US Pat. No. 9,193,037

PREPARATION OF NANOCRYSTALLINE DIAMOND COATED DIAMOND PARTICLES AND APPLICATIONS THEREOF

NATIONAL OILWELL DHT, L.P...

1. A method of making a cutter element for a drill bit, the method comprising:
forming a suspension comprising a plurality of nanocrystalline diamond particles and a solvent, wherein the solvent is a polar
liquid;

disposing a plurality of polycrystalline diamond particles in the suspension to form a mixture, wherein a plurality of the
plurality of nanocrystalline diamond particles are homogenously distributed about each of the plurality of polycrystalline
diamond particles in the mixture, and wherein the plurality of polycrystalline diamond particles are distributed homogenously
throughout the mixture;

wherein the zeta potential of at least one of the suspension and the mixture is from ±30 to ±100 mV;
drying the mixture using one of a spray-drying or a solgel process, wherein the dry mixture comprises a plurality of nanocrystalline
diamond coated polycrystalline diamond particles (NDCPD), wherein the plurality of nanocrystalline diamond particles are homogenously
distributed around each of the plurality of polycrystalline diamond particles;

forming a dried mixture after drying the mixture, wherein the dried mixture comprises the plurality of the plurality of nanocrystalline
diamond particles homogenously distributed about each of the plurality of polycrystalline diamond particles, and wherein the
plurality of polycrystalline diamond particles are distributed homogenously throughout the dried mixture;

sintering the dry mixture to form the cutter element.

US Pat. No. 9,364,936

DISPERSION OF HARDPHASE PARTICLES IN AN INFILTRANT

NATIONAL OILWELL DHT, L.P...

1. A composite material comprising:
a product of heating a mixture to a temperature above a melting point of an infiltrant and below a melting point of a second
binder, wherein the mixture comprises:

a first pre-infiltrated hardphase constituent comprising a first porous carbide having a first binder disposed therein;
at least a second partially sintered pre-infiltrated hardphase constituent, wherein the second pre-infiltrated hardphase constituent
comprises a second porous carbide and at least about 15 weight % to about 25 weight % of the second binder wherein the second
pre-infiltrated hardphase constituent comprises at least about 1% porosity, wherein the second pre-infiltrated hardphase constituent
has a smaller average particle size than the first pre-infiltrated hardphase constituent; and

the infiltrant, wherein the melting point of the infiltrant is below the melting point of the second binder;
wherein the composite material comprises a disintegrated particulate structure of the second pre-infiltrated hardphase constituent,
wherein the disintegrated particulate structure comprises a plurality of particulates formed from the disintegrated second
pre-infiltrated hardphase constituent directly embedded in the infiltrant, and wherein the plurality of particulates have
a size of 20% or less of the second pre-infiltrated hardphase constituent, and wherein the composite material comprises a
plurality of localized uniform hard phase regions disposed within the interstitial spaces between the larger first pre-infiltrated
hardphase constituent in the infiltrant, wherein the plurality of localized uniform hard phase regions are formed from the
disintegrated particulate structures of the second pre-infiltrated hard phase constituent.

US Pat. No. 9,249,628

HYBRID ROLLING CONE DRILL BITS AND METHODS FOR MANUFACTURING SAME

National Oilwell DHT, L.P...

1. A rolling cone drill bit for drilling a borehole in earthen formations, the bit comprising:
a bit body having a bit axis; and
a first rolling cone cutter mounted on the bit body and having a cone axis of rotation;
wherein the first cone cutter includes a cone body having an outer surface, a plurality of teeth extending from the outer
surface of the cone body, and a plurality of inserts, wherein the plurality of teeth are arranged in a first inner row;

wherein each insert is disposed within one tooth in the first inner row, and wherein each insert extends from the corresponding
tooth through the outer surface of the cone body into the cone body.

US Pat. No. 9,140,071

APPARATUS AND METHOD FOR RETAINING INSERTS OF A ROLLING CONE DRILL BIT

NATIONAL OILWELL DHT, L.P...

1. An insert for a rolling cone drill bit, the insert having a first end and second end opposite the first end, the insert
comprising:
a base portion having a central axis, wherein the base portion extends axially from the first end of the insert and is configured
to be seated in a mating socket in a cone cutter of the rolling cone drill bit;

a cutting portion extending axially from the second end of the insert to the base portion and configured to engage an earthen
formation;

wherein the base portion has a radially outer surface with respect to the central axis, the radially outer surface of the
base portion including a first region extending axially from the cutting portion toward the first end of the insert;

wherein the first region of the radially outer surface of the base portion has a width measured perpendicular to the central
axis in side view, wherein the width increases moving axially from the cutting portion, and wherein the first region of the
radially outer surface of the base portion defines a non-cylindrical first axial retention feature configured to prevent the
insert from moving axially out of the mating socket;

wherein the radially outer surface of the base portion further comprises a torque holding feature configured to prevent the
insert from rotating about the central axis relative to the cone cutter;

wherein the torque holding feature of the base portion is distinct and separate from the first axial retention feature, and
wherein the torque holding feature is adjacent the first axial retention feature and intersects the first axial retention
feature along an edge.

US Pat. No. 9,441,422

CUTTING INSERT FOR A ROCK DRILL BIT

NATIONAL OILWELL DHT, L.P...

18. A method of drilling subterranean boreholes comprising:
forming an extrudate with a cutting edge of at least one cutting insert of a rock drill bit; and
splitting the extrudate at a location proximate to the cutting edge with a ridge formed on a cutting face of the at least
one cutting insert with a first end of said ridge to reduce a mechanical specific energy that is expended to move the extrudate
across the cutting face;

wherein the cutting face extends from the cutting edge and includes the ridge and a back-support region positioned opposite
the cutting edge, wherein the cutting ridge has a first end proximal the cutting edge and a second end distal the cutting
edge, wherein the first end of said ridge is positioned a distance from said cutting edge and points towards the cutting edge,
and wherein the second end of the cutting ridge intersects the back-support region, wherein the back-support region is oriented
substantially perpendicular to the ridge, and wherein the ridge extends to a height that increases moving from the first end
to the back-support region.

US Pat. No. 9,435,168

DOWNHOLE ACTIVATION ASSEMBLY AND METHOD OF USING SAME

National Oilwell DHT, L.P...

1. A downhole activation assembly for activating a downhole component of a downhole tool positionable in a wellbore penetrating
a subterranean formation, the activation assembly comprising:
a housing operatively connectable to the downhole tool;
a spring-loaded sleeve slidably positionable in the housing, the sleeve having a flow channel therethrough and an outer surface
defining a chamber between the sleeve and the housing, the chamber divided into an upper variable volume chamber and a lower
variable volume chamber, the upper and lower variable volume chambers in fluid isolation from each other, the sleeve having
therethrough about a sleeve end thereof to permit fluid from the flow channel to pass therethrough; and

a ball catcher slidably positionable in the housing, the ball catcher having a catcher end engageable with the sleeve end
to selectively divert the fluid thereabout and a ball seat therein to receivingly engage a ball passing through the sleeve
whereby the ball catcher selectively moves the downhole component between activation positions.

US Pat. No. 9,410,379

DOWNHOLE CUTTING TOOL

NATIONAL OILWELL DHT, L.P...

1. A tool for reaming a borehole, the tool comprising:
a tubular body having a central axis, a first end, and a second end opposite the first end;
an uphole eccentric reamer section mounted to the tubular body, wherein the uphole eccentric reamer section is eccentric about
the central axis of the tubular body;

a downhole eccentric reamer section mounted to the tubular body and axially positioned below the uphole eccentric reamer section,
wherein the downhole eccentric reamer section is eccentric about the central axis of the tubular body;

wherein each eccentric reamer section includes a first blade extending radially from the tubular body, wherein the first blade
of each eccentric reamer section has an uphole end and a downhole end axially positioned below of the uphole end, wherein
the first blade of the uphole eccentric reamer section circumferentially overlaps with the first blade of the downhole eccentric
reamer section;

wherein the first blade of the uphole eccentric reamer section extends helically about the tubular body in a first helical
direction moving from the uphole end of the first blade of the uphole eccentric reamer section to the downhole end of the
first blade of the uphole eccentric reamer section:

wherein the first blade of the downhole eccentric reamer section extends helically about the tubular body in a second helical
direction moving from the uphole end of the first blade of the downhole eccentric reamer section to the downhole end of the
first blade of the downhole eccentric reamer section;

wherein the second helical direction is opposite the first helical direction; and
a cutter element mounted to the first blade of each eccentric reamer section;
wherein the cutter element mounted to the first blade of the uphole reamer section and the cutter element mounted to the first
blade of the downhole reamer section are each configured to engage and ream the borehole.

US Pat. No. 9,840,874

HYBRID ROLLING CONE DRILL BITS AND METHODS FOR MANUFACTURING SAME

National Oilwell DHT, L.P...

12. A rolling cone drill bit for drilling a borehole in earthen formations, the bit comprising:
a bit body having a bit axis; and
a rolling cone cutter mounted on the bit body and having a cone axis of rotation;wherein the cone cutter includes a cone body, a plurality of circumferentially-spaced teeth monolithically formed with the
cone body and arranged in a first inner row, and a plurality of circumferentially-spaced inserts disposed in the first inner
row, wherein each pair of circumferentially adjacent teeth comprises a leading tooth relative to a direction of cone rotation
about the cone axis and a trailing tooth relative to a direction of cone rotation about the cone axis;
wherein each tooth in the first inner row has a convex leading flanking surface relative to the direction of cone rotation,
a concave trailing flanking surface relative to the direction of cone rotation, and a curved chisel crest disposed at the
intersection of the leading flanking surface and the trailing flanking surface;

wherein each insert in the first inner row is positioned in a pocket defined by the concave trailing flanking surface of the
corresponding leading tooth in the first inner row.

US Pat. No. 9,631,435

MATRIX FIXED CUTTER DRILL BITS AND METHODS FOR MANUFACTURING SAME

NATIONAL OILWELL DHT, L.P...

1. A fixed cutter drill bit for drilling a borehole in earthen formations, the bit having a central axis and a cutting direction
of rotation, the bit comprising:
a blank assembly including an annular mandrel and a plurality of elongate studs fixably coupled to the mandrel;
a matrix crown fixably mounted to the blank assembly;
wherein the mandrel is coaxially aligned with the central axis and has a first end distal the crown and a second end engaging
the crown;

wherein the mandrel includes a plurality of bores extending axially from the second end;
wherein each elongate stud has a first end disposed within one of the bores and a second end disposed in the crown distal
the mandrel; and

wherein at least one elongate stud has a different length than the other elongate studs of the plurality of elongate studs.

US Pat. No. 9,732,573

DOWNHOLE ACTIVATION ASSEMBLY WITH OFFSET BORE AND METHOD OF USING SAME

National Oilwell DHT, L.P...

1. A downhole activation assembly for activating a downhole component of a downhole tool positionable in a wellbore penetrating
a subterranean formation, the activation assembly comprising:
a housing operatively connectable to the downhole tool;
a piston slidably positionable in the housing with a chamber defined therebetween, the piston having a flow channel therethrough;
and

a valve positionable about the flow channel of the piston, the valve comprising a fixed plate and a rotatable plate, the rotatable
plate movable about the fixed plate to define a variable bore to selectively restrict flow through the flow channel and to
vary pressure about the piston whereby the piston is selectively moved to shift the downhole component between activation
positions.

US Pat. No. 9,604,345

HARD-FACING FOR DOWNHOLE TOOLS AND MATRIX BIT BODIES WITH ENHANCED WEAR RESISTANCE AND FRACTURE TOUGHNESS

NATIONAL OILWELL DHT, L.P...

1. A composite material comprising:
a first material comprising a plurality of grains of eutectic WC and W2C, wherein each of the plurality of grains of the first
material has an elongated microstructure with a thickness less than about 2 microns and an aspect ratio of about 10 to about
100; and

a second material comprising a shell around said first material, wherein said shell has a thickness of about 0.1 micron to
about 35 micron.

US Pat. No. 9,593,547

DOWNHOLE SHOCK ASSEMBLY AND METHOD OF USING SAME

National Oilwell DHT, L.P...

1. A shock assembly for use with a motion tool deployable into a wellbore penetrating a subterranean formation by a conveyance,
the shock assembly comprising:
a mandrel operatively connectable to one of the conveyance and the motion tool;
a housing operatively connectable to another of the conveyance and the motion tool, the housing having an opening to slidingly
receive the mandrel; and

a first spring and a second spring slidably positionable in the housing between the mandrel and the housing, the first spring
having a first spring stiffness and the second spring having a second spring stiffness, the second spring stiffness being
less than the first spring stiffness such that the first and second springs selectively engage as the housing slidingly moves
in both directions about the mandrel in response to forces applied to the motion tool to selectively restrict movement between
the mandrel and the housing whereby the motion tool is vibrated.

US Pat. No. 9,574,407

DRILLING SYSTEMS AND MULTI-FACED DRILL BIT ASSEMBLIES

NATIONAL OILWELL DHT, L.P...

14. A method for drilling a borehole in an earthen formation, the method comprising:
(a) rotatably coupling a bit body to a sleeve that is concentrically and moveably disposed about a shank, wherein the shank
includes a central shank axis, a first end, a second end opposite the first end, a fluid flow bore extending axially from
the first end toward the second end, and a drill bit seat disposed at the second end, and wherein the sleeve is configured
to translate axially relative to the shank;

wherein the bit body includes a first bit face having a first cutting structure configured to engage the earthen formation
and a second bit face having a second cutting structure configured to engage the earthen formation;

(b) rotating the bit body, the sleeve, and the shank about the central shank axis in a cutting direction after (a);
(c) engaging the earthen formation with the second bit face and second cutting structure during (b);
(d) decreasing a pressure within an annular chamber radially positioned between the sleeve and the shank, wherein the annular
chamber is in fluid communication with the fluid flow bore;

(e) translating the sleeve and bit body from a first position with the first cutting structure seated within the drill bit
seat in a first axial direction relative to the shank to a second position with the bit body axially spaced from the drill
bit seat after (c) and in response to (d);

(f) rotating the bit body about an axis of rotation oriented orthogonal to the shank axis during (d) to expose the first bit
face and first cutting structure to the earthen formation;

(g) rotating the bit body about the shank axis after (f); and
(h) engaging the earthen formation with the first bit face and first cutting structure during (g).

US Pat. No. 9,752,411

DOWNHOLE ACTIVATION ASSEMBLY WITH SLEEVE VALVE AND METHOD OF USING SAME

NATIONAL OILWELL DHT, L.P...

1. An activation assembly for a wellsite having a wellbore penetrating a subterranean formation, the wellsite having a downhole
tool deployable into the wellbore, the activation assembly comprising:
a ball;
a housing operatively connectable to the downhole tool, the housing having a housing passage for flow of fluid therethrough;
an indexing assembly positionable in the housing, the indexing assembly comprising a multiple position indexer and an indexing
tube, the indexing assembly operatively connectable to the downhole tool; and

a sleeve valve comprising a multi-portion tubular sleeve having a fixed sleeve portion and a movable sleeve portion positionable
in the housing passage of the housing and defining a ball passage therethrough, the sleeve valve having a valve seat defined
therein to receive the ball such that the flow of the fluid is selectively restricted through the ball passage, the fixed
sleeve portion fixed relative to the housing and the movable sleeve portion moveable relative to the housing and engagable
with the indexing tube to selectively shift the indexer between multiple positions whereby the downhole tool is selectively
activatable; and

wherein each of the fixed sleeve portion and the movable sleeve portion is a partial tubular that is complementary to the
other portion and that together define the multi-portion tubular sleeve.

US Pat. No. 9,695,641

DRILLING SYSTEMS AND FIXED CUTTER BITS WITH ADJUSTABLE DEPTH-OF-CUT TO CONTROL TORQUE-ON-BIT

NATIONAL OILWELL DHT, L.P...

1. A drill bit for drilling a borehole in an earthen formation, the bit having a central axis and a cutting direction of rotation,
the bit comprising:
a connection member having a pin end;
a bit body coupled to the connection member, wherein the bit body is configured to rotate with the connection member about
the central axis under a first torque-on-bit and wherein the bit body is configured to rotate relative to the connection member
about the axis under a second torque-on-bit that is greater than the first toque-on-bit, wherein the bit body includes a bit
face and a blade extending radially along the bit face;

a plurality of cutter elements mounted to a cutter-supporting surface of the blade; and
a depth-of-cut limiting structure slidably disposed in a bore extending axially from the cutter-supporting surface;
wherein the depth-of-cut limiting structure is configured to move axially relative to the bit body in response to rotation
of the bit body relative to the connection member.

US Pat. No. 9,909,395

WELLSITE HARDFACING WITH DISTRIBUTED HARD PHASE AND METHOD OF USING SAME

NATIONAL OILWELL DHT, L.P...

1. A hardfacing disposable on a surface of a component, comprising:
a surface portion and a bottom portion with a segregation line defined therebetween, the surface portion and the bottom portion
each comprising:

a matrix phase comprising a matrix composition comprising a metal alloy; and
a hard phase distributed in the matrix phase, the hard phase comprising an abrasion-resistant composition comprising a hard
material;

wherein the surface portion has a first concentration of the abrasion-resistant composition and the bottom portion has a second
concentration of the abrasion-resistant composition with the first concentration being greater than the second concentration
whereby a wear resistant surface is defined on the surface of the component;

wherein the hard material comprises a plurality of particles having a particle size distribution D(90) of 60 to 200 ?m.

US Pat. No. 9,771,790

DOWNHOLE MEASUREMENT ASSEMBLY, TOOL AND METHOD

NATIONAL OILWELL DHT, L.P...

1. A downhole measurement assembly of a downhole tool positionable in a wellbore penetrating a subterranean formation, the
downhole tool comprising a bottomhole assembly with a drill bit at an end thereof deployable into the wellbore on a drill
string, comprising:
at least one drill collar having at least one compensation portion and at least one force portion with a load path therethrough,
the at least one compensation portion having a different dimension from the at least one force portion;

a plurality of compensation sensors positionable about the at least one compensation portion to measure downhole tool pressures
applied thereto, wherein the plurality of compensation sensors are positioned a distance from the load path such that the
plurality of compensation sensors are isolated from a load applied to the at least one force portion; and

a plurality of force sensors positionable about the at least one force portion to measure downhole forces applied thereto;
wherein the plurality of compensation sensors and the plurality of force sensors are positionable about the at least one drill
collar in a strain configuration along the load path whereby the measured downhole tool pressure is isolatable from the measured
downhole forces on the at least one drill collar.

US Pat. No. 10,000,970

DOWNHOLE DRILLING ASSEMBLY WITH MOTOR POWERED HAMMER AND METHOD OF USING SAME

NATIONAL OILWELL DHT, L.P...

1. A drilling assembly of a downhole drilling tool for drilling a wellbore penetrating a subterranean formation, the downhole drilling tool driven by surface equipment and comprising a drill string, a bottom hole assembly, and a drill bit, the drilling assembly comprising:a housing positionable about the bottom hole assembly;
a hammer motor positionable in the housing and rotationally driven by fluid flow therethrough;
a shaft operatively connectable to the hammer motor and rotatably thereby;
a driver operatively connectable to the shaft, the driver comprising a cam rotatable with the shaft and a guide having a guide surface thereon, the cam engageable with the guide surface and axially movable thereabout during rotation thereof;
a hammer operatively connectable to the driver and axially movable therewith, the hammer axially movable within the housing independently from axial movement of the housing, the hammer engageable with the bit to impart an impact thereto whereby the bit is hammered; and
a fluid passage extending through the drillstring, through the hammer, and through the bit, the fluid passage including a flow restriction positioned to restrict flow of fluid through the hammer and directs an axially-downward fluid force against the hammer when fluid flows through the flow restriction;
wherein the flow restriction is coupled for movement with the hammer and is axially movable relative to the drill bit.

US Pat. No. 9,988,846

GAUGE FOR BENT HOUSING MOTOR DRILL BIT

National Oilwell DHT, L.P...

13. A method of designing a drill bit comprising:selecting a bottom hole assembly including a drill bit having a blade and a bent housing having a bend angle, wherein the blade extends radially outward from the drill bit and is defined by a leading edge and a trailing edge and having cutters attached to the leading edge;
selecting a set of drill parameters including a wellbore having a wellbore wall;
evaluating the bottom hole assembly and the set of drill parameters to determine a range of contact for the drill bit during cutting operation of the wellbore wall by the cutters;
simulating the movement of the drill bit within the wellbore to determine if the blade interferes with the wellbore wall;
configuring a gauge surface extending from the leading edge to a surface break; and
configuring a recessed surface extending from the surface break to the trailing edge,
wherein the gauge surface and the recessed surface are configured so that the gauge surface provides contact between the blade and the wellbore wall when the drill bit is sliding through the wellbore and the recessed surface minimizes interference between the trailing edge and the wellbore wall when the drill bit is being rotated.

US Pat. No. 9,976,357

FIXED CUTTER DRILL BIT WITH FLOW GUIDE

National Oilwell DHT, L.P...

21. A drill bit comprising:a bit body, the bit body having a body face;
a plurality of fixed blades extending from the body face, each of the plurality of fixed blades having a leading face, a trailing face, and a shoulder;
a junk slot located in between a leading face of a first one of the plurality of fixed blades and a trailing face of a second one of the plurality of fixed blades; and
a flow guide located in the junk slot,
wherein the flow guide extends axially from a base surface that is located in the junk slot and on the body face, by about half of a height of the first one of the plurality of fixed blades, and up to a guide edge surface that is offset inwardly from the shoulder of the first one of the plurality of fixed blades, and
wherein the guide edge surface spans between the leading face of the first one of the plurality of fixed blades and a surface of the flow guide that extends along the leading face of the first one of the plurality of fixed blades.

US Pat. No. 9,976,231

FIXED CUTTER DRILL BIT CUTTER ELEMENTS INCLUDING HARD CUTTING TABLES MADE FROM CVD SYNTHETIC DIAMONDS

NATIONAL OILWELL DHT, L.P...

1. A method for forming a cutter element for a drill bit, the method comprising:(a) transforming a graphite powder into a CVD diamond powder;
(b) growing a plurality of CVD single crystal diamonds on a substrate, wherein the plurality of CVD single crystal diamonds are grown in an orientation along the [100] crystallographic plane;
(c) removing at least a portion of the CVD single crystal diamonds from the substrate after (b);
(d) transforming the removed CVD single crystal diamonds into a CVD single crystal diamond powder, wherein the CVD single crystal diamond powder comprises a plurality of CVD single crystal diamonds, wherein each CVD single crystal diamond of the plurality of CVD single crystal diamonds is a rectangular cube, wherein each side of each rectangular cube has a width between 10 and 20 microns;
(e) disposing the CVD single crystal diamond powder and a tungsten carbide support element into a mold; and
(f) thermo-mechanically processing the CVD single crystal diamonds powder in the mold to form a solid CVD diamond crystal table secured to the tungsten carbide support element, wherein the solid CVD diamond crystal table comprises a plurality of single crystal diamonds.

US Pat. No. 10,214,812

CUTTER ELEMENTS FOR DRILL BITS AND METHODS FOR FABRICATING SAME

NATIONAL OILWELL DHT, L.P...

1. A method for fabricating a PCD cutter element, comprising:(a) coating, by atomic layer deposition (ALD), a plurality of diamond particles by directly depositing the coating on an outer surface of each diamond particle of the plurality of diamond particles to form a plurality of coated diamond particles;
(b) removing oxides from the plurality of coated diamond particles after (a);
(c) forming a PCD cutter element using the coated diamond particles after (b) by sintering the coated diamond particles together to form a diamond table and leaching the diamond table after sintering the coated diamond particles to remove one or more metals from the diamond table.

US Pat. No. 10,294,726

DOWNHOLE ADJUSTABLE BEND ASSEMBLIES

National Oilwell DHT, L.P...

48. A method for forming a deviated borehole, comprising:(a) providing a bend adjustment assembly of a downhole mud motor in a first position that provides a first deflection angle between a longitudinal axis of a driveshaft housing of the downhole mud motor and a longitudinal axis of a bearing mandrel of the downhole mud motor;
(b) with the downhole mud motor positioned in the borehole, actuating the bend adjustment assembly from the first position to a second position that provides a second deflection angle between the longitudinal axis of the driveshaft housing and the longitudinal axis of the bearing mandrel, the second deflection angle being different from the first deflection angle; and
(c) oscillating the bearing mandrel axially in a bearing housing of the downhole mud motor in response to pumping drilling fluid into the borehole from the surface pump.

US Pat. No. 10,288,065

MUD MOTOR COUPLING SYSTEM

National Oilwell DHT, LP,...

1. A mud motor comprising:a bearing assembly;
a transmission in communication with said bearing assembly having:
an input coupling having a first end in communication with a power section and a second end with an input coupling recessed partial hemisphere with an input coupling slot disposed therein;
a first torque and thrust transfer coupling having a first end with a first torque and thrust transfer coupling first partial hemisphere with a first torque and thrust transfer coupling first tab disposed thereon and a second end with a first torque and thrust transfer coupling second partial hemisphere with a first torque and thrust transfer coupling second tab disposed thereon;
a first pin connecting said input coupling second end and said first torque and thrust transfer coupling first end wherein said first torque and thrust transfer coupling first tab pivotally communicates with said input coupling slot;
an intermediate shaft having a first end with a first intermediate shaft recessed partial hemisphere with a first intermediate shaft slot disposed therein and a second end with a second intermediate shaft recessed partial hemisphere with a second intermediate shaft slot disposed therein;
a second pin connecting said first torque and thrust transfer coupling second end and said intermediate shaft first end wherein said first torque and thrust transfer coupling second tab pivotally communicates with said first intermediate shaft slot;
a second torque and thrust transfer coupling, having a first end with a first second torque and thrust transfer coupling partial hemisphere with a first second torque and thrust transfer coupling tab disposed thereon and a second end with a second second torque and thrust transfer coupling partial hemisphere with a second second torque and thrust transfer coupling tab disposed thereon;
a third pin connecting said intermediate shaft second end and said second torque and thrust transfer coupling first end wherein said tab pivotally communicates with said second intermediate shaft slot;
an output coupling having a first end with an output coupling recessed partial hemisphere with an output coupling slot disposed therein and a second end in communication with said bearing assembly; and
a fourth pin connecting said second torque and thrust transfer coupling second end and said output coupling first end wherein said second torque and thrust transfer coupling second end tab pivotally communicates with said output coupling slot;
said power section in communication with said transmission;
a rotor catch assembly in communication with said power section; and
a cross over sub-valve in communication with said rotor catch assembly.

US Pat. No. 10,240,399

DOWNHOLE DRILL BIT CUTTING ELEMENT WITH CHAMFERED RIDGE

NATIONAL OILWELL DHT, L.P...

1. A cutting element for a drill bit, the drill bit advanceable into a subterranean formation to form a wellbore, the cutting element comprising:an element body having a face at an end thereof, wherein the face includes a planar ramp, a first side region, a second side region, and a ridge thereon, wherein the planar ramp has a curved edge along a periphery of the face and two sides, wherein each of the two sides of the planar ramp extend from opposite ends of the curved edge and converge at a location along the face, wherein the face has a chamfer along a peripheral edge thereof; and
wherein the ridge extends along the face from the chamfer to the location, wherein the ridge is positioned between the first side region and the second side region, wherein the first side region extends between the periphery, the ridge, and one of the two sides of the planar ramp, wherein the second side region extends between the periphery, the ridge, and one of the two sides of the planar ramp, wherein the planar ramp extends from the first side region to the second side region, whereby the chamfer engages a wall of the wellbore and extrudate is drawn along the pair of side regions.

US Pat. No. 10,280,683

MUD MOTOR APPARATUS AND SYSTEM

National Oilwell DHT, LP,...

1. A mud motor comprising:a bearing assembly;
a transmission in communication with said bearing assembly having:
an input coupling having a first end in communication with said bearing assembly, a second end with a recessed partial hemisphere disposed therein, and a diameter;
a first torque and thrust transfer coupling having a first end with partial hemisphere, a second end with partial hemisphere, and a diameter;
a first pin connecting said input coupling second end and said first torque and thrust transfer coupling first end wherein said first torque and thrust transfer coupling is adapted to pivotally communicate with said input coupling;
an intermediate shaft having a first end with a recessed partial hemisphere, a second end with a recessed partial hemisphere, and a diameter;
a second pin connecting said first torque and thrust transfer coupling second end and said intermediate shaft having the first end wherein said first torque and thrust transfer coupling is adapted to pivotally communicate with said intermediate shaft;
a second torque and thrust transfer coupling, having a first end with partial hemisphere, a second end with partial hemisphere, and a diameter;
a third pin connecting said intermediate shaft second end and said second torque and thrust transfer coupling said first end wherein said second torque and thrust transfer coupling is adapted to pivotally communicate with said intermediate shaft;
an output coupling having a first end with a recessed partial hemisphere, a second end in communication with a power section, and a diameter; and
a fourth pin connecting said second torque and thrust transfer coupling second end and said output coupling first end wherein said second torque and thrust transfer coupling is adapted to pivotally communicate with said output coupling;
said power section in communication with said transmission;
a rotor catch assembly in communication with said power section; and
a cross over sub-valve in communication with said rotor catch assembly.