Наддолотный измельчитель шлама

Изобретение относится к области бурения глубоких скважин, а именно к наддолотным измельчителям шлама. Устройство включает вал, сетку, ротор, отбойник. Вал выполнен заодно с фланцем и одноступенчатым лопастным насосом. Устройство снабжено сеткой, имеющей нижнюю крышку, снабженную патрубками, верхнюю крышку, внутренняя поверхность которой имеет канавки и образует с верхней поверхностью фланца, имеющей канавки, одноступенчатую мельницу. Крышки имеют отверстия, через эти отверстия устанавливается вал. Повышается эффективность работы и надежность устройства. 4 ил.

Downhole cutting seperator

Apparatus for catching debris in a well bore

APPARATUS FOR DRILLING OIL WELLS

Solids control methods, apparatus, and systems

Abrasive jet drilling assembly.

Device for transporting particles of a magnetic material and tool comprising such a device.

Device for transporting particles of magnetic material.

WITH A DEVICE FOR TRANSPORTING PARTICLES FROM A MAGNETIC MATERIAL EQUIPPED CUTTING TOOL

SPACER WITH SCREW-SHAPED SLOT

PROCEDURE AND ARRANGEMENT FOR THE ABRASIVE BLASTING BORING

Downhole debris retriever

DOWNHOLE DEBRIS RETRIEVER A method and apparatus for removing debris from a wellbore using a cleaning tool (100). The tool (100) may comprise an inner mandrel (17) and a cup member (20) coupled to the inner mandrel (17). The cup member (20) is moveable between a collapsed position where fluid may flow across the exterior of the cup member (20), and an extended position where fluid is diverted into a flow path disposed between the inner mandrel (17) and the cup member (20). The fluid is diverted through a filter member (30) that is coupled to the inner mandrel (17) below the cup member (20).

SEALED ROTARY BLAST HOLE DRILL BIT UTILIZING AIR PRESSURE FOR SEAL PROTECTION

Systems and methods for managing milling debris

Systems and methods of managing cuttings and debris resulting from milling a casing exit are disclosed. An exemplary milling system includes a mill arranged within a shroud and configured to translate axially with respect to the shroud once detached therefrom, a guide block is coupled to a distal end of the mill and supports the mill while the mill forms the casing exit. A guide support arranged within the shroud defining one or more longitudinal channels configured to accumulate cuttings and debris. The shroud defines a plurality of perforations arranged as first and second axial perforation sets, and a sleeve is arranged therein and defines one or more piston guides that align one or more pistons with either the first or second axial perforation sets, depending on the amount of cuttings and debris.

Dual circulation drilling system

A ground drill system 10 has a drill string 14 which forms first and second mutually isolated fluid paths 16 and 18 respectively. The drill string 14 has an up hole end 20 5 coupled to a dual circulation rotation head 22 and a down hole end 24 which is coupled to a drilling tool 12. The drilling tool 12 is operated by the flow of fluid delivered through the first flow path 16. A second fluid outlet 26 is provided intermediate the up hole end 20 and the drilling tool 12. The outlet 26 is in fluid communication with the second fluid flow path 18 and located a constant or fixed distance from the drilling toll 10 12. The second fluid outlet 26 discharges a flushing fluid flowing through the flushing flow path 18 into a hole being drilled by the drilling system 10. The rotation head 22 provides torque to the drill string 14 and thus the drilling tool 12.

Down hole bypass valve

Device for transporting particles of magnetic material

CONTINUOUS FLOW DRILLING SYSTEMS AND METHODS

In one embodiment, a method for drilling a wellbore includes injecting drilling fluid into a top of a tubular string disposed in the wellbore at a first flow rate. The tubular string includes: a drill bit tubular joints connected together, a longitudinal bore therethrough, and a port through a wall thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The cuttings and drilling fluid (returns) flow to the surface via an annulus defined between the tubular string and the wellbore. The method further includes rotating the drill bit while injecting the drilling fluid; remotely removing a plug from the port, thereby opening the port; and injecting drilling fluid into the port at a second flow rate while adding a tubular joint or stand of joints to the tubular string. The injection of drilling fluid is continuously maintained between drilling and adding the joint or stand to the drill string. The method further includes remotely installing a plug into the port ...

DOWNHOLE TOOL FOR BOREHOLE CLEANING OR FOR MOVING FLUID IN A BOREHOLE

The present invention relates to a downhole tool (1) for borehole cleaning or for moving fluid in a borehole. The tool comprises a tool housing (29), a chamber inlet (6) and a chamber outlet (36), and the tool housing comprises a pump (8) arranged in a pump housing (4) and a driving unit powered by an electrical conducting means for driving the pump.

ROTATING SHAFT SEAL AND BEARING LUBRICATING APPARATUS

ROTATING SHAFT SEAL AND BEARING LUBRICATING APPARATUS An accordance with an illustrative embodiment of the present invention, a seal or bearing lubricating system adapted for use in a downhole tool such as a drilling motor includes chamber means packed with grease for lubricating said seal and/or bearing, and centrifugal separator means responsive to rotation of a shaft included in said tool for separating and trapping solid particles suspended in the well fluids to prevent contamination of the grease by such solid particles.

TWO STAGE DOWNHOLE DRILLING FLUID FILTER

A two stage filter for drilling fluid using downhole tools filters solid materials from the drilling fluid and has a first, outer filter section and a second, inner filter section. A portion of the drilling fluid flowing through the first section is received by the second section, and passed on to the fluid using device of the tool. A flow area of the first filter section is greater than a flow area of the second filter section.

SEALED BEARING ROLLER CONE BIT HAVING ANTI-PLUGGING DEVICE

A roller cone drill bit is disclosed which includes a bit body having at least one leg depending from the bit body. The leg has a journal formed on its at a lower end. The bit body includes an air channel extending at least from an interior of the bit body to the seal area of the journal. A roller cone is sealingly, rotatably mounted on the journal. The cone has a plurality of cutting elements disposed on it. The bit includes a backflow valve disposed in the bit body, so that an intake end of the air channel is disposed upstream of the backflow valve. In one embodiment, the backflow valve is disposed in a connection end of the bit body, and the air channel includes a flow tube extending from the air passage in the bit body to the backflow valve so that its intake end is upstream of the backflow valve.

ROCK BIT WATER DEFLECTOR AND SEPARATOR

INVERT EMULSION BASED DRILLING FLUID AND METHODS OF USING SAME

A drilling fluid composition which includes a base fluid, one or more additives, and a viscosifier package. The base fluid is an invert emulsion comprising oil and water. Further, the one or more additives is chosen from an emulsifier, a weighting material, a fluid-loss control additive, or an alkaline compound. The viscosifier package includes a fatty acid having 6 or more carbon atoms and an aliphatic polyester. The drilling fluid composition has a yield point of from 30 lbf/100ft2 to 100 lbf/100ft2 and a low shear yield point of from 10 lbf/100ft2 to 40 lbf/100ft2. The associated method of drilling a subterranean well including operating a drill in a wellbore in the presence of the drilling fluid composition is also provided.

METHOD AND APPARATUS FOR THE DOWNHOLE TRANSFER OF DRILL CUTTINGS

A drilling fluid delivery system for drilling boreholes with a drill bit, includes a primary flow circuit having a relatively high flow rate for transferring drilling fluid to and from the drill bit. The system also includes a secondary flow circuit having a relatively low flow rate for transferring drilling fluid to and from the primary flow circuit. Furthermore, the system includes a cuttings transfer system, such as a hydrocyclone or a rotating filter, between the primary and secondary flow circuits. When the cutting transfer system is in use, it receives fluid containing cuttings from the primary circuit and separates the fluid into a first stream that contains substantially no cuttings and a second stream containing cuttings. The first stream is returned to the primary flow circuit and the second stream is directed to the secondary flow circuit.

SELF-CLEANING FILTER

An assembly can include a filter body having an open end and a closed end. The filter body can also include a plurality of perforations. A fan may be positionable within the filter body. The fan may include a mount that extends along a length of the fan. A blade may be coupled to and extend from the mount. The fan may also include an outer edge of the blade for contacting an inner surface of the filter body.

MODULAR DOWNHOLE DEBRIS SEPARATING ASSEMBLIES

A downhole system can include multiple sub-components of a downhole debris separator assembly that is modular. The system can also include multiple couplers arranged on or among the sub-components of the multiple sub-components. Each of the couplers can connect with others of the couplers in different combinations to form respectively different configurations of the downhole debris separator assembly.

METHOD AND DEVICE FOR TRENCHLESS PIPE LAYING

The invention relates to a boring and laying device for trenchless pipe laying, comprising a boring head for loosening the rock, said boring head having a connection for a pilot bore linkage; a pump for suctioning and discharging debris loosened by the boring head; a transport portion behind the boring head, at least one suction element being provided in said transport portion for receiving and discharging the loosened rock; and a connecting portion which has a connection for the pipeline. The invention also relates to a boring and laying method for trenchless pipe laying, wherein a pilot boring process is carried out from a starting point to a destination along a specified boring line. The pilot boring process is carried out by advancing a pilot boring head with a pilot bore linkage, a boring and laying head being connected to an end of the pilot bore linkage after reaching the destination. The boring and laying head is connected to the pipeline and is used to expand the borehole, and ...

METHOD AND DEVICE FOR TRENCHLESS PIPE LAYING

The invention relates to a boring and laying device for the trenchless laying of a pipeline, with a boring head for loosening the rock, wherein the boring head has a connection for a pilot bore linkage, with a pump for suctioning and conveying away the drillings loosened by the boring head, with a conveying portion behind the boring head in which at least one suction element for receiving and conveying away the loosened rock is provided, and with a connecting portion which has a connection for the pipeline, and to a boring and laying method for the trenchless laying of a pipeline, in which a pilot bore is produced from a starting point to a destination point along a predetermined boring line, wherein the pilot bore is obtained by advancing a pilot boring head with a pilot bore linkage, and in which, after reaching the destination point, a boring and laying head is connected to one end of the pilot bore linkage, which head is connected to the pipeline and via which the borehole is expanded ...

DEBRIS CATCHER

A debris catcher and system is provided for removing debris from fluids such as in wellbore stimulation operations. A generally tubular housing axially supports a tubular screen inside a housing bore. Debris-laden fluid flows from an intake end of the housing axially into the bore of the screen and exits screen openings radially into an axially elongated flow annulus formed between a tubular wall of the screen body and the housing bore. Debris is retained in the upstream portion of screen body and clean fluid, in the annulus, returns downstream of the screen for exit out a discharge end of the housing. The screen is removably installable to the housing.

DOWNHOLE DEBRIS RETRIEVER

A method and apparatus (100) for removing debris from a wellbore using a cleaning tool. The tool may comprise an inner mandrel (17) and a cup member (20) coupled to the inner mandrel. The cup member is moveable between a collapsed position where fluid may flow across the exterior of the cup member, and an extended position where fluid is diverted into a flow path disposed between the inner mandrel and the cup member. The fluid is diverted through a filter member (30) that is coupled to the inner mandrel below the cup member.

DISTANCE HOLDER WITH HELICAL SLOT

A distance holder (1) for connection to, and rotation with, a drill string in an earth formation drilling device arranged to supply a jet of abrasive fluid for the purpose of providing a borehole (4) by removing earth formation material through abrasion, comprises a housing with a chamber (13) which is essentially rotational symmetric and which is to face the earth formation material, and a jet nozzle (10) which arranged for discharging a jet of the abrasive fluid in said chamber, said housing comprising at least one slot (18) for allowing the abrasive fluid to leave the chamber. The slot is continued over the housing outer surface so as to counteract rolling motions of the particles which are comprised in the abrasive fluid.

CONTINUOUS FLOW DRILLING SYSTEMS AND METHODS

In one embodiment, a method for drilling a wellbore includes injecting drilling fluid into a top of a tubular string disposed in the wellbore at a first flow rate. The tubular string includes: a drill bit disposed on a bottom thereof, tubular joints connected together, a longitudinal bore therethrough, and a port through a wall thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The cuttings and drilling fluid (returns) flow to the surface via an annulus defined between the tubular string and the wellbore. The method further includes rotating the drill bit while injecting the drilling fluid; remotely removing a plug from the port, thereby opening the port; and injecting drilling fluid into the port at a second flow rate while adding a tubular joint or stand of joints to the tubular string. The injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the joint or stand to the drill string. The method further ...

SUB-ASSEMBLY FOR LUBRICATING ROCK DRILL BIT

A lubricating sub-assembly for a rock drill, comprising a housing with means to couple the housing into a drill string carrying a drill bit at its front end, a cavity disposed within the housing for holding a predetermined amount of a bearing lubricant, means for communicating the interior of the cavity with one or more air circulation passages provided in the bit leading to bearings within the drill bit, and means for dispensing a preset amount of lubricant from the cavity to the communicating means.

DOWN HOLE BYPASS VALVE

The invention relates to bypass valves for use in wellbores, particularly but not exclusively to bypass valves used during the setting of hydraulic anchor packers. The invention provides a bypass valve for selectively isolating the interior of a down-hole assembly from the exterior thereof, the bypass valve comprising constraining means (42, 44, 52) being adapted to permit movement of a piston (30) from a first position to a second position in response to a predetermined pressure differential between a bore (58) of the piston (30) and the exterior of a boy (4) but normally preventing movement of the piston (30) to a third position in which the bore (58) of the piston (30) is substantially isolated from the exterior of the body (4), and overriding means for overriding the constraining means (42, 44, 52) so as to permit movement of the piston (30) to the third position. The invention thereby provides a bypass valve which resists any tendency to close prematurely and which communicates any ...

Appareil à soupape destiné à être monté dans une chaîne de forage

ГАЗОСЕПАРАТОР

Устройство для отделения газа от жидкости, скомбинированное с устройством для гидравлического бурения, включает в себя корпус (1), содержащий вращающийся барабан (2), статор (6), расположенный во входном конце корпуса (1) и предназначенный для закручивания газожидкостной смеси, ротор (9), прикрепленный к барабану (2) с возможностью вращения указанной смесью, с обеспечением отделения газа от жидкости. Жидкость и газ выпускаются через раздельные суженные отверстия (28, 32) за барабаном. Во вращающейся головке (43) могут быть расположены отверстия (44, 59) для чистки, проходки или других внутрискважинных операций.

СПОСОБ И УСТРОЙСТВО ДЛЯ УПРАВЛЕНИЯ БУРОВЫМ РАСТВОРОМ ПЕРЕМЕННОЙ ПЛОТНОСТИ

Описаны способ и система для бурения ствола скважины. Система включает ствол скважины с буровым раствором переменной плотности, бурильную трубу, оборудование низа бурильной колонны, расположенное в стволе скважины, и установку для обработки бурового раствора в жидкостной связи со стволом скважины. Буровой раствор переменной плотности содержит сжимаемые частицы и буровую жидкость. Оборудование низа бурильной колонны соединено с бурильной трубой, а установка для обработки бурового раствора обеспечивает отделение сжимаемых частиц от бурового раствора переменной плотности. Сжимаемые частицы в данном варианте осуществления могут включать сжимаемые полые объекты, заполненные сжатым газом, поддерживающие плотность бурового раствора между градиентом давления гидроразрыва и градиентом порового давления. Кроме того, указанные система и способ могут также управлять использованием сжимаемых частиц, имеющих различные характеристики, такие как размер, в ходе буровых работ.

СТРУЙНО-АБРАЗИВНАЯ УСТАНОВКА ДЛЯ БУРЕНИЯ

... 1. Установка для бурения скважины в земной породе, включающая колонну бурильных труб (1), расположенную внутри скважины (2), струйное устройство (5), укрепленное на нижнем конце колонны бурильных труб, камеру смешения (10), имеющую первый вход (12), сообщающийся по жидкости с каналом (9, 9а) подачи бурового раствора, второй вход (14) для абразивных частиц и выход (15), который сообщается по жидкости со струйным соплом, предназначенным для формирования струи из потока, включающего абразивные частицы и буровой раствор, направленной, по меньшей мере, на дно (7) скважины или стенку скважины, и систему рециркуляции абразивных частиц для отделения абразивных частиц от бурового раствора, отличающаяся тем, что струйное устройство (5) снабжено камерой смешения (10) и системой рециркуляции абразивных частиц, а также тем, что система рециркуляции абразивных частиц выполнена так, чтобы обеспечивать отделение абразивных частиц от бурового раствора в выбранном месте, где поток течет от, по меньшей мере ...

ГАЗОСЕПАРАТОР

Устройство для отделения газа от жидкости, скомбинированное с устройством для гидравлического бурения, содержит корпус (1), содержащий вращающийся барабан (2), статор (6), расположенный во входном конце корпуса (1) и предназначенный для закручивания газожидкостной смеси, ротор (9), прикрепленный к барабану (2) с возможностью вращения указанной смесью, с обеспечением отделения газа от жидкости. Жидкость и газ выпускаются через раздельные суженные отверстия (28, 32) за барабаном. Во вращающейся головке (43) могут быть расположены отверстия (44, 59) для чистки, проходки или других внутрискважинных операций.

SYSTEM (VERSIONS) AND METHOD (VERSIONS) CONTROL RUBBLE, FORMED IN MILLING BLANK IN THE WELL

METHOD AND TOOL FOR FRACTURING AN UNDERGROUND FORMATION

PROCEDE POUR EPURER LES LIQUIDES UTILISES DANS LES FORAGES DE SOLS ET DISPOSITIF POUR SA MISE EN OEUVRE

La présente invention concerne un procédé pour épurer les liquides utilisés dans les excavations de sols, caractérisé par le fait qu'il consiste à créer un courant circulatoire dans le liquide contenu dans l'excavation, à séparer les particules de détritus en suspension, à les recueillir et à les évacuer hors de l'excavation, à l'aide d'un dispositif caractérisé par le fait qu'il comprend un corps A' constitué par une enveloppe 14a fermée par un chapeau 120a qui retient un moteur B; le chapeau 120a présente une chambre cylindrique 66a dans laquelle est logée la couronne mobile G1 d'une pompe assujettie à l'arbre 26a. L'invention est particulièrement utilisée dans les forages de sols.

TRAIN OF DRILLING

OUTIL DE HAVAGE, EN PARTICULIER POUR DES MACHINES POUR TRACAGES EN VEINE

OUTIL DE HAVAGE COMPRENANT UN PIC DE HAVAGE ET UN SUPPORT DE PIC 2, LE SUPPORT DE PIC PRESENTANT UN INJECTEUR DE REFRIGERANT POUR LE PIC DE HAVAGE ET UN CONDUIT DE REFRIGERANT MENANT VERS L'INJECTEUR. CE CONDUIT DE REFRIGERANT EST SUBDIVISE EN UN ALESAGE D'APPUI POUR L'INJECTEUR DE REFRIGERANT ET UN ALESAGE D'ALIMENTATION 4B. L'ALESAGE D'ALIMENTATION PRESENTE UNE SECTION BEAUCOUP PLUS GRANDE QUE L'ALESAGE D'APPUI ET IL EST ACCESSIBLE PAR L'EXTERIEUR. DANS L'ALESAGE D'ALIMENTATION EST ENGAGE UN FILTRE DE REFRIGERANT AVEC UNE SURFACE FILTRANTE PLUS GRANDE ENCONSEQUENCE DE TELLE FACON QU'UN FILTRE A MAILLES RELATIVEMENT SERREES PEUT ETRE UTILISE SANS RISQUE D'ENCRASSEMENT. IL EN RESULTE LA POSSIBILITE DE MONTER, SANS RISQUE D'OBSTRUCTION, UN INJECTEUR DE REFRIGERANT AVEC UNE SECTION DE TUYERE RELATIVEMENT FAIBLE DE TELLE FACON QUE L'ARROSAGE ET DONC LE REFROIDISSEMENT DU PIC DE HAVAGE PEUVENT ETRE ASSURES AVEC UN DEBIT DE REFRIGERANT REDUIT LEQUEL NE PROVOQUE PLUS DE GENE POUR LES TRAVAUX ...

Retarded acid systems, emulsions, and methods for using in acidizing carbonate formations

In one embodiment, a retarded acid system comprises an aqueous acid and a retarding surfactant. The aqueous acid may comprise from 5 wt. % to 25 wt. % of a strong acid, that is, an acid having a K a greater than or equal to 0.01. The aqueous acid may further comprise from 75 wt. % to 95 wt. % water. The retarding surfactant may have the general chemical formula R—(OC 2 H 4 ) X —OH where R is a hydrocarbon having from 11 to 15 carbon atoms and x is an integer from 6 to 10. The retarding surfactant may have a hydrophilic-lipophilic balance from 8 to 16.

Consolidating Spacer Fluids and Methods of Use

Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus. 1. A method of evaluating a spacer fluid for use in separating a drilling fluid and a cement composition in a well bore comprising:providing the spacer fluid, wherein the spacer fluid comprises kiln dust; andmeasuring a transition time and/or zero gel time of the spacer fluid.2. The method of wherein the transition time of the spacer fluid is about 45 minutes or less at well bore conditions.3. The method of wherein the transition time of the spacer fluid is about 20 minutes or less at a temperature in a range of from about 40° F. to about 300° F. and a pressure in a range of from about 2 claim 1 ,000 psi to about 10 claim 1 ,000 psi.4. The method of further comprising measuring a compressive strength of the spacer fluid.5. The method of further comprising: providing a cement composition claim 1 , measuring a transition time of the cement composition claim 1 , and comparing the transition time of the cement composition and the transition time of the spacer fluid claim 1 , wherein the transition time of the spacer fluid is shorter than the transition time of the cement composition.6. The method of wherein the zero gel time of the spacer fluid is about 4 hours or less at well bore conditions.7. The method of further comprising: providing a cement composition claim 1 , measuring a zero gel time of the cement composition claim 1 , and comparing the zero gel time of the cement composition and the zero gel time of the spacer fluid.8. The method of wherein the zero gel time of the spacer fluid is longer than the zero time of the cement composition.9. The method of wherein the spacer fluid is foamed and has a density in a range of from about 4 pounds per gallon to about 13 pounds per gallon.10. The method of wherein the kiln dust is selected from the group consisting of cement kiln ...

METHOD AND APPARATUS FOR MANAGING VARIABLE DENSITY DRILLING MUD

EXCAVATION DEVICE AND METHOD FOR CREATING A HOLE

Die Erfindung betrifft ein Tiefbaugerät zum Erstellen eines Lochs im Boden mit einem Geräterahmen, einer Halteeinrichtung an einem oberen Bereich des Geräterahmens zum Halten des Tiefbaugerätes an einem Tragseil oder einer Tragstange, einer Abtragseinrichtung, welche mindestens ein drehend antreibbares Abtragselement aufweist und an einem unteren Endbereich des Geräterahmens angeordnet und zum Abtragen von Bodenmaterial ausgebildet ist, einem am Geräterahmen angeordneten Antrieb zum drehenden Antreiben des mindestens einen Abtragselementes und einer Absaugeinrichtung zum Absaugen von abgetragenem Bodenmaterial zusammen mit einer Flüssigkeit, die sich im Loch befindet, nach oben mittels einer Absaugleitung, wobei die Absaugeinrichtung mindestens eine Absaugöffnung am unteren Endbereich des Geräterahmens und eine Absaugpumpe umfasst, die am Geräterahmen angeordnet ist. Nach der Erfindung ist vorgesehen, dass die Absaugleitung in einer Verteileinheit mündet, welche am Geräterahmen angeordnet ...

Self-cleaning filter

An assembly can include a filter body having an open end and a closed end. The filter body can also include a plurality of perforations. A fan may be positionable within the filter body. The fan may include a mount that extends along a length of the fan. A blade may be coupled to and extend from the mount. The fan may also include an outer edge of the blade for contacting an inner surface of the filter body.

Lateral well drilling apparatus and method

Downhole cutting separator

A downhole cutting separator is disclosed. The separator can be mounted anywhere on the drillstring. The separator employs a seal (35) which directs the normally circulating fluid during the cutting or milling operation in through an internal passage (60) in the tool. The cutting-laden fluid passes though a slotted liner (16) where the cuttings drop out and are collected in a compartment (24) within the tool. The circulating fluid exits the tool into the annulus. The tools can be used in series so that the lowermost tool takes out the large cuttings, while an upper tool takes out the finer cuttings. Provisions can be made to bypass the tool should it become plugged with cuttings by using rupture discs or movable sleeves responsive to pressure differential. A portion of the body assembly (30) can be magnetic to further assist in removal of cuttings as the circulating flow passes through the tool.

Self-lubricating well tools and seal elements therefor

A seal element for oil well tools, such as drilling cutters and roller reamers, which allows the drilling media to permeate into the bearing system of the cutter to cool and lubricate the internal mechanism. The seal element is adapted to control the particle size of contaminants flowing into the bearing system by filtering the drilling media. The bearings act as agitators during operation of the cutter to promote fluid motion through the bearing system. The seal and lubrication system may be utilized as a back-up to the conventional lubrication supply or as supplemental lubrication.

CUTTING TOOL FOR GALLERY DRIVING MACHINES

Two stage filter assembly

Downhole material retention apparatus

Lateral well drilling apparatus and method

Securing an internal assembly within a tool

A tool includes an internal assembly configured to be positioned at least partially within a body. The tool also includes a collet configured to be positioned at least partially within the body and axially-adjacent to the internal assembly. The collet includes a plurality of fingers that are circumferentially-offset from one another. At least one of the fingers includes a protrusion that extends radially-outward and is configured to be positioned at least partially within a recess formed in an inner surface of the body to secure the collet in place with respect to the body. The tool also includes a collet pin configured to be positioned at least partially within the body, axially-adjacent to the internal assembly, and at least partially within the collet. The collet pin is configured to contact the internal assembly to secure the internal assembly in place within the body.

Wellbore treatment fluids with no-heat liquid solder additives

Sinking drilling hammer

PNEUMATIC RAMMING DRILLING EQUIPMENT.

Sealed bearing roller cone bit having anti-plugging device

Drilling debris separator

In accordance with embodiments of the present disclosure, a debris separator device for use with a casing system may include an impeller having a plurality of blades to generate a vortex of mud in the section of the casing system when the casing system is lowered into a wellbore. The device may also include a baffle disposed in the section of the casing system, the baffle having an annular cup shape that forms an outer circumferential pocket to capture debris from the vortex of mud. The impeller and baffle may enable the debris separator device to separate debris and other debris from a flow of mud through the casing system so that the debris does not clog a float collar of the system. The disclosed debris separator device may be flushable so that the device does not become clogged with debris and can thereby maintain auto-fill through the casing system.

Method and system for sealing an annulus enclosing a tubular element

The invention provides a method and system for sealing an annulus enclosing a tubular element in a wellbore. The method comprises the steps of: i) introducing a first drilling fluid in the wellbore; ii) drilling an open hole section of the wellbore using a drilling tool suspended at the end of a tool string; iii) pumping a second drilling fluid comprising particles into the wellbore; iv) filtering the particles out of the second drilling fluid near a downhole end of the tubular element; v) extending the tubular element into the open hole section of the wellbore while directing at least part of the filtered particles to an annulus between the tubular element and a wellbore wall. Steps i) to v) may be repeated as often as required.

ABRASIVE JET DRILLING ASSEMBLY

A drilling assembly for drilling a borehole into an earth formation is provided, comprising drill string extending into the borehole and a jetting device arranged at a lower part of the drill string, the jetting device being provided with a mixing chamber having a first inlet in fluid communication with a drilling fluid supply conduit, a second inlet for abrasive particles and an outlet which is in fluid communication with a jetting nozzle arranged to jet a stream of abrasive particles and drilling fluid against at least one of the borehole bottom and the borehole wall. The jetting device is further provided with an abrasive particles recirculation system for separating the abrasive particles from the drilling fluid at a selected location where the stream flows from said at least one of the borehole bottom and the borehole wall towards the upper end of the borehole and for supplying the separated abrasive particles to the second inlet.

GAS SEPARATOR

A combination liquid and gas separator and jetting tool includes a housing (1) containing a rotatable drum (2), a stator (6) in the inlet end of the housing (1) for swirling a liquid/gas mixture, a rotor (9) attached to the drum (2) for rotation by the mixture; whereby the gas and liquid are separated. The liquid and gas are discharged through separate restricted orifices (28, 32) downstream of the drum. Orifices (44, 59) can be located in a rotating head (43) for cleaning, cutting or other downhole operations.

METHOD AND TOOL FOR FRACTURING AN UNDERGROUND FORMATION

A method for fracturing an underground formation (2) surrounding an oil and/or gas well comprises positioning a fracturing tool (3) in a selected orientation in the borehole (1) and expanding the tool such that it exerts a circumferentially varying pressure against the borehole wall over a selected period of time thereby initiating in the surrounding formation one or more fractures,(11, 12) which each intersect the borehole wall in a selected orientation and simultaneously injecting a proppant into the fracture(s).

TWO STAGE DOWNHOLE DRILLING FLUID FILTER

A two stage filter for drilling fluid using downhole tools filters solid materials from the drilling fluid and has a first, outer filter section and a second, inner filter section. A portion of the drilling fluid flowing through the first section is received by the second section, and passed on to the fluid using device of the tool. A flow area of the first filter section is greater than a flow area of the second filter section.

FLUID JET DRILLING TOOL

GAS SEPARATOR

LONGITUDINALLY OFFSET PARTIAL AREA SCREENS FOR WELL ASSEMBLY

A downhole assembly can include screens along a length of a tubular member. Screens covering differing portions of a cross-sectional area of the tubular and less than an entirety of the cross-sectional area can be offset from one another along a length of the tubular. Fluid flowing through an area not covered by a first screen can encounter an area covered by an offset screen. If the offset screen is blocked with accumulated debris, fluid may pass the offset screen by passing through an area not covered by the offset screen.

LONGITUDINALLY OFFSET PARTIAL AREA SCREENS FOR WELL ASSEMBLY

A downhole assembly can include screens along a length of a tubular member. Screens covering differing portions of a cross-sectional area of the tubular and less than an entirety of the cross-sectional area can be offset from one another along a length of the tubular. Fluid flowing through an area not covered by a first screen can encounter an area covered by an offset screen. If the offset screen is blocked with accumulated debris, fluid may pass the offset screen by passing through an area not covered by the offset screen.

CONTINUOUS FLOW DRILLING SYSTEMS AND METHODS

In one embodiment, a method for drilling a wellbore includes injecting drilling fluid into a top of a tubular string disposed in the wellbore at a first flow rate. The tubular string includes: a drill bit disposed on a bottom thereof, tubular joints connected together, a longitudinal bore therethrough, and a port through a wall thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The cuttings and drilling fluid (returns) flow to the surface via an annulus defined between the tubular string and the wellbore. The method further includes rotating the drill bit while injecting the drilling fluid; remotely removing a plug from the port, thereby opening the port; and injecting drilling fluid into the port at a second flow rate while adding a tubular joint or stand of joints to the tubular string. The injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the joint or stand to the drill string. The method further ...

CONTINUOUS FLOW DRILLING SYSTEMS AND METHODS

In one embodiment, a method for drilling a wellbore includes injecting drilling fluid into a top of a tubular string disposed in the wellbore at a first flow rate. The tubular string includes: a drill bit disposed on a bottom thereof, tubular joints connected together, a longitudinal bore therethrough, and a port through a wall thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The cuttings and drilling fluid (returns) flow to the surface via an annulus defined between the tubular string and the wellbore. The method further includes rotating the drill bit while injecting the drilling fluid; remotely removing a plug from the port, thereby opening the port; and injecting drilling fluid into the port at a second flow rate while adding a tubular joint or stand of joints to the tubular string. The injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the joint or stand to the drill string. The method further ...

METHOD AND ASSEMBLY FOR ABRASIVE JET DRILLING

A method for operating an earth formation drilling device (1) arranged to supply a jet of abrasive fluid for the purpose of providing a borehole by removing earth formation material through abrasion, comprises a drill string and a drilling assembly connected to the drill string. Said drilling assembly comprises a jetting device with a mixing space (13), a drilling fluid, a particle inlet (12), an abrasive fluid outlet (40) for discharging a mixture of drilling fluid and magnetic particles, and a magnetic particle circulation system comprising a supporting surface which is exposed to a return stream along the drilling assembly. Furthermore, a magnetic device (9) is provided for attracting the magnetic particles onto the supporting. Said method is characterized buy the steps of : -fixing the magnetic device with respect to the supporting surface, -selecting a magnetic field density which increases along the sloping supporting surface towards, the entrance, -attracting magnetic particles onto ...

DUAL CIRCULATION DRILLING SYSTEM

A ground drill system (10) has a drill string 14 which forms first and second mutually isolated fluid paths (16 and 18) respectively. The drill string (14) has an up hole end (20) coupled to a dual circulation rotation head (22) and a down hole end (24) which is coupled to a drilling tool (12). The drilling tool (12) is operated by the flow of fluid delivered through the first flow path (16). A second fluid outlet (26) is provided intermediate the up hole end (20) and the drilling tool (12). The outlet (26) is in fluid communication with the second fluid flow path (18) and located a constant or fixed distance from the drilling toll (2). The second fluid outlet (26) discharges a flushing fluid flowing through the flushing flow path (18) into a hole being drilled by the drilling system (10). The rotation head (22) provides torque to the drill string (14) and thus the drilling tool (12).

DOWN HOLE BYPASS VALVE

The invention relates to bypass valves for use in wellbores, particularly bu t not exclusively to bypass valves used during the setting of hydraulic anchor packers. The invention provides a bypass valve for selectively isolating the interior of a down-hole assembly from the exterior thereof, the bypass valve comprising constraining means (42, 44 , 52) being adapted to permit movement of a piston (30) from a first position to a second position in response to a predetermined pressur e differential between a bore (58) of the piston (30) and the exterior of a boy (4) but normally preventing movement of the piston (30) to a third position in which the bore (58) of the piston (30) is substantially isolated from the exterior of the body (4), and overriding means for overriding the constraining means (42, 44, 52) so as to permit movement of the piston (30) to the third position. The invention thereby provides a bypass valve which resists any tendency to close prematurely and which communicates ...

ИНСТРУМЕНТ ДЛЯ ВЫКАПЫВАНИЯ ОБЪЕКТА

Инструмент для выкапывания объекта содержит устройство для транспортировки частиц магнитного материала в выбранном направлении, имеющее опорный элемент, имеющий опорную поверхность (21), предназначенную для поддержки частиц и проходящую в заданном направлении, магнит (28), предназначенный для генерирования магнитного поля, удерживающего магнитные частицы на опорной поверхности и имеющего на опорной поверхности по меньшей мере один участок (32) с пониженной напряженностью поля по сравнению с напряженностью магнитного поля на опорной поверхности за пределами указанного участка, и приводное средство (36) для перемещения каждого участка с пониженной напряженностью поля относительно опорной поверхности в направлении, имеющем компонент в заданном направлении.

СПОСОБ И УСТРОЙСТВО ДЛЯ УПРАВЛЕНИЯ БУРОВЫМ РАСТВОРОМ ПЕРЕМЕННОЙ ПЛОТНОСТИ

Описаны способ и система для бурения ствола скважины. Система включает ствол скважины с буровым раствором переменной плотности, бурильную трубу, оборудование низа бурильной колонны, расположенное в стволе скважины, и установку для обработки бурового раствора в жидкостной связи со стволом скважины. Буровой раствор переменной плотности содержит сжимаемые частицы и буровую жидкость. Оборудование низа бурильной колонны соединено с бурильной трубой, а установка для обработки бурового раствора обеспечивает отделение сжимаемых частиц от бурового раствора переменной плотности. Сжимаемые частицы в данном варианте осуществления могут включать сжимаемые полые объекты, заполненные сжатым газом, поддерживающие плотность бурового раствора между градиентом давления гидроразрыва и градиентом порового давления. Кроме того, указанные система и способ могут также управлять использованием сжимаемых частиц, имеющих различные характеристики, такие как размер, в ходе буровых работ.

DEVICE FOR TRANSPORTING PARTICLES OF MAGNETIC MATERIAL

СПОСОБ И ИНСТРУМЕНТ ДЛЯ РАЗРЫВА ПОДЗЕМНОГО ПЛАСТА

... 1. Способ разрыва подземного пласта, окружающего буровую скважину для добычи углеводородного флюида, содержащий - перемещение в буровую скважину разрывного инструмента, который выполнен с возможностью оказания давления, которое изменяется в окружном направлении, на стенку скважины; - расположение разрывного инструмента в выбранном месте в скважине и с выбранной окружной ориентацией; - расширение разрывного инструмента так, чтобы инструмент оказывал изменяющееся в окружном направлении давление на стенку скважины в течение выбранного периода времени, с инициированием тем самым в окружающем пласте, по меньшей мере, одного разрыва, который пересекает стенку скважины с выбранной ориентацией; и - введение расклинивающего наполнителя, по меньшей мере, в один разрыв в течение, по меньшей мере, части указанного периода времени. 2. Способ по п.1, в котором период времени, в течение которого инструмент оказывает изменяющееся в окружном направлении давление на стенку скважины, составляет, по меньшей ...

УСТРОЙСТВО ДЛЯ ТРАНСПОРТИРОВКИ ЧАСТИЦ МАГНИТНОГО МАТЕРИАЛА И ИНСТРУМЕНТ, СОДЕРЖАЩИЙ ЭТО УСТРОЙСТВО

Предложено устройство для транспортировки частиц магнитного материала в заданном направлении, содержащее магнит (7), выполненный с возможностью генерирования магнитного поля для удерживания частиц на несущей поверхности (15), при этом магнитное поле на несущей поверхности имеет зону повышенной напряженности магнитного поля, зону пониженной напряженности магнитного поля и градиент магнитного поля между упомянутыми зонами повышенной и пониженной напряженностей магнитного поля, средство для продвижения зон повышенной и пониженной напряженностей магнитного поля относительно несущей поверхности (15) в направлении, имеющем составляющую в направлении упомянутого градиента магнитного поля, в результате чего за зоной повышенной напряженности магнитного поля следует зона пониженной напряженности магнитного поля, причем вдоль зоны повышенной напряженности магнитного поля по меньшей мере первый магнитный полюс и второй магнитный полюс противоположной полярности расположены таким образом, что первый ...

Sonde pour pénétrer et se déplacer dans une masse de matière pulvérulente.

L'invention est relative à une sonde (1) pour pénétrer et se déplacer dans une masse de matière pulvérulente notamment des grains ou du sable comportant: - une enceinte, - une zone de frappe avant (3) et/ou une zone de frappe arrière (4) axialement opposées, pour transmettre des impulsions à ladite enceinte. - un piston frappeur (2) et, - des moyens moteurs pour la mise en mouvement duit piston frappeur (2) de façon à le projeter contre une zone de frappe (3, 4) solidaire de l'enceinte.

MOTEUR DE FOND A VIS MULTIFILETS SANS JOINT DE CARDAN

L'INVENTION CONCERNE UN MOTEUR DE FOND A VIS DANS LEQUEL LE JOINT DE CARDAN A ETE REMPLACE, COMME REPRESENTE SUR LA FIGURE 1, PAR UN DEUXIEME MOTEUR A VIS AYANT UN NOMBRE DE FILETS DIFFERENT DU PREMIER. LES DEUX ROTORS 10 ET 16 SONT LIES ET TOURNENT AVEC LA MEME EXCENTRICITE " E " PAR RAPPORT A LEURS STATORS 8 ET 14. DANS CES CONDITIONS, LE DEUXIEME STATOR 14 TOURNE CONCENTRIQUEMENT PAR RAPPORT AU PREMIER STATOR 8 LIE A LA GAINE 1 DU MOTEUR ET PEUT DONC ENTRAINER LE TREPAN SANS JOINT DE CARDAN. LES DEUX ROTORS 10 ET 16 TOURNENT ENTRE DEUX BUTEES 3 ET 23 ET LE DEUXIEME STATOR 14 EST GUIDE RADIALEMENT ET AXIALEMENT PAR UN PALIER LISSE 17 LUBRIFIE PAR UNE PARTIE DE LA BOUE ET PAR DES ROULEMENTS A ROULEAU 31, 32 ET 36 TOURNANT DANS LA GRAISSE.

APPARATUS AND METHOD FOR DOWNHOLE FLUID PHASE SEPARATION

A method and apparatus for separating fluids flowing through a downhole well passageway (D) includes separating fluids pumped downhole (WB) by centrifugal separation, gradually increasing centrifugal acceleration, establishing annular flow, gradually establishing annular flow, and receiving fluid in a receiving chamber (2) of increasing cross-sectional area of flow. A method and apparatus is suggested for use of a fluid separator tool (DFS) with tubing for downhole well operations, particulary with coiled tubing (CT).

DEVICE FOR TRANSPORTING PARTICLES OF MAGNETIC MATERIAL

A device for transporting particles of a magnetic material in a selected direction, the device comprising a support member having a support surface (21) for supporting the particles, the support surface extending in the selected direction, a magnet (28) arranged to generate a magnetic field retaining the magnetic particles on the support surface, the magnetic field having at least one region (32) of reduced field strength at the support surface relative to a field strength of the magnetic field at the support surface outside said region, and drive means (36) for moving each region of reduced field strength relative to the support surface in a direction having a component in the selected direction.

METHODS AND APPARATUS FOR DOWNLOAD TRANSFER OF DRILL CUTTINGS

A drilling fluid delivery system for use in drilling boreholes with a drill bit, the system comprising: a primary flow circuit having a relatively high flow rate for transferring drilling fluid to and from the drill bit; a secondary flow circuit having a relatively low flow rate for transferring drilling fluid to and from the primary flow circuit; and a cuttings transfer system, such as a hydrocyclone or a rotating filter, between the primary and secondary flow circuits which, in use, receives fluid containing cuttings from the primary circuit, separates the fluid into a first stream that contains substantially no cuttings and a second stream containing cuttings, the first stream being returned to the primary flow circuit and the second stream being directed to the secondary flow circuit.

Rotating Cutter Apparatus For Reducing The Size Of Solid Objects In A Fluid

A rotating cutter apparatus including a housing having a housing interior surface defining a housing bore, a shaft extending through the housing bore such that an annular space is provided between the housing interior surface and the shaft, and at least one cutter carried on the shaft. The shaft is rotatable relative to the housing about a shaft axis. The at least one cutter extends radially toward the housing interior surface and is rotatable relative to the housing about the shaft axis. A method for reducing a size of solid objects contained in a fluid, including providing a rotating cutter apparatus, introducing the fluid containing the solid objects into the rotating cutter apparatus, and rotating a shaft and at least one cutter in order to reduce the size of the solid objects while passing the fluid through the rotating cutter apparatus.

Valve assembly with a filter chamber

A valve assembly (10) comprises a flow path extending from an assembly inlet (20) to an assembly outlet (22), a valve (24a/26a) arranged within the flow path and a filter assembly arranged within the flow path between the assembly inlet and the valve. The filter assembly comprises a filter chamber defining a particle settlement region, a filter chamber inlet for facilitating inflow of a fluid into the chamber, and a filter chamber outlet for facilitating outflow of fluid from the chamber towards the valve, wherein the filter chamber outlet includes a particle filter.

Methods of downhole testing subterranean formations and associated apparatus therefor

Methods and apparatus are provided which permit well testing operations to be performed downhole in a subterranean well. In various described methods, fluids flowed from a formation during a test may be disposed of downhole by injecting the fluids into the formation from which they were produced, or by injecting the fluids into another formation. In several of the embodiments of the invention, apparatus utilized in the methods permit convenient retrieval of samples of the formation fluids and provide enhanced data acquisition for monitoring of the test and for evaluation of the formation fluids. A fluid separation device or plug (106) which may be reciprocated within the assembly (86) is used.

Continuous flow drilling systems and methods

In one embodiment, a method for drilling a wellbore includes injecting drilling fluid into a top of a tubular string disposed in the wellbore at a first flow rate. The tubular string includes: a drill bit disposed on a bottom thereof, tubular joints connected together, a longitudinal bore therethrough, and a port through a wall thereof. The drilling fluid exits the drill bit and carries cuttings from the drill bit. The cuttings and drilling fluid (returns) flow to the surface via an annulus defined between the tubular string and the wellbore. The method further includes rotating the drill bit while injecting the drilling fluid; remotely removing a plug from the port, thereby opening the port; and injecting drilling fluid into the port at a second flow rate while adding a tubular joint or stand of joints to the tubular string. The injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the joint or stand to the drill string. The method further ...

Двухэшелонная экологически безопасная буровая установка в арктическом исполнении

Изобретение относится к буровой установке для кустового бурения разведочных и эксплуатационных нефтяных и газовых скважин в холодных климатических условиях, например, Крайнего Севера России. Установка содержит вышечно-лебедочный блок с основанием и вышкой, установленное на направляющих в два эшелона оборудование циркуляционной системы, включая блок приготовления, очистки и хранения бурового раствора и насосный блок для подачи бурового раствора, а также блок приемного моста и соединенный с оборудованием циркуляционной системы блок электрооборудования. Модуль блока электрооборудования, содержащий трансформатор, комплектное тиристорное устройство и низковольтное комплектное устройство, расположен в первом ярусе, а модуль блока электрооборудования, содержащий дизельную электростанцию, - во втором. Установка имеет укрытие. Первый эшелон содержит вышечно-лебедочный блок с П-образной мачтовой вышкой для кустового бурения, блок очистки бурового раствора, блок хранения бурового раствора, блок электрооборудования ...

СПОСОБ И УСТРОЙСТВО ДЛЯ БЕСТРАНШЕЙНОЙ УКЛАДКИ ТРУБОПРОВОДОВ

УЗЕЛ СОПЛА И СПОСОБ БУРЕНИЯ ОТВЕРСТИЯ В ОБЪЕКТЕ

... 1. Узел сопла для создания абразивной струи, содержащий первое сопло, соединенное с источником несущей текучей среды под давлением, имеющее на участке своего максимального сужения отверстие с площадью А1поперечного сечения, смесительную камеру, в которую разгружается первое сопло, второе сопло, подсоединенное к смесительной камере и имеющее в своей наиболее суженной части отверстие с площадью А2 поперечного сечения, и вход для абразивных частиц, разгружающийся в смесительную камеру, при этом отношение А1/А2 по меньшей мере равно 0,50 и менее 1, и содержащее внутреннюю стенку, выровненную с внутренней стенкой смесительной камеры. 2. Узел сопла по п.1, в котором длина смесительной камеры по направлению течения такова, что принимая во внимание дивергенцию струи, выпускаемой из первого сопла, диаметр струи, выходящей из смесительной камеры, меньше диаметра отверстия второго сопла. 3. Узел сопла по п.1 или 2, в котором длина смесительной камеры по направлению течения составляет от 0,8 до 2 диаметров ...

Wasserabscheider, insbesondere fuer Druckluftgeraete

Filter assembly having a bypass passageway

Two stage downhole drilling fluid filter

Pneumatic rock-boring device

Flow diverter ring for a rotary drill bit and method

A rotary cone drill bit (10) having a bit body (22) with a number of support arms (24) formed to extend from the bit body (22). Each support arm (24) has an inside surface (26) with a spindle (28) connected thereto and an outer surface. A number of cutter cones (12) are rotatably mounted on respective spindles (28) each including an internal cylindrical cavity (42) for receiving the respective spindle (28). A gap with a generally cylindrical portion is formed between the spindle (28) and the cavity (42). A bearing element (44) and a seal element (54) is disposed within the gap. A diverter ring (60) is disposed on the exterior of each spindle (28) approximate to the respective inside surface (26) and located within the opening to the respective gap. The diverter ring (60) comprises a disk (70) having a plurality of ribs (72) extending therefrom to divert abrasive fluids away from the gap.

Fish-Thru Screen Apparatus and Method

A down hole apparatus for filtering debris from a fluid in a well bore including a screen sub, a diverter assembly connected to the screen sub, a screen section extending from the diverter assembly and connected to the screen sub. The screen section includes a plurality of openings for filtering debris from the fluid. The debris collects in an annulus between the screen section and the screen sub. The diverter assembly includes a detachable plug having a fishing portion capable of engaging a fishing tool. Removal of the detachable plug with a fishing tool opens a central passage through the diverter assembly and the screen section. The diverter assembly may include an outer and an inner body and one or more passages between the outer and inner bodies. The detachable plug may include one or more dog members capable of engaging the inner body.

Lateral Well Drilling Apparatus and Method

In one aspect, a drilling apparatus is provided, where the drilling apparatus includes a fluid pump disposed in a main wellbore, a lateral well in fluid communication with the fluid pump and a drilling assembly disposed in the lateral well, wherein the drilling assembly is configured to receive a fluid from the fluid pump to power the drilling assembly and to transport cuttings from the drilling assembly to the main wellbore. The drilling apparatus further includes a sealing mechanism disposed in the main wellbore, the sealing mechanism being configured to direct the cuttings in the fluid downhole of the sealing mechanism.

Downhole tool for borehole cleaning or for moving fluid in a borehole

The present invention relates to a downhole tool ( 1 ) for borehole cleaning or for moving fluid in a borehole. The tool comprises a tool housing ( 29 ), a chamber inlet ( 6 ) and a chamber outlet ( 36 ), and the tool housing comprises a pump ( 8 ) arranged in a pump housing ( 4 ) and a driving unit powered by an electrical conducting means for driving the pump.

Method of drilling and abrasive jet drilling assembly

A method of drilling comprises providing a drill string in a borehole, the drill siring comprising an abrasive jet drill head including a jet nozzle, and providing a fluid passageway between the object's surface and the jet nozzle; supplying a fluid mixture comprising magnetic particles to the abrasive jet drill head and blasting from the nozzle an abrasive jet into impingement with the object; and modulating a jetting concentration of magnetic particles in the abrasive jet by modulating a magnetic field a first value, at which magnetic particles are collected from the fluid mixture, and a second value, at which magnetic particles are released into the fluid mixture. Further, an abrasive jet drilling assembly comprising a modulation means for modulating the concentration of the magnetic abrasive particles in the fluid jet a modulation control means for selectively changing a magnetic field between first and second values.

Consolidating Spacer Fluids and Methods of Use

Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus.

Systems and Methods for Managing Milling Debris

Systems and methods of managing cuttings and debris resulting from milling a casing exit are disclosed. An exemplary milling system includes a mill arranged within a shroud and configured to translate axially with respect to the shroud once detached therefrom, a guide block is coupled to a distal end of the mill and supports the mill while the mill forms the casing exit. A guide support arranged within the shroud defining one or more longitudinal channels configured to accumulate cuttings and debris. The shroud defines a plurality of perforations arranged as first and second axial perforation sets, and a sleeve is arranged therein and defines one or more piston guides that align one or more pistons with either the first or second axial perforation sets, depending on the amount of cuttings and debris. 1. A milling system for forming a casing exit , comprising:a mill arranged within a shroud and configured to translate axially with respect to the shroud once detached therefrom;a guide block coupled to a distal end of the mill and configured to guide and support the mill while the mill forms the casing exit; andan arcuate guide support arranged within the shroud and having a ramp portion that transitions into a planar portion, the arcuate guide support defining one or more longitudinal channels configured to accumulate cuttings and debris generated by the mill as the mill traverses the one or more longitudinal channels.2. The milling system of claim 1 , wherein the arcuate guide support forms an integral part of the shroud.3. The milling system of claim 1 , wherein the one or more longitudinal channels are defined on the planar portion of the arcuate guide support.4. The milling system of claim 3 , wherein the planar portion comprises an arcuate surface and the one or more longitudinal channels are defined in and extend below the arcuate surface.5. The milling system of claim 1 , wherein the one or more longitudinal channels are defined on both the ramp portion and the ...

BARRIER PILLS

The present disclosure relates to systems and methods for wellbore pressure control with separated fluid columns. One embodiment is a composition comprising: a base fluid, a hectorite clay, a secondary clay comprising at least one clay selected from the group consisting of an attapulgite clay, a sepiolite clay, a polygorskite clay, and any combination thereof, and a plurality of fibers. Another embodiment is a method comprising: introducing a first fluid into a wellbore; introducing a barrier pill into the wellbore, wherein the barrier pill comprises: a base fluid, a hectorite clay, and a plurality of fibers; and introducing a second fluid into the wellbore. Another embodiment is a method comprising: introducing a first fluid into a wellbore; introducing a barrier pill into the wellbore, wherein the barrier pill comprises: a base fluid, a hectorite clay, and a secondary clay comprising at least one clay selected from the group consisting of an attapulgite clay, a sepiolite clay, a polygorskite clay, and any combination thereof; and introducing a second fluid into the wellbore. 1. A composition comprising:a base fluid,a hectorite clay,a secondary clay comprising at least one clay selected from the group consisting of an attapulgite clay, a sepiolite clay, a polygorskite clay, and any combination thereof, anda plurality of fibers.2. The composition of claim 1 , wherein the composition further comprises a strong base selected from the group consisting of a hydroxide base claim 1 , quick lime claim 1 , and any combination thereof.3. The composition of claim 1 , wherein the composition further comprises a weighting agent.4. The composition of claim 1 , wherein the fibers comprise at least one material selected from the group consisting of: polypropylene claim 1 , polyaramide claim 1 , polyester claim 1 , polyacrylonitrile claim 1 , polyvinyl alcohol claim 1 , chitosan claim 1 , soya claim 1 , modified chitosan claim 1 , polycaprolactone claim 1 , poly(3-hydroxybutyrate) ...

SPACER FLUIDS AND CEMENT SLURRIES THAT INCLUDE SURFACTANTS

According to at least one embodiment of the present disclosure, a well bore cementing system may comprise a spacer fluid and a cement slurry. The spacer fluid may be positioned within a well bore, and the spacer fluid may comprise a first surfactant package comprising one or more surfactants. The cement slurry may be positioned within the well bore, and the cement slurry may comprise a second surfactant package comprising one or more surfactants. 1. A well bore cementing system comprising: a base fluid that is an aqueous-based fluid; and', {'sub': 2', '4', 'x1, 'a first surfactant package consisting essentially of one or more surfactants having the chemical structure R1-(OCH)—OH, where R1 is a hydrocarbyl group having from 5 to 20 carbon atoms, and x1 is an integer from 5 to 15, where the one or more surfactants of the first surfactant package has a HLB of from 11 to 13.5; and'}], 'a spacer fluid positioned within a well bore, the spacer fluid comprising{'sub': 2', '4', 'x2, 'a cement slurry positioned within the well bore, the cement slurry comprising a second surfactant package consisting essentially of one or more surfactants having the chemical structure R2-(OCH)—OH, where R2 is a hydrocarbyl group having from 5 to 20 carbon atom, and x2 is an integer from 5 to 15, where the one or more surfactants of the second surfactant package has a HLB of from 11 to 13.5.'}2. The well bore cementing system of claim 1 , where the cement slurry is in contact with the spacer fluid.3. The well bore cementing system of claim 1 , where the spacer fluid is in contact with a drilling fluid and the cement slurry.4. The well bore cementing system of claim 1 , where the one or more surfactants of the first surfactant package has a HLB of from 12.5 to 13 claim 1 , the one or more surfactants of the second surfactant package has a HLB of from 12.5 to 13 claim 1 , or both.5. The well bore cementing system of claim 1 , where x1 is an integer from 5 to 10 claim 1 , x2 is an integer from 5 ...

DEVELOPMENT OF ANTI-BIT BALLING FLUIDS

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OCH)—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH—CH)—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided. 2. The method of claim 1 , where the surfactant has an HLB of from 8 to 16.3. The method of claim 1 , where R is:an alkyl group comprising 12 to 15 carbons; oran alkenyl group comprising from 12 to 15 carbon atoms.4. The method of claim 1 , where x is from 5 to 10.5. The method of claim 1 , where the surfactant has an HLB of from 13 to 15.6. The method of claim 1 , where the surfactant comprises ethylene oxide condensate of branched isotridecyl alcohol.7. The method of claim 1 , where the polyethylene glycol has a weight average molecular weight of from 300 grams per mol (g/mol) to 500 g/mol claim 1 , as measured according to GPC.8. The method of claim 1 , where the drilling fluid comprises from 28 to 850 lb/bbl water based on total weight of the drilling fluid.9. The method of claim 1 , where the drilling fluid comprises from 28 to 720 lb/bbl of the clay-based component based on total weight of the drilling fluid.10. The method of claim 1 , where the drilling fluid comprises from 0.02 to 180 lb/bbl of the surfactant claim 1 , the polyethylene glycol claim 1 , or both claim 1 , based on total weight of the drilling fluid.11. The method of claim 1 , where the clay-based component comprises one or more components selected from the group consisting of lime (CaO) claim 1 , CaCO claim 1 , bentonite claim 1 , montmorillonite clay claim 1 , barium sulfate (barite) claim 1 , hematite (FeO) claim 1 , mullite (3AlO.2SiOor 2AlO.SiO) claim 1 , kaolin claim 1 , (AlSiO(OH)or kaolinite) ...

METHOD AND DEVICE FOR TRENCHLESS PIPE LAYING

The invention relates to a boring and laying device for the trenchless laying of a pipeline, with a boring head for loosening the rock, wherein the boring head has a connection for a pilot bore linkage, with a pump for suctioning and conveying away the drillings loosened by the boring head, with a conveying portion behind the boring head in which at least one suction element for receiving and conveying away the loosened rock is provided, and with a connecting portion which has a connection for the pipeline, and to a boring and laying method for the trenchless laying of a pipeline, in which a pilot bore is produced from a starting point to a destination point along a predetermined boring line, wherein the pilot bore is obtained by advancing a pilot boring head with a pilot bore linkage, and in which, after reaching the destination point, a boring and laying head is connected to one end of the pilot bore linkage, which head is connected to the pipeline and via which the borehole is expanded, and simultaneously the pipeline is laid by pulling the pilot bore linkage out of the borehole on one side and/or by pushing the pipeline into the borehole, wherein drillings loosened by the boring head are hydraulically received behind the boring head of the boring and laying device and conveyed away out of the borehole by means of a pump. 1. A boring and laying device for the trenchless laying of a pipeline , a connection for a pilot bore linkage;', 'a connection for a following element of the boring and laying device;, 'with a boring head for loosening the rock comprisinga rotary element,with a connecting portion as a connection for the pipeline,including a conveying portion behind the boring head comprising at least one receiving element for receiving the loosened rock, and, a pump for suctioning and conveying away the drillings loosened by the boring head and', 'the connecting portion for a following element of the boring and laying device, 'a functional portion ...

OIL WELL MONITORING APPARATUS AND METHOD

The present disclosure relates to an oil well monitoring apparatus and method. The oil well monitoring apparatus includes a mixed liquid inlet and a mixed liquid outlet of a mixed liquid of oil, gas, and water in a ground pipeline connected to a wellhead of an oil well, a gas-liquid separator, an inlet of which is connected to the mixed liquid inlet, and a liquid monitoring member, which is connected between a liquid outlet of the gas-liquid separator and the mixed liquid outlet, and a gas monitoring member, which is connected between a gas outlet of the gas-liquid separator and the mixed liquid outlet, and a data processing device, which is configured to calculate a liquid production amount of the oil well based on the liquid monitoring data and calculate a gas production amount of the oil well based on the gas monitoring data. 1. An oil well monitoring apparatus comprising:a mixed liquid inlet and a mixed liquid outlet of a mixed liquid of oil, gas, and water in a ground pipeline connected to a wellhead of an oil well;a gas-liquid separator, an inlet of which is connected to the mixed liquid inlet, and which is configured to separate gas and liquid phases of the mixed liquid;a liquid monitoring member, which is connected between a liquid outlet of the gas-liquid separator and the mixed liquid outlet, and which is configured to collect liquid monitoring data;a gas monitoring member, which is connected between a gas outlet of the gas- liquid separator and the mixed liquid outlet, and which is configured to collect gas monitoring data; anda data processing device, which is electrically connected to the liquid monitoring member and the gas monitoring member, and which is configured to calculate a liquid production amount of the oil well based on the liquid monitoring data and calculate a gas production amount of the oil well based on the gas monitoring data.2. The oil well monitoring apparatus according to claim 1 , wherein the liquid monitoring member further ...

APPARATUS, SYSTEM AND METHOD FOR DEBRIS REMOVAL

An apparatus, method and system for debris removal using a debris removal tool. The tool has a generally-cylindrical tool body having an upper end, a lower end, a central axis, an interior chamber and an external surface. A nozzle plate, disposed within the tool body, has an array of nozzles disposed therein. Each of the nozzles has a principal axis angled with respect to the central axis of the body of the debris removal tool, in order to direct fluid from the interior chamber of the tool body to the exterior of the tool at an angle. 1. A debris removal tool comprising:a generally-cylindrical tool body having an upper end, a lower end, a central axis, an interior chamber and an external surface;a nozzle plate, disposed within and secured to the tool body, having an array of nozzles disposed therein, having principal axes angled with respect to the central axis of the body of the debris removal tool, in order to direct fluid from the interior chamber of the tool body to the exterior of the tool at an angle; andan array of radially-spaced, angled apertures formed in the tool body, connecting the interior chamber of the tool body to the external surface thereof, each having a principal axis aligned to the principal axis of a nozzle in the nozzle plate.2. The debris removal tool as set forth in wherein the nozzle plate holds at least 3 nozzles.3. The debris removal tool as set forth in wherein the nozzle plate holds at least 4 nozzles.4. The debris removal tool as set forth in wherein the nozzles are oriented at approximately 12 degrees from the center line of the body.5. The debris removal tool as set forth in further comprising threaded connections at the upper and lower ends of the body.6. The debris removal tool as set forth in further comprising a debris screen disposed in the lower end of the tool body.7. The debris removal tool as set forth in further comprising a tube type screen disposed in the upper end of the tool body.8. The debris removal tool as set forth ...

DOWNHOLE DEBRIS RETRIEVER

A method and apparatus for removing debris from a wellbore using a cleaning tool. The tool may comprise an inner mandrel and a cup member coupled to the inner mandrel. The cup member is moveable between a collapsed position where fluid may flow across the exterior of the cup member, and an extended position where fluid is diverted into a flow path disposed between the inner mandrel and the cup member. The fluid is diverted through a filter member that is coupled to the inner mandrel below the cup member. 1. A wellbore cleaning tool , comprising:an inner mandrel;a cup member coupled to the inner mandrel, wherein the cup member is moveable between a collapsed position where fluid may flow across the exterior of the cup member, and an extended position where fluid is diverted into a first flow path disposed between the inner mandrel and the cup member; anda filter member coupled to the inner mandrel below the cup member.2. The tool of claim 1 , further comprising a piston coupled to the inner mandrel by a shearable member claim 1 , wherein the piston is movable upon release of the shearable member to open fluid communication between the first flow path and the exterior of the tool.3. The tool of claim 1 , further comprising an outer housing coupled to the inner mandrel claim 1 , and one or more rupture disks coupled to the outer housing claim 1 , wherein the rupture disks are configured to open fluid communication between the first flow path and the exterior of the tool.4. The tool of claim 1 , further comprising a filter housing coupled to the inner mandrel claim 1 , and a second flow path disposed between the interior of the filter housing and the exterior of the filter member.5. The tool of claim 4 , wherein one or more openings in the filter member provide fluid communication between the first flow path and the second flow path.6. The tool of claim 5 , further comprising a support member having one or more openings in fluid communication with the second flow path ...

EMULSIFIER COMPOSITIONS FOR INVERT EMULSION FLUIDS AND METHODS OF USING THE SAME

Drilling fluid compositions include invert emulsion fluids having an oleaginous phase, an aqueous phase, and an emulsifier composition that includes an ethoxylated alcohol compound and a polyaminated fatty acid compound. The ethoxylated alcohol compound has the formula R—(OCHCH)—OH, where Ris a hydrocarbyl group having from 8 to 22 carbon atoms and n is from 1 to 8. The ethoxylated alcohol compound has a Hydrophilic-Lipophilic Balance (HLB) of less than or equal to 6. The polyaminated fatty acid compound has the formula R—CO—NH—CH—CH—N(COR)—CH—CH—NH—CO—R, where Ris a hydrocarbyl group having from 1 to 20 carbon atoms and Ris a hydrocarbyl group having 1 to 10 carbon atoms or an alkylene carboxylate group having formula —R—COOH, where Ris a saturated or unsaturated hydrocarbylene having from 1 to 10 carbon atoms. Methods of drilling wells include operating a drill in a wellbore in the presence of drilling fluid compositions. 1. A method of drilling a subterranean well , the method comprising: [ [{'br': None, 'sup': '1', 'sub': 2', '2', 'n, 'R—(OCHCH)—OH\u2003\u2003(I)'}, {'sup': '1', 'where Ris a hydrocarbyl group having from 8 to 22 carbon atoms and n is an integer from 1 to 6, the ethoxylated alcohol compound having a Hydrophilic-Lipophilic Balance (HLB) of less than or equal to 6; and'}], 'an ethoxylated alcohol compound having formula (I), [{'br': None, 'sup': 2', '2', '3, 'sub': 2', '2', '2', '2, 'R—CO—NH—CH—CH—N(COR)—CH—CH—NH—CO—R\u2003\u2003(II)'}, {'sup': 2', '3', '4', '4, 'where Ris hydrocarbyl group having from 1 to 20 carbon atoms and Ris a hydrocarbyl group having 1 to 10 carbon atoms or an alkylene carboxylate group having formula —R—COOH, where Ris a saturated or unsaturated hydrocarbylene having from 1 to 10 carbon atoms.'}], 'a polyaminated fatty acid compound having formula (II)], 'operating a drill in a wellbore in the presence of an invert emulsion fluid composition comprising a weighting material and an invert emulsion fluid, the invert emulsion ...

Diffuser Assembly with Vibration Feature

A diffuser assembly is provided, comprising a diffuser adapted to reside within a conduit, having an upper member mountable within the conduit and having a fluid inlet port, and a lower section having a diffuser screen. A resilient member is connected between the upper member and the lower section, wherein the resilient member enables the diffuser screen to vibrate relative to the upper member. A plurality of diffusing members is positioned below the resilient member, wherein the diffusing members are oriented relative to a central axis of the diffuser screen. A centralizing member is positioned above the diffuser screen having a diameter greater than the diffuser screen. The diffuser screen is a cylinder having a plurality of diffuser apertures formed therein, the cylinder including a bottom cap having a fluid exit port; and wherein the plurality of diffusing members extends substantially parallel to the central axis. A filter assembly is also provided having a resilient member connected between an upper member and a lower section, wherein the resilient member enables the filter screen to vibrate relative to the upper member. 1. A diffuser assembly , comprising:(a) a diffuser adapted to reside within a conduit, having an upper member mountable within the conduit and having a fluid inlet port, and a lower section having a diffuser screen;(b) a resilient member connected between the upper member and the lower section, wherein the resilient member enables the diffuser screen to vibrate relative to the upper member;(c) a plurality of diffusing members below the resilient member, wherein the diffusing members are oriented relative to a central axis of the diffuser screen; and(d) a centralizing member above the diffuser screen having a diameter greater than the diffuser screen;wherein the diffuser screen is a cylinder having a plurality of diffuser apertures formed therein, the cylinder including a bottom cap having a fluid exit port; andwherein the plurality of ...

Defoaming Agent Compositions and Methods of Making and Using Same

A method of servicing a wellbore in a subterranean formation comprising placing a foamed wellbore servicing fluid into a wellbore; flowing the foamed wellbore servicing fluid back to the wellbore surface; and contacting the foamed wellbore servicing fluid with an immobilized defoaming agent structure comprising an inert substrate and a defoamer. A system comprising a foamed wellbore servicing fluid in contact with a de-foaming structure, wherein the de-foaming structure comprises a defoamer covalently bonded to an inert substrate. 1. A system comprising a first volume of a foamed wellbore servicing fluid in contact with a de-foaming structure , wherein the defoaming structure comprises a defoamer and an inert substrate.2. The system of claim 1 , wherein the immobilized defoaming structure comprises a porous structure claim 1 , a screen claim 1 , a flexible sponge claim 1 , or combinations thereof.3. The system of claim 1 , wherein the defoaming structure comprises a screen.4. The system of claim 1 , further comprising a fluid container claim 1 , wherein at least a portion of the fluid container comprises the defoaming structure.5. The system of claim 4 , wherein the fluid container comprises a median or baffle claim 4 , wherein at least a portion of the median or baffle comprises the defoaming structure.6. The system of claim 1 , further comprising a fluid conduit claim 1 , wherein at least a portion of the fluid conduit comprises the defoaming structure.7. The system of claim 6 , wherein the fluid conduit is a pipe.8. The system of claim 6 , wherein the fluid conduit is disposed within a wellbore.9. The system of claim 1 , further comprising a wellbore servicing equipment component.10. The system of claim 8 , wherein at least a portion of the wellbore servicing equipment component comprises the defoaming structure.11. The system of claim 1 , further comprising a second volume of the foamed wellbore servicing fluid disposed within a wellbore.12. The system of claim ...

DISPERSANT IN CEMENT FORMULATIONS FOR OIL AND GAS WELLS

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, improved rheology, such as improved flowability and pumpability and may be used, for instance, in the oil and gas drilling industry. The cement slurry contains water, a cement precursor material and a surfactant having the formula R—(OCH)—OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10. The cured cement have improved strength and density properties due to reduced fluid loss and even placement during curing. The cured cement contains a surfactant having the formula R—(OCH)—OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10. 1. A cement slurry comprising:water;a cement precursor material; anda surfactant having a HLB of from 12 to 13.5.2. The cement slurry of claim 1 , where the cement slurry contains from 10 to 70 wt % BWOC (By Weight Of Cement Precursor) water.3. The cement slurry of claim 1 , where the cement slurry contains from 10 to 90 wt % BWOC of the cement precursor material.4. The cement slurry of claim 1 , where the cement slurry contains from 0.1 to 10 wt % BWOC of the surfactant.5. The cement slurry of claim 1 , where the cement slurry contains from 0.1 to 10 wt % BWOC of one or more additives selected from the group consisting of accelerators claim 1 , retarders claim 1 , extenders claim 1 , weighting agents claim 1 , fluid loss control agents claim 1 , lost circulation control agents claim 1 , antifoaming agents claim 1 , and combinations of these.6. The cement slurry of claim 1 , where the cement precursor material is a hydraulic or a non-hydraulic cement precursor.7. The cement slurry of claim 1 , where the cement precursor material is a hydraulic cement precursor.8. The cement slurry of claim 1 , where the cement precursor material comprises one or more components selected ...

METHOD AND SYSTEM FOR SEALING AN ANNULUS ENCLOSING A TUBULAR ELEMENT

The invention provides a method and system for sealing an annulus enclosing a tubular element in a wellbore. The method comprises the steps of: i) introducing a first drilling fluid in the wellbore; ii) drilling an open hole section of the wellbore using a drilling tool suspended at the end of a tool string; iii) pumping a second drilling fluid comprising particles into the wellbore; iv) filtering the particles out of the second drilling fluid near a downhole end of the tubular element; v) extending the tubular element into the open hole section of the wellbore while directing at least part of the filtered particles to an annulus between the tubular element and a wellbore wall. Steps i) to v) may be repeated as often as required. 1. A method for sealing an annulus enclosing a tubular element in a wellbore ,wherein the tubular element is an expandable tubular element enclosing a tool string, wherein a downhole end portion of a wall of the expandable tubular element is bent radially outward and in axially reverse direction defining an expanded tubular section extending around an unexpanded tubular section, the method comprising the steps of:i) introducing a first drilling fluid in the wellbore;ii) drilling an open hole section of the wellbore using a drilling tool suspended at the end of the tool string;iii) pumping a second drilling fluid comprising particles into the wellbore;iv) filtering the particles out of the second drilling fluid near a downhole end of the tubular element;v) extending the tubular element into the open hole section of the wellbore by pushing the unexpanded section into the expanded tubular section, while directing at least part of the filtered particles to an annulus between the expanded tubular section and a wellbore wall.2. The method of claim 1 , comprising the step of:vi) repeating steps i) to v).3. The method of claim 1 , wherein the particles directed to the annulus fill said annulus with a layer of particles.4. The method of claim 1 , ...

DEVELOPMENT OF ANTI-BIT BALLING FLUIDS

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OCH)—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH—CH)—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided. 1. A method for using a drilling fluid in drilling operations , the method comprising: {'br': None, 'sub': 2', '4', 'x, 'R—(OCH)—OH\u2003\u2003Formula (I)'}, 'mixing water, a clay-based component, and a surfactant comprising Formula (I)where R is a hydrocarbyl group having from 10 to 20 carbon atoms,x is an integer from 1 and 10, andintroducing the drilling fluid to a subterranean formation.2. The method of claim 1 , where introducing the drilling fluid comprises injecting the drilling fluid and at least partially circulating the drilling fluid within the subterranean formation.3. The method of claim 1 , where the surfactant has an HLB of from 8 to 16.4. The method of claim 1 , where the drilling fluid comprises from 28 to 850 lb/bbl water claim 1 , from 28 to 720 lb/bbl of the clay-based component based on total weight of the drilling fluid claim 1 , and from 0.02 to 180 lb/bbl of the surfactant based on total weight of the drilling fluid.5. The method of claim 1 , where the drilling fluid has an accretion percentage of less than or equal to 18%.6. The method of claim 1 , where R is:an alkyl group comprising 12 to 15 carbons; oran alkenyl group comprising from 12 to 15 carbon atoms.7. The method of claim 1 , where x is from 5 to 10.8. The method of claim 1 , where the surfactant has an HLB of from 13 to 15.9. The method of claim 1 , where the surfactant comprises ethylene oxide condensate of branched isotridecyl alcohol.10. The method of claim 1 , where the drilling fluid ...

CONTINUOUS FLOW DRILLING SYSTEMS AND METHODS

A method for drilling a wellbore includes drilling the wellbore by injecting drilling fluid into a top of a tubular string disposed in the wellbore at a first flow rate and rotating a drill bit. The tubular string includes: the drill bit disposed on a bottom thereof, tubular joints connected together, a longitudinal bore therethrough, a port through a wall thereof, and a sleeve operable between an open position where the port is exposed to the bore and a closed position where a wall of the sleeve is disposed between the port and the bore. The method further includes moving the sleeve to the open position; and injecting drilling fluid into the port at a second flow rate while adding a tubular joint(s) to the tubular string. The injection of drilling fluid into the tubular string is continuously maintained between drilling and adding the joint(s). 1. A continuous flow sub for use with a drill string , comprising:a tubular housing having a longitudinal bore therethrough and a port formed through a wall thereof;a ball valve disposed in the bore; and a body having an outer wall coupled to a portion of the housing wall adjacent to the port and an inner wall connected to the outer wall by a web;', 'a poppet disposed through a bore of the inner wall and movable relative to the body between an open position and a closed position; and', 'a spring biasing the poppet toward the closed position., 'a check valve disposed in the port and comprising2. The continuous flow sub of claim 1 , wherein:the poppet engages a seat formed in an end of the body in the closed position,the poppet extends into the housing bore in the open position, thereby allowing fluid flow through the port and into the bore, andthe poppet moves between the positions in response to differentials between a pressure of the housing bore and an external pressure.3. The continuous flow sub of claim 1 , further comprising a cap fastened to the body and isolating the poppet from the external pressure.4. The continuous ...

Consolidating Spacer Fluids and Methods of Use

Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus. 1. A method of displacing a drilling fluid disposed in a well bore annulus , comprising:providing a consolidating spacer fluid that comprises a lost circulation material;using the consolidating spacer fluid to displace at least a portion of the drilling fluid from the well bore annulus; andallowing at least a portion of the consolidating spacer fluid to consolidate in the well bore annulus.2. The method of wherein the drilling fluid is an oil-based drilling fluid.3. The method of wherein the consolidating spacer fluid comprises cement kiln dust.4. The method of wherein the consolidating spacer fluid comprises lime kiln dust.5. The method of wherein the consolidating spacer fluid comprises kiln dust in an amount in a range of from about 1% to about 60% by weight of the consolidating spacer fluid.6. The method of further comprising introducing a cement composition into the well bore annulus after the consolidating spacer fluid claim 1 , wherein the consolidating spacer fluid separates the cement composition from the drilling fluid.7. The method of further comprising running a bond log on the portion of the consolidating spacer fluid in the well bore annulus to measure bonding of the consolidating spacer fluid to a pipe string in the well bore.8. The method of wherein the consolidating spacer fluid is foamed and has a density in a range of from about 4 pounds per gallon to about 13 pounds per gallon.9. The method of wherein the consolidating spacer fluid comprises at least one additive selected from the group consisting of a free water control additive claim 1 , a lightweight additive claim 1 , a foaming agent claim 1 , a supplementary cementitious material claim 1 , a weighting agent of any suitable size claim 1 , a viscosifying agent claim 1 , a fluid loss control agent claim ...

DUAL CIRCULATION DRILLING SYSTEM

A ground drill system has a drill string which forms first and second mutually isolated fluid paths and respectively. The drill string has an up hole end coupled to a dual circulation rotation head and a down hole end which is coupled to a drilling tool The drilling tool is operated by the flow of fluid delivered through the first flow path A second fluid outlet is provided intermediate the up hole end and the drilling tool The outlet is in fluid communication with the second fluid flow path and located a constant or fixed distance from the drilling toll The second fluid outlet discharges a flushing fluid flowing through the flushing flow path into a hole being drilled by the drilling system The rotation head provides torque to the drill string and thus the drilling tool 1. A method of drilling a hole in the ground using a fluid operated water hammer , the method comprising:delivering a working fluid through a drill string to the water hammer to operate the water hammer, wherein the working fluid comprises water or oil or a mixture thereof;delivering a flushing fluid through the drill string toward the water hammer, wherein the flushing fluid while flowing in the drill string is isolated from the working fluid; and,releasing the flushing fluid from a location that is fixed with respect to the water hammer and up hole thereof, wherein the location advances with the drill string, and wherein the flushing fluid is released adjacent to the water hammer near a bottom of the hole being drilled.2. The method according to comprising releasing the working fluid into the hole near a toe of the hole to enable a-mixing of the working fluid and the flushing fluid in the hole.3. The method according to comprising recirculating the working fluid through the drill string wherein the working fluid is not mixed with the flushing fluid in the hole.4. The method according to comprising adjusting down hole pressure by varying a physical characteristic of one or both of the flushing ...

Systems and apparatuses for separating wellbore fluids and solids during production

There is provided parts for assembly to produce a flow diverter configured for disposition within a wellbore. The parts include an insert-receiving part including a passageway, and a flow diverter-effecting insert configured for insertion within the passageway. The flow diverter-effecting insert is co-operatively configured with the insert-receiving part such that a flow diverter is defined while the flow diverter-effecting insert is disposed within the passageway. The flow diverter is configured for: receiving and conducting a reservoir fluid flow; discharging the received reservoir fluid flow into the wellbore such that gaseous material is separated from the discharged reservoir fluid flow within the wellbore, in response to at least buoyancy forces, such that a gas-depleted reservoir fluid flow is obtained; and receiving and conducting the obtained gas-depleted reservoir fluid flow.

Fish through Filter Device

A filter device housed within a body component. The filter device can include an outer filter and an inner filter positioned coaxially within the outer filter. The outer and inner filters may be composed of a material having mesh, slots, holes, or any other openings being of a sufficient size and shape to restrict passage of items of a predetermined size or larger. Formed between the inner and outer filters is a first annular space into which fluid that is provided down the drill string may enter. The filter device may also include a valve within the internal bore which regulates passage of wellbore fluid provided to the drill string, or for a wireline or slickline, to pass through the filter device in order to access other components of the drill string downhole from the filter device.

Dual circulation drilling system

A ground drill system ( 10 ) has a drill string 14 which forms first and second mutually isolated fluid paths ( 16 and 18 ) respectively. The drill string ( 14 ) has an up hole end ( 20 ) coupled to a dual circulation rotation head ( 22 ) and a down hole end ( 24 ) which is coupled to a drilling tool ( 12 ). The drilling tool ( 12 ) is operated by the flow of fluid delivered through the first flow path ( 16 ). A second fluid outlet ( 26 ) is provided intermediate the up hole end ( 20 ) and the drilling tool ( 12 ). The outlet ( 26 ) is in fluid communication with the second fluid flow path ( 18 ) and located a constant or fixed distance from the drilling toll ( 2 ). The second fluid outlet ( 26 ) discharges a flushing fluid flowing through the flushing flow path ( 18 ) into a hole being drilled by the drilling system ( 10 ). The rotation head ( 22 ) provides torque to the drill string ( 14 ) and thus the drilling tool ( 12 ).

Self-Cleaning Filter

An assembly can include a filter body having an open end and a closed end. The filter body can also include a plurality of perforations. A fan may be positionable within the filter body. The fan may include a mount that extends along a length of the fan. A blade may be coupled to and extend from the mount. The fan may also include an outer edge of the blade for contacting an inner surface of the filter body. 1. An assembly comprising:a filter body having an open end and a closed end, the filter body including a plurality of perforations; and a mount that extends along a length of the fan;', 'a blade coupled to and extending from the mount; and', 'an outer edge of the blade for contacting an inner surface of the filter body., 'a fan positionable within the filter body, the fan comprising2. The assembly of claim 1 , wherein the closed end of the filter body includes an opening for receiving an end of the mount.3. The assembly of claim 1 , wherein the filter body is generally cylindrical shape.4. The assembly of claim 1 , wherein the outer edge comprises a rubber material for wiping the inner surface of the filter body.5. The assembly of claim 1 , wherein the outer edge of the blade comprises a plurality of fibers for sweeping the inner surface of the filter body.6. The assembly of claim 1 , wherein the blade extends at least partially circumferentially around the mount.7. The assembly of claim 1 , wherein the filter body is coupled to the inner surface of a casing string.8. The assembly of claim 1 , wherein the filter body and the fan both comprise a drillable material.9. An assembly comprising:a fan positionable within a filter body having a plurality of perforations, the fan comprising:a mount that extends along a length of the fan;a blade coupled to and extending from the mount, the blade having a width that corresponds to a radius of the filter body; andan outer edge of the blade for contacting an inner surface of the filter body.10. The assembly of claim 9 , ...

DEBRIS CATCHER

A debris catcher and system is provided for removing debris from fluids such as in wellbore stimulation operations. A generally tubular housing axially supports a tubular screen inside a housing bore. Debris-laden fluid flows from an intake end of the housing axially into the bore of the screen and exits screen openings radially into an axially elongated flow annulus formed between a tubular wall of the screen body and the housing bore. Debris is retained in the upstream portion of screen body and clean fluid, in the annulus, returns downstream of the screen for exit out a discharge end of the housing. The screen is removably installable to the housing. 1. A debris catcher for removing debris from fluids , comprising:a generally tubular housing having an intake end, a discharge end, a housing bore extending axially therethrough; ["an upstream portion supported by the housing, the upstream portion having a tubular wall having a screen bore within, and having an intake end open to the housing's intake end and a downstream end wall,", "the tubular wall having a plurality of screen openings for establishing fluid communication between the screen bore and the flow annulus, wherein the screen openings pass fluid therethrough whilst retaining wellbore debris within the screen bore, a cumulative flow area of the screen openings being greater than a cross-sectional flow area of the screen's intake end."], 'a tubular screen supported axially inside the housing bore and forming a flow annulus between the housing and the screen, the flow annulus in fluid communication with the discharge end, the screen comprising'}2. The debris catcher of claim 1 , wherein the screen's tubular wall at the intake end is cantilevered at the housing's intake end.3. The debris catcher of wherein the screen's upstream portion further comprises a retaining structure at the screen's intake end to secure the screen against axial movement within the housing bore.4. The debris catcher of wherein the ...

METHODS OF USING DRILLING FLUID COMPOSITIONS WITH ENHANCED RHEOLOGY

Drilling fluid compositions include a base fluid, at least one additive chosen from an emulsifier, weighting material, fluid-loss additive, viscosifier, or alkali compound, and from 0.1 wt. % to 1 wt. %, based on total weight of the drilling fluid composition, of an ethoxylated alcohol compound having the formula R—(OCHCH)—OH, in which R is a saturated or unsaturated, linear or branched hydrocarbyl group having from 8 to 20 carbon atoms. The base fluid may be an aqueous base fluid. Methods for drilling a subterranean well include operating a drill in a wellbore in the presence of a drilling fluid composition including the base fluid, the additive, and the ethoxylated alcohol compound. 1. A drilling fluid composition consisting essentially of:a base fluid;at least one additive chosen from an emulsifier, a weighting material, a fluid-loss additive, a viscosifier, or an alkali compound; and {'br': None, 'sub': 2', '2', '7, 'R—(OCHCH)—OH \u2003\u2003(I)'}, 'from 0.1 wt. % to 1 wt. %, based on the total weight of the drilling fluid composition, of an ethoxylated alcohol compound having formula (I){'sup': '3', 'where R is a hydrocarbyl group having exactly 12 carbon atoms; in which the drilling fluid composition has a density equal to or greater than 90 lbm/ft.'}2. The drilling fluid composition of where the drilling fluid composition has a yield point of from 45 lbf/100 ftto 100 lbf/100 ftand a 10-second gel strength of from 1 lbf/100 ftto 30 lbf/100 ftas determined according to test methods provided in API RP 13B-1.3. The drilling fluid composition of claim 1 , in which the base fluid is an aqueous base fluid.4. The drilling fluid composition of claim 3 , in which the aqueous base fluid comprises at least 50 weight percent water based on the total weight of the aqueous base fluid.5. The drilling fluid composition of claim 3 , in which the aqueous base fluid is chosen from fresh water claim 3 , filtered water claim 3 , distilled water claim 3 , sea water claim 3 , salt ...

INTELLIGENT SENSOR SYSTEMS AND METHODS

According to one aspect, an intelligent sensor system is adapted to monitor at least a first operating parameter of a first vessel during oil and gas exploration and production operations. The system includes a first sensor housing assembly, which includes a first sensor adapted to measure a first physical property associated with the first vessel. The monitored first operating parameter is, or is based on, the first physical property measured by the first sensor. A control unit may be in communication with the first sensor. The control unit may be adapted to be in communication with an electronic drilling recorder (EDR). According to another aspect, a system is located at a drilling rig site, and includes first and second sensor housing assemblies connected to first and second vessels, respectively. According to yet another aspect, an intelligent sensor system is adapted to monitor an operating parameter of a gas vent line. 1. A system adapted to monitor at least a first operating parameter of a first vessel , the first vessel defining a first internal region , the system comprising: a first fitting adapted to be connected to the first vessel, the first fitting defining a first internal passage adapted to be in fluid communication with the first internal region;', 'a second fitting adapted to be connected to the first vessel, the second fitting defining a second internal passage adapted to be in fluid communication with the first internal region;', 'a housing extending between the first and second fittings, the housing defining a second internal region adapted to be in fluid communication with the first internal region via the first and second passages; and', 'a first sensor connected to at least one of the first fitting, the second fitting, and the housing;, 'a first sensor housing assembly, the first sensor housing assembly comprisingwherein the first sensor is adapted to measure a first physical property associated with the first vessel; andwherein the monitored ...

SPACER FLUID COMPOSITIONS THAT INCLUDE SURFACTANTS

In one embodiment, a spacer fluid may comprise a base fluid and a surfactant package. The surfactant package may comprise one or more surfactants, where the surfactant package comprises a first surfactant having the chemical structure R—(OCH)—OH. R may be a hydrocarbyl group having from 9 to 20 carbon atom, and x may be an integer from 5 and 15. The first surfactant may have a hydrophilic-lipophilic balance (HLB) of from 12 to 13.5. 2. The spacer fluid of claim 1 , further comprising a weighting agent.3. The spacer fluid of claim 2 , where the weight ratio of base fluid to weighting agent is from 100:3 to 100:350.4. The spacer fluid of claim 1 , further comprising a viscosifier.5. The spacer fluid of claim 4 , where the weight ratio of base fluid to the viscosifier is from 100:0.05 to 100:7.6. The spacer fluid of claim 1 , where the weight ratio of base fluid to the first surfactant is from 100:1 to 100:20.7. A method for cementing a well bore claim 1 , the method comprising:displacing at least a portion of a drilling fluid positioned in the well bore with a spacer fluid, where the spacer fluid comprises:a base fluid; and{'sub': 2', '4', 'x, 'claim-text': R is a hydrocarbyl group having from 9 to 20 carbon atom;', 'x is an integer from 5 and 15; and', 'the first surfactant has a hydrophilic-lipophilic balance (HLB) of from 12 to 13.5., 'a surfactant package comprising one or more surfactants, where the surfactant package comprises a first surfactant having the chemical structure R—(OCH)—OH, where8. The method of claim 7 , further comprising displacing the spacer fluid with a cement slurry.9. The method of claim 8 , where:the spacer fluid is pumped into a first conduit defined by an interior wall of a tubular in the well bore;the cement slurry is pumped into the first conduit;at least a portion of the drilling fluid exits the well bore through a second conduit defined by an exterior wall of the tubular and a wall of the well bore. This application claims priority to ...

Wellbore treatment fluids with no-heat liquid solder additives

Treatment material for a wellbore operation can be mixed with a metal material coated with a layer that is controllably activated to release the metal material downhole in a wellbore. The wellbore treatment material can be mixed with the metal material prior to being positioned downhole in the wellbore.

APPARATUS AND METHODS FOR USE WITH DRILLING FLUIDS

A method for facilitating a downhole cutting operation comprises providing a drilling fluid conditioning device in a surface portion of a tubular string providing mounting for a cutting tool on a downhole portion of the string. Initially, drilling fluid is circulated through the conditioning device and the tubular string to condition the drilling fluid. The drilling fluid conditioning device is then removed from the string and the conditioned drilling fluid circulated through the tubular string and the cutting tool. 150-. (canceled)51. A method for facilitating a downhole operation , the method comprising:providing a drilling fluid conditioning device in a proximal portion of a tubular string providing mounting for at least one tool on a distal downhole portion of the tubular string;circulating drilling fluid along a fluid circulating flow path including the drilling fluid conditioning device and the tubular string, to condition the drilling fluid;reconfiguring the fluid circulating flow path to bypass at least a portion of the drilling fluid conditioning device; andcirculating conditioned drilling fluid through the tubular string and the at least one tool.52. The method of claim 51 , comprising at least one of:reconfiguring the fluid circulating flow path by removing the drilling fluid conditioning device from the tubular string;reconfiguring the fluid circulation flow path by directing drilling fluid along a flow path parallel to the drilling fluid conditioning device;reconfiguring the fluid circulation flow path by reconfiguring the drilling fluid conditioning device.53. The method of claim 51 , wherein the at least one tool comprises at least one of:a cutting tool;a drill bit;a reamer;a mill.54. The method of claim 51 , wherein the at least one tool is at least partially fluid pressure-actuated.55. The method of claim 51 , comprising at least one of:circulating conditioned fluid through the at least one tool and actuating the tool;circulating conditioned fluid ...

CEMENT SLURRIES, CURED CEMENTS AND METHODS OF MAKING AND USE THEREOF

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurry contains water, a cement precursor material, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OCH)—OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10. The cured cement contains water, cement, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OCH)—OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10. 1. A cured cement comprising: {'br': None, 'sub': 2', '4', 'x, 'R—(OCH)—OH'}, 'an alcohol surfactant comprising ethylene oxide condensate of branched isotridecyl alcohol having the formulawhere x is an integer from 1 and 10, anda carboxylic acid comprising an aliphatic carbon chain having from 16 to 18 carbon atoms.2. The cured cement of claim 1 , where the alcohol surfactant has a hydrophilic -lipophilic balance (HLB) of from 12 to 13.5.3. The cured cement of claim 1 , where the cured cement contains from 10 to 70% BWOC (By Weight of Cement) water.4. The cured cement of claim 1 , where the cured cement contains from 0.1 to 10% BWOC of the alcohol surfactant.5. The cured cement of claim 1 , where the cured cement contains from 0.1 to 10% BWOC of the carboxylic acid.6. The cured cement of claim 1 , where the carboxylic acid is selected from the group consisting of palmitic acid claim 1 , palmitoleic acid claim 1 , vaccenic acid claim 1 , oleic acid claim 1 , elaidic acid claim 1 , linoleic acid claim 1 , α-linolenic acid claim 1 , γ-linolenic acid claim 1 , stearidonic acid claim 1 , or combinations thereof.7. The cured cement of claim 1 ...

CEMENT SLURRIES, CURED CEMENTS AND METHODS OF MAKING AND USE THEREOF

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurry contains water, a cement precursor material, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OCH)—OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10. The cured cement contains water, cement, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OCH)—OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10. 1. A cement slurry comprising:water;a cement precursor material; and {'br': None, 'sub': 2', '4', 'x, 'R—(OCH)—OH'}, 'an alcohol surfactant comprising ethylene oxide condensate of branched isotridecyl alcohol having the formulawhere x is an integer from 1 and 10.3. The cement slurry of claim 1 , where the alcohol surfactant has a hydrophilic-lipophilic balance (HLB) of from 12 to 13.5.4. The cement slurry of claim 1 , where the cement slurry contains from 10 to 70% BWOC (By Weight of Cement) water.5. The cement slurry of claim 1 , where the cement slurry contains from 10 to 90% BWOC of the cement precursor material.6. The cement slurry of claim 1 , where the cement slurry contains from 0.1 to 10% BWOC of the alcohol surfactant.7. The cement slurry of claim 1 , where the cement slurry has a total fluid loss of less than or equal to 50 milliliters (mL) after 30 minutes claim 1 , as measured according to ASTM API RP 10B-2.8. The cement slurry of claim 1 , where the cement precursor material is a hydraulic cement precursor material.9. The cement slurry of claim 1 , where the cement precursor material is a non-hydraulic cement precursor ...

Drilling fluid compositions with enhanced rheology and methods of using same

Drilling fluid compositions include a base fluid, at least one additive chosen from an emulsifier, weighting material, fluid-loss additive, viscosifier, or alkali compound, and from 0.1 wt. % to 1 wt. %, based on total weight of the drilling fluid composition, of an ethoxylated alcohol compound having the formula R—(OCH2CH2)7—OH, in which R is a saturated or unsaturated, linear or branched hydrocarbyl group having from 8 to 20 carbon atoms. The base fluid may be an aqueous base fluid. Methods for drilling a subterranean well include operating a drill in a wellbore in the presence of a drilling fluid composition including the base fluid, the additive, and the ethoxylated alcohol compound.

SPACER FLUID COMPOSITIONS, METHODS, AND SYSTEMS FOR AQUEOUS BASED DRILLING MUD REMOVAL

Spacer fluids include an emulsion, a surfactant package, and at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both. The emulsion may include an aqueous external phase and a hydrocarbon-based internal phase. The surfactant package may include one or more surfactants. The surfactant package may also include a surfactant having the general structure R—(OCHCH)—OH, where R is a hydrocarbyl having 12 carbon atoms, 13 carbon atoms, or 14 carbon atoms. The spacer fluid may contain at least 4.25 pounds of R—(OCHCH)—OH per barrel of the spacer fluid. 1. A spacer fluid comprising:an emulsion comprising an aqueous external phase and a hydrocarbon-based internal phase;{'sub': 2', '4', '9, 'a surfactant package comprising one or more surfactants, where the surfactant package comprises a surfactant having the chemical structure R—(OCH)—OH, where R is a hydrocarbyl having 12 carbon atoms, and where the surfactant is present in a concentration of at least 4.25 pounds per barrel of spacer fluid; and'}at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both.2. A spacer fluid comprising:an emulsion comprising an aqueous external phase and a hydrocarbon-based internal phase;{'sub': 2', '4', '9, 'a surfactant package comprising one or more surfactants, where the surfactant package comprises a surfactant having the chemical structure R—(OCH)—OH, where R is a hydrocarbyl having 13 carbon atoms; and'}at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both.3. A spacer fluid comprising:an emulsion comprising an aqueous external phase and a hydrocarbon-based internal phase;{'sub': 2', '4', '9, 'a surfactant package comprising one or more surfactants, where the surfactant package comprises a surfactant having the chemical structure R—(OCH)—OH, where R is a hydrocarbyl having 14 carbon atoms; and'}at least one additive that modifies ...

Subterranean Tool With Sealed Electronic Passage Across Multiple Sections

The invention relates generally to oil and gas exploration and production and, more particularly, to a system and associated method for producing hydrocarbons from multiple layers of subterranean formations, and the mixing or comingling of such hydrocarbons as necessary or desired during the production process. A subterranean tool is disclosed, having a plurality of tubular sections connected by a novel non-threaded linear connection system. An electrical passage can then be provided within the cylinder wall of contiguous sections permitting connection of electronics in different sections of the tool. Bushings and seals located in the electrical passage maintain an atmospheric pressure environment for electrical components inside the tool. 1. A subterranean reservoir comingling tool , comprising:a hollow tubular body having a cylindrical wall;the body comprising a plurality of sections;the plurality of sections connected by non-threaded linear connections;an electrical passage located within the cylinder wall of contiguous sections, located in lengthwise orientation;a seal located in the electrical passage at a juncture between contiguous sections; a circuit board having a computer processor;', 'an electric motor, electrically connected to the circuit board;', 'a gearbox connected to the motor;', 'a shaft extending from the gearbox;, 'the plurality of sections comprisingthe tool having an inlet orifice at one end for receiving a first fluid into the tool;an outlet port perforating the cylindrical wall of the tubular body;a rotatable valve connected to the shaft, and having a vented portal; and,the valve being controllably rotatable between an open position in which the vented portal is aligned with the outlet port and fluid inside the tool flows through the outlet, and a closed position in which the vented portal is not aligned with the outlet and flow through the outlet is blocked.2. The tool of claim 1 , further comprising:the valve being positionable to select ...

RARE EARTH-CONTAINING COMPOUNDS TO ENHANCE PERFORMANCE OF DOWNHOLE TREATMENT COMPOSITIONS

A downhole treatment composition comprises a rare earth-containing compound comprising one or more of the following: scandium; yttrium; lanthanum; cerium; praseodymium; neodymium; promethium; samarium; lutetium; europium; gadolinium; terbium; dysprosium; holmium; erbium; thulium; or ytterbium, wherein the downhole treatment composition is a cement slurry, a drilling fluid, or a spacer fluid. Also disclosed are methods of cementing a wellbore, methods of displacing a first fluid, and methods of drilling a wellbore in a subterranean formation using the cement slurry, the spacer fluid, or the drilling fluid. 1. A method of displacing a first fluid from a wellbore , the method comprisinginjecting the first fluid into the wellbore; anddisplacing the first fluid with a spacer fluid, the spacer fluid comprising: a carrier, a rare earth-containing compound as a weighting agent, and an additive comprising one or more of the following: a viscosifier; a surfactant; a weighting agent other than the rare earth-containing compound; a lubricant; a fluid loss agent; a clay stabilizer; a biocide; an acid; a corrosion inhibitor; or an oxygen scavenger;wherein the rare earth-containing compound comprises one or more of the following: scandium; yttrium; lanthanum; cerium; praseodymium; neodymium; promethium; samarium; lutetium; europium; gadolinium; terbium; dysprosium; holmium; erbium; thulium; or ytterbium.2. The method of claim 1 , wherein the first fluid comprises a drilling fluid.3. The method of claim 1 , further comprising displacing the spacer fluid with a second fluid.4. The method of claim 3 , wherein the second fluid is a cement slurry.5. The method of claim 3 , wherein the rare earth-containing compound comprises at least one of cerium and lanthanum.6. The method of claim 3 , wherein the rare earth-containing compound comprises one or more of the following: cerium oxide; cerium chloride; cerium bromide; cerium hydroxide (hydrate); cerium carbonate; cerium sulfate; cerium ...

ENHANCED FILTRATION CONTROL PACKAGES, WELLBORE SERVICING FLUIDS UTILIZING THE SAME, AND METHODS OF MAINTAINING THE STRUCTURE OF A WELLBORE

A wellbore servicing fluid comprises an aqueous base fluid, one or more alkali metal or alkali earth metal salts, at least one visocisifier, and a filtration control package. The filtration control package may comprise a carboxylic acid and an ethoxylated alcohol compound. Alternatively, the filtration control package may comprise a polyethylene glycol. The carboxylic acid may have from 8 to 20 carbon atoms. The ethoxylated alcohol compound may have a general formula R—(OCHCH)—OH, where R is a hydrocarbon having from 10 to 16 atoms and x is an integer from 6 to 9. The ethoxylated alcohol compound may have a hydrophilic-lipophilic balance of from 8.0 to 16.0. The polyethylene glycol may have a mass average molar mass (M) of less than or equal to 1500 daltons. 126-. (canceled)27. A wellbore servicing fluid comprising:an aqueous base fluid;xanthan gum polymer; anda filtration control package comprising from 30 wt. % to 70 wt. % of at least one carboxylic acid having from 16 to 18 carbon atoms; and{'sub': 'w', 'from 30 wt. % to 70 wt. % of a polyethylene glycol with a mass average molar mass (M) less than or equal to 1500 daltons;'}where the amount of polyethylene glycol does not exceed 30 pounds per barrel of wellbore servicing fluid.28. The wellbore servicing fluid of claim 27 , further comprising a carboxylic acid having from 8 to 20 carbon atoms.29. The wellbore servicing fluid of claim 28 , where the carboxylic acid has from 14 to 20 carbon atoms.30. The wellbore servicing fluid of claim 28 , where the carboxylic acid has from 16 to 18 carbon atoms.31. The wellbore servicing fluid of claim 27 , where the polyethylene glycol has a mass average molar mass (M) less than or equal to 800 daltons.32. The wellbore servicing fluid of claim 27 , where the polyethylene glycol is present in the wellbore servicing fluid in an amount no more than 20 pounds per barrel of wellbore servicing fluid.33. The wellbore servicing fluid of claim 28 , where the carboxylic acid is present ...

ENHANCED FILTRATION CONTROL PACKAGES, WELLBORE SERVICING FLUIDS UTILIZING THE SAME, AND METHODS OF MAINTAINING THE STRUCTURE OF A WELLBORE

A wellbore servicing fluid comprises an aqueous base fluid, one or more alkali metal or alkali earth metal salts, at least one visocisifier, and a filtration control package. The filtration control package may comprise a carboxylic acid and an ethoxylated alcohol compound. Alternatively, the filtration control package may comprise a polyethylene glycol. The carboxylic acid may have from 8 to 20 carbon atoms. The ethoxylated alcohol compound may have a general formula R—(OCHCH)—OH, where R is a hydrocarbon having from 10 to 16 atoms and x is an integer from 6 to 9. The ethoxylated alcohol compound may have a hydrophilic-lipophilic balance of from 8.0 to 16.0. The polyethylene glycol may have a mass average molar mass (M) of less than or equal to 1500 daltons. 136-. (canceled)37. A method of maintaining the structure of a wellbore , the method comprising:adding a wellbore servicing fluid to a wellbore; andoperating a drill string in the presence of the wellbore servicing fluid, maintaining the structure of the wellbore; wherein xanthan gum polymer; and', from 30 wt. % to 70 wt. % of at least one carboxylic acid having from 16 to 18 carbon atoms;', [{'br': None, 'sub': 2', '2', 'X, 'R—(OCHCH)—OH; where, 'R is a hydrocarbon group having from 12 to 14 carbon atoms:', 'x is an integer from 6 to 9; and', 'the ethoxylated alcohol compound has a hydrophilic-lipophilic balance value of from 12.5 to 13.5; and, 'from 30 wt. % to 70 wt. % of an ethoxylated alcohol compound having a general formula,'}], 'a filtration control package comprising], 'the wellbore servicing fluid comprises an aqueous base fluid;'}where the carboxylic acid and ethoxylated alcohol compound are present in the wellbore servicing fluid in an amount no more than 30 pounds per barrel of wellbore servicing fluid each.38. The method of claim 37 , where R is a branched isotridecyl hydrocarbon group.39. The method of claim 37 , where x is 8.40. The method of claim 37 , where the aqueous base fluid is fresh water ...

SEGREGATING FLUIDS, METHODS OF MAKING, AND METHODS OF USE

A segregating fluid for use in a wellbore includes an aqueous segregating carrier fluid; and a preformed synthetic polymer swellable in the aqueous segregating carrier fluid in an amount effective to segregate a first fluid from a second fluid in a wellbore. 1. A segregating fluid for use in a wellbore , comprisingan aqueous segregating carrier fluid; anda preformed synthetic polymer swellable in the aqueous segregating carrier fluid in an amount effective to segregate a first fluid from a second fluid in a wellbore.2. The segregating fluid of claim 1 , wherein the carrier fluid comprises fresh water claim 1 , salt water claim 1 , aqueous acid claim 1 , aqueous base claim 1 , or a combination comprising at least one of the foregoing.3. The segregating fluid of claim 1 , wherein the preformed synthetic polymer is stable up to about 350° F.4. The segregating fluid of claim 1 , wherein the preformed synthetic polymer comprises poly(hydroxyCalkyl (meth)acrylate) claim 1 , poly(Calkyl (meth)acrylate) claim 1 , poly(meth)acrylamide claim 1 , poly(vinyl pyrrolidine) claim 1 , poly(vinyl acetate) claim 1 , or a combination comprising at least one of the foregoing polymers claim 1 ,5. The segregating fluid of claim 1 , wherein the preformed synthetic polymer comprisesa homopolymer of (meth)acrylamide or a copolymer of (meth)acrylamide with maleic anhydride, vinyl acetate, ethylene oxide, ethylene glycol, acrylonitrile, or a combination comprising at least one of the foregoing;poly(acrylamide) having crosslinks derived from polyethylene glycol diacrylate;poly(acrylic acid) having crosslinks are derived from a vinyl ester oligomer; ora poly(acrylic acid) partial sodium salt-graft-poly(ethylene glycol).6. The segregating fluid of claim 1 , wherein the preformed synthetic polymer is present in the form of particles comprising the polymer.7. The segregating fluid of claim 1 , wherein the particles are swelled and at least about 50% of the polymer particles have an average largest ...

LUBRICANTS FOR WATER-BASED DRILLING FLUIDS

Embodiments are directed to a lubricant package for water based drilling fluids. The lubricant package includes water, a polyethylene glycol, and a lubricating agent. The lubricating agent includes triethanolamine, or a C-Calcohol ethoxylate, or a combination of triethanolamine and C-Calcohol ethoxylate. The weight ratio of the polyethylene glycol to the lubricating agent in the lubricant package is from 1:2 to 2:1. Embodiments are also directed to a water-based drilling fluid composition including an aqueous base fluid, one or more additives, and the lubricant package for water based drilling fluids. 1. A lubricant package for water based drilling fluids , the lubricant package comprising:water;{'sub': 2', '2', 'n, 'a polyethylene glycol having a general formula in accordance with H—(O—CH—CH)—OH with n representing a distribution of integers to provide an average molecular weight of 250 to 700 grams/mole; and'}{'sub': 12', '14', '12', '14, 'a lubricating agent comprising triethanolamine, or a C-Calcohol ethoxylate, or a combination of triethanolamine and C-Calcohol ethoxylate,'}in which the weight ratio of the polyethylene glycol to the lubricating agent in the lubricant package is from 1:2 to 2:1.2. The lubricant package of claim 1 , in which the polyethylene glycol comprises polyethylene glycols having a distribution of molecular weights and an average molecular weight of 500 to 700 grams/mole.3. The lubricant package of claim 1 , in which the polyethylene glycol comprises polyethylene glycols having a distribution of molecular weights and an average molecular weight of 250 to 350 grams/mole.4. The lubricant package of claim 1 , in which the lubricating agent comprises triethanolamine or a combination of triethanolamine and C-Calcohol ethoxylate.5. The lubricant package of claim 1 , in which the lubricating agent comprises C-Calcohol ethoxylate or a combination of triethanolamine and C-Calcohol ethoxylate.6. The lubricant package of claim 1 , in which the C- ...

Integrated Pump and Compressor and Method of Producing Multiphase Well Fluid Downhole and at Surface

An integrated system is disclosed to handle production of multiphase fluid consisting of oil, gas and water. The production stream is first separated into two streams: a liquid dominated stream (GVF <5% for example) and a gas dominated stream (GVF >95% for example). The separation can be done through shrouds, cylindrical cyclonic, gravity, in-line or the like separation techniques. The two streams are then routed separately to pumps which pump dissimilar fluids, such as a liquid pump and a gas compressor, and subsequently recombined. Both pumps are driven by a single motor shaft which includes an internal passageway associated with one of the pumps for reception of the fluid from the other pump, thereby providing better cooling and greater overall efficiency of all systems associated therewith. A method for providing artificial lift or pressure boosting of multiphase fluid is also disclosed. 113-. (canceled)14. A method comprising:driving, by a first pumping device, a first phase-dominant stream in a direction;while driving the first phase-dominant stream, driving, by a second pumping device, a second phase-dominant stream in the direction; andflowing the first phase-dominant stream driven by the first pumping device through the second pumping device to cool the first pumping device.15. The method of claim 14 , further comprising simultaneously driving claim 14 , by a common power source claim 14 , the first pumping device and the second pumping device.16. The method of claim 14 , wherein the first single phase-dominant stream and the second single phase-dominant stream flow together in a multiphase fluid towards the first pumping device and the second pumping device claim 14 , and wherein the method further comprises separating the multiphase fluid into the first single phase-dominant stream and the second single phase-dominant stream.17. The method of claim 14 , further comprising combining the first phase-dominant stream driven by the first pumping device and the ...

Solids Control Methods, Apparatus, and Systems

A weir assembly system comprises an insert dimensioned to be inserted into a section of a wellbore and a plurality of weirs spaced within the insert so as to increase the separation of solids from fluid within the section of the wellbore when the fluid is flowing through the wellbore. The plurality of weirs may be oriented to create a tortuous fluid flow path, such that a flow opening of a first weir causes solids to deposit at a second weir without obstructing a flow opening of the second weir. Additional apparatus, methods, and systems are disclosed.

Drilling debris separator

In accordance with embodiments of the present disclosure, a debris separator device for use with a casing system may include an impeller having a plurality of blades to generate a vortex of mud in the section of the casing system when the casing system is lowered into a wellbore. The device may also include a baffle disposed in the section of the casing system, the baffle having an annular cup shape that forms an outer circumferential pocket to capture debris from the vortex of mud. The impeller and baffle may enable the debris separator device to separate debris and other debris from a flow of mud through the casing system so that the debris does not clog a float collar of the system. The disclosed debris separator device may be flushable so that the device does not become clogged with debris and can thereby maintain auto-fill through the casing system.

SHOCK ABSORBING UBHO/PULSER SUB ASSEMBLY WITH OPTIONAL MUD FILTER

A shock sleeve is positioned above a UBHO sleeve, and both are received inside a substantially tubular sub collar. The shock sleeve is free to reciprocate with respect to the UBHO sleeve and sub collar. A mud pulse transmitter valve is received into the shock sleeve. The shock sleeve is interposed between upper and lower shock springs, which provide compensating compression spring bias to dampen the transmitter valve (as received in the shock sleeve) from vibration or shock forces experienced by the sub collar. At least one shock absorbing compression ring interposed between mating portions of the shock sleeve and transmitter valve also dampens the transmitter valve against vibration or shock. An optional mud filter received over the shock sleeve removes particulate matter from drilling fluid before it encounters the shock sleeve. 1. A shock absorbing UBHO/pulser assembly , comprising:a generally cylindrical UBHO sleeve received inside a substantially tubular sub collar, the UBHO sleeve having first and second ends, the first end of the UBHO connected to a substantially cylindrical main orifice unit;a generally cylindrical shock sleeve having first and second ends, the second end of the shock sleeve providing an internal circular opening, the first end of the shock sleeve received over the second end of the UBHO sleeve;a helical lower shock spring interposed between the first end of the shock sleeve and the second end of the UBHO sleeve such that the shock sleeve is in compression spring bias with the UBHO sleeve;at least one cylindrical compression ring affixed to an interior wall of the sub collar, a helical upper shock spring interposed between the compression ring and the second end of the shock sleeve such that the shock sleeve is in compression spring bias with the compression ring;the upper and lower shock springs engaged in reciprocating compression and release so as to allow the shock sleeve dampened reciprocating displacement with respect to the sub collar ...

Integrated pump and compressor and method of producing multiphase well fluid downhole and at surface

An integrated system is disclosed to handle production of multiphase fluid consisting of oil, gas and water. The production stream is first separated into two streams: a liquid dominated stream (GVF<5% for example) and a gas dominated stream (GVF>95% for example). The separation can be done through shrouds, cylindrical cyclonic, gravity, in-line or the like separation techniques. The two streams are then routed separately to pumps which pump dissimilar fluids, such as a liquid pump and a gas compressor, and subsequently recombined. Both pumps are driven by a single motor shaft which includes an internal passageway associated with one of the pumps for reception of the fluid from the other pump, thereby providing better cooling and greater overall efficiency of all systems associated therewith. A method for providing artificial lift or pressure boosting of multiphase fluid is also disclosed.

SPACER FLUID COMPOSITIONS, METHODS, AND SYSTEMS FOR AQUEOUS BASED DRILLING MUD REMOVAL

Spacer fluids include an emulsion, a surfactant package, and at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both. The emulsion may include an aqueous external phase and a hydrocarbon-based internal phase. The surfactant package may include one or more surfactants. The surfactant package may also include a surfactant having the general structure R—(OCHCH)—OH, where R is a hydrocarbyl having 12 carbon atoms, 13 carbon atoms, or 14 carbon atoms. The spacer fluid may contain at least 4.25 pounds of R—(OCHCH)—OH per barrel of the spacer fluid. 1. A method of removing aqueous muds from a wellbore , the method comprising: an emulsion comprising an aqueous external phase and a hydrocarbon-based internal phase;', {'sub': 2', '4', '9, 'claim-text': R is a hydrocarbyl having from 12 to 14 carbon atoms and the surfactant has a hydrophilic-lipophilic balance from 11 to 15; and', 'at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both;, 'a surfactant package comprising one or more surfactants, where the surfactant package comprises a surfactant having the chemical structure R—(OCH)—OH, where], 'adding a spacer fluid according to any of the preceding claims to a wellbore comprising an aqueous mud, the spacer fluid comprisingpassing the spacer fluid through the wellbore, where at least a portion of the aqueous mud exits the wellbore through a conduit defined by an exterior wall of the tubular and a wall of the wellbore.213. The method of claim , in which the spacer fluid has a yield point from 10 lbf/100 ftto 50 lbf/100 ftas measured by American Petroleum Institute Recommended Practice 13B-1.313. The method of claim , in which the spacer fluid has a yield point from 10 lbf/100 ftto 25 lbf/100 ftas measured by American Petroleum Institute Recommended Practice 13B-1.413. The method of claim , in which the hydrocarbon-based internal phase comprises one or more of safra ...

SPACER FLUID COMPOSITIONS, METHODS, AND SYSTEMS FOR AQUEOUS BASED DRILLING MUD REMOVAL

Spacer fluids include an emulsion, a surfactant package, and at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both. The emulsion may include an aqueous external phase and a hydrocarbon-based internal phase. The surfactant package may include one or more surfactants. The surfactant package may also include a surfactant having the general structure R—(OCHCH)—OH, where R is a hydrocarbyl having 12 carbon atoms, 13 carbon atoms, or 14 carbon atoms. The spacer fluid may contain at least 4.25 pounds of R—(OCHCH)—OH per barrel of the spacer fluid. 1. A spacer fluid comprising:an emulsion comprising an aqueous external phase and a hydrocarbon-based internal phase;{'sub': 2', '4', '9, 'a surfactant package comprising one or more surfactants, where the surfactant package comprises a surfactant having the chemical structure R—(OCH)—OH, where R is a hydrocarbyl having 12 to 14 carbon atoms, and where the surfactant is present in a concentration of at least 4.25 pounds per barrel of spacer fluid; and'}at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both.2. The spacer fluid of claim 1 , in which the surfactant package has a hydrophilic-lipophilic balance value from 13 to 15.3. The spacer fluid of claim 1 , in which the spacer fluid has a yield point from 10 lbf/100 ftto 50 lbf/100 ftas measured by American Petroleum Institute Recommended Practice 13B-1.4. The spacer fluid of claim 1 , in which the spacer fluid has a yield point from 10 lbf/100 ftand 25 lbf/100 ftas measured by American Petroleum Institute Recommended Practice 13B-1.5. The spacer fluid of claim 1 , in which the spacer fluid has a density from 62.5 pcf to 160 pcf.6. The spacer fluid of claim 1 , in which the spacer fluid has a density from 72.0 pcf to 87.5 pcf.7. The spacer fluid of claim 1 , in which the hydrocarbon-based internal phase comprises one or more of safra oil claim 1 , diesel claim 1 , ...

DEVELOPMENT OF RETARDED ACID SYSTEM

In one embodiment, a retarded acid system comprises an aqueous acid and a retarding surfactant. The aqueous acid may comprise from 5 wt. % to 25 wt. % of a strong acid, that is, an acid having a Kgreater than or equal to 0.01. The aqueous acid may further comprise from 75 wt. % to 95 wt. % water. The retarding surfactant may have the general chemical formula R—(OCH)—OH where R is a hydrocarbon having from 11 to 15 carbon atoms and x is an integer from 6 to 10. The retarding surfactant may have a hydrophilic-lipophilic balance from 8 to 16.

SYSTEM AND METHOD FOR ELECTROMECHANICAL ACTUATOR APPARATUS HAVING A SCREEN ASSEMBLY

An electromechanical actuator having a servo valve is described. The servo valve has a valve housing having a wall surrounding the servo valve, the valve housing having a first end and a second end with the servo valve positioned between the first end and the second end. The valve housing also includes at least one debris vent positioned on an exterior surface of the wall between the servo valve and the first end of the valve housing, the debris vent having a first dimension; and, at least one fluid vent positioned on the exterior surface of the wall between the servo valve and the second end of the valve housing, the fluid vent having a second dimension. The first dimension is smaller than the second dimension. 1. An electromechanical actuator , comprising:a servo valve;a valve housing having a wall surrounding the servo valve, the valve housing having a first end and a second end with the servo valve positioned between the first end and the second end, the valve housing comprising:at least one debris vent positioned on an exterior surface of the wall between the servo valve and the first end of the valve housing, the debris vent having a first dimension; and,at least one fluid vent positioned on the exterior surface of the wall between the servo valve and the second end of the valve housing, the fluid vent having a second dimension;wherein the first dimension is smaller than the second dimension.2. The electromechanical actuator of claim 1 , wherein the valve housing includes a first debris vent and a second debris vent with dimension of the first debris vent and the second debris vent being different.3. The electromechanical actuator of claim 1 , wherein the valve housing includes a first fluid vent and a second fluid vent with dimensions of the first fluid vent and the second fluid vent being different.4. The electromechanical actuator of claim 1 , wherein the valve housing further includes a screen assembly claim 1 , the screen assembly covering at least one of ...

DEVELOPMENT OF ANTI-BIT BALLING FLUIDS

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OCH)—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH—CH)—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided. 2. The method of claim 1 , where introducing the drilling fluid comprises injecting the drilling fluid and at least partially circulating the drilling fluid within the subterranean formation.3. The method of claim 1 , where the surfactant has an HLB of from 8 to 16.4. The method of claim 1 , where the drilling fluid comprises from 28 to 850 lb/bbl water claim 1 , from 28 to 720 lb/bbl of the clay-based component based on total weight of the drilling fluid claim 1 , and from 0.02 to 180 lb/bbl of the surfactant claim 1 , the polyethylene glycol claim 1 , or both claim 1 , based on total weight of the drilling fluid.5. The method of claim 1 , where the drilling fluid has an accretion percentage of less than or equal to 18%.6. The method of claim 1 , where R is:an alkyl group comprising 12 to 15 carbons; oran alkenyl group comprising from 12 to 15 carbon atoms.7. The method of claim 1 , where x is from 5 to 10.8. The method of claim 1 , where the surfactant has an HLB of from 13 to 15.9. The method of claim 1 , where the surfactant comprises ethylene oxide condensate of branched isotridecyl alcohol.10. The method of claim 1 , where the polyethylene glycol has a weight average molecular weight of from 300 grams per mol (g/mol) to 500 g/mol claim 1 , as measured according to GPC.11. The method of claim 1 , where the drilling fluid comprises from 28 to 850 lb/bbl water based on total weight of the drilling fluid.12. The method of claim 1 , where the drilling fluid comprises from ...

Method and Apparatus for Fracking and Producing A Well

A technique facilitates performance of well operations. According to an embodiment, the technique employs a modular assembly configured for coupling with a wellhead assembly. The modular assembly may have a production subassembly and a fracturing subassembly. By way of example, the production subassembly may comprise a connection block positioned for coupling to the wellhead assembly, a production outlet fluidly connected to the connection block, and a valve between the connection block and the production outlet. Additionally, the fracturing subassembly may be releasably coupled to the production subassembly. According to an embodiment, the fracturing subassembly comprises an inlet for receiving fracturing fluids, an outlet coupled to the connection block, and a bore between the inlet and the outlet for communicating a fracturing fluid to a well. 1. A system for use with a wellhead assembly , mounted over a borehole , to perform well operations , comprising: [ a connection block positioned for coupling to the wellhead assembly;', 'a production outlet fluidly connected to the connection block; and', 'a valve between the connection block and the production outlet; and, 'a production subassembly comprising, an inlet for receiving fracturing fluid;', 'is an outlet coupled to the connection block; and', 'a bore between the inlet and the outlet for communicating a fracturing fluid to the well., 'a fracturing subassembly releasably coupled to the production subassembly, the fracturing subassembly comprising], 'a modular assembly configured for coupling with the wellhead assembly, the modular assembly having2. The system as recited in claim 1 , wherein the connection block has a first conduit to provide fluid communication between the fracturing subassembly and the borehole.3. The system as recited in claim 2 , wherein the connection block has a second conduit to provide fluid communication through the connection block to the production outlet.4. The system as recited in ...

Methods of using drilling fluid compositions with enhanced rheology

Drilling fluid compositions include a base fluid, at least one additive chosen from an emulsifier, weighting material, fluid-loss additive, viscosifier, or alkali compound, and from 0.1 wt. % to 1 wt. %, based on total weight of the drilling fluid composition, of an ethoxylated alcohol compound having the formula R—(OCH 2 CH 2 ) 7 —OH, in which R is a saturated or unsaturated, linear or branched hydrocarbyl group having from 8 to 20 carbon atoms. The base fluid may be an aqueous base fluid. Methods for drilling a subterranean well include operating a drill in a wellbore in the presence of a drilling fluid composition including the base fluid, the additive, and the ethoxylated alcohol compound.

SYSTEM, METHOD, AND DEVICE FOR POWERING ELECTRONICS DURING COMPLETION AND PRODUCTION OF A WELL

A system, method, and power control device for powering electronics located in a wellbore intersecting a subterranean earth formation. The system comprises a battery, a turbine generator, an electronic device, and a processor. The battery is locatable in the wellbore and the turbine generator is locatable in the wellbore so as to be in fluid communication with a flow path in the wellbore. The electronic device is locatable in the wellbore and electrically coupled to the battery and the turbine generator. The processor determines if a power condition is satisfied to allow the turbine generator to power the electronic device. The method comprises powering an electronic device located in the wellbore using a battery and opening a closed flow path in communication with a turbine generator. The method also comprises powering the electronic device using the turbine generator if a power condition is satisfied. 1. A system for powering electronics located in a wellbore intersecting a subterranean earth formation , comprising:a battery locatable in the wellbore;a turbine generator locatable in the wellbore so as to be in fluid communication with a flow path in the wellbore;an electronic device locatable in the wellbore and electrically coupled to the battery and the turbine generator; anda processor configured to determine if a power condition is satisfied to allow the turbine generator to power the electronic device.2. The system of claim 1 , wherein the electronic device is powered by the battery if the power condition is not satisfied.3. The system of claim 1 , wherein the electronic device includes any one or combination of a sensor claim 1 , a valve claim 1 , a pump claim 1 , and an actuator.4. The system of claim 3 , wherein the sensor is configured to measure any one or combination of pressure claim 3 , flow rate claim 3 , tool position claim 3 , tool orientation claim 3 , valve position claim 3 , vibration claim 3 , fluid composition claim 3 , and temperature.5. The ...

Integrated Pump and Compressor and Method of Producing Multiphase Well Fluid Downhole and at Surface

An integrated system is disclosed to handle production of multiphase fluid consisting of oil, gas and water. The production stream is first separated into two streams: a liquid dominated stream (GVF<5% for example) and a gas dominated stream (GVF>95% for example). The separation can be done through shrouds, cylindrical cyclonic, gravity, in-line or the like separation techniques. The two streams are then routed separately to pumps which pump dissimilar fluids, such as a liquid pump and a gas compressor, and subsequently recombined. Both pumps are driven by a single motor shaft which includes an internal passageway associated with one of the pumps for reception of the fluid from the other pump, thereby providing better cooling and greater overall efficiency of all systems associated therewith. A method for providing artificial lift or pressure boosting of multiphase fluid is also disclosed. 113-. (canceled)14. A system comprising:a first pumping device configured to receive and pump a first single phase-dominant stream of a multiphase fluid;a second pumping device configured to receive and pump a second single phase-dominant stream of the multiphase fluid; and a solid portion located within the first pumping device, and', 'a hollow portion located within the second pumping device, the hollow portion configured to receive the first single phase-dominant stream pumped by the first pumping device., 'a drive shaft common to the first pumping device and the second pumping device, each of the first pumping device and the second pumping device configured to be simultaneously driven on the drive shaft, the drive shaft comprising15. The system of claim 14 , wherein the first single phase-dominant stream and the second single phase-dominant stream flow together in a multiphase fluid towards the first pumping device and the second pumping device claim 14 , and wherein the system comprises a separator configured to separate the multiphase fluid into the first single phase- ...

Method of completing a well

A method of completing a well includes, pumping treating fluid into a tool string in the well, displacing drilling mud within the tool string with the treating fluid, and treating an earth formation with the treating fluid.

MULTI-COMPONENT DOWNHOLE TREATMENT

A downhole treatment system, apparatus, and methods are disclosed. In some embodiments a treatment apparatus includes a first conduit configured to transport a first fluid from a first fluid source through a first enclosed channel to a first outlet. A second conduit is configured to transport a second fluid from a second fluid source through a second enclosed channel to a second outlet. The treatment apparatus further comprises a mixing applicator that includes the first outlet positioned to provide a discharge path for the first fluid that at least partially intersects a flow path of the second fluid within a confluence region within or external to the second conduit. 1. A downhole treatment apparatus comprising:a first conduit configured to transport a first fluid from a first fluid source through a first enclosed channel to a first outlet;a second conduit configured to transport a second fluid from a second fluid source through a second enclosed channel to a second outlet; anda mixing applicator that includes the first outlet positioned to provide a discharge path for the first fluid that at least partially intersects a flow path of the second fluid within a confluence region within or external to the second conduit.2. The downhole treatment apparatus of claim 1 , further comprising a coiled tubing tool string within which the second conduit is coextensively disposed in substantially parallel proximity with respect to the first conduit.3. The downhole treatment apparatus of claim 1 , wherein the first conduit is coextensively disposed within the second conduit.4. The downhole treatment apparatus of claim 3 , wherein the mixing applicator comprises an internal mixing sub in which the first outlet comprises one or more orifices in the first conduit and the second outlet comprises one or more orifices in the second conduit downstream of the one or more orifices in the first conduit.5. The downhole treatment apparatus of claim 4 , wherein each of the one or more ...

EMULSIFIED DRILLING FLUIDS AND METHODS OF MAKING AND USE THEREOF

Drilling fluids and methods of making and using drilling fluids are provided. The drilling fluid contains an aqueous phase, an oleaginous phase, and at least one surfactant having the formula R—(OCH)—OH, where R is a hydrocarbyl group having from 8 to 20 carbon atoms and x is an integer from 1 to 10. Methods of producing drilling fluids include mixing an aqueous phase, an oleaginous phase, and at least one surfactant, and shearing the mixture. Methods of using drilling fluids to drill subterranean formations include mixing an aqueous phase, an oleaginous phase, and at least one surfactant to produce a mixture, which is sheared to form a drilling fluid, and pumped through a drill string in a drill bit located in a subterranean formation. Rock cuttings are transported from the drill bit to a surface of the subterranean formation and the drilling fluid is circulated in the subterranean formation. 1. A drilling fluid comprising:an aqueous phase;an oleaginous phase; and [{'br': None, 'sub': 2', '4', 'x, 'R—(OCH)—OH'}, 'where R is a hydrocarbyl group having from 8 to 20 carbon atoms, and', 'x is an integer from 1 and 10., 'at least one surfactant comprising the formula2. The drilling fluid of claim 1 , where the surfactant has a hydrophilic-lipophilic balance (HLB) of from 8 to 16.3. The drilling fluid of claim 1 , where the drilling fluid comprises from 28 to 630 pounds per barrel (lb/bbl) of the aqueous phase based on the total weight of the drilling fluid.4. The drilling fluid of claim 1 , where the drilling fluid comprises from 28 to 810 lb/bbl of the oleaginous phase based on the total weight of the drilling fluid.5. The drilling fluid of claim 1 , where the drilling fluid comprises from 0.02 to 180 lb/bbl of the surfactant based on the total weight of the drilling fluid.6. The drilling fluid of claim 1 , where the oleaginous phase comprises one or more components selected from the group consisting of natural oil claim 1 , synthetic oil claim 1 , diesel oil claim 1 , ...

Drilling debris separator

In accordance with embodiments of the present disclosure, a debris separator device for use with a casing system may include an impeller having a plurality of blades to generate a vortex of mud in the section of the casing system when the casing system is lowered into a wellbore. The device may also include a baffle disposed in the section of the casing system, the baffle having an annular cup shape that forms an outer circumferential pocket to capture debris from the vortex of mud. The impeller and baffle may enable the debris separator device to separate debris and other debris from a flow of mud through the casing system so that the debris does not clog a float collar of the system. The disclosed debris separator device may be flushable so that the device does not become clogged with debris and can thereby maintain auto-fill through the casing system.

Consolidating spacer fluids and methods of use

Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus.

Drilling tool for well drilling and flushing thereof, well drilling method and drilling rig

FIELD: well drilling, particularly methods or apparatus for flushing boreholes. SUBSTANCE: drilling tool comprises drilling part for rock cutting and receiver to collect drill fines. Device having members, which provide flushing medium pumping, is also disclosed. Above device provides transforming of fluid medium from well filling zone into flow, which conveys drill fines to receiver. Drilling tool comprises tubular body provided with crown bit located from drilling tool bottom and with lid located from drilling tool top. The lid has at least one liquid medium passage means. The lid and the tubular body define inner cavity. Drill fines receiver is arranged on upper lid side. Liquid medium passage means has valve assembly, which permits fluid flow movement through the passage means to inner cavity and closes the passage means when fluid flow passes in reverse direction. EFFECT: simplified drilling operation. 13 cl, 4 dwg ÐÎÑÑÈÉÑÊÀß ÔÅÄÅÐÀÖÈß RU (19) (11) 2 282 012 (13) C2 (51) ÌÏÊ E21B 21/00 (2006.01) E21B 7/00 (2006.01) ÔÅÄÅÐÀËÜÍÀß ÑËÓÆÁÀ ÏÎ ÈÍÒÅËËÅÊÒÓÀËÜÍÎÉ ÑÎÁÑÒÂÅÍÍÎÑÒÈ, ÏÀÒÅÍÒÀÌ È ÒÎÂÀÐÍÛÌ ÇÍÀÊÀÌ (12) ÎÏÈÑÀÍÈÅ ÈÇÎÁÐÅÒÅÍÈß Ê ÏÀÒÅÍÒÓ (21), (22) Çà âêà: 2004117327/03, 09.06.2004 (72) Àâòîð(û): ØÒÅÒÖÅÐ Ýðâèí Ýìèëü (DE) (24) Äàòà íà÷àëà îòñ÷åòà ñðîêà äåéñòâè ïàòåíòà: 09.06.2004 (73) Ïàòåíòîîáëàäàòåëü(è): Áàóýð Ìàøèíåí ÃìáÕ (DE) R U (30) Êîíâåíöèîííûé ïðèîðèòåò: 25.06.2003 (ïï.1-13) DE 10328609.8 (43) Äàòà ïóáëèêàöèè çà âêè: 20.11.2005 (45) Îïóáëèêîâàíî: 20.08.2006 Áþë. ¹ 23 2 2 8 2 0 1 2 (56) Ñïèñîê äîêóìåíòîâ, öèòèðîâàííûõ â îò÷åòå î ïîèñêå: DE 19702533 À, 30.07.1998. SU 126826 À, 17.05.1960. SU 588344 À, 30.01.1978. ÄÅÐÓÑΠÂ.Ï. Îáðàòíà ïðîìûâêà ïðè áóðåíèè ãåîëîãîðàçâåäî÷íûõ ñêâàæèí. - Ì.: Íåäðà, 1984, ñ.43-45, ñ.62-63. 2 2 8 2 0 1 2 R U (54) ÁÓÐÎÂÎÅ ÓÑÒÐÎÉÑÒÂÎ ÄËß ÁÓÐÅÍÈß Ñ ÏÐÎÌÛÂÊÎÉ, ÑÏÎÑÎÁ ÏÐÎÕÎÄÊÈ ÑÊÂÀÆÈÍÛ Â ÃÐÓÍÒÅ È ÁÓÐÎÂÀß ÓÑÒÀÍÎÂÊÀ (57) Ðåôåðàò: Èçîáðåòåíèå îòíîñèòñ ê ñïîñîáó ïðîõîäêè ñêâàæèíû â ãðóíòå ñ èñïîëüçîâàíèåì áóðîâîãî óñòðîéñòâà äë áóðåíè ñ ...

Соединения с редкоземельными элементами для улучшения характеристик скважинных обрабатывающих композиций

Изобретение относится к скважинной обрабатывающей композиции, содержащей соединение с редкоземельным элементом, которое содержит один или более из следующих элементов: скандий, иттрий, лантан, церий, празеодим, неодим, прометий, самарий, лютеций, европий, гадолиний, тербий, диспрозий, гольмий, эрбий, тулий или иттербий; причем скважинная обрабатывающая композиция представляет собой цементную суспензию, буровой раствор или буферную жидкость. Раскрыты также способы цементирования ствола скважины, способы вытеснения первого флюида и способы бурения ствола скважины в подземном пласте с использованием цементной суспензии, буферной жидкости или бурового раствора. Изобретение развито в зависимых пунктах формулы изобретения. Технический результат - улучшение эксплуатационных свойств. 4 н. и 6 з.п. ф-лы, 4 табл. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 2 695 198 C1 (51) МПК C09K 8/467 (2006.01) C09K 8/04 (2006.01) C09K 8/40 (2006.01) E21B 33/13 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ИЗОБРЕТЕНИЯ К ПАТЕНТУ (52) СПК C09K 8/467 (2018.08); C09K 8/40 (2018.08); C09K 8/03 (2018.08); E21B 33/13 (2018.08) (21)(22) Заявка: 2018115832, 14.10.2016 (24) Дата начала отсчета срока действия патента: Дата регистрации: (73) Патентообладатель(и): БЕЙКЕР ХЬЮЗ, Э ДЖИИ КОМПАНИ, ЛЛК (US) 22.07.2019 (56) Список документов, цитированных в отчете о поиске: US 2012211227 A1, 23.08.2012. US 2010243236 A1, 30.09.2010;. US 2013098615 A1, 25.04.2013. RU 2513581 C2, 30.11.2015. 21.10.2015 US 14/918,637 (45) Опубликовано: 22.07.2019 Бюл. № 21 (85) Дата начала рассмотрения заявки PCT на национальной фазе: 27.04.2018 (86) Заявка PCT: 2 6 9 5 1 9 8 R U (87) Публикация заявки PCT: WO 2017/070016 (27.04.2017) Адрес для переписки: 105082, Москва, Спартаковский пер., д. 2, стр. 1, секция 1, этаж 3, ЕВРОМАРКПАТ (54) СОЕДИНЕНИЯ С РЕДКОЗЕМЕЛЬНЫМИ ЭЛЕМЕНТАМИ ДЛЯ УЛУЧШЕНИЯ ХАРАКТЕРИСТИК СКВАЖИННЫХ ОБРАБАТЫВАЮЩИХ КОМПОЗИЦИЙ (57) Реферат: Изобретение относится к скважинной буферную ...

Longitudinally offset partial area screens for well assembly

A downhole assembly can include screens along a length of a tubular member. Screens covering differing portions of a cross-sectional area of the tubular and less than an entirety of the cross-sectional area can be offset from one another along a length of the tubular. Fluid flowing through an area not covered by a first screen can encounter an area covered by an offset screen. If the offset screen is blocked with accumulated debris, fluid may pass the offset screen by passing through an area not covered by the offset screen.

Methods of downhole testing subterranean formations and associated apparatus therefor

Methods and apparatus are provided which permit well testing operations to be performed downhole in a subterranean well. In various described methods, fluids flowed from a formation during a test may be disposed of downhole by injecting the fluids into the formation from which they were produced, or by injecting the fluids into another formation. In several of the embodiments of the invention, apparatus utilized in the methods permit convenient retrieval of samples of the formation fluids and provide enhanced data acquisition for monitoring of the test and for evaluation of the formation fluids.

Fish through filter device

Consolidating spacer fluids and methods of use

Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus.

Consolidating spacer fluids and methods of use

Disclosed are spacer fluids and methods of use in subterranean formations. Embodiments may include use of consolidating spacer fluids in displacement of drilling fluids from a well bore annulus.

Methods and apparatus for download transfer of drill cuttings

A drilling fluid delivery system for drilling boreholes with a drill bit, includes a primary flow circuit having a relatively high flow rate for transferring drilling fluid to and from the drill bit. The system also includes a secondary flow circuit having a relatively low flow rate for transferring drilling fluid to and from the primary flow circuit. Furthermore, the system includes a cuttings transfer system, such as a hydrocyclone or a rotating filter, between the primary and secondary flow circuits. When the cutting transfer system is in use, it receives fluid containing cuttings from the primary circuit and separates the fluid into a first stream that contains substantially no cuttings and a second stream containing cuttings. The first stream is returned to the primary flow circuit and the second stream is directed to the secondary flow circuit.

Anti-bit balling drilling fluids, and methods of making and use thereof

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OC 2 H 4 ) x —OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH 2 —CH 2 ) n —OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided.

Emulsifier compositions for invert emulsion fluids and methods of using the same

Drilling fluid compositions include invert emulsion fluids having an oleaginous phase, an aqueous phase, and an emulsifier composition that includes an ethoxylated alcohol compound and a polyaminated fatty acid compound. The ethoxylated alcohol compound has the formula R1—(OCH2CH2)n—OH, where R1 is a hydrocarbyl group having from 8 to 22 carbon atoms and n is from 1 to 8. The ethoxylated alcohol compound has a Hydrophilic-Lipophilic Balance (HLB) of less than or equal to 6. The polyaminated fatty acid compound has the formula R2—CO—NH—CH2—CH2—N(COR2)—CH2—CH2—NH—CO—R3, where R2 is a hydrocarbyl group having from 1 to 20 carbon atoms and R3 is a hydrocarbyl group having 1 to 10 carbon atoms or an alkylene carboxylate group having formula —R4—COOH, where R4 is a saturated or unsaturated hydrocarbylene having from 1 to 10 carbon atoms. Methods of drilling wells include operating a drill in a wellbore in the presence of drilling fluid compositions.

Spacer fluids and cement slurries that include surfactants

According to at least one embodiment of the present disclosure, a well bore cementing system may comprise a spacer fluid and a cement slurry. The spacer fluid may be positioned within a well bore, and the spacer fluid may comprise a first surfactant package comprising one or more surfactants. The cement slurry may be positioned within the well bore, and the cement slurry may comprise a second surfactant package comprising one or more surfactants.

Spacer fluid compositions, methods, and systems for aqueous based drilling mud removal

Spacer fluids include an emulsion, a surfactant package, and at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both. The emulsion may include an aqueous external phase and a hydrocarbon-based internal phase. The surfactant package may include one or more surfactants. The surfactant package may also include a surfactant having the general structure R—(OCH2CH2)9—OH, where R is a hydrocarbyl having 12 carbon atoms, 13 carbon atoms, or 14 carbon atoms. The spacer fluid may contain at least 4.25 pounds of R—(OCH2CH2)9—OH per barrel of the spacer fluid.

Enhanced filtration control packages, wellbore servicing fluids utilizing the same, and methods of maintaining the structure of a wellbore

A wellbore servicing fluid comprises an aqueous base fluid, one or more alkali metal or alkali earth metal salts, at least one visocisifier, and a filtration control package. The filtration control package may comprise a carboxylic acid and an ethoxylated alcohol compound. Alternatively, the filtration control package may comprise a polyethylene glycol. The carboxylic acid may have from 8 to 20 carbon atoms. The ethoxylated alcohol compound may have a general formula R—(OCH 2 CH 2 ) x —OH, where R is a hydrocarbon having from 10 to 16 atoms and x is an integer from 6 to 9. The ethoxylated alcohol compound may have a hydrophilic-lipophilic balance of from 8.0 to 16.0. The polyethylene glycol may have a mass average molar mass (M w ) of less than or equal to 1500 daltons.

Cement slurries, cured cement and methods of making and use thereof

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, improved rheology, such as improved flowability and pumpability and may be used, for instance, in the oil and gas drilling industry. The cement slurry contains water, a cement precursor material and a surfactant having the formula R—(OC2H4)x—OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10. The cured cement have improved strength and density properties due to reduced fluid loss and even placement during curing. The cured cement contains a surfactant having the formula R—(OC2H4)x—OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10.

Development of anti-bit balling fluids

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OC2H4)x—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH2—CH2)n—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided.

Anti-bit balling drilling fluids, and methods of making and use thereof

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and a polyethylene glycol having the formula: H—(O—CH2—CH2)n—OH, where n is an integer from 1 to 50.

Development of anti-bit balling fluids

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OC2H4)x—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH2—CH2)n—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided.

Methods of using drilling fluid compositions with enhanced rheology

Drilling fluid compositions include a base fluid, at least one additive chosen from an emulsifier, weighting material, fluid-loss additive, viscosifier, or alkali compound, and from 0.1 wt. % to 1 wt. %, based on total weight of the drilling fluid composition, of an ethoxylated alcohol compound having the formula R—(OCH2CH2)7—OH, in which R is a saturated or unsaturated, linear or branched hydrocarbyl group having from 8 to 20 carbon atoms. The base fluid may be an aqueous base fluid. Methods for drilling a subterranean well include operating a drill in a wellbore in the presence of a drilling fluid composition including the base fluid, the additive, and the ethoxylated alcohol compound.

Drilling fluid compositions with enhanced rheology and methods of using same

Drilling fluid compositions include a base fluid, at least one additive chosen from an emulsifier, weighting material, fluid-loss additive, viscosifier, or alkali compound, and from 0.1 wt. % to 1 wt. %, based on total weight of the drilling fluid composition, of an ethoxylated alcohol compound having the formula R—(OCH 2 CH 2 ) 7 —OH, in which R is a saturated or unsaturated, linear or branched hydrocarbyl group having from 8 to 20 carbon atoms. The base fluid may be an aqueous base fluid. Methods for drilling a subterranean well include operating a drill in a wellbore in the presence of a drilling fluid composition including the base fluid, the additive, and the ethoxylated alcohol compound.

Spacer fluid compositions that include surfactants

In one embodiment, a spacer fluid may comprise a base fluid and a surfactant package. The surfactant package may comprise one or more surfactants, where the surfactant package comprises a first surfactant having the chemical structure R—(OC 2 H 4 ) x —OH. R may be a hydrocarbyl group having from 9 to 20 carbon atom, and x may be an integer from 5 and 15. The first surfactant may have a hydrophilic-lipophilic balance (HLB) of from 12 to 13.5.

Dispersant in cement formulations for oil and gas wells

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, improved rheology, such as improved flowability and pumpability and may be used, for instance, in the oil and gas drilling industry. The cement slurry contains water, a cement precursor material and a surfactant having the formula R—(OC 2 H 4 ) x —OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10. The cured cement have improved strength and density properties due to reduced fluid loss and even placement during curing. The cured cement contains a surfactant having the formula R—(OC 2 H 4 ) x —OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10.

Lubricants for water-based drilling fluids

Embodiments are directed to a lubricant package for water based drilling fluids. The lubricant package includes water, a polyethylene glycol, and a lubricating agent. The lubricating agent includes triethanolamine, or a C12-C14 alcohol ethoxylate, or a combination of triethanolamine and C12-C14 alcohol ethoxylate. The weight ratio of the polyethylene glycol to the lubricating agent in the lubricant package is from 1:2 to 2:1. Embodiments are also directed to a water-based drilling fluid composition including an aqueous base fluid, one or more additives, and the lubricant package for water based drilling fluids.

Invert emulsion based drilling fluid and methods of using same

A drilling fluid composition which includes a base fluid, one or more additives, and a viscosifier package. The base fluid is an invert emulsion comprising oil and water. Further, the one or more additives is chosen from an emulsifier, a weighting material, a fluid-loss control additive, or an alkaline compound. The viscosifier package includes a fatty acid having 6 or more carbon atoms and an aliphatic polyester. The drilling fluid composition has a yield point of from 30 lb f /100 ft 2 to 100 lb f /100 ft 2 and a low shear yield point of from 10 lb f /100 ft 2 to 40 lb f /100 ft 2 . The associated method of drilling a subterranean well including operating a drill in a wellbore in the presence of the drilling fluid composition is also provided.

Development of retarded acid system

In one embodiment, a retarded acid system comprises an aqueous acid and a retarding surfactant. The aqueous acid may comprise from 5 wt. % to 25 wt. % of a strong acid, that is, an acid having a K a greater than or equal to 0.01. The aqueous acid may further comprise from 75 wt. % to 95 wt. % water. The retarding surfactant may have the general chemical formula R—(OC 2 H 4 ) X —OH where R is a hydrocarbon having from 11 to 15 carbon atoms and x is an integer from 6 to 10. The retarding surfactant may have a hydrophilic-lipophilic balance from 8 to 16.

Dispersant in cement formulations for oil and gas wells

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurries have, among other attributes, improved rheology, such as improved flowability and pumpability and may be used, for instance, in the oil and gas drilling industry. The cement slurry contains water, a cement precursor material and a surfactant having the formula R—(OC2H4)x—OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10. The cured cement have improved strength and density properties due to reduced fluid loss and even placement during curing. The cured cement contains a surfactant having the formula R—(OC2H4)x—OH where R is a hydrocarbyl group comprising from 10 to 20 carbon atoms and x is an integer from 1 and 10.

Development of anti-bit balling fluids

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OC 2 H 4 ) x —OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH 2 —CH 2 ) n —OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided.

Development of anti-bit balling fluids

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OC 2 H 4 ) x —OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH 2 —CH 2 ) n —OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided.

Cement slurries, cured cements and methods of making and use thereof

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurry contains water, a cement precursor material, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OC2H4)x—OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10. The cured cement contains water, cement, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OC2H4)x—OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10.

Enhanced filtration control packages, wellbore servicing fluids utilizing the same, and methods of maintaining the structure of a wellbore

A wellbore servicing fluid comprises an aqueous base fluid, one or more alkali metal or alkali earth metal salts, at least one visocisifier, and a filtration control package. The filtration control package may comprise a carboxylic acid and an ethoxylated alcohol compound. Alternatively, the filtration control package may comprise a polyethylene glycol. The carboxylic acid may have from 8 to 20 carbon atoms. The ethoxylated alcohol compound may have a general formula R—(OCH2CH2)x—OH, where R is a hydrocarbon having from 10 to 16 atoms and x is an integer from 6 to 9. The ethoxylated alcohol compound may have a hydrophilic-lipophilic balance of from 8.0 to 16.0. The polyethylene glycol may have a mass average molar mass (Mw) of less than or equal to 1500 daltons.

Development of anti-bit balling fluids

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OC2H4)x—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH2—CH2)n—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided.

Cement slurries, cured cements and methods of making and use thereof

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurry contains water, a cement precursor material, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OC 2 H 4 ) x —OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10. The cured cement contains water, cement, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OC 2 H 4 ) x —OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10.

Cement slurries, cured cements and methods of making and use thereof

Cement slurries, cured cements, and methods of making cured cement and methods of using cement slurries are provided. The cement slurry contains water, a cement precursor material, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OC 2 H 4 ) x —OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10. The cured cement contains water, cement, an alcohol surfactant having from 10 to 20 carbon atoms and a carboxylic acid comprising an aliphatic chain having from 16 to 18 carbons. In some embodiments, the alcohol surfactant may comprise the formula R—(OC 2 H 4 ) x —OH where R is a hydrocarbyl group having from 10 to 20 carbons and x is an integer from 1 to 10.

Enhanced filtration control packages, wellbore servicing fluids utilizing the same, and methods of maintaining the structure of a wellbore

A wellbore servicing fluid comprises an aqueous base fluid, one or more alkali metal or alkali earth metal salts, at least one visocisifier, and a filtration control package. The filtration control package may comprise a carboxylic acid and an ethoxylated alcohol compound. Alternatively, the filtration control package may comprise a polyethylene glycol. The carboxylic acid may have from 8 to 20 carbon atoms. The ethoxylated alcohol compound may have a general formula R—(OCH2CH2)X—OH, where R is a hydrocarbon having from 10 to 16 atoms and x is an integer from 6 to 9. The ethoxylated alcohol compound may have a hydrophilic-lipophilic balance of from 8.0 to 16.0. The polyethylene glycol may have a mass average molar mass (Mw) of less than or equal to 1500 daltons.

Spacer fluid compositions, methods, and systems for aqueous based drilling mud removal

Spacer fluids include an emulsion, a surfactant package, and at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both. The emulsion may include an aqueous external phase and a hydrocarbon-based internal phase. The surfactant package may include one or more surfactants. The surfactant package may also include a surfactant having the general structure R—(OCH2CH2)9—OH, where R is a hydrocarbyl having 12 carbon atoms, 13 carbon atoms, or 14 carbon atoms. The spacer fluid may contain at least 4.25 pounds of R—(OCH2CH2)9—OH per barrel of the spacer fluid.

Spacer fluid compositions, methods, and systems for aqueous based drilling mud removal

Spacer fluids include an emulsion, a surfactant package, and at least one additive that modifies the rheology of the spacer fluid, the density of the spacer fluid, or both. The emulsion may include an aqueous external phase and a hydrocarbon-based internal phase. The surfactant package may include one or more surfactants. The surfactant package may also include a surfactant having the general structure R—(OCH 2 CH 2 ) 9 —OH, where R is a hydrocarbyl having 12 carbon atoms, 13 carbon atoms, or 14 carbon atoms. The spacer fluid may contain at least 4.25 pounds of R—(OCH 2 CH 2 ) 9 —OH per barrel of the spacer fluid.