WO2011140426A1 - Système de forage et de complétion universel - Google Patents

Système de forage et de complétion universel Download PDF

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Publication number
WO2011140426A1
WO2011140426A1 PCT/US2011/035496 US2011035496W WO2011140426A1 WO 2011140426 A1 WO2011140426 A1 WO 2011140426A1 US 2011035496 W US2011035496 W US 2011035496W WO 2011140426 A1 WO2011140426 A1 WO 2011140426A1
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WO
WIPO (PCT)
Prior art keywords
entitled
drilling
mud
pressure
incorporated
Prior art date
Application number
PCT/US2011/035496
Other languages
English (en)
Inventor
William Banning Vail, Iii.
Robert I. Dekle
Damir S. Skeri
James E. Chitwood
Original Assignee
Smart Drilling And Completion, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US13/068,133 external-priority patent/US9027673B2/en
Application filed by Smart Drilling And Completion, Inc. filed Critical Smart Drilling And Completion, Inc.
Publication of WO2011140426A1 publication Critical patent/WO2011140426A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/18—Anchoring or feeding in the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/18—Connecting or disconnecting drill bit and drilling pipe
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/10—Valve arrangements in drilling-fluid circulation systems
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/08—Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
    • E21B23/10—Tools specially adapted therefor

Definitions

  • PCT/US02/26066 filed on Aug. 16, 2002, entitled “High Power Umbilicals for Subterranean Electric Drilling Machines and Remotely Operated Vehicles", that has the International Publication Number WO 03/016671 A2, that has International Publication Date of Feb. 27, 2003, that issued as European Patent No. 1,436,482 Bl on the date of Apr. 18, 2007, an entire copy of which is incorporated herein by reference.
  • Provisional Patent Application Serial. No. 61/189,253 was erroneously referenced as Serial. No. 60/ . . . within Provisional Patent Application Serial. No. 61/270,709 and within Provisional Patent Application No. 61/274,215 mailed to the USPTO on Aug. 13, 2009, and these changes are noted here, and are incorporated by herein by reference. Entire copies of the cited Provisional Patent Applications are incorporated herein by reference unless they present information which directly conflicts with any explicit statements in the application herein.
  • the term “smart shuttle” will be capitalized as “Smart Shuttle”; the term “well locomotive” will be capitalized as “Well Locomotive”; the term “downhole rig” will be capitalized as “Downhole Rig”; the term “universal completion device” will be capitalized as “Universal Completion Device”; and the term “downhole bop” will be capitalized as “Downhole BOP”.
  • Liner/Drainhole Drilling MachineTM or “LDDMTM”
  • Drill and Drag Casing Boring MachineTM or “DDCBMTM”
  • NDCBMTM Down Down Down Boring Machine
  • NDCBMTM Next Step Drilling MachineTM
  • NSDMTM Next Step Electric Drilling MachineTM
  • NSEDMTM Next Step Subterranean Electric Drilling MachineTM
  • NSSEDMTM Next Step Subterranean Electric Drilling MachineTM
  • Subterranean Liner Expansion ToolTM or “SLETTM”
  • SAECSTM Adaptive Electronics Control System
  • APCSTM Adaptive Power Control System
  • SAPCSTM Subsea Adaptive Power Control System
  • the fundamental field of the invention relates to methods and apparatus used to drill and complete wellbores.
  • Such wellbores include extended reach horizontal wellbores, for example in shales, deep subsea extended reach wellbores, and multilateral wellbores.
  • Relevant to the invention are topics that include liner drilling, deep water drilling, extended reach drilling, Managed Pressure Drilling (MPD), and one of it's variants, Constant Bottom Hole Pressure (CBHP) drilling.
  • the invention relates to adding simple threaded subassemblies to existing threaded tubular drilling and completion equipment typically already present at a given wellsite that are used to dramatically increase the lateral reach using that existing on-site equipment.
  • the field of the invention also relates to dramatically reducing the cost to drill new wells by reducing the strength requirements on wellsite drilling and completion equipment to reach a predetermined lateral distance.
  • the field of invention also relates to the reduction in drilling costs of a multiple well drilling program, for example in shales. Such an approach would be particularly useful in the Barnette, Marcellus, and in the Bakken formations.
  • CSUG/SPE 137821 entitled “New Approach to Improve the Horizontal Drilling reach", by Vestavik, et al, the Reelweel Drilling Method (RDM) is described.
  • the Dual Drill String (DSS) method is described that uses a Top Drive.
  • the rotating Dual Drill String seals against the interior of a Sliding Piston.
  • the exterior portion of the Sliding Piston seals against the interior of a casing.
  • Applied annular pressure to that Sliding Piston is used to push the Bottom Hole Assembly (BHA) into a horizontal section of a well.
  • BHA Bottom Hole Assembly
  • Reelwell reports a 14 ton increase in net force applied to the BHA with an applied annular pressure of 50 bar (approximately 725 psi). So, Reelwell does use applied annular pressure to increase Weight on Bit (WOB).
  • WOB Weight on Bit
  • the Reelwell Drilling Method uses the annulus for pressuring their Sliding Piston to increase WOB, and uses the Dual Drill String to maintain circulation while increasing WOB.
  • the Dual Drill String is comprised of a pipe-within-a pipe.
  • a further significant disadvantage of the RDM is that the interior of a Dual Drill String is used to circulate fluids both ways.
  • One channel of the pipe system carries clean mud downhole, and the other channel carries dirty mud uphole. Normally, dirty mud goes up an annulus.
  • the dirty mud goes up one channel within the DDS, and is therefore called a "reverse circulation” technique (SPE 89505, entitled “Reverse Circulation With Coiled Tubing - Results of 1600 + jobs, by Michel, et. al.”).
  • SPE 89505 entitled “Reverse Circulation With Coiled Tubing - Results of 1600 + jobs, by Michel, et. al.”
  • reverse circulation causes an increase in pressure at the bit because the area available to fluid flow up is much smaller compared to the typically available area to annular annular flow up.
  • an increase in the pressure on clean mud flowing down the annulus is necessary to compensate for the extra pressure required to push mud up the inside of the drill pipe at the same flow rate. That increase in pressure appears at
  • This increase in pressure can be defined as a "Back Pressure” and is caused by the frictional fluid flow within pipes and tubulars. Such frictional flow within pipes is well documented in standard text books and can be calculated at the website www.efunda.com. Such increase in Back Pressure can result in drilling conditions outside the desirable pressure range at the intersection of the drill bit with the rock face. That desirable pressure range is called the “Drilling Window” (IADC/SPE 122281, entitled “Managed Pressure Drilling: What It Is and What it is Not", by Malloy, et. al).
  • any such device would be challenged technologically for use in any drilling machine having a clean mud flow rate of 600 gallons per minute, a pressure drop across the device of 725 psi, which therefore, internally dissipates about 250 horsepower within the device.
  • Such technological challenges include at least the following: the heating of such devices dissipating high horsepower would present many problems; the mud at such high flow rates is very abrasive, and the springs, balls, and ball seats, are subject to wear from such high mud flow rates; the mechanisms can clog up or jam; such devices can set up pressure oscillations because of the natural frequencies of the springs and balls and their interaction with tubular structures in the wellbore; the force characteristics of the springs are temperature dependent; the check valves are difficult to maintain in calibration with wear; and such check valves can have relatively complex pressure vs. flow rate characteristics.
  • An object of the invention is to provide a new method to drill wells with standard drill pipe where pressurized clean mud is pumped down the annulus that provides additional force on the bit (WOB) AND which provides fresh mud to circulate down to the drill bit.
  • WOB additional force on the bit
  • Another object of the invention is to provide new apparatus to drill wells with standard drill pipe that includes a threaded tubular element having a Leaky Seal and a Cross-Over that is inserted into an existing threaded drill string that provides additional force on the bit (WOB) AND which provides fresh mud to circulate down to the drill bit.
  • a threaded tubular element having a Leaky Seal and a Cross-Over that is inserted into an existing threaded drill string that provides additional force on the bit (WOB) AND which provides fresh mud to circulate down to the drill bit.
  • Another object of the invention is to use annular mud flow for at least two purposes simultaneously: to provide additional WOB and to provide fresh mud to the drill bit.
  • Another object of the invention is to use annular mud flow for multiple purposes simultaneously including (for example): to provide additional WOB; and to provide fresh mud to the drill bit; and to provide power to a mud motor powered progressing cavity pump that is to be used for Underbalanced Drilling, or for Managed Pressure Drilling, or for Constant Pressure Drilling; and to provide power to a mud motor to turn the shaft of attached to a rotary drill bit.
  • Yet another object of the invention is to provide new reverse circulation methods for drilling and completing wellbores.
  • Another object of the invention is to provide methods and apparatus that reduces the Back Pressure during reverse circulation methods of operation using the Force
  • Another object of the invention is to provide a new drilling methods and apparatus that as an option, can use commercially available Wired Drill Pipe for high speed data communications .
  • Another object of the invention is to provide new drilling methods and apparatus to drill extended reach wellbores.
  • Yet another object of the invention is to provide new drilling apparatus that may be used in conjunction with other commercially available systems to reduce mechanical friction, such as the LoTADTM system.
  • Another object of the invention is to provide a Leaky Seal having a passageway through the seal that passes high mud flow rates, such as 600 gallons per minute, that provides a pressure differential across the seal related to the flow rate of the mud through the passageway of the seal, and which is relatively indestructible at such a high mud flow rate.
  • Yet another object of the invention is to provide extended reach horizontal wellbores, for example in shales.
  • Another object of the invention is to provide deep subsea extended reach wellbores.
  • Another object of the invention to provide subsea multilateral wellbores.
  • Yet another object of the invention is to provide simple threaded subassemblies that are added to existing threaded tubular drilling and completion equipment which are used to dramatically increase the lateral reach using that existing on-site equipment.
  • Another object of the invention is to provide tubular subassemblies for use in wellbores that extract power from downward flowing clean mud, or other fluids, in an annulus to provide additional force on tubular elements within the wellbore, while maintaining circulation, to extend the lateral reach of the drilling and completion equipment.
  • Another object of the invention is to provide tubular subassemblies for use in wellbores that extract power from downward flowing clean mud, or other fluids, in an annulus to provide additional torque on tubular elements within the wellbore, while maintaining circulation, to extend the lateral reach of the drilling and completion equipment.
  • Another object of the invention is to provide tubular subassemblies for use in wellbores that that extract power from downward flowing clean mud, or other fluids, in an annulus to provide additional force and torque on tubular elements within the wellbore, while maintaining circulation, to extend the lateral reach of the drilling equipment and completion equipment.
  • Yet another object of the invention is provide simple add-on tubular elements to an existing drill string within a wellbore that allows comparatively lighter drilling equipment to successfully drill through a given set of geological formations that are used to reach a given lateral distance, therefore reducing drilling costs at the wellbore.
  • another object of the invention is to provide simple add-on tubular elements to an existing drill string within a wellbore that allows lighter completion equipment to be used to complete a well at a given lateral distance, therefore reducing completion costs of the wellbore.
  • Figure 1 shows a partially cased wellbore with an open hole segment.
  • Figure 2 shows a rotary drill string attempting to further extend the open hole segment, but cannot drill any further because of wellbore frictional effects.
  • Figure 3 shows the Leaky Seal and Cross-Over on separate threaded subassemblies screwed into a rotary drill string for drilling an extending portion of the open-hole well in Figures 1 and 2 which is a first embodiment the Universal Drilling MachineTM.
  • the well can be drilled further with existing drilling equipment located at the wellsite.
  • a pressure differential across Leaky Seal causes an additional force on the drill bit, and mud flow through the Cross-Over provides clean drilling mud to the bit.
  • Figure 3C is similar to Figures 3, 3A and 3B, except in this preferred embodiment the Leaky Seal possesses a round hollow tube passing through the portion of the body of the Leaky Seal.
  • Figure 3D is similar to Figure 3C, except several reference points are identified for pressure and other measurements.
  • Figure 3E shows a cross section of a Leaky Seal.
  • Figure 3F shows a cross section of a Cross-Over.
  • Figure 4 shows an expanded view of a Cross-Over that is rigidly attached to a threaded sub that screws into a rotary drill string.
  • Figure 5 shows an expanded view of another Cross-Over that possesses bearings which allows it to rotate with respect to the rotary drill string.
  • Figure 6 shows an expanded view of the Leaky Seal that is rigidly attached to a threaded sub that screws into a rotary drill string.
  • Figure 6A shows an expanded view of a Leaky Seal that possesses bearings which allows it to rotate with respect to a rotary drill string.
  • Figure 7 shows another form of a Leaky Seal that allows fluid passage around its outside diameter that also allows the drill string to rotate within the casing with minimal resulting friction caused by the Leaky Seal.
  • Figure 8 shows the Leaky Seal and Cross-Over on separate mandrels inserted into a drill string in a previously cased well for extending an open hole portion of the well using slide drilling techniques which is a second embodiment of the Universal Drilling Machine.
  • Figure 9 shows a Leaky Seal and Cross-Over on separate mandrels attached to coiled tubing for drilling an extended portion of an open hole well that is a third embodiment of the Universal Drilling Machine.
  • Figure 10 shows an embodiment of wellbore pressure management with the Universal Drilling Machine.
  • Figure 11 shows an embodiment of a closed-loop mud management system with the Universal Drilling Machine.
  • Figure 11A shows an embodiment of The Force SubTM used with the Universal Drilling Machine shown in Figure 11.
  • FIG 1 IB shows an embodiment of The Torque SubTM used with the Universal Drilling Machine shown in Figure 11.
  • Figure 11C shows how annular portions of the apparatus are sequentially defined and how interior tubular elements of the apparatus are sequentially defined in one preferred embodiment of the invention.
  • Figure 12 shows one embodiment of the closed- loop feedback control an entire drilling system at the wellsite to perform Managed Pressure Drilling with the Universal Drilling Machine shown in Figure 11.
  • Figure 13 shows one embodiment of an Annular Rotary Control Device used with the Universal Drilling Machine.
  • Figure 14 shows a typical BOP installed with an embodiment of the invention.
  • Figure 15 shows an embodiment of the invention with a check valve installed within a Cross-Over used for the purposes of the pressure control of wells.
  • Figure 16 shows an embodiment of the invention used as a mud-motor driven progressing cavity pump that is used for Underbalanced Drilling or Managed Pressure Drilling with the Universal Drilling Machine.
  • Figure 16A shows the mud-motor driven progressing cavity pump of Figure 16 that is used as a portion of yet another embodiment of the invention called The Annular Pressure Tractor & ShuttleTM which is a form of an annular mud powered conveyance system.
  • FIG 17 shows how other Horsepower Dissipating Devices (“HPDD”) may be used with different embodiments of the invention.
  • HPDD Horsepower Dissipating Devices
  • Figure 18 shows one embodiment of the Universal Completion MachineTM used to convey a liner into an open hole section of a well.
  • Figure 19 shows another embodiment of the Universal Completion Machine used to convey a liner into an open hole section of a well.
  • Figure 20 shows Fig. 1 from WO 94/13925 (Vestavik) that is Prior Art.
  • Figure 1 shows the existing situation at typical drilling site.
  • casing 102 has been cemented in place with cement 104 within previously drilled borehole 106 in subterranean geological formation 108.
  • the well was drilled and cased to a first distance 110.
  • additional open hole 112 has been drilled to a maximum lateral distance 114 within the geological formation.
  • the existing drilling equipment and existing completion equipment cannot drill or complete further, although this equipment is still located and available at the wellsite, but is not shown in Figure 1.
  • the direction to the right-hand side is the direction downhole.
  • FIG 2 shows rotary drill string 116 attached to rotary drill bit 118 within the well previously shown in Figure 1.
  • Typical pipe joint 120 is shown where individual drill pipes are typically threaded together to form the drill string.
  • This drilling equipment is being used to try to drill an extra distance into formation but cannot drill further than the lateral distance 114 because of frictional losses and other limiting factors during typical drilling operations. Put simply, the existing drilling equipment cannot drill further than the lateral distance 114 shown in Figure 2.
  • Drilling mud is shown flowing downward by the downward flowing arrow 122 within the inside area of the drill pipe 124 through which fluids may flow. Element 124 is also called the interior of the drill pipe.
  • the downward flowing fluid 122 may be any mud or any type of fluid typically found within wells in the oil and gas industries.
  • the dirty drilling mud with rock cuttings is shown flowing uphole by upward pointing arrow 126.
  • the upward flowing dirty mud first flows in sequence within the annulus 128 between the OD of the drill pipe and the ID of the open hole 112, and then within the annulus 130 between the ID of the well casing and the OD of the drill pipe.
  • OD is an abbreviation for "Outside Diameter”
  • ID is an abbreviation for "Inside Diameter”.
  • the casing 102 has an outside diameter 132, an inside diameter 134, and a typical wall thickness 136 (which numerals 132, 134, and 136 are not shown on Figures 1 and 2 for the sake of brevity).
  • Drill string 116 is comprised of segments of drill pipes having OD 138, ID 140, a typical wall thickness 142, and mating threads 144 as typically used in the industry (which numerals 138, 140, 142, and 144 are not shown on Figures 1 and 2 for the sake of brevity).
  • the ID 146 of the open hole segment 148 is shown in Figure 2.
  • the ID of the original borehole in the cased section is designated by the numeral 149 (which numeral is not shown for the purposes of brevity).
  • the materials of all the components defined herein are those materials typically used in the industry.
  • the lower end of drill pipe 150 having "male threads" is threaded into the upper end of drill pipe 152 having "female threads" at pipe joint 120.
  • Figure 3 shows one embodiment of the invention having Leaky Seal Subassembly 154 and Cross-Over Subassembly 156 added to the rotary drill string shown in Figure 2 to extend the open hole well bore. It is desired to extend the wellbore by a distance 157 shown in Figure 3. In one embodiment, these components are added to existing drilling equipment at the wellsite.
  • Figure 3 shall mean Figure 3 and/or Figure 3A and/or Figure 3B as a group.
  • first pipe joint 120 is opened up by unthreading the mating parts.
  • the lower end of the Cross-Over Subassembly 158 having male threads is then screwed into the upper end of drill pipe 152 having female threads.
  • the lower end of the Leaky Seal Subassembly 160 having male threads is screwed into the upper end 162 of the Cross-Over
  • Subassembly 164 having female threads is joined to the lower end of drill pipe 150 having male threads.
  • lower Drilling Bottom Hole Assembly 166 has also been added as a portion of the drilling machine as is typical in the art. This is abbreviated as a "DBHA" for Drilling Bottom Hole Assembly.
  • DBHA is not shown in Figure 3 for the purposes of brevity.
  • Another term for Drilling Bottom Hole Assembly is "downhole drill bit apparatus", and the terms may be used interchangeably for the purposes herein.
  • This DBHA may be selected to have any number of sensors, transmitters, mud-pulse transmitters, bidirectional
  • the machine created by adding the Leaky Seal Subassembly and the Cross- Over Subassembly to the existing drilling apparatus in Figure 2 is one embodiment of the Universal Drilling Machine.
  • the Leaky Seal Subassembly 154 may simply be called the Leaky Seal Sub or simply the Leaky Seal.
  • the Cross-Over Subassembly 156 may be called the Cross-Over Sub, or simply the Cross-Over. This shortened nomenclature shall be used unless stated otherwise in the specification which follows.
  • the Leaky Seal 154 possess fluid passage 170.
  • This fluid passage 170 may be called interchangeably the orifice of the Leaky Seal, the fluid passageway through the Leaky Seal and is an example of a fluid passage means.
  • Fluid passage means 170 provides means to pass fluids from a first side of the Leaky Seal (uphole in one embodiment) to a second side of the Leaky Seal (downhole side in another embodiment).
  • a fluid passage means may also provide a passageway for fluids to pass around the Leaky Seal, for example, through a portion of the mandrel underneath what would normally be called a seal mounted on the exterior of the mandrel.
  • Such a fluid passage means may include one or more of any such passages, through the seal, and/or around it.
  • Any one well component may in fact possess one or more fluid passage means.
  • uphole side 172 of Leaky Seal 154 is exposed to average ambient wellbore pressure PI 72 in its vicinity.
  • Downhole side 174 of Leaky Seal 154 is exposed to ambient wellbore pressure PI 74 in its vicinity. (These averages include the variations in pressure across the area exposed to the wellbore fluids caused by the presence of the orifice itself.)
  • the numerical difference in pressure between the Uphole Side of the Leaky Seal and the Downhole Side of the Leaky Seal is the algebraic quantity: ( P172 - P174 ). That algebraic quantity multiplied by the area A of the Leaky Seal (if cylindrical in shape) generates a force FLS1 on the Leaky Seal given approximately by the following:
  • the legend FLS 1 is shown in Figure 3 A. That force FLS 1 is transmitted downhole through rigidly attached tubulars and provides an extra force, or an additional force, that is part of the total force on bit TFOB1 in Figure 3 A. That legend TFOB1 appears in Figure 3 A. Before the application of the force from FLS1, the initial, or beginning force of bit is defined as IFOB1, which legend is +not shown in Figure 3 A in the interests of brevity. The extra force contributed through the tubulars of the system by the Force Sub is then algebraically (TFOB1 - IFOB2). There are, of course, some losses in transmitting the force FLS1 through the tubulars, but that subject is subject to standard torque and drag analysis on drill strings that is known to anybody having ordinary skill in the art.
  • the uphole side 172 of Leaky Seal 154 may also be called a first side 172 of Leaky Seal 154 that, in several embodiments, may also be called a high pressure side 172 of the Leaky Seal.
  • the downhole side 174 of the Leaky Seal 154 may also be called a second side 174 of the Leaky Seal 154 that, in several embodiments, may also be called a lower pressure side 172 of the Leaky Seal.
  • the Leaky Seal 154 is rigidly attached to its mandrel 176 by attachment means 178.
  • the Leaky Seal 154 has exterior sliding and rotating seal 180 that makes hydraulic sealing contact with the interior of portion of the casing designated by 182 in Figure 3.
  • Arrow 184 shows fluid flowing through the annulus 186 between the OD of drill pipe 150 and the ID of casing 102 and into the orifice 170 of the Leaky Seal.
  • Arrow 188 shows fluid flowing out of the orifice of the Leaky Seal. The fluid flows through the body of the Leaky Seal which body is not shown in Figure 3, but which is shown in Figure 6 (element 372).
  • FIG 3 shows Cross-Over 156.
  • Cross-Over 156 is rigidly attached to its mandrel 190 by suitable attachment means 192.
  • the Cross-Over 156 has exterior sliding and rotating seal 194 that makes hydraulic sealing contact with the interior portion of the casing designated by 196 in Figure 3.
  • Arrow 198 shows fluid flowing through the annulus 200 between the OD of mandrels 176 and 190 and the ID of casing 102 below the Leaky Seal and above the Cross-Over.
  • Fluid 202 then flows through first channel entry 204 and down first channel 206 through the body of the Cross-Over to first channel exit 208 through second interior portion 350 of mandrel 190.
  • Fluid 209 continues to flow downhole through the second interior portion 350 of mandrel 190 through the interior 210 of Drilling Bottom Hole Assembly 166 and through the nozzles 212 of the drill bit (element 212 not shown for brevity).
  • dirty mud with cuttings 213 then flows up the annulus 214 formed between the Drilling Bottom Hole Assembly 166 and the inside wall of the open hole 216. Thereafter, the dirty mud with cuttings 218 flows upward in the annulus 220 formed between the OD of drill pipe 152 and the OD of mandrel 190 and the interior portion of the casing 196. Thereafter, dirty mud with cuttings 222 flows through second channel entry 226 and then through second channel 228 through the body of the Cross-Over to second channel exit 230 through the first interior portion 348 of mandrel 190. Dirty mud with cuttings 232 then flows uphole through the first interior portion 348 of mandrel 190, through the interior 354 of mandrel 176 and through the inside diameter 356 of drill pipe 150 towards the surface.
  • Figure 3 shows that the pressure drop across Leaky Seal causes an additional force on the bit, and the mud flow through Cross-Over provides clean drilling mud to the bit.
  • the additional force on bit is transmitted via rigid tubulars connecting the Leaky Seal to the drill bit, collectively identified by the legend 298 in Figure 3A in particular.
  • Such tubulars include mandrels and drill strings that are attached to various different types of DBHA's.
  • Cross-Over 156 possesses first channel entry 204. That first channel entry 204 is located on a first annular side 334 of Cross-Over 156 that is also called the upper annular side 334 of Cross-Over 156 that, in some
  • fluid flows down first channel 206 through the body of the Cross- Over to the first channel exit 208 and through the second interior portion 350 of mandrel 190.
  • Fluid 209 flowing downward within the second portion 350 of mandrel 190 is flowing downward within the lower central portion 336 of Cross-Over 156, which is also called the second central portion of Cross-Over 156, that in some embodiments is called the low pressure central portion of Cross-Over 156.
  • dirty mud with cuttings 222 flows through second channel entry 226.
  • That second channel entry 226 is located on a second annular side 338 of Cross- Over 156 that is also called the lower annular side 338 of Cross-Over 156, that in some embodiments, is called the low pressure annular side 338 of Cross-over 156.
  • fluid flows through second channel 228 through the body of the Cross-Over to second channel exit 230 through the first interior portion 348 of mandrel 190.
  • Dirty mud with cuttings 232 then flows uphole through the first interior portion 348 of mandrel 190.
  • Dirty mud with cuttings 340 is flowing upward within the upper central portion 342 of Cross-Over 156, which is also called the first central portion 342 of Cross-Over 156, that is some embodiments is called the flowing uphole pressure side 342 of Cross-Over 156.
  • mandrel 190 is comprised of tubular-like body 344 with interior blockage 346, having male threaded ends on the downhole side and female threads on the uphole side, that is manufactured as one component of steel, for example, type 304 stainless steel. Accordingly, mandrel 190 has a first interior portion 348 and has a second interior portion 350. First interior portion 348 is also called the uphole interior portion of mandrel 190. Second interior portion 350 is also called the downhole interior portion of mandrel 190.
  • Figure 3C is similar to Figures 3, 3 A and 3B, except in this preferred embodiment the Leaky Seal 234 possesses a round hollow tube 236 passing through the portion of the body 238 of the Leaky Seal.
  • the length of round hollow tube 236 is designated by L236, and its inside diameter is ID236, although those legends are not shown on Figure 3C in the interests of brevity.
  • Leaky Seal 234 has exterior sliding and rotating seal portion 240 that makes hydraulic sealing contact with the interior of portion of the casing designated by 242 in Figure 3C.
  • the Leaky Seal 234 is rigidly attached to its mandrel 244 by attachment means 246.
  • Round hollow tube 236 is an example of a fluid passageway through the Leaky Seal and is an example of a fluid passage means. Round hollow tube 236 is also an example of a fluid channel through the Leaky Seal.
  • the uphole side 248 of Leaky Seal 234 is exposed to average ambient wellbore pressure P248 in its vicinity, but the legend P248 is not shown in Figure 3C for the purposes of brevity.
  • Downhole side 250 of Leaky Seal 234 is exposed to ambient wellbore pressure P250 in its vicinity, but the legend P250 is not shown in the interests of brevity.
  • the difference in these pressures provides the Pressure Differential on the Leaky Seal that produces a force on the Leaky Seal.
  • the force FLS2 on the Leaky Seal 234 is shown as a legend in Figure 3C.
  • the total force on bit TFOB2 is also shown as a legend in Figure 3C.
  • FIG. 3C Also shown in Figure 3C is the Cross-Over generally shown as element 252. This is essentially the same as element 156 in Figure 3.
  • the uphole side of annular portion 254 of Cross-Over 252 is exposed to average ambient wellbore pressure P254 in its vicinity, but the legend P254 is not shown in Figure 3C for the purposes of brevity.
  • Downhole side of annular portion 256 of Cross-Over 252 is exposed to ambient wellbore pressure P256 in its vicinity, but the legend P256 is not shown in the interests of brevity. The difference in these pressures provides any Pressure Differential on the Cross-Over.
  • first fluid flow channel 258 has a substantial tubular shape and an average inside diameter ID258, although the legend ID258 is not shown on Figure 3C for the purposes of brevity.
  • second fluid flow channel 260 has a substantial tubular shape and an average inside diameter ID260, although this legend is not shown in Figure 3C for the purposes of brevity. If ID258 and ID260 are larger than ID236, then there will be relatively little Pressure Differential across the Cross-Over, and therefore little net force applied to the Cross-Over due to flowing fluids. In this case, the primary force on the combined Leaky Seal and Cross-Over in Figure 3C will come from the net force on just the Leaky Seal caused by the Pressure Differential Across the Leaky Seal.
  • Figure 3D is similar to Figure 3C, except several reference points are identified for pressure measurements.
  • Numeral 262 is located a distance D262 above the Upper Face 266 of the Leaky Seal, although the legend D262 is not shown in Figure 3D for the purposes of brevity.
  • a first pressure vs. distance Pl(262 vs. Zl) is then calculated and/or measured starting with Zl having the value of zero at position 262, and various different values measured with a tape measure, for example, at the following sequence of locations ("first path"): 268, 270, 272, 274, 276 and at the face of the drill bit 264.
  • Z2 is then calculated and/or measured starting with Z2 having the value of zero at the position of 264, and various different values at the following sequence of locations: 278, 280, 282, and ending at the position 266 that is a distance D276 above the Upper Face 266 of the Leaky Seal ("second path"), although that legend is not shown in Figure 3D for the purposes of brevity.
  • the mud flow system in the well shown in Figure 3D takes path 1 downhole, and then takes path 2 uphole. Paths 1 and 2 cross-over between certain annular portions and certain portions flowing through the ID's of mandrels and drill pipes as described above. Collectively Paths 1 and Paths 2 is called the "Mud Flow Path" for the well shown in Figure 3D that is identified by numeral 308. Element 308 depicts the entire Mud Flow Path downhole, and then uphole. The portion of the "Mud Flow Path" 290 carrying clean mud downhole is shown in Figure 3D. The portion of the "Mud Flow Path" 291 carrying dirty mud uphole is not shown in Figure 3D for the purpose of clarity.
  • the drilling machine 292 has a Mud Flow Path that provides clean drilling mud 294 to the drill bit and returns dirty mud with rock chips 296 that is a direction towards the surface.
  • the portion of the Mud Flow Path Carrying clean mud is defined as numeral 299 (not shown for the purposes of simplicity).
  • the average pressure is available at all points within the Mud Flow Path.
  • the average mud flow rate often expressed in gallons per minute, is available at all points within the Mud Flow Path.
  • a first mud flow rate vs. distance MFR(262 vs. Zl) is calculated or measured.
  • a second mud flow rate vs. distance MFR(264 vs. Z2) is calculated or measured.
  • Pressure at location 288 is the ambient pressure P288 on a first side of the Leaky Seal 234.
  • Pressure at location 286 is the ambient pressure P286 on a second side of the Leaky Seal 234.
  • the average fluid flow rate through round hollow tube 236 at point 290 is given by MFR290.
  • the legends P286, P288, and MFR290 are not sown in Figure 3D for the purposes of brevity.
  • Figures 3C and 3D have shown a Leaky Seal (234) possessing a fluid passageway (236) through the Leaky Seal that causes a predetermined volume of fluid per unit time (MFR290) to pass through the fluid passageway upon application of a predetermined pressure difference (P288-P286) applied between a first side of the Leaky Seal (288) and a second side (286) of the Leaky Seal.
  • MFR290 fluid per unit time
  • Bingham plastic fluids behave differently.
  • the Oilfield Dictionary further states: "Fluids obeying this model (two parameter rheological model) are called Bingham plastic fluids and exhibit a linear shear-stress, shear-rate behavior after an initial shear stress threshold has been reached.
  • Plastic viscosity (PV) is the slope of the line and the yield pint (YP) is the threshold stress.”
  • any check valve into the Mud Flow Path 308 that contains a Leaky Seal is an embodiment of this invention.
  • the method of inserting one or more check valves into the Mud Flow Path 308 that contains a Leaky Seal is an embodiment of this invention.
  • the use of any float valve, normally associated with cementing operations, in Mud Flow Path 308 that contains a Leaky Seal is also an embodiment of this invention.
  • the use of any flapper valve in the Mud Flow Path 308 that contains a Leaky Seal is an embodiment of this inventing.
  • the use of any hydraulic device, or hydraulic means, in the Mud Flow Path 308 that contains a Leaky Seal is an embodiment of the invention.
  • the use of any ball and dart device or system in the Mud Flow Path 308 that contains a Leaky Seal is an embodiment of this invention.
  • Figure 3E shows a cross section of Leaky Seal 234.
  • Figure 3C defines cross- section A-A (a plane perpendicular to the paper of Figure 3C defines the planar cross- section). Any numerals not defined in this description of Figure 3E have already been previously defined.
  • Figure 3E shows the cross section of Leaky Seal 234. All the numerals except a few have already been defined.
  • the central passage through mandrel 244 is identified by numeral 362.
  • Figure 3F shows a cross section of Cross-Over 252.
  • Figure 3C defines cross- section B-B (a plane perpendicular to the paper of Figure 3C defines the planar cross- section).
  • Figure 3F shows the cross section of Cross-Over 252. All the numerals except a few have already been defined.
  • the central passage 366 is shown through the upper central portion 342 of Cross-Over 156. Any numerals not defined in this description of Figure 3E have already been previously defined.
  • the area 368 is subject to applied fluid pressure. That area is defined as A368, but that legend is not shown on Figure 3F in the interests of brevity.
  • the area of the first channel entry 204 is chosen to be much larger than the area of round hollow tube 236 passing through the portion of the body 238 of the Leaky Seal. As previously discussed, when the passageways through the Cross-Over are much larger than the area of the round hollow tube 236, the net force from fluid pressure on the Cross-Over can be designed to be negligible.
  • the size of area of the passageways through the Cross-Over may be made smaller so that the Cross-Over can be designed to influence the force on the drill bit, but those embodiments will not be discussed further here in the interest of brevity.
  • Figure 4 shows an expanded view of a Cross-Over that is rigidly attached to a threaded sub that screws into a rotary drill string.
  • Figure 4 shows an expanded view of the detail in Cross-Over 252 that is defined in Figure 3C.
  • the Cross-Over 252 has Cross-Over body 482.
  • the body 482 is formed nitrile, and is attached by attachment means 484 to the exterior of portion of threaded mandrel 486.
  • the exterior sliding and rotating seal 488 is a nitrile with good wear resistant properties.
  • the attachment means 484 is a thin layer of glue that was used when the body was formed on mandrel 486. In another
  • the body 482 is formed with any appropriate elastomer for the wellbore conditions and the exterior sliding and rotating seal 488 is formed from another appropriate wear resistant elastomer.
  • Typical techniques and materials in the industry are used to construct different embodiments of the Cross-Over and to attach it by attachment means 484 to its mandrel 486.
  • One preferred method of manufacture is to form a Cross-Over made of an elastomer on its mandrel.
  • Figure 5 shows an expanded view of another Cross-Over that possesses bearings which allows it to rotate with respect to the rotary drill string.
  • Figure 5 shows Cross- Over 360 having bearings 362 mounted on mandrel 364 which has exterior sliding (and rotating if desirable) seal 366 that makes hydraulic sealing contact with the interior of portion of the casing designated by numeral 368.
  • the bearings extend the life of the exterior sliding seal 366.
  • the exterior seal 488 which predominantly slides in this application, but may also do some rotation, is made of a suitably wear resistant elastomer chosen for the wellbore conditions.
  • Figure 6 shows an expanded view of the Leaky Seal that is rigidly attached to a threaded sub that screws into a rotary drill string.
  • Leaky Seal 154 as shown in Figure 3.
  • First hollow passageway 370 through the body 372, and second hollow passageway 374 through the body 372 are shown.
  • the body 372 is formed nitrile
  • the exterior sliding and rotating seal 180 is a nitrile with good wear resistant properties
  • the attachment means 178 is a thin layer of glue that was used when the body was formed on mandrel 176.
  • the body 372 is formed with any appropriate elastomer for the wellbore conditions and the exterior sliding seal 180 is formed from another appropriate wear resistant elastomer. Typical techniques and materials in the industry are used to construct different embodiments of the Leaky Seal and to attach it by attachment means 178 to its mandrel 176.
  • One method of manufacture is to form a Leaky Seal made of an elastomer on its mandrel.
  • first hollow passageway 370 there is a first tapered entrance 310 into the interior of that passageway on a first uphole side 312 of the Leaky Seal, and there is a second tapered entrance 314 on the exit of that passageway on a second downhole side 316 of the Leaky Seal (elements 310, 312, 314 and 316 are not shown in Figure 6 for the purposes of simplicity). Similar comments apply to the second hollow passageway 374.
  • the uphole annular side 490 of the Cross-Over 482 is identified in Figure 4.
  • the downhole annular side of Cross-Over 492 of Cross- Over 482 is also identified in Figure 4.
  • Leaky Seal 318 possesses a rotating bearing assembly 320 that is comprised of bearing mounting 324 on the OD of mandrel 176 and bearing rotating portion 322.
  • the body of the Leaky Seal is suitably attached to the outer portion of the bearing rotating portion 322 by suitable attachment means 324 (not shown).
  • One attachment means includes a glue.
  • the body is fabricated from a suitable elastomer, and is formed in-place on the bearing rotating portion 322.
  • the exterior seal 226, which predominantly slides in this application, but may also do some rotation, is made of a suitably wear resistant elastomer chosen for the wellbore conditions.
  • Figure 7 shows another form of a Leaky Seal that allows fluid passage around its outside diameter that also allows the drill string to freely rotate within the casing.
  • Leaky Seal 376 has an outside diameter OD376 that is smaller than the inside diameter of the casing 378 designated with the legend ID378.
  • the legends OD376 and ID378 are not shown in Figure 7 for the purposes of brevity.
  • This embodiment of the invention allows fluids 380 to pass around the space available between the respective inside and outside dimensions.
  • This extra available space 382 is a form of a passageway around the Leaky Seal which is an example of one preferred
  • Leaky Seal 376 possesses exterior sliding and rotating seal 384 that makes hydraulic
  • Leaky Seal 386 allows the drill pipe to rotate freely while minimizing friction between the Leaky Seal and the inside diameter of the casing.
  • fluid passage means include passage around a seal through a passageway on the interior side of the seal that would require a modification of the mandrel (compared to that shown in Figure 7).
  • the fluid passing by the Leaky Seal would flow through a portion of the mandrel on which the seal is mounted.
  • fluid passage means There are many embodiments of fluid passage means that allow a Pressure Differential to be established across the Leaky Seal which results in a force applied to the Leaky Seal.
  • fluid includes any wellbore fluid normally encountered in a wellbore specifically including oil, water, gas, solids, and mixtures of them.
  • Figure 8 shows a Cross-Over and Leaky Seal on separate mandrels inserted into a drill string in a previously cased well for extending an open hole portion of the well using slide drilling techniques which is a second embodiment of the Universal Drilling Machine. Slide drilling techniques often require rotation in addition to sliding the drill bit forward into the well as drilling continues.
  • Leaky Seal 154 and Cross-Over 156 are attached to collectively identified tubular portions 392 of a drilling machine 393.
  • Drilling machine 393 possesses a Drilling Bottom Hole Assembly 394 which has a mud motor 396 and drill bit 398.
  • First tubular portion 399 of the drilling machine 393 is comprised of one or more mandrels 400 attached to said Leaky Seal and to said Cross-Over. (As shown in Figure 8, first mandrel has numeral 401 and supports the Leaky Seal, and second mandrel has numeral 403 that is integral with the Cross-Over).
  • Second tubular portion of drilling machine 393 is a drill string 402 comprised of one or more segmented drill pipes attached to Drilling Bottom Hole Assembly 394.
  • Third tubular portion of drilling machine 393 is a drill string 404 comprised of segmented drill pipes that is controlled and positioned in the well by surface hoist equipment 406 (not shown in Figure 8 for purposes of simplicity.
  • Wellbore 408 is comprised of two downhole sections.
  • the first downhole section of wellbore 408 is a cased well having casing 410, surrounded by cement 412 that are located within the first borehole 414. That first downhole section has numeral 409 (not shown in the interests of brevity).
  • the second downhole section of wellbore 408 is the open-hole section 416 previously drilled to a maximum lateral distance 418 with the standard drilling equipment. That section has numeral 411 (which is not shown in the interests of simplicity).
  • that previous maximum open-hole section is currently being extended to the new distance 420. It is desired to drill an additional distance 423.
  • the Leaky Seal makes a rotating and sliding seal (429) with the interior of the casing 410, that results in a force (428) applied to the first tubular portion 399 of the drilling machine 393 disposed within the first downhole section of the wellbore 408. At least a portion of that force is applied to the second tubular portion of drilling machine 393, which is drill string 402, that in turn is applied to the Drilling Bottom Hole Assembly 394, and then to the bit 398. At least a portion of that force 428 is applied to the weight on bit "WOB" at the cutting face of the drill bit against the open hole at location 420.
  • Clean drilling mud flowing through second annular portion 426 of the first downhole section of wellbore 408 continues to flow into first channel 430 of Cross- Over 156 and then crosses into the lower interior flow channel 432 within the downhole interior portion 405 of mandrel 403 that is a part of the interior of the first tubular portion 399 of drilling machine 393.
  • Element 405 is not shown in Figure 8 for the purposes of simplicity and is located below interior blockage 407 of Cross-Over 156.
  • the clean drilling mud then flows within the second tubular portion of the drilling machine 393 that is drill string 402, and then through interior flow channels of the drill bit 434 (not shown for simplicity) and into the open borehole near location 420.
  • Dirty drilling mud 436 with rock cuttings flows through open-hole annulus 438 and then through the third annular portion 440 of the first downhole section of the wellbore 408.
  • the dirty mud then flows into second channel 442 of the Cross-Over, through the uphole interior portion 443 of mandrels 401 and 403, then ultimately through the interior of the third tubular portion of the drilling machine 393 towards the surface.
  • Element 443 is not shown in Figure 8 for the purposes of simplicity and is located above interior blockage 407 of Cross-Over 156.
  • Drilling Bottom Hole Assembly 394 possessing a mud motor 396 and drill bit 398 may also be called one embodiment of a Drilling Bottom Hole Assembly 444.
  • Many different embodiments of the Drilling Bottom Hole Assembly 444 include components typically used in the industry which include measurement- while-drilling components, logging-while-drilling components, mud pulse
  • communications components for sending information uphole in the mud column, downhole sensor components of many types including those for pressure, weight on bit, drill bit parameters, electronics communications components for sending information uphole, electronics communications components for receiving
  • drilling machine 450 in Figure 9 is disposed in the first downhole section of wellbore 452 that is cased well having casing 454, surrounded by cement 456 which are located within the first borehole
  • the second downhole section of wellbore 452 is the open-hole section which is not shown in the interests of simplicity because it substantially resembles that shown in Figure 8.
  • Third tubular portion of drilling machine 450 is a coiled tubing 460 controlled and positioned by a surface coiled tubing unit 462 (not shown in Figure 9 in the interests of simplicity).
  • first tubular portion of drilling machine 450 is comprised of a coiled tubing connection mandrel 464 which is joined by the differential threaded coupler assembly 465 to the mandrel 466 supporting the Leaky Seal 468 that is in turn joined to mandrel 470 that is integral with the Cross-Over 472.
  • Second tubular portion of drilling machine 450 is a drill string 474 comprised of one or more segmented drill pipes attached to Drilling Bottom Hole Assembly 476.
  • the drilling machine 450 is used to drill an extended reach portion of the open hole 478. Drilling machine 450 is yet another embodiment of the Universal Drilling Machine.
  • FIG. 10 One preferred embodiment of the invention showing important features of wellbore pressure management is shown in Figure 10. Many of the elements have been described heretofore.
  • Fl is the downward force on drill pipe 514 near the position of the wellbore makes a transition from vertical to horizontal; F2 is the force generated by the Leaky Seal 522 and Cross-Over 524; XI is the first horizontal section that was drilled and cased; X2 the additional distance capable of being drilled because of the use of the Leaky Seal 522; Z is the depth from the surface to the horizontal well being drilled; and C is clean drilling mud and D is dirty mud with cutting being returned to the surface.
  • Clean mud tank 502 has clean drilling mud level 504 which provides a
  • Tank 502 provides mud through pipe 506 to mud pump 508 which in turn pumps mud through pipe 510 which in turn flows through the annular inlet pipe 512.
  • rotating drill pipe 514 proceeds through annular seal 516 which is rigidly mounted to the wall of the casing and which has a surface 518 that makes a rotational seal with drill rotating drill pipe 514.
  • Clean drilling mud proceeds down the upper annular area 520 which proceeds to the Leaky Seal 522 and Cross-Over 524 that provides extra force F2 on the portion of the drill pipe in the region defined by these elements. Clean drilling mud then proceeds through the interior of the drill pipe 526 through instrumentation package 528 to drill bit 530 that is one embodiment of a Drilling Bottom Hole Assembly 531 (which element is not shown in Figure 10 for the purposes of simplicity).
  • Dirty mud with cuttings then proceeds through annular space 532 to Cross-Over 524. Thereafter, dirty mud with cuttings proceed to the surface through the interior of the drill pipe 534 to mud swivel assembly 542. Then dirty mud proceeds through pipe 538 to the return mud pit 540.
  • Element 544 is also called equivalently an elevator link assembly.
  • element 542 is instead a top drive that is supported by the derrick (not shown) and the traveling hook link assembly 544.
  • Figure 11 shows a closed- loop mud system. All the elements in Figure 10 also appear in Figure 11.
  • dirty mud recycle line 546 in Figure 11 has valve 548 that in another optional preferred embodiment, provides a quantity of dirty mud R to input line 550 having valve 552 of the dirty mud cleaning apparatus 554.
  • the dirty mud cleaning apparatus 554 processes the mud so that it can be sent downhole again - ie, it is recycled.
  • the recycled mud proceeds through line 556 having valve 558 and flows through orifice 560 into the clean mud tank 502.
  • Any mud lost into formation, or otherwise lost, will be determined and measured by the volume in clean mud tank 502 as indicated in one embodiment by drilling mud level 504.
  • Figure 12 shows the measurements performed and the feedback control of the drilling system shown in Figure 10. This is just one particularly simple preferred embodiment of the invention.
  • Instrumentation package 528 possesses pressure sensor package S528 that includes a pressure measurement device measuring the pressure P528 (the pressure of the borehole fluid at that location). Instrumentation package (528) also possesses a data transmission device T528, and in this preferred embodiment, this is a mud pressure encoded transducer that sends data corresponding to P528 up the mud column towards the surface. In one embodiment, this mud pulse encoder is battery powered. In another embodiment, the battery is re-charged by a generator which obtains its energy from the mud flow.
  • Instrumentation package 562 possesses sensor package S562 that includes mud pulse receiver R562 that sends electrical signals over wire 564 to computer 566.
  • Computer 566 therefore obtains information that is interpreted to be the Pressure 528.
  • the technique desired is MPD. Therefore, the P528 must be kept within a Drilling Window between the Fracture Pressure and the Pore Pressure. This will be called the Acceptable Drilling Pressure Range for P528.
  • PR for "Pressure Range” on Figure 12.
  • the pressure is kept constant at the bit, and this variant is called "Constant Pressure Drilling".
  • Instrumentation package 568 possesses sensor package S568 that pressure sensor P568 and this sensor sends information over wire W568 to computer 566.
  • the pressure P568 should provide adequate mud flow through the Leaky Seal to provide force F2 and to provide pressure P528 within the Acceptable Drilling Range.
  • valve 572 there is a short stab of threaded drill pipe 570 that connects into the top most drill pipe in the well. It has valve 572 in it. When a new section of pipe needs to be added, valve 572 is closed. However, if the pressure P568 is NOT increased, then it is possible to have a blow-out situation. So, as the flow is decreased with valve 572, then the computer issues commands through wire 574 to mud pump 508 to increase the pressure of its output even though the fluid flow is dropping. This closed-loop feedback control is used to keep pressure P528 equal to a selected constant (within the Drilling Window) during all phases of drilling.
  • This closed-loop feedback control is also used to maintain the pressure P528 within acceptable limits if the mud is a Newtonian fluid, or a Bingham plastic fluid, or any other wellbore fluid. In certain preferred embodiments, this is done by requiring the computer 566 issue commands to mud pump 508 to continually adjust and update the pressure instant by instant to maintain the desired flow rate and to maintain the pressure at the bit within the Drilling Window.
  • the computer 566 controls the mud pump 508, and the mud pump 508 is able to control its output pressure as a first independent parameter at any instant in time, and its mud flow rate as a second independent parameter at any instant in time.
  • This is one example of a closed-loop feedback control system. Many different embodiments employ closed-loop feedback control.
  • the computer 566 is also used to control the entire process to recalculate dirty mud as shown in Figure 11. However, it is evident from this description how that can be done with additional instrumentation packages, selected sensors including pressure sensors, etc.
  • Rotary Control Device is used in the SPE 122281 about MPD on page 2 and in Reelwell's SPE 12489 about MPD among other topics. That Annular Rotary Control Device seals against the rotating drill pipe 578.
  • Annular blow-out prevention device generally shown as 582 is comprised of a check valve assembly 584.
  • the check valve assembly 584 possesses spring 586, ball 588, seat 590 and tube 592. Mud pumped by the mud pump into the annulus forces the ball downward, and mud flows into the annulus. In a blow-out situation, pressure builds up in the annulus, and the ball is forced against the seat cutting off potentially dangerous reverse annular fluid flow.
  • Figure 14 shows a typical BOP installed with an embodiment of the invention.
  • Large conductor pipe 598 is installed within the earth 600 and firmly anchored in place with cement 602.
  • the Rotating Control Device 604 is installed within casing 606.
  • the Rotating Control Device 604 is located below Blow Out Preventer Assembly 608 having many typical components 610 that include shear rams, ram preventers on the bottom and annular preventers at the top. Multiple BOP's are often used. In Schlumberger's definition of "BOP stack”, it says:
  • the BOP stack also includes various spools, adapters, and piping outlets to permit the circulation of wellbore fluids under pressure in the event of a well control incident".
  • Various embodiments of the invention use those components.
  • the Rotating Control Device 204 may be located above the Rotating Control Device 204
  • Cross-Over 616 is shown in Figure 3D.
  • check valve 618 is used to prevent high pressure fluids from running in the reverse direction up the inside of the drill pipe in a blowout situation.
  • similar check valves may be installed within channels of the Cross-Overs, in passageways through Leaky Seals, and in other portions of the downhole apparatus.
  • the check valve 618 may function as a cooperative portion of the interaction between a Leaky Seal and a Cross-Over to generate extra WOB.
  • Any check valve 618 in a clean mud flow path 619 (not shown in Figure 15) used in combination with any Leaky Seal is an embodiment of this invention.
  • Any flapper valve in a clean mud flow path used in combination with any Leaky Seal is an embodiment of this invention.
  • Any float valve, normally used for cementing purposes, used in a clean mud flow path is an embodiment of this invention.
  • Darts and balls which are often used with downhole apparatus for a variety of different purposes. Any darts and/or balls used in a clean mud flow path in combination with a Leaky Seal is also an embodiment of the invention. Many such configurations are shown in drawings that are in U.S.
  • Any hydraulic device, or hydraulic means, that is inserted into any clean mud flow path possessing a Leaky Seal is an embodiment of the invention. Provided that inserted hydraulic means does not dissipated significant power compared to that dissipated by the Leaky Seal, then the Leaky Seal will normally operate in
  • This Extra Back Pressure can be useful to prevent blow-outs and for other purposes. That being said, there are a number of ways to overcome the Extra Back Pressure including using lower density drilling mud; using a downhole hydraulic pump that is useful for Underbalanced Drilling ("UBD"); increasing the size of the drill pipe; etc.
  • UBD Underbalanced Drilling
  • FIG. 11 A Many of the numerals in Figure 11 A have already been defined.
  • Previously defined rotating drill pipe (514) proceeds through annular seal (516) which is rigidly mounted to the wall of the casing in one embodiment.
  • Leaky Seal 522 and Cross- Over 524 have already been defined.
  • Cross-Over 524 may also be callused the "First Cross-Over”.
  • Distances between each element in Figure 11A may be defined as L(516 to 702); L(702 to 704); L (704 to 522); L(522 to 524); and L(524 to 528); and DL(528 to 530).
  • L means the length between the two elements cited within the parentheses.
  • the Torque SubTM adds torque for drilling purposes by a hydraulic means.
  • the Torque Sub 710 adds torque to downhole pipe section 712. Downhole pipe section 712 is able to turn in relation to uphole pipe section 713. First portion 714 of The Torque Sub is temporarily locked in place within the casing 716 by locking dogs 718. Clean pressurized mud flow down annulus 720 enters The Torque Sub 710 that has an interior hydraulic motor means that rotates second portion 722 of The Torque Sub that in turn causes the downhole pipe section 712 to rotate.
  • An example of a hydraulic motor means 726 is any type of positive displacement motor 728 that fits into the available space 730 (which numerals 726, 728 and 730 are not shown for the purposes of simplicity).
  • the mud flow rate 732 and the pressure drop 734 are related to the power 736 delivered to The Torque Sub (which numerals 732, 734, and 736 are not shown for the purposes of simplicity).
  • Seal 724 prevents the pressurized clean mud from bypassing The Torque Sub.
  • Many detailed designs for The Torque Sub appear in several of the U.S. Provisional Patent Applications that are incorporated herein by reference. Many such embodiments possess a ratchet-device 738 to prevent back-spinning of the positive displacement motor, so that it rotate in only one direction 740 (which numerals 738 and 740 are not shown for the purposes of simplicity).
  • the Torque Sub and The Force Sub work together in one downhole drilling machine for drilling purposes.
  • the Torque Sub and the normal Leaky Seal with Cross-Over are used together for drilling purposes.
  • annular portions of the apparatus can be described as follows: first annular potion 932, second annular portion 934, third annular portion 936, fourth annular portion 938, and fifth annular portion 940 which ends at the face of the rock bit engaging the formation 944.
  • interior tubular portions can be described as follows: first interior tubular portion 952, second interior tubular portion 954, third interior tubular portion 956, fourth interior tubular portion, fifth interior tubular portion 958, sixth interior tubular portion 960, seventh interior portion 962, seventh interior portion 964 (on the interior of the drill bit), that ends at the face of the rock bit engaging the formation 944.
  • any machine may be similarly labeled commencing with a the location of a particular numeral.
  • the labeling goes from the uphole side going downhole in this system of enumerating apparatus portions.
  • Figure 16 shows a downhole mud pump being powered by clean mud flow down the annulus that is useful for Underbalanced Drilling and other uses. Another description for this apparatus is a mud motor driven downhole progressing cavity pump.
  • Figure 16 shows cased well 742 having casing 744, cement 746, which are in borehole 748.
  • Cross-Overs X01, X02, and X03 are integral with mandrel 750.
  • Clean mud flow from the surface 752 (designated by the legend C in Figure 16) is used to turn shaft 754 of mud motor section 756 that eventually turns the drill bit.
  • the stator of the motor section 755 is not shown in the drawing for the purposes of simplicity.
  • the attached drill bit 757 is not shown in Figure 16 for the purposes of simplicity nor is the coupling apparatus 781 that connects the rotating shaft 754 to the drill bit.
  • the rotating metal shaft 754 of the mud motor extends into another stator housing 774 of a downhole progressing cavity pump 758.
  • this portion 759 of the metal shaft within the progressing cavity pump is different than the portion of the metal shaft 753 within the mud motor.
  • This pump 758 is used to pump dirty mud 760 to the surface to establish underbalanced drilling conditions.
  • the dirty mud 760 is also designated by the legend DM in Figure 16.
  • This device consumes horsepower. It is a Horsepower Dissipating Device ("HDD") designated by numeral 770, although that is not shown in Figure 16 for the purposes of simplicity. Because mud flows through it, and its operation results in a pressure drop 772 to the mud flowing downhole in the annulus, there is necessarily a force 764 imparted to the entire apparatus that adds weight on bit 766. The numerals 764, 766, and 772 are not shown in Figure 16 in the interests of brevity.
  • One embodiment of the invention may be described as a mud-motor driven progressing cavity pump designated by the numeral 768 in Figure 16.
  • Annular Pressure Tractor & ShuttleTM 872 which is generally shown in Figure 16A. This is also called a
  • Conveyance System 873 or simply a Shuttle 873 for the purposes herein, which numerals are not shown in the interest of brevity.
  • the mud-motor driven progressing cavity pump 768 is a portion of this Shuttle 872.
  • a logging tool 876 (not shown) attached to Retrieval Sub 878 to measure formation parameters of geological formation 879.
  • the Retrieval Sub 878 and the many devices for drilling, completion, workover and abandonment that are attached to that Retrieval Sub are described in U.S. Patent No. 7,836,950 and in U.S.
  • the casing 880 has perforations 882 and production fluids 884 are entering the cased wellbore.
  • Pressurized clean fluids 886 are pressurized in the upper annulus 887 by surface pumps 889 (that are not shown).
  • the pressurized clean fluids are designated by the legend C in Figure 16A.
  • the pressurized fluids are water.
  • treated wellbore fluids are recalculated.
  • Those pressurized clean fluids 886 cause the motor section 888 to turn the shaft 889 which is a portion of the progressing cavity pump section 890 as explained in Figure 16.
  • the pressurized clean fluids 886 are used to deliver power to the progressing cavity pump section 890, and are eventually exhausted into the interior of the cased well at position 892 through hole 894 in tool mandrel 895.
  • FIG 16A A portion of the clean fluids 896 exhausting into the interior of the casing are shown in Figure 16A.
  • Those clean fluids 896 are co-mingled with production fluids 884, which flow through channel 898 of roller-locking mechanism 900 that become the dirty fluids 902 designated by the legend DF.
  • Those dirty fluids are pumped uphole by the progressing cavity pump section 890 through the interior portion 903 of the upper mandrel assembly 904 and the fluids are then sent uphole through the interior of tubular 906 to the surface 908.
  • numerals 906 and 908 are not shown for the purposes of simplicity.
  • the tubular 906 is chosen to be a coiled tubing suspended by a coiled tubing rig 910 (not shown in Figure 16A) located on the surface 908 (not shown in Figure 16A).
  • Computers 912, sensor systems 914, and closed-loop feedback control system 916 prevent any "reverse fluid flow” 918 in the reverse direction 920 through hole 882 into geological formation 879 during any transit into or out of the wellbore by Conveyance System 872.
  • Numerals 912, 914, 916, 918, and 920 are not shown in Figure 16A for the purposes of brevity. These components and systems also prevent any "fluid lock-up" in the event the well is sealed, having no perforations, and is full of fluids during the transit of Conveyance System 872 into or out of the well.
  • FIG 17 shows other Horsepower Dissipating Devices ("HPDD") may be used in various embodiments of the invention.
  • HPDD Horsepower Dissipating Devices
  • Such devices include mud motors, restrictions to flow, etc.
  • Figure 17 shows several cross-overs X01, X02, and X03, Leaky Seals LSI and LS2, and first Horsepower Dissipating Device HPDD1 and Second Horsepower Dissipating Device HPDD2.
  • a sequence of such devices will result in a force on such a device when clean mud is passed through the horsepower dissipating devices which will place additional weight on bit (“WOB").
  • the apparatus shown in Figure 17 may be called a Horsepower Dissipating Assembly 782 having one or more Cross-Overs and one or more Leaky Seals. Any device extracting power from the mud flow is called a Horsepower Dissipating Device 784 having a volume of mud per second flowing through it 786, that generates a pressure differential 788 from a first side 789 to a second side 790 of the device, said numerals 784, 786, 788, 789 and 790 are not shown in Figure 17 for the purposes of brevity.
  • Universal Completion Machine 792 is disposed in the first downhole section of wellbore 794 that is cased well having casing 796, surrounded by cement 798 which are located within the first borehole 800. That first downhole section of wellbore 794 is designated with numeral 795.
  • the second downhole section of wellbore 794 is the open-hole section 802 previously drilled to a maximum lateral distance 804.
  • the first tubular portion of the Universal Completion Machine 792 is comprised of mandrel 808 supporting the Leaky Seal 810 that is, in turn, joined to mandrel 812 that is integral with the Cross-Over 814.
  • the second tubular portion of Universal Completion Machine 794 is a drill string 816 comprised of one or more segmented drill pipes attached to the Completion Bottom Hole Assembly 818.
  • the Completion Bottom Hole Assembly 818 has various components including the liner hanger 820, the liner engagement tool 822, the well completion control and communication unit 824, optionally added electronics 826, and the liner 828.
  • the Completion Bottom Hole Assembly may also be abbreviated as "CBHA”.
  • the third tubular portion of Universal Completion Machine 792 are sections of drill pipe 830 attached to surface hoist equipment 832 (neither numerals 830 nor 832 are shown in Figure 18 in the interests of brevity).
  • the downward pointing arrow 834 shows clean mud being forced downhole by one or more surface mud pumps.
  • the upward pointing arrow 836 shows recirculating mud going uphole.
  • the numeral 837 designates the entire mud flow path, although that is not shown in Figure 18 in the interests of brevity.
  • High pressure and high flow rate mud from the surface mud pump generates a large force 838 on the Completion Bottom Hole Assembly 818 to help convey that assembly into place.
  • the liner 828 is placed into the proper position in the well, and then the Universal Completion Machine 792 is retrieved to the surface.
  • Element 304 in Figure 3D shows a first annular portion of a cased wellbore in that figure, and a similar annular space exists in Figure 18 that shall be designated by the same numeral.
  • a Leaky Seal and Cross-Over on a set of mandrels screwed into an existing threaded set of drill pipes can be used to generate a large force on a liner to be conveyed downhole.
  • Well Completion is defined in Schlumberger's on-line Oilfield Glossary as follows:
  • Specific completion steps that can be done with various embodiments of the Universal Completion Machine include, but are not limited to, the following: running in a tubular so that cement can be pumped into the wellbore; running in perforation guns and perforating; conveying production tubing downhole to land in a liner; and conveying downhole any tubular means attached to any Completion Bottom Hole Assembly in wellbore having any portion that has casing.
  • This invention allows mud circulation AND the application of an extra force while forcing the liner down.
  • the circulating mud helps to maintain borehole stability and assists to maintain pressure control of the well.
  • Figure 19 shows another embodiment of the Universal Completion Machine.
  • a liner is being conveyed downhole.
  • the direction of mud flow 854 has been reversed in the open hole region and elsewhere.
  • only one Leaky Seal 856 on its mandrel 858 comprises the first tubular portion 860 of the Universal Completion Machine.
  • only one Leaky Seal is in the mud flow path 862. Otherwise, the components are similar to those shown in Figure 18.
  • Figure 20 provides a copy of Fig. 1 from WO 94/13925 having the inventor of Ola
  • Pipe 9 provides annular pressure that generates a hydraulic force on piston 5 that in turn contributes to weight on bit.
  • clean mud is pumped down drill string 4, and dirty mud with rock cuttings returns to the surface via return line 6.
  • the elements 4 and 6 described here have been functionally implemented within the Dual Drill String of the Reelwell Drilling
  • Fig. 1 of this patent the annulus is used to provide hydraulic pressure on the piston 5, but does not use downward flowing mud within an annulus for multiple purposes.
  • Each Leaky Seal may have one fluid passageway within the body of the Leaky Seal. Each Leaky Seal may have two fluid passageways in the body of the Leaky Seal. Each Leaky Seal may have two or more fluid passageways through the body of the Leaky Seal. All of these variations are embodiments of the invention.
  • two Leaky Seals may be used in parallel in different geometric arrangements, which are embodiments of the invention.
  • the Universal Drilling and Completion SystemTM is comprised of the Universal
  • UDCSTM is the trademarked abbreviation for the Universal Drilling and Completion System.
  • UDMTM is the trademarked abbreviation for the Universal Drilling MachineTM.
  • UCMTM is the trademarked abbreviation for the Universal Completion MachineTM.
  • the Leaky SealTM, The Force SubTM and The Torque SubTM are used in various embodiments of these systems and machines.
  • US7350410 entitled “System and method for measurements of depth and velocity of instrumentation within a wellbore”
  • US7334650 entitled “Apparatus and methods for drilling a wellbore using casing”
  • US7325610 entitled “Methods and apparatus for handling and drilling with tubulars or casing”
  • US7313480 entitled “Integrated drilling dynamics system”
  • US7311148 entitled “Methods and apparatus for wellbore construction and completion”
  • US7303022 entitled “Wired casing”
  • US7301338 entitled “Automatic adjustment of NMR pulse sequence to optimize SNR based on real time analysis”
  • US7287605 entitled “Steerable drilling apparatus having a differential displacement side-force exerting mechanism”
  • US7284617 entitled
  • the present invention provides a closed-loop drilling system for drilling oilfield boreholes.
  • the system includes a drilling assembly with a drill bit, a plurality of sensors for providing signals relating to parameters relating to the drilling assembly, borehole, and formations around the drilling assembly.
  • Processors in the drilling system process sensors signal and compute drilling parameters based on models and programmed instructions provided to the drilling system that will yield further drilling at enhanced drilling rates and with extended drilling assembly life.
  • the drilling system then automatically adjusts the drilling parameters for continued drilling.
  • the system continually or periodically repeats this process during the drilling operations.
  • the drilling system also provides severity of certain dysfunctions to the operator and a means for simulating the drilling assembly behavior prior to effecting changes in the drilling parameters.”
  • An automated drilling system for drilling oilfield wellbores at enhanced rates of penetration and with extended life of drilling assembly comprising: (a) a tubing adapted to extend from the surface into the wellbore; (b) a drilling assembly comprising a drill bit at an end thereof and a plurality of sensors for detecting selected drilling parameters and generating data representative of said drilling parameters; (c) a computer comprising at least one processor for receiving signals representative of said data; (d) a force application device for applying a predetermined force on the drill bit within a range of forces; (e) a force controller for controlling the operation of the force application device to apply the predetermined force; (f) a source of drilling fluid under pressure at the surface for supplying a drilling fluid (g) a fluid controller for controlling the operation of the fluid source to supply a desired predetermined pressure and flow rate of the drilling fluid; (h) a rotator for rotating the bit at a predetermined speed of rotation within a range

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)

Abstract

L'invention concerne des procédés et des appareils utilisés pour le forage et la complétion de puits de forage. Ces puits de forage comprennent des puits de forages horizontaux de portée accrue, par exemple dans les schistes, des puits de forage sous-marins profonds de portée accrue, et des puits de forage multilatéraux. Plus précisément, l'invention concerne des sous-ensembles filetés simples qui sont ajoutés à l'équipement de forage et de complétion tubulaire fileté existant, qui sont utilisés afin d'augmenter considérablement la portée latérale en utilisant l'équipement existant sur site. Ces sous-ensembles extraient la puissance de la boue propre, ou d'autres fluides, s'écoulant vers le bas dans un espace annulaire afin de fournir une force ou un couple supplémentaire sur les éléments tubulaires dans le puits de forage tout en maintenant la circulation, ceci afin d'étendre la portée latérale de l'équipement de forage et de l'équipement de complétion. Ces éléments ajoutés comprennent des combinaisons de Leaky Seal™, de pont, de The Force Sub™ et de The Torque Sub™. L'utilisation de ces éléments simples supplémentaires permet d'utiliser un équipement de forage plus léger pour atteindre une distance latérale voulue, ce qui réduit les coûts de forage.
PCT/US2011/035496 2010-05-06 2011-05-06 Système de forage et de complétion universel WO2011140426A1 (fr)

Applications Claiming Priority (40)

Application Number Priority Date Filing Date Title
US39508110P 2010-05-06 2010-05-06
US61/395,081 2010-05-06
US39603010P 2010-05-19 2010-05-19
US61/396,030 2010-05-19
US39642010P 2010-05-25 2010-05-25
US61/396,420 2010-05-25
US39694010P 2010-06-05 2010-06-05
US61/396,940 2010-06-05
US39784810P 2010-06-16 2010-06-16
US61/397,848 2010-06-16
US39911010P 2010-07-06 2010-07-06
US61/399,110 2010-07-06
US39993810P 2010-07-20 2010-07-20
US61/399,938 2010-07-20
US40197410P 2010-08-19 2010-08-19
US61/401,974 2010-08-19
US40497010P 2010-10-12 2010-10-12
US61/404,970 2010-10-12
US45512310P 2010-10-13 2010-10-13
US61/455,123 2010-10-13
US45698610P 2010-11-15 2010-11-15
US61/456,986 2010-11-15
US45840310P 2010-11-22 2010-11-22
US61/458,403 2010-11-22
US45849010P 2010-11-24 2010-11-24
US61/458,490 2010-11-24
US201061459896P 2010-12-20 2010-12-20
US61/459,896 2010-12-20
US201061460053P 2010-12-23 2010-12-23
US61/460,053 2010-12-23
US201161461266P 2011-01-14 2011-01-14
US61/461,266 2011-01-14
US201161462393P 2011-02-02 2011-02-02
US61/462,393 2011-02-02
US201161465608P 2011-03-22 2011-03-22
US61/465,608 2011-03-22
US201161517218P 2011-04-15 2011-04-15
US61/517,218 2011-04-15
US13/068,133 2011-05-02
US13/068,133 US9027673B2 (en) 2009-08-13 2011-05-02 Universal drilling and completion system

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US9027673B2 (en) 2009-08-13 2015-05-12 Smart Drilling And Completion, Inc. Universal drilling and completion system
US9051781B2 (en) 2009-08-13 2015-06-09 Smart Drilling And Completion, Inc. Mud motor assembly
EP2872726A4 (fr) * 2012-07-13 2016-08-17 Halliburton Energy Services Inc Système de poussée à piston de tube dans tube
US9587435B2 (en) 2001-08-19 2017-03-07 Smart Drilling And Completion, Inc. Universal drilling and completion system
US9745799B2 (en) 2001-08-19 2017-08-29 Smart Drilling And Completion, Inc. Mud motor assembly
US10174572B2 (en) 2009-08-13 2019-01-08 Smart Drilling And Completion, Inc. Universal drilling and completion system
CN110344757A (zh) * 2019-07-29 2019-10-18 四川轻化工大学 一种反循环钻井系统及反循环钻井方法
CN110344772A (zh) * 2019-07-29 2019-10-18 四川轻化工大学 一种反循环钻井循环通道切换短节
WO2021108301A1 (fr) * 2019-11-25 2021-06-03 Ulterra Drilling Technologies, L.P. Outil de vibration de fond de trou pour train de tiges de forage

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US9587435B2 (en) 2001-08-19 2017-03-07 Smart Drilling And Completion, Inc. Universal drilling and completion system
US9745799B2 (en) 2001-08-19 2017-08-29 Smart Drilling And Completion, Inc. Mud motor assembly
US10174572B2 (en) 2009-08-13 2019-01-08 Smart Drilling And Completion, Inc. Universal drilling and completion system
US9051781B2 (en) 2009-08-13 2015-06-09 Smart Drilling And Completion, Inc. Mud motor assembly
US9027673B2 (en) 2009-08-13 2015-05-12 Smart Drilling And Completion, Inc. Universal drilling and completion system
US10689927B2 (en) 2009-08-13 2020-06-23 Smart Drilling And Completion, Inc. Universal drilling and completion system
EP2872726A4 (fr) * 2012-07-13 2016-08-17 Halliburton Energy Services Inc Système de poussée à piston de tube dans tube
US9670748B2 (en) 2012-07-13 2017-06-06 Halliburton Energy Services, Inc Pipe in pipe piston thrust system
CN110344757A (zh) * 2019-07-29 2019-10-18 四川轻化工大学 一种反循环钻井系统及反循环钻井方法
CN110344772A (zh) * 2019-07-29 2019-10-18 四川轻化工大学 一种反循环钻井循环通道切换短节
CN110344772B (zh) * 2019-07-29 2020-09-01 四川轻化工大学 一种反循环钻井循环通道切换短节
CN110344757B (zh) * 2019-07-29 2020-09-11 四川轻化工大学 一种反循环钻井系统及反循环钻井方法
WO2021108301A1 (fr) * 2019-11-25 2021-06-03 Ulterra Drilling Technologies, L.P. Outil de vibration de fond de trou pour train de tiges de forage

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