US20040237640A1 - Method and apparatus for measuring in-situ rock moduli and strength - Google Patents

Method and apparatus for measuring in-situ rock moduli and strength Download PDF

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Publication number
US20040237640A1
US20040237640A1 US10/447,634 US44763403A US2004237640A1 US 20040237640 A1 US20040237640 A1 US 20040237640A1 US 44763403 A US44763403 A US 44763403A US 2004237640 A1 US2004237640 A1 US 2004237640A1
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United States
Prior art keywords
tool
piston
tool body
mud
borehole
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Abandoned
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US10/447,634
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English (en)
Inventor
Matthias Meister
Sven Krueger
Wolfgang Herberg
Christian Liss
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Baker Hughes Holdings LLC
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Baker Hughes Inc
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Publication date
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Priority to US10/447,634 priority Critical patent/US20040237640A1/en
Assigned to BAKER HUGHES INCORPORATED reassignment BAKER HUGHES INCORPORATED ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: MEISTER, MATTHIAS, LISS, CHRISTIAN, HERBERG, WOLFGANG, KRUEGER, SVEN
Priority to GB0524424A priority patent/GB2417329B/en
Priority to PCT/US2004/016695 priority patent/WO2004106699A1/en
Publication of US20040237640A1 publication Critical patent/US20040237640A1/en
Abandoned legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/006—Measuring wall stresses in the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/005—Testing the nature of borehole walls or the formation by using drilling mud or cutting data
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/24—Earth materials
    • G01N33/241—Earth materials for hydrocarbon content

Definitions

  • the invention relates generally to devices and methods for determining the strength and moduli of rock formations within a wellbore. More particularly, the invention relates to devices and methods for making such determinations in-situ.
  • rock strength can be measured by exerting a defined force (F) against a contact area (A) over a measured distance, or way, (I).
  • Rock moduli include Young's modulus and other static rock moduli (i.e., tangent modulus, average modulus, and secant modulus).
  • U.S. Pat. No. 4,149,409, issued to Serata discloses a downhole penetrometer device that uses diametrically opposed pistons that extend radially outwardly to engage and penetrate a borehole wall.
  • U.S. Pat. No. 5,165,274 issued to Thiercelin describes a downhole penetrometer device that uses a pair of diametrically opposed indenters that also are radially extended to penetrate a borehole wall.
  • the Serata device is actuated by hydraulic fluid that is pumped down into the wellbore by a separate, surface-based fluid pump.
  • This arrangement requires additional equipment that is costly to deploy as the hydraulic fluid used for actuation flows into the wellbore via a flexible hose that is disposed between the wellbore casing and the drill string. Large amounts of hydraulic fluid are required for actuation.
  • the device described in the Thiercelin patent is typically run in on a wireline.
  • a downhole pump is used to energize the penetrometer device.
  • a downhole motor in turn, actuates the pump. This arrangement is not optimal for use within a drill string.
  • the present invention addresses the problems of the prior art.
  • An in-situ rock strength measurement tool features a sub that is integrated into a drill string, or other downhole tool string, and lowered into an uncased borehole.
  • the sub includes a plurality of lateral pistons that are selectively extendable in a radial orientation to engage the wall of the borehole.
  • the pistons exert a force against a defined area of the borehole wall and penetrate the borehole across the defined area. The force needed to penetrate the borehole may then be measured and used to calculate rock strength and to determine other formation properties.
  • the tool features a set of pistons that are spaced axially apart from one another along an axial line upon the sub body. Thus, when actuated, the force of the pistons is exerted upon a single side of the borehole wall, thereby permitting more accurate measurement of rock strength and other borehole and formation parameters.
  • the pistons of the sub are actuated for radial outward and inward movement hydraulically or electrically and energized by a mud turbine that is contained within the drill string.
  • the mud turbine is powered by flowing drilling mud downward through the drill string.
  • Control of the pistons is preferably surface-based.
  • the tool features radially expanded stabilizer portions with enlarged engagement surfaces for generally centering the tool within the borehole during operation and mud channels defined on the outer surface of the tool to permit drilling mud to move upwardly within the borehole past the tool.
  • This feature permits the tool to be sized so that its outer diameter will be in close proximity to the borehole wall, thereby lessening the distance over which the piston must be moved to engage the borehole wall.
  • the pistons are provided with a curved engagement plate having a roughened engagement surface.
  • the tool body provides three sets of axially aligned pistons that are angularly spaced from one another about the circumference of the tool.
  • the tools of the present invention also perform the desirable function of locking the drill string into place against the borehole wall to secure the drill string against axial and rotational movement.
  • pistons are described for deploying the pistons radially outwardly into contact with the borehole wall.
  • the pistons are actuated into a deployed position using a spindle drive with a sliding shoe.
  • pistons are deployed outwardly by a radially expandable inflatable element.
  • FIG. 1 is a schematic drawing depicting the measurement of rock strength using applied force over a defined area.
  • FIG. 2 is a schematic side view of an exemplary land-based well illustrating use within a borehole of an in-situ rock strength measurement tool constructed in accordance with the present invention.
  • FIG. 3 is a schematic side view of an exemplary offshore well illustrating use within a borehole of an in-situ rock strength measurement tool constructed in accordance with the present invention.
  • FIG. 4 is an external, isometric view of an exemplary rock strength measurement tool constructed in accordance with the present invention.
  • FIG. 4A is an external, isometric view of an alternative rock strength measurement tool depicting arrangement of piston members helically about the axis of the tool.
  • FIG. 5 is a side, cross-sectional cutaway view of the rock strength measurement tool shown in FIG. 4.
  • FIG. 6 is an axial cross-section taken along lines 6 - 6 in FIG. 4.
  • FIG. 7A is a cross-sectional view of an alternative embodiment for a rock strength measurement tool constructed in accordance with the present invention.
  • FIG. 7B is an external, isometric view of a lower side of the tool shown in FIG. 7A.
  • FIG. 8 is a side, cross-sectional cutaway of a further alternative embodiment for a rock strength measurement tool constructed in accordance with the present invention.
  • FIG. 9 is an enlarged view of a portion of the exterior of the rock strength measurement tool shown in FIG. 8, illustrating features of the engagement plate.
  • FIG. 10 is an exterior view of a further exemplary alternative rock strength measurement tool in accordance with the present invention.
  • FIG. 11 is a cross-sectional view of a piston assembly for use with the rock strength measurement tools previously depicted.
  • FIG. 12 is a side view, partially in cross-section, illustrating an exemplary deployment arrangement for a piston assembly utilizing a spindle drive and sliding shoe.
  • FIG. 13 is a side view of the deployment arrangement depicted in FIG. 12 with the piston assembly in the deployed position.
  • FIG. 14 is a side view, partially in cross-section, depicting an alternative exemplary deployment arrangement incorporating an inflatable element.
  • FIG. 15 is a side, cross-sectional view of the arrangement shown in FIG. 14 with the piston assembly in the deployed position.
  • FIGS. 2 and 3 depict in schematic fashion two general scenarios for the use of the rock strength measurement tool assemblies described herein.
  • a land-based hydrocarbon well 10 is depicted wherein a borehole 12 has been drilled through the earth 14 and into a subterranean hydrocarbon formation 16 from a surface based wellhead 18 .
  • a drill string 20 is shown disposed within the borehole 12 , which is not lined by casing.
  • the drilling operation is ongoing.
  • the drill string 20 includes a plurality of standard drill pipe sections, of a type known in the art, that define an axial bore therein for transmission of drilling mud downwardly from the wellhead 18 .
  • the lower, or furthest downstream, end of the drill string 20 includes a bottom hole assembly (BHA) 22 having a drill bit thereupon.
  • BHA bottom hole assembly
  • MWD measurement-while-drilling
  • the drill string 20 may also incorporate centralizers or other known devices, which are well known and, therefore, will not be described in any detail here.
  • a rock strength measurement tool assembly, generally shown at 26 is shown integrated into the drill string 20 above the MWD tool 24 . The tool assembly 26 is used to perform in-situ rock strength tests of the formation 16 in a manner that will be described shortly.
  • FIG. 3 illustrates a drilling scenario wherein an offshore well 30 provides a wellbore 32 that is drilled into the seabed 34 into subterranean formation 36 .
  • the drill string 20 extends downwardly from a floating vessel 38 having a support rig 40 thereupon.
  • the drill string 20 is constructed in essentially the same manner as the drill string 20 described earlier, having a BHA, MWD tool 24 and the rock strength measurement tool assembly 26 .
  • the drill string 20 of the offshore well 30 is subject to movement with respect to the wellbore 32 as a result of wave action.
  • the tool assembly 26 includes a piston tool sub 50 and a mud motor sub 52 .
  • the piston tool sub 50 has a generally cylindrical tool body 54 that defines an axial bore 56 within and has a pair of axial ends 58 , 60 .
  • the ends 58 , 60 are configured, by threading or the like for attachment to adjacent threaded members.
  • the tool body 54 has a central portion 62 of enlarged diameter and end portions 64 , 66 that have a reduced diameter.
  • Exterior mud channels 68 are formed into the enlarged portion 62 of the tool body 54 .
  • the mud channels 68 are areas of reduced diameter that extend from reduced diameter portion 64 to reduced diameter portion 66 and are sized and shaped to permit drilling mud to pass around the enlarged central portion 62 .
  • the enlarged portion 62 of the tool body 54 presents an enlarged stabilizer portion 69 with a curved outer surface that will rest against the borehole wall during actuation of the tool assembly 26 .
  • the central portion 62 of the tool body 54 also presents a piston section 70 that houses four piston members 72 .
  • the piston members 72 are axially aligned with one another and serve as testing arms for determining rock strength of the formation 16 or 36 . It is noted that the piston members 72 are positioned diametrically across the tool from the stabilizer portion 69 (see FIG. 6).
  • FIG. 4A illustrates an alternative tool 26 ′ wherein the piston members 72 are arranged helically, rather than axially, upon the body 54 .
  • the piston members 72 each present an engagement surface 74 of defined and known area.
  • the piston members 72 are reciprocally mounted within the tool body 54 so that they may be moved between a radially inward position and a radially outward position. Details of the construction and operation of the piston members 72 are best shown in FIG. 6, which shows the piston 72 in a radially extended position and FIG. 11, which shows a piston 72 in a radially withdrawn position.
  • the piston member 72 has an enlarged piston head 76 and a radially reduced insert portion 78 that is secured to the piston head 76 by a threaded connector 80 .
  • the piston head 76 is shaped in FIG.
  • FIG. 11 illustrates a slightly modified piston head 76 a wherein the engagement surface 74 a is substantially flat.
  • the insert portion 78 resides within a surrounding piston sleeve 82 .
  • a first hydraulic chamber 84 (visible in FIG. 6) is formed between the insert portion 78 and the piston sleeve 82 so that, when the chamber 84 is filled with hydraulic fluid (as in FIG. 6), the piston member 72 is urged radially outwardly from the tool body 54 .
  • a second hydraulic chamber 86 is also formed between the insert portion 78 and the piston sleeve 82 so that, when the second hydraulic chamber 86 is filled with hydraulic fluid, the piston member 72 is moved radially inwardly with respect to the tool body 54 .
  • a pair of hydraulic fluid passages 88 , 90 extend axially through the central portion 62 of the tool body 54 .
  • a lateral fluid pathway (not shown) extends from the first fluid passage 88 to the first hydraulic chamber 84 .
  • a lateral fluid pathway (not shown) also extends from the second fluid passage 90 to the second hydraulic chamber 86 .
  • a pair of drilling mud tubes 92 extends through the central portion 62 of the tool body 54 from the end portion 64 to the end portion 66 and joins, at each end, the axial bore 56 . As a result, drilling mud pumped down the drill string 20 may pass completely through the tool assembly 26 via the axial bore 56 and mud tubes 92 .
  • the tool body 54 also houses a set of four pressure transducers 94 that are each positioned within the first hydraulic chamber 84 in order to detect the amount of fluid pressure within the first hydraulic chamber 84 during actuation of the tool assembly 26 to move the piston member 72 radially outwardly into penetrating contact with the wall of the borehole 12 .
  • a linear variable differential transducer (LVDT) 95 (shown in FIG. 11) is incorporated into the wall of the piston housing 82 for sensing the position of the insert portion 78 and, thus, detecting movement of the piston 72 with respect to the housing 82 .
  • the pressure transducers 94 and LVDTs 95 are electrically interconnected with a means for recording the pressure sensed and the location and movement of the piston 72 . However, as the details of such interconnection and recording means are well known to those of skill in the art, they are not described herein.
  • the mud motor sub 52 includes an outer housing 96 that defines an axial bore 98 therethrough.
  • a mud motor 100 resides within the outer housing 96 .
  • the mud motor 100 converts kinetic energy from the axial flow of drilling mud through the drill string 20 into hydraulic power.
  • the mud motor 100 includes a rotary mud turbine 102 and a power generator 104 that is operably interconnected with the mud turbine 102 to be driven thereby.
  • the mud motor 100 may comprise a BCPM device, which is commercially available from Baker Hughes, INTEQ in Houston, Tex.
  • the power generator 104 selectively provides pressurized hydraulic fluid through the first and second fluid passages 88 , 90 of the tool body 54 in order to provide hydraulic fluid to either the first or second hydraulic chambers 84 or 86 , thereby moving the piston members 72 radially inward or outward as necessary.
  • the power generator 104 of the mud motor 100 can comprise a device that generates electrical power rather than hydraulic power from the kinetic energy of drilling mud flow. If an electrical power generator is used, the pistons 72 will need to be actuated using electrical energy.
  • the drill string 20 is positioned within the wellbore 12 so that the tool assembly 26 is proximate the location in the formation 16 or 36 , wherein it is desired to perform testing of the formation 16 or 36 .
  • Drilling mud is flowed down the drill string 20 to actuate the mud motor 100 and cause it to operate the piston tool sub 50 and drive the piston members 72 radially outwardly against a side of wellbore 12 .
  • the drilling mud continues past the mud motor 100 through the piston tool sub 50 and downward to the BHA 22 .
  • Drilling mud exiting the BHA 22 is returned up the annulus formed between the wellbore 12 and the drill string 20 .
  • the mud channels 68 permit the drilling mud to bypass the piston tool sub 50 .
  • the piston tool sub 50 When the piston tool sub 50 is energized by hydraulic fluid, the pistons 72 are urged outwardly into penetrating contact with the wall of the wellbore 12 . This contact also locks the drill string 20 into place within the borehole against relative movement, thereby substantially precluding axial or angular movement of the drill string 20 with respect to the borehole 12 . Such movement is a particular problem when the well is an offshore well, such as that shown in FIG. 3 and, thus, the locking function of the tool assembly 26 is quite valuable. It is noted that, when the pistons 72 are placed into penetrating engagement with the wall of the borehole 12 , the stabilizer portion 69 is also set against the wall of the borehole 12 . The pressure required to set the pistons 72 is measured, as is the amount of movement of the pistons 72 during setting. These data are then used to determine rock strength and moduli.
  • Retraction of the piston members 72 from engagement is accomplished by energizing the mud motor 100 so that the second hydraulic chamber 86 is filled with pressurized hydraulic fluid.
  • an active, positive release mechanism is provided for the piston members 72 .
  • the drill string 20 may then be relocated within or removed from the wellbore 12 .
  • FIGS. 7A and 7B depict an exemplary alternative embodiment for a rock strength measurement tool 110 .
  • the tool 110 is similar in most respects of construction and operation to the piston tool 50 described earlier.
  • the four piston members 112 (visible in FIG. 7A) support a unitary engagement plate 114 .
  • the engagement plate 114 is generally rectangular and has a longitudinal axis that lies parallel with the axis of the tool body 116 .
  • the short axis of the engagement plate 114 is curved so as to substantially match the curvature of the tool body 116 .
  • FIGS. 8 and 9 illustrate a further exemplary rock strength measurement tool assembly 120 which also features a unitary engagement plate 122 that is longitudinal and substantially rectangular in shape and is secured to four axially aligned pistons 124 .
  • the engagement surface 126 of the engagement plate 122 is roughened by the use of horizontally disposed ridges 128 .
  • the roughened engagement surface 126 is provided to increase the gripping power of the assembly 120 .
  • a large engagement surface area, such as is provided by the large unitary plate 122 provides a gripping advantage over the use of a number of separate pistons, such as pistons 112 .
  • the engagement plate 122 also features a defined measurement area portion 129 (visible in FIG. 9) that projects radially outwardly beyond the roughened surface 126 .
  • the measurement area portion 129 engages a borehole wall prior to the roughened surface 126 and provides an area of known size so that strength and moduli calculations may be made.
  • FIG. 10 depicts a further alternative embodiment for an exemplary rock strength measurement tool 130 being configured for testing and measurement of in-situ rock strength and stress anisotropy.
  • the tool 130 features a generally tubular mandrel 132 with axial ends 134 , 136 configured for integration of the tool 130 into a drill string.
  • the mandrel 132 houses a plurality of piston members, or testing arms, 138 .
  • the piston members 138 are in three, axially aligned groups (only two of which are visible) in FIG. 10. The three groups of pistons are separated angularly about the tool body by approximately 120 degrees.
  • While the tool 130 presents piston members 138 that are expanded radially outwardly in more than one radial direction, none of the piston members 138 are diametrically opposed to one another. As a result, the tool 130 is more easily actuated than a tool that might utilize diametrically opposed piston members.
  • the tool 130 allows for variations in the roughness of the borehole wall.
  • FIGS. 12 and 13 there is depicted an exemplary rock strength measurement tool 140 having an outer tool housing 142 with lateral windows 144 cut therein. Although two such windows 144 are shown in FIGS. 12 and 13, it should be understood that there may be more or fewer than two such windows.
  • Piston members 146 have enlarged portions 147 that reside within the housing 142 to dispose contact portions 148 through the windows 144 .
  • the piston members 146 are capable of moving radially inwardly and outwardly so that the contact portions 148 are retracted or extended through the windows 144 , as may be seen by a comparison between FIG. 12 (retracted) and FIG. 13 (extended).
  • the tool 140 incorporates therein a deployment arrangement, generally indicated at 150 , that includes a motor 152 and spindle drive 154 that is rotationally driven by the motor 152 .
  • the motor 150 is indicated schematically and may be a mud motor of the type described earlier or other power sources known in the art.
  • the spindle drive 154 includes a shaft 156 with a threaded spindle portion 158 .
  • the threads of the spindle portion 158 engage complimentary threads 160 on an axial wedge member 162 that is reciprocally retained with the tool housing 142 .
  • the wedge member 162 is a cylindrical body 164 that presents an annular frustoconical surface 166 at its lower end.
  • the frustoconical surface 166 lies adjacent upwardly and inwardly directed surfaces 168 on the piston members 146 .
  • Rotation of the spindle drive 154 by the motor 152 causes the wedge member 162 to be moved axially within the tool housing 142 .
  • This axial movement causes the frustoconical surface 166 to slide along the surfaces 168 of the piston members 146 , thereby urging them radially outwardly to the deployed position shown in FIG. 13 in the manner of sliding shoes.
  • the spindle drive 154 is rotated in the opposite direction to move the wedge member axially upwardly within the housing 142 .
  • Pressure transducers and LVDTs may be incorporated into the frustoconical surface 166 of the wedge member 164 , as schematically indicated at 170 , so that the movement and pressure applied by the piston members 146 may be measured.
  • FIGS. 14 and 15 illustrate a further exemplary rock strength measurement tool 180 which incorporates an radially expandable deployment mechanism.
  • the tool 180 features an outer housing 182 with a plurality of lateral windows 184 disposed therethrough.
  • An inner housing 186 is retained radially within the outer housing 182 and defines a mud flow bore 188 therewithin through which drilling mud is pumped downwardly for lubrication of a drilling bit.
  • An annular space 190 is defined between the inner and outer housings 182 , 186 .
  • a radially expandable bladder element, commonly referred to as an inflatable packer, 192 is secured within the annular space 190 and is aligned within the windows 184 .
  • a solid plug 194 is disposed within the annular space 190 at the lower end of the bladder element 192 to help secure the bladder element 192 in place and to form a fluid seal within the space 190 .
  • a second plug 196 is disposed within the space 190 at the upper end of the bladder element 192 to help secure the upper end of the bladder element 192 in place.
  • the second plug 196 has a fluid passage 198 disposed therethrough.
  • Piston members 200 are secured to the outer radial surface of the bladder element 192 .
  • Pressure transducers and LVDTs 202 may be sandwiched between the bladder element 192 and the piston members 200 .
  • FIG. 14 depicts the tool 180 in a retracted position, the position used for running the tool 180 into a wellbore.
  • the bladder element 192 is inflated to the position illustrated by FIG. 15. This may be done by transmitting fluid, under pressure, through the fluid passage 198 of the upper plug 196 and into the fluid chamber 204 that is defined between the upper and lower plugs 196 , 194 and between the inner and outer housings 186 , 182 .
  • the increased fluid pressure causes the bladder element 192 to inflate.
  • Means for accurately measuring static rock moduli and strength in-situ utilizing the devices of the present invention would materially improve data logging.
  • One preferred method for strength measurement of rock employs the concept that shear stress (T) tends to cause failure across a plane (A) that is resisted by the cohesion (c) of the material being tested and by the coefficient of internal friction ( ⁇ ) times the normal stress ( ⁇ n ) across the plane A.
  • ⁇ n normal stress
  • the Young's modulus For engineering use, the deformation properties are described by a number of moduli, including the Tangent modulus, Average modulus, and Secant modulus. These moduli can be measured and calculated as well. In combination with the orientation of the tool (i.e., azimuth, inclination), in-situ stress anisotropy can be estimated from the comparison of the force/way diagrams when multiple arms are instrumented and measured.

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US10/447,634 2003-05-29 2003-05-29 Method and apparatus for measuring in-situ rock moduli and strength Abandoned US20040237640A1 (en)

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US10/447,634 US20040237640A1 (en) 2003-05-29 2003-05-29 Method and apparatus for measuring in-situ rock moduli and strength
GB0524424A GB2417329B (en) 2003-05-29 2004-05-27 Method and apparatus for in-situ measuring static rock moduli and strength
PCT/US2004/016695 WO2004106699A1 (en) 2003-05-29 2004-05-27 Method and apparatus for in-situ measuring static rock moduli and strength

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US20090070042A1 (en) * 2007-09-11 2009-03-12 Richard Birchwood Joint inversion of borehole acoustic radial profiles for in situ stresses as well as third-order nonlinear dynamic moduli, linear dynamic elastic moduli, and static elastic moduli in an isotropically stressed reference state
US20090133486A1 (en) * 2007-11-27 2009-05-28 Baker Hughes Incorporated In-situ formation strength testing
US20090164128A1 (en) * 2007-11-27 2009-06-25 Baker Hughes Incorporated In-situ formation strength testing with formation sampling
WO2009085516A1 (en) * 2007-11-27 2009-07-09 Baker Hughes Incorporated In-situ formation strength testing with coring
WO2010083166A3 (en) * 2009-01-13 2010-10-28 Schlumberger Canada Limited In-situ stress measurements in hydrocarbon bearing shales
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US20110000665A1 (en) * 2009-07-01 2011-01-06 Smith International, Inc. Hydraulically Locking Stabilizer
US20110010097A1 (en) * 2009-07-08 2011-01-13 Baker Hughes Incorporated Borehole stress module and methods for use
US20110015907A1 (en) * 2009-07-20 2011-01-20 Crawford Brian R Petrophysical Method For Predicting Plastic Mechanical Properties In Rock Formations
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WO2012125936A2 (en) * 2011-03-17 2012-09-20 Baker Hughes Incorporated Downhole rebound hardness measurement while drilling or wireline logging
US20130028287A1 (en) * 2011-07-29 2013-01-31 Diego Marchetti Device comprising an automated cableless dilatometer
US20130105222A1 (en) * 2011-10-26 2013-05-02 Precision Energy Services, Inc. Sensor Mounting Assembly for Drill Collar Stabilizer
CN103492659A (zh) * 2011-03-08 2014-01-01 兰德马克绘图国际公司 在页岩地层中钻设侧井的方法和系统
US20140338977A1 (en) * 2013-05-17 2014-11-20 Baker Hughes Incorporated Bottomhole assembly design method to reduce rotational loads
US9411071B2 (en) 2012-08-31 2016-08-09 Exxonmobil Upstream Research Company Method of estimating rock mechanical properties
WO2016130648A1 (en) * 2015-02-13 2016-08-18 Baker Hughes Incorporated An extendable probe and formation testing tool and method
WO2017116412A1 (en) * 2015-12-29 2017-07-06 Halliburton Energy Services, Inc. Wellbore material continuous hardness testing methods and tools
WO2017165386A1 (en) * 2016-03-22 2017-09-28 Baker Hughes Incorporated Downhole rebound hardness measurement while drilling or wireline logging
US10048403B2 (en) 2013-06-20 2018-08-14 Exxonmobil Upstream Research Company Method and system for generation of upscaled mechanical stratigraphy from petrophysical measurements
US10472959B2 (en) 2013-03-21 2019-11-12 Halliburton Energy Services, Inc. In-situ geomechanical testing
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