion of the insulation being disposed about the test cell and the thermal element. An apparatus may generally include a housing, a drive connection, and a shaft operably connected to the test cell and extending parallel to the cell central axis from the test cell through the insulation to the drive connection to which the shaft is operably connected. Testing a sample in the test cell of an apparatus operably connected to a driving mechanism may generally include at least manipulating the test cell and analyzing the sample. | 02-28-2013 |
20130112414 | Engineered Methods and Materials for Wellbore Strengthening in Subterranean Operations - 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. | 05-09-2013 |
20130139572 | METHODS TO CHARACTERIZE SAG IN FLUIDS - Systems and methods for direct and indirect measurement of the density of a fluid which exhibits sag characteristics is disclosed. The sag measurement system includes a test container for holding a fluid mixture to be analyzed and a suction port on the test container. A pump is coupled to the suction port for circulating the fluid mixture from the test container through a circulation loop. A measurement device is coupled to the circulation loop and a return port directs the fluid mixture from the circulation loop back to the test container at substantially the same vertical location as the suction port. The fluid mixture flowing through the circulation loop passes through the measurement device before returning to the test container through the return port. The measurement device is operable to monitor the particle distribution of the fluid mixture as it changes due to gravity. | 06-06-2013 |
20130139583 | METHODS TO CHARACTERIZE SAG IN FLUIDS - Systems and methods for direct and indirect measurement of the density of a fluid which exhibits sag characteristics is disclosed. The sag measurement system includes a test container for holding a fluid mixture to be analyzed and a suction port on the test container. A pump is coupled to the suction port for circulating the fluid mixture from the test container through a circulation loop. A measurement device is coupled to the circulation loop and a return port directs the fluid mixture from the circulation loop back to the test container at substantially the same vertical location as the suction port. The fluid mixture flowing through the circulation loop passes through the measurement device before returning to the test container through the return port. The measurement device is operable to monitor the particle distribution of the fluid mixture as it changes due to gravity. | 06-06-2013 |
20130186197 | METHODS TO CHARACTERIZE SAG IN FLUIDS - Systems and methods for direct and indirect measurement of the density of a fluid which exhibits sag characteristics is disclosed. The sag measurement system includes a test container for holding a fluid mixture to be analyzed and a suction port on the test container. A pump is coupled to the suction port for circulating the fluid mixture from the test container through a circulation loop. A measurement device is coupled to the circulation loop and a return port directs the fluid mixture from the circulation loop back to the test container at substantially the same vertical location as the suction port. The fluid mixture flowing through the circulation loop passes through the measurement device before returning to the test container through the return port. The measurement device is operable to monitor the particle distribution of the fluid mixture as it changes due to gravity. | 07-25-2013 |
20130192358 | METHOD AND APPARATUS FOR TESTING LOST CIRCULATION MATERIALS FOR SUBTERRANEAN FORMATIONS - An apparatus for testing lost circulation materials (“LCMs”) for use in a formation is disclosed. The apparatus may comprise a LCM cell that contains at least one formation simulation component. A pressurized tank may be in fluid communication with the LCM cell, and may force a sample LCM slurry into the LCM cell. An LCM receiver may also be in fluid communication with the LCM cell, and may receive the LCM slurry that flows through the LCM cell. | 08-01-2013 |
20130192360 | SYSTEMS, METHODS AND DEVICES FOR ANALYZING DRILLING FLUID - System, methods and devices for analyzing drilling fluids are presented herein. A fluid analysis system for determining at least one characteristic of a drilling fluid is disclosed. The system includes a pump and two reversible fluid ports each configured, when in a first state, to intake drilling fluid into the fluid analysis system and, when in a second state, to expel drilling fluid from the fluid analysis system. A valve fluidly couples the reversible fluid ports to the pump. The valve controls the respective states of the reversible fluid ports. At least one measurement module is fluidly coupled to the pump to receive drilling fluid therefrom. The at least one measurement module is configured to determine at least one characteristic of the drilling fluid. Filters can be fluidly coupled with each of the reversible fluid ports. The filters prevent solids of a predetermined size from entering the fluid analysis system. | 08-01-2013 |
20130217603 | USE OF NEUTRAL-DENSITY PARTICLES TO ENHANCE BARITE SAG RESISTANCE AND FLUID SUSPENSION TRANSPORT - The present invention relates to particles that are useful for enhancing hindered settling in suspensions. One embodiment of the present invention provides a method of providing a subterranean treatment fluid including a base fluid and a weighting agent having a first average settling velocity; and a neutral-density particle; and mixing the subterranean treatment fluid with the neutral-density particle thereby reducing the weighting agent to a second average settling velocity. | 08-22-2013 |
20130218545 | METHODS AND SYSTEMS FOR SUBTERRANEAN BORE HOLE FRACTURE SIMULATION - Apparatus and methods for simulation of bore hole fractures are disclosed. A device for simulating a fracture in a subterranean formation comprises a housing, an inlet for directing a sample fluid to the housing, and a first disk and a second disk positioned within the housing. The second disk is movable relative to the first disk to form an adjustable gap between the first disk and the second disk and the sample fluid flows through the adjustable gap. A common collector receives at least a portion of the sample fluid that flows through at least one of the first disk and the second disk. | 08-22-2013 |
20130226473 | Apparatus and Method for Constant Shear Rate and Oscillatory Rheology Measurements - A rheometer instrument including a stationary frame, a sleeve suspended from said frame, means for rotating the sleeve, a bob suspended within the sleeve, a cross-spring pivot suspending the bob from the stationary frame and a force rebalance system for effecting the rotational displacement of the bob with a torque. The force rebalance system includes an arm attached to the movable portion of the cross-spring pivot, a rotational position sensor in close proximity to the arm for measuring the rotational displacement and angular frequency of the arm, and a force actuator positioned to apply force to the arm. The rheometer instrument may be used to calculate the rheological properties of Newtonian and non-Newtonian fluids. | 08-29-2013 |
20130298662 | METHODS AND SYSTEMS FOR TESTING LOST CIRCULATION MATERIALS - Apparatus and methods for simulation of bore hole fractures are disclosed. A device for simulating a fracture in a subterranean formation comprises a housing, a gap in the housing, and one or more shims positioned inside the gap. The shims cover at least a portion of a surface of a wall forming the gap. The device further comprises an inlet for directing a sample fluid into the gap. The sample fluid flows through the gap and flows out of the gap through an outlet. | 11-14-2013 |
20130312511 | METHOD AND APPARATUS FOR AUTOMATICALLY TESTING HIGH PRESSURE AND HIGH TEMPERATURE SEDIMENTATION OF SLURRIES - A method and apparatus for automatically testing high pressure and high temperature sedimentation of slurries is described. The method includes pumping a sample drilling fluid into a test cell. The sample drilling fluid may be subjected to a pre-determined pressure and a pre-determined temperature for a pre-determined period of time. The test cell may also be oriented at non-vertical angle. The sample drilling fluid may be pumped out of the test cell and the density of the sample drilling fluid automatically measured relative to a displaced fluid volume of the sample drilling fluid. | 11-28-2013 |
20130314241 | OPTIMIZATION VISUALIZATION USING NORMALIZED ACHIEVEMENT VARIABLES - The present disclosure describes various systems and methods for creating and presenting optimization visualizations that use normalized achievement variables. At least one illustrative method includes defining achievement functions that each operates on at least one of several achievement variables (each of the achievement variables representing a characteristic of a physical object or process), and transforming value ranges for at least two achievement variables into corresponding achievement level ranges by applying at least one of the achievement functions to the value ranges of the achievement variables (the achievement variables being a function of at least one common control variable). The method further includes combining the corresponding achievement level ranges to produce a combined achievement level range, and presenting a visual representation of the combined achievement level range to a user, enabling the user to select value ranges for the common control variable. | 11-28-2013 |
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 |
20150027707 | ENGINEERED METHODS AND MATERIALS FOR WELLBORE STRENGTHENING IN SUBTERRANEAN OPERATIONS - 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. | 01-29-2015 |
20150330215 | SYSTEMS AND METHODS FOR MEASURING DOWNHOLE FLUID CHARACTERISTICS IN DRILLING FLUIDS - Disclosed are systems and methods for monitoring drilling fluids. One system includes a flow path containing a fluid having at least one component present therein, and a movable housing having at least one optical computing device configured to move with the movable housing along a detection path, the at least one optical computing device including at least one integrated computational element (ICE) configured to optically interact with the fluid over the detection path, wherein the at least one ICE is configured to detect a characteristic of the at least one component and generate an output signal corresponding to the characteristic. | 11-19-2015 |
20150354300 | FLEXURE MEMBRANE FOR DRILLING FLUID TEST SYSTEM - A disclosed dynamic receiver includes a housing defining a receiver chamber and having a first end cap at one end of the housing and a second end cap at an opposing end of the housing, a flexure membrane arranged within the receiver chamber and providing a membrane wall having a first end that is closed and arranged adjacent a fluid inlet into the receiver chamber and a second end that is open and secured to an inner wall of the receiver chamber, and a piston assembly movably arranged in the receiver chamber and including a piston head and a piston rod extending axially from the piston head, wherein, as filtrate from a test fluid enters the fluid inlet, the filtrate acts on the flexure membrane such that hydraulic fluid disposed within the membrane cavity is displaced and thereby moves the piston assembly axially within the receiver chamber. | 12-10-2015 |
20150360241 | ASSESSMENT AND CONTROL OF CENTRIFUGE OPERATION - A drilling fluid conditioning system can include a centrifuge, and at least one heat transfer property sensor that outputs real time measurements of a heat transfer property of a drilling fluid that flows through the centrifuge. A method can include measuring a heat transfer property of a drilling fluid, and determining, based on the measured heat transfer property, an operational parameter of a centrifuge through which the drilling fluid flows. A well system can include a drilling fluid that circulates through a wellbore, and a drilling fluid conditioning system including a centrifuge and at least one heat transfer property sensor that measures a heat transfer property of the drilling fluid. | 12-17-2015 |
20160024906 | DRILLING OPERATIONS THAT USE COMPOSITIONAL PROPERTIES OF FLUIDS DERIVED FROM MEASURED PHYSICAL PROPERTIES - The physical properties of a fluid may be used in deriving the compositional properties of the fluid, which may, in turn, be used to influence an operational parameters of a drilling operation. For example, a method may include drilling a wellbore penetrating a subterranean formation with a drilling fluid as part of a drilling operation; circulating or otherwise containing the drilling fluid in a flow path that comprises the wellbore; measuring at least one physical property of the drilling fluid at a first location and a second location along the flow path; deriving a compositional property of the drilling fluid at the first location and the second location based on the at least one physical property that was measured; comparing the compositional property of the drilling fluid at the first location and the second location; and changing an operational parameter of the drilling operation based on the comparison. | 01-28-2016 |
20160033382 | METHODS AND SYSTEMS FOR TESTING LOST CIRCULATION MATERIALS - Apparatus and methods for simulation of bore hole fractures are disclosed. A device for simulating a fracture in a subterranean formation comprises a housing, a gap in the housing, and one or more shims positioned inside the gap. The shims cover at least a portion of a surface of a wall forming the gap. The device further comprises an inlet for directing a sample fluid into the gap. The sample fluid flows through the gap and flows out of the gap through an outlet. | 02-04-2016 |
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 |
20130130945 | Drilling Fluids Having Reduced Sag Potential and Related Methods - Invert emulsion drilling fluids that have extended emulsion stability and reduced sag potential can be realized through incorporation of colloidal particles therein. The invert emulsion drilling fluids can be free of organophilic clays. The organophilic clay-free drilling fluids can comprise: an oleaginous fluid continuous phase; an aqueous fluid internal phase; a surfactant; a weighting agent; and a plurality of colloidal particles, the colloidal particles comprising fibrous colloidal particles and at least one other type of colloidal particle; wherein at least a portion of the plurality of colloidal particles interact with the surfactant to form an associative supporting structure that inhibits sag of the weighting agent. | 05-23-2013 |
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 |
20140118157 | Communication Using a Spacer Fluid - Disclosed are systems and methods for transmitting commands from a surface to downhole electronic equipment using pills of a spacer fluid. One method of communicating down a wellbore may include providing a flow of a first fluid along a flow path, introducing a series of one or more pills of a second fluid into the flow of the first fluid at a first point along the flow path, and detecting the series of one or more pills of the second fluid at a second point along the flow path, the second point being separated from the first point. In certain embodiments, a series of brine pills may be introduced into a flow of a drilling fluid. | 05-01-2014 |
20140151030 | Method of Inserting a Fiber Optic Cable into Coiled Tubing - Methods and apparatuses used with coiled tubing are disclosed. A method of inserting a fiber optic cable into coiled tubing is provided. The method comprises providing a coiled tubing having a first opening at a first end of the coiled tubing and a second opening at a second end of the coiled tubing. The fiber optic cable is fed into the first opening of the coiled tubing so that the fiber optic cable advances inside the coiled tubing along a direction from the first end to the second end. The fiber optic cable is vibrated during the feeding of the fiber optic cable into the coiled tubing. | 06-05-2014 |
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 |
20140166361 | Systems and Methods for Real Time Drilling Fluid Management - Disclosed are systems and methods for monitoring drilling fluid components in real time. One system includes solids control equipment fluidly coupled to a borehole and configured to receive drilling fluid from the borehole, the solids control equipment having a first optical computing device arranged adjacent the inlet and configured to optically interact with the drilling fluid as it enters the solids control equipment and thereby generate a first output signal corresponding to a characteristic of the drilling fluid, a second optical computing device arranged adjacent the outlet and configured to optically interact with the drilling fluid as it exits the solids control equipment and thereby generate a second output signal corresponding to the characteristic of the drilling fluid, and a signal processor communicably coupled to the first and second optical computing devices and configured to receive the first and second output signals and provide a resulting output signal. | 06-19-2014 |
20140166871 | Systems and Methods for Measuring Fluid Additive Concentrations for Real Time Drilling Fluid Management - Disclosed are systems and methods for monitoring drilling fluid components in real time. One system includes a flow path fluidly coupled to a borehole and containing a drilling fluid having at least one component present therein, an optical computing device arranged in the flow path and having at least one integrated computational element configured to optically interact with the drilling fluid and thereby generate optically interacted light, and at least one detector arranged to receive the optically interacted light and generate an output signal corresponding to a characteristic of the at least one component. | 06-19-2014 |
20140172177 | Systems and Methods for Real Time Monitoring of Gas Hydrate Formation - Disclosed are systems and methods for monitoring a drilling fluid for the formation of gas hydrates. One system includes a borehole containing a drilling fluid being circulated therethrough, a first optical computing device arranged in the borehole and having at least one integrated computational element configured to optically interact with the drilling fluid and detect one or more gas hydrates present therein, and at least one detector arranged to receive optically interacted light generated from optical interaction between the at least one integrated computational element and the drilling fluid, the at least one detector being configured to generate a first output signal corresponding to a characteristic of the one or more gas hydrates. | 06-19-2014 |
20140172305 | Systems and Methods for Real-Time Sag Detection - Disclosed are systems and methods for the real-time detection and measurement of sag within a deviated borehole. One method includes measuring a first pressure at a first time at a point within the borehole, predicting a characteristic of the drilling fluid at the point using a computer model, thereby obtaining a predicted characteristic, calculating the characteristic based on the first pressure, thereby obtaining a calculated characteristic, and determining whether sag has occurred based on a comparison between the calculated characteristic and the predicted characteristic. | 06-19-2014 |
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 |
20140209290 | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto - Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Such wellbore fluids may be included as a portion of a wellbore drilling assembly that includes a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid comprises a base fluid and a plurality of mineral particles, for example, mineral particles that comprise at least one selected from the group consisting of manganese carbonate, NixFe (x=2-3), copper oxide, and any combination thereof, the mineral particles having a median diameter between about 5 nm and about 5000 microns. | 07-31-2014 |
20140209307 | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto - Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in methods that include introducing a wellbore fluid having a density of about 7 ppg to about 50 ppg into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles, and the wellbore fluid having a first viscosity; contacting at least some of the mineral particles with a linking agent so as to link the at least some of the mineral particles, thereby increasing the first viscosity to a second viscosity. | 07-31-2014 |
20140209386 | Precipitated Particles and Wellbore Fluids and Methods Relating Thereto - A method of using precipitated particles in a wellbore may comprise circulating a wellbore fluid in a wellbore penetrating a subterranean formation, the wellbore fluid having a density of about 7 ppg to about 50 ppg and comprising a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star shaped, and any hybrid thereof. | 07-31-2014 |
20140209387 | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto - Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in a method that comprises introducing a wellbore fluid into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles that comprise at least one selected from the group consisting of manganese carbonate, NixFe (x=2-3), copper oxide, and any combination thereof, the mineral particles having a median diameter between about 5 nm and about 5000 microns. | 07-31-2014 |
20140209388 | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto - Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Methods of using mineral particles may include circulating a wellbore fluid with a first density of about 7 ppg to about 50 ppg in a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid, a plurality of first mineral particles, and a plurality of second mineral particles such that the first mineral particles and the second mineral particles are present in a first relative ratio, and the first mineral particles and the second mineral particles having a multiparticle specific gravity of about 3 to about 20; and changing the first relative ratio to a second relative ratio on-the-fly so as to yield the wellbore fluid with a second density. | 07-31-2014 |
20140209390 | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto - Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Such wellbore fluids may be included in systems that comprise a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid comprises a base fluid, a plurality of first mineral particles, and a plurality of second mineral particles such that the first mineral particles and the second mineral particles having a multiparticle specific gravity of about 3 to about 20. | 07-31-2014 |
20140209391 | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto - Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Such mineral particles may be included as a portion of a wellbore drilling assembly that includes a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid has a density of about 7 ppg to about 50 ppg and comprises a base fluid, a plurality of linkable mineral particles, and optionally a linking agent. | 07-31-2014 |
20140209392 | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto - A wellbore drilling assembly may include a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid comprises a base fluid and a wellbore additive. In some instances, a wellbore additive may include first mineral particles having a specific gravity of about 2.6 to about 20; second mineral particles having a specific gravity of about 5.5 to about 20; lubricant particles having a specific gravity of about 2.6 to about 20; wherein the first mineral particles, the second mineral particles, and the lubricant particles are different; and wherein the first mineral particles, the second mineral particles, and the lubricant particles have a multiparticle specific gravity of about 3 to about 20. | 07-31-2014 |
20140209393 | Precipitated Particles and Wellbore Fluids and Methods Relating Thereto - Precipitated mineral particles may provide for wellbore fluids with tailorable properties and capabilities. Such wellbore fluids may be included as a portion of a wellbore drilling assembly that includes a pump in fluid communication with a wellbore via a feed pipe; and a wellbore fluid disposed in at least one selected from the group consisting of the pump, the feed pipe, the wellbore, and any combination thereof, wherein the wellbore fluid has a density of about 7 ppg to about 50 ppg and comprises a base fluid and a plurality of precipitated particles having a shape selected from the group consisting of ovular, substantially ovular, discus, platelet, flake, toroidal, dendritic, acicular, spiked with a substantially spherical or ovular shape, spiked with a discus or platelet shape, rod-like, fibrous, polygonal, faceted, star-shaped, and any hybrid thereof. | 07-31-2014 |
20140213488 | Wellbore Fluids Comprising Mineral Particles and Methods Relating Thereto - Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. In some instances, a dry wellbore additive may comprise a plurality of first mineral particles having a specific gravity of about 2.6 to about 20; a plurality of second mineral particles having a specific gravity of about 5.5 to about 20; a plurality of lubricant particles having a specific gravity of about 2.6 to about 20; wherein the first mineral particles, the second mineral particles, and the lubricant particles are different; and wherein the first mineral particles, the second mineral particles, and the lubricant particles have a multiparticle specific gravity of about 3 to about 20. | 07-31-2014 |
20140231082 | METHODS AND COMPOSITIONS FOR TREATING SUBTERRANEAN FORMATIONS WITH INTERLOCKING LOST CIRCULATION MATERIALS - The present invention provides for methods of treating a fluid loss zone in a wellbore in a subterranean formation including providing interlocking notched particulates having an outer face comprising at least one notch therethrough; wherein the at least one notch has a shape and an inner perimeter value; providing interlocking protruding particulates having an outer perimeter portion that protrudes in an approximate equivalent to the shape and value of the inner perimeter of the at least one notch; introducing the interlocking protruding particulates and the interlocking notched particulates into the wellbore in the subterranean formation; interlocking the interlocking protruding particulates and the interlocking notched particulates through the at least one notch to form an interlocking network of at least one interlocking protruding particulate and at least one interlocking notched particulate; sealing at least a portion of the fluid loss zone. | 08-21-2014 |
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 |
20140238674 | Clean Fluid Loss Control Additives - Methods of providing fluid loss control in a portion of a subterranean formation comprising: providing a treatment fluid comprising a base fluid and a plurality of seeds; introducing the treatment fluid into a portion of a subterranean formation penetrated by a well bore such that the seeds block openings in the subterranean formation to provide fluid loss control; and degrading the seeds over time within the subterranean formation. In some methods, the seeds are present in the treatment fluid in an amount of at least about 5 pounds per barrel. In addition, in some methods the seeds are preferably degradable. | 08-28-2014 |
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 |
20140342950 | Methods for Use of Oil-Soluble Weighting Agents in Subterranean Formation Treatment Fluids - Methods of treating a subterranean formation including providing a treatment fluid comprising an oil-based fluid component and an oil-soluble weighting agent that comprises a metal, wherein the oil-soluble weighting agent has a density in the range of from about 1.1 g/cm | 11-20-2014 |
20140360786 | Lubricants for Oil-Based and Water-Based Fluids for Use in Subterranean Formation Operations - Methods of treatment subterranean formations including providing a treatment fluid comprising a base fluid and a lubricating agent, wherein the lubricating agent is selected from the group consisting of bismuth dialkyl dithiophosphate; tungsten disulfide; a mixture of micronized graphite and micronized metal disulfide; and any combination thereof; and introducing the treatment fluid into a wellbore in the subterranean formation. | 12-11-2014 |
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 |
20160068733 | WELLBORE FLUIDS COMPRISING MINERAL PARTICLES AND METHODS RELATING THERETO - Mineral particles may provide for wellbore fluids with tailorable properties and capabilities, and methods relating thereto. Mineral particles may be utilized in methods that include introducing a wellbore fluid having a density of about 7 ppg to about 50 ppg into a wellbore penetrating a subterranean formation, the wellbore fluid comprising a base fluid and a plurality of mineral particles, and the wellbore fluid having a first viscosity; contacting at least some of the mineral particles with a linking agent so as to link the at least some of the mineral particles, thereby increasing the first viscosity to a second viscosity. | 03-10-2016 |