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WO2011071586A1 - Système et procédé de forage d'un puits qui s'étend sur une grande distance horizontale - Google Patents

Système et procédé de forage d'un puits qui s'étend sur une grande distance horizontale Download PDF

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Publication number
WO2011071586A1
WO2011071586A1 PCT/US2010/050534 US2010050534W WO2011071586A1 WO 2011071586 A1 WO2011071586 A1 WO 2011071586A1 US 2010050534 W US2010050534 W US 2010050534W WO 2011071586 A1 WO2011071586 A1 WO 2011071586A1
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WO
WIPO (PCT)
Prior art keywords
well
drilling
horizontal tubular
pump
port
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/US2010/050534
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English (en)
Inventor
Stuart R. Keller
Adel H. Younan
Mark C. Gentry
Timothy J. Nedwed
Bruce A. Dale
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ExxonMobil Upstream Research Co
Original Assignee
ExxonMobil Upstream Research Co
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
Application filed by ExxonMobil Upstream Research Co filed Critical ExxonMobil Upstream Research Co
Priority to US13/505,217 priority Critical patent/US9163465B2/en
Priority to RU2012153778/03A priority patent/RU2012153778A/ru
Priority to US13/642,084 priority patent/US20130037272A1/en
Priority to CA2798806A priority patent/CA2798806A1/fr
Priority to PCT/US2011/035202 priority patent/WO2011143034A1/fr
Publication of WO2011071586A1 publication Critical patent/WO2011071586A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/001—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor specially adapted for underwater drilling
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/12—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using drilling pipes with plural fluid passages, e.g. closed circulation systems

Definitions

  • the present invention relates to drilling wells that extend for a large horizontal distance between the surface location of the well and the bottom portion of the well. More particularly, apparatus and method are provided for decreasing the pressure of drilling fluid at the bottom of the hole as the well is drilled to the large horizontal distance and to facilitate extended horizontal reach between the location of a drilling or other vessel/facility and a subsea wellbore.
  • Extended Reach Drilling often reduces field development costs for hydrocarbons because it allows remote reserves to be accessed from a surface location that allows a lower-cost drilling unit to be used than would be required to drill a vertical well to the hydrocarbon reservoir.
  • a significant portion of the Chayvo field in Russia has been developed using a land-based rig to drill more than 15 10-km-throw wells ("throw" is the horizontal distance from surface to bottom-hole location) rather than drilling from a more costly offshore Arctic drilling platform.
  • the current reach (throw) record of a well is about 12 km, but 15-km-reach wells are reportedly being planned. There is a growing need to dramatically increase the reach capability for ERD even beyond 15 km.
  • Torque and drag can be reduced by rotating the drill string, using lighter- weight materials for the tubulars, floating-in casing and liners, adding lubricants in the surrounding fluid and/or using mechanical devices (e.g., roller centralizers).
  • mechanical devices e.g., roller centralizers.
  • delta ECD The limiting parameter in drilling many ERD wells is “delta ECD.”
  • the pressure outside the bit required to flow the mud back to the surface is called “Equivalent Circulating Density” (ECD).
  • ECD Equivalent Circulating Density
  • delta ECD is caused by fluid frictional pressure.
  • the delta ECD in some ERD wells while drilling 8-1/2-inch hole through 9 km of 9-5/8-inch casing was measured at about 4 ppg (pounds per gallon).
  • a 30-km well would have more than 12 ppg in delta ECD, which is unacceptably high. If the ECD is too high, the well will lose returns and cuttings will build up, eventually causing the Bottom Hole Assembly (BHA) to become stuck. This is a costly problem that typically would cause the well to be abandoned.
  • the ECD issue can be mitigated by using liners, but typically the liners would have to be set in a full casing string (typically 13-3/8-inch OD) that could withstand kick pressures. The reduced ID of the full casing string compared to the conductor means that ECD would likely still be a major problem.
  • MPD Managed Pressure Drilling
  • At least one service company has performed research on a downhole annular mud pump that is incorporated into the drill string, which is described in "A Downhole Tool for Reducing ECD," Amer. Association of Drilling Engineers, AADE-07-NTCE-69 (2007).
  • the pump takes suction from the mud below the pump and pumps the annular fluid above the pump to the surface. This reduces the pressure seen by the formation at total depth (TD).
  • the idea of using a pump to reduce the pressure at TD has merit, but incorporating a pump into the drill string is fraught with problems. First, when pulling upwards, the pump may create a swab pressure that may induce wellbore instability or formation fluid influx.
  • the pump represents a potential hazard to well control because it cannot be easily stripped through the blowout preventers.
  • the current design uses the downward fluid flow as an energy source to drive the pump, and this saps horsepower from the rig pumps.
  • the pump must be placed inside casing and has rotating seals that are a prime failure point.
  • suspended pump systems examples include the Ocean Riser Drilling System discussed by Fossli (SPE 91633).
  • DGD methods include injecting a lightweight fluid (sometimes containing hollow beads) into the drilling riser above the blowout preventer (BOP) (e.g., SPE 99135).
  • BOP blowout preventer
  • SPE 99135 blowout preventer
  • the DGD systems can lower the bottomhole pressure and ECD by lowering pressure at the mudline, but the bottomhole pressure will still be affected by the long interval (measured depth) below the mudline in ERD wells, i.e., by the annular frictional pressure losses from the bottom of the borehole to the mudline.
  • Previously known technology may relegate vessel or facility locations to areas that are subject to sea ice, especially icebergs, that limit arctic well operations to intermittent or seasonal activities.
  • the present invention discloses apparatus and method for avoiding high pressure- losses that occur in the drilling mud flowing back to surface in a well drilled a long horizontal distance through the earth (an "Extended Reach Well”).
  • a "horizontal tubular" is installed from a drilling rig to a selected location in the direction that an Extended Reach Well is to be drilled.
  • the horizontal tubular can be used for conveying the drill bit and drill string to the selected location, which will be selected to be nearer the desired bottom hole location than the drilling rig.
  • a mud return line and pump may be installed outside the horizontal tubular for bringing drilling mud back to the surface, preferably alongside the horizontal tubular.
  • the mud return line may be connected to the horizontal tubular through a port near the distal end of the tubular.
  • One or more wells may be directionally drilled from the distal end of the tubular.
  • a first casing string having a port, is placed in the well.
  • Drilling fluid may then flow from inside the first casing string to the mud return line through the ports in the casing string and in the horizontal tubular.
  • the horizontal tubular preferably extends across the majority of the horizontal displacement or throw of the well. Control of the pump in the mud return line allows pressure to be controlled at the port in the first casing.
  • Other sections of the well may then be drilled by successfully drilling and cementing liners in the drilled sections.
  • two tubulars may extend from a structure having two drilling rigs, along with two pumps and mud return lines outside the tubulars. Such installation may be used for drilling relief wells from the structure in addition to the primary well.
  • the lower sections of an offshore well may be drilled after upper sections have been drilled using another drilling rig, which may be on an offshore vessel.
  • a sacrificial inner string which may be replaceable, is placed at selected locations in a casing to prevent excessive wear during drilling.
  • FIG 1 a illustrates a horizontal tubular at the mudline (e.g., seafloor) to be used for Extended Reach Drilling (ERD) of an offshore well from a platform drilling rig.
  • FIG. 1 b illustrates a horizontal tubular at the mudline to be used for extended reach drilling of an offshore well from a slant rig onshore or on an island.
  • ERP Extended Reach Drilling
  • FIG 2a illustrates drilling of a first hole below a horizontal tubular after installation of a mud return line and pump.
  • FIG. 2b illustrates one embodiment of a well after placement of a first casing string through the horizontal tubular and into the first hole, drilled to a first intermediate depth, and a mud return line and pump.
  • FIG. 3 illustrates one embodiment of the well after placement of a liner string in a second hole, drilled to a second intermediate depth.
  • FIG. 4 illustrates an embodiment for drilling a relief well using a second platform drilling rig and two horizontal tubulars for ERD from a single platform.
  • FIG. 5 illustrates an embodiment for drilling multiple wells through the same horizontal tubular.
  • FIG. 6 illustrates one embodiment including sacrificial inner strings in the casing at selected locations.
  • FIG. 7 illustrates a well having a vertical access tree, the well providing intervention access from a horizontal tubular conductor located above the mudline to an access point with the well at or near the mudline.
  • Fig. 8 illustrates a well having a vertical access tree, the well facilitating intervention from a second point of entry into the well significantly below the mudline, joining a horizontal tubular conductor.
  • FIG. 1 a illustrates horizontal tubular 10 placed at the mudline 12 under a body of water 11 and brought to a vertical direction at drilling rig 14.
  • the horizontal tubular may be assembled onshore and towed to the location or installed using a pipeline installation barge or other pipeline installation techniques well known in industry.
  • a horizontal tubular is a tubular structure that is oriented primarily or substantially in a horizontal direction and that may arc vertical or bend at an intermediate angle at each end, and/or along the length of the tubular.
  • horizontal tubular is defined broadly herein to mean a tubular body that is oriented not only along a seafloor and that is substantially parallel with the water surface or seafloor, but also includes following a path having horizontal displacement and at an angle with respect to the water surface, the angle being in a range of from substantially zero (0) degrees with respect to the water surface (e.g., substantially parallel with the water surface) to forty-five (45) degrees with respect to the water surface.
  • orientations thus include tubular positions that are disposed on or near the seafloor and including orientation angles that may follow or diverge from the sea floor, such as angles of up to forty-five (45) degrees with respect to the water surface.
  • the horizontal tubular is disposed below the water surface (e.g., subsea, commonly on or along the sea floor or mudline).
  • a common use of horizontal tubulars in industry is as a pipeline, to convey fluids between points spaced apart on or near the surface of the earth, including points under water.
  • the curvature in horizontal tubular 10 where it turns from vertical to horizontal is preferably limited to minimize torque and drag as a drillstring or casing strings pass through the curved portion. If the proximal end of the horizontal tubular is on an offshore rig, the horizontal tubular can be brought to the rig drilling floor using a catenary drilling riser. Conventional tow or J-lay or S-lay technology can be used.
  • Horizontal tubular 10, having port 22 preferably extends horizontally from rig 14 in the direction of the desired location of the bottom of a wellbore.
  • the horizontal tubular is shown at the mudline, it can be placed below the mudline by forming a trench (not shown) before laying the horizontal tubular.
  • the depth of a trench can be selected to allow the horizontal tubular to be below the zone that could be affected by gouging of ice into the seafloor 12.
  • the horizontal tubular may also be near ground level on land.
  • the length of the horizontal tubular can be selected to reach a location such that a well can be drilled using a drill string exiting the end of the horizontal tubular to reach a desired target location in the earth.
  • the length of the horizontal tubular may be, for example, in the range from about 15 km or less to about 60 km or more.
  • the measured depth (MD) of the well is 120 km and the throw is 60 km
  • the systems now in use in industry can only reduce the pressure from the last 12 km of the well annulus, while the system and method disclosed herein can reduce the pressure from almost 60 km of the well annulus.
  • the pump can be placed much closer to the bottom of an ERD well than with the approach now used in industry.
  • drilling or “drill” as used herein are defined broadly to include not only the activity of creating a bore or wellbore, but also includes substantially any related or subsequent activity performed within such well bore, including but not limited to drilling activities, completion activities, production activities, and remedial activities that are conducted at least in part through a horizontal tubular member positioned between a surface vessel and the wellbore.
  • vessel as used herein is defined broadly to also include not only displacement type drill vessels, but also facilities and platforms which may be rested upon a sea floor, an island or other inland or on-shore location.
  • FIG. 1 b illustrates a slant rig 15, which may be used to facilitate placement of a drillstring into horizontal tubular 10 from land 13 into the seafloor 12 for drilling under a body of water 11.
  • rig 15 may also be located on a floating rig, a shallow water platform, or land location.
  • a horizontal tubular 10 as disclosed herein can serve the purpose of the conductor casing that is normally used in wells. It can have an OD of 20 inches, for example, but other sizes may be used, and different sizes may be used in the same horizontal tubular.
  • the distal end of horizontal tubular 10 may be laid in sloping trench 16, which may be formed before installation of the horizontal tubular, to facilitate starting the drilled portion of the well.
  • Methods for constructing trenches in the sea floor are well known.
  • the wells would be constructed using drill stings, casing strings and liners run through the horizontal tubular or conductor.
  • the hydrocarbon can be produced through a tubing string run through the conductor and production casing and any other casing in the well or can be produced through a gathering pipeline installed separately.
  • Fig. 2a illustrates mud return line 20 along with pump 21 , which may be installed during horizontal tubular installation.
  • Horizontal tubular 10 includes a port with connectors 22, which may be releasable, for attaching return line 20 when horizontal tubular 10 is in place.
  • Pump 21 in return line 20 can be a progressive cavity pump (PCP).
  • PCPs are well suited for pumping mud and cuttings.
  • Other types of pumps, such as multi-disk pumps, can also be used.
  • Multi-disk subsea pumps for pumping drilling muds have been developed by AGR ASA of Norway for their riserless mud returns system.
  • Pump 21 can be driven by an electric motor or other power source.
  • Pump 21 can be controlled to have a flow rate less than or equal to the main rig mud pump.
  • the rate of pump 21 is manually or automatically controlled to maintain the pressure in tubulars below the pump in a selected range.
  • Pressure sensor 23 may be used to monitor pressure in return line 20. Such pressure may be used to control the rate of pump 21.
  • Flow meter 24 may be used to measure flow rate in return line 20.
  • Other sensors, such as fluid density and conductivity, may be placed in horizontal tubular 10 or return line 20.
  • FIG. 2a also illustrates first hole section 27 (typically 17-1/2-inch) that has been drilled using drill bit 25 on drillstring 26 through horizontal tubular 10 to a selected intermediate depth. Drilling fluid and cuttings may be partially or completely returned to surface through return line 20 while drilling of first hole section 27.
  • Rotating blowout preventer 26a can be used to isolate the top of the annulus outside drillstring 26 from the atmosphere.
  • casing 29 (e.g., 13-3/8-inch) has been run into first hole section 27 and cemented in place.
  • Casing 29 contains ports 29a and preferably packers 29b and 29c.
  • Casing 29 is placed in horizontal tubular 10 such that ports 29a are in fluid communication with return line 20 and are isolated from fluid above and below port 22 by packers 29b and 29c.
  • packers 29b and 29c Such packers may be a straddle packer and may be hydraulically set.
  • drillstring 24 and bit 25 have been used to drill a second hole section, which is below casing 29, to a second intermediate depth. Drilling fluid and cuttings would normally have been partially or completely returned to surface through ports 29a and return line 20 while drilling of the second hole section. Ports 29a can be opened or closed by operation of a sliding sleeve or valve 30. Liner 32 has been placed in the second hole section and cemented in place.
  • Drilling may use a specially designed drill string to minimize torque and drag.
  • the string may incorporate lightweight materials such as aluminum, titanium, composites, or thin-wall high yield strength steel (e.g., 165 ksi yield strength) to reduce side loads.
  • the drill string may use mechanical friction reduction devices that incorporate bearings. There are a variety of these devices on the market.
  • special drilling fluid formulations containing additives to reduce both mechanical and fluid flow friction may be used. These additives are well known to drilling practitioners.
  • All subsequent casings below casing 29 are preferably run as liners with a liner top packer set below port 29a in casing 29. This allows returns to be taken via pump 21 and mud return line 20 on all drilling intervals below casing 29 when port 29a is open.
  • the casing or liner strings can be cemented or the annulus outside the strings can be isolated by swell packers, which are well known in industry.
  • a kick is taken while drilling, the kick can be circulated out through pump 21 and mud return line 20 or casing 29.
  • Pump 21 should be built to withstand the highest kick pressure expected. Conventional mud motors, an analog to a PCP, are rated to high pressures similar to other drill string components.
  • Mud return line 20 should be attached to the necessary shut-off valves and kick manifold to enable the kick to be safely circulated out.
  • the packers 29b and 29c should be tested to ensure that they could withstand the highest anticipated differential pressures.
  • port 29a can be closed by valve 30 and the kick circulated out using the normal path (between the drill string and the 13-3/8- inch casing) and controlled using the conventional surface BOP equipment.
  • Apparatus and method described above are used for drilling and completing a single well.
  • One of the main concerns in any Arctic drilling situation is the ability to drill a relief well in the case of loss of well control on an initial well. This is often a key regulatory and company requirement. Typically, this necessitates reasonable access to a second drilling rig.
  • a similar approach was taken at the Hibernia Field, for example, where the relief well requirement was satisfied by having two rigs on a platform. Drilling a relief well can be very challenging in Arctic deepwater environments (where there are few qualified rigs) and it provides a further strain on the economics of Arctic development.
  • Horizontal tubular 33 may be used for drilling a first well to a selected bottom-hole location using drilling rig 34.
  • Horizontal tubular 36 may be installed before drilling the first well for use as a conductor for a possible relief well, if needed, to be drilled by rig 38.
  • the horizontal tubular drilling method disclosed herein can serve as the relief well capability for conventional floating drilling. To expedite relief well drilling, the relief well could be pre-drilled down to a predetermined depth to minimize the time to intersect the uncontrolled flow of another well.
  • FIG. 5 In another embodiment of apparatus and method disclosed herein, illustrated in FIG. 5, multiple wells are drilled sequentially through the same horizontal tubular.
  • Horizontal tubular 50 and a mud return line such as shown in FIG. 2a, may be laid from platform 54, having drilling rig 56 to a preferred location.
  • Selective whipstock 58 can be used to direct a drill string and casing strings in a selected direction when exiting horizontal tubular 50.
  • Whipstock 58 may be controlled electrically or hydraulically from the surface.
  • whipstock 58 After a first well 59a or portion of a first well is drilled, whipstock 58 can be operated to make possible drilling of a second well, 59b. Subsequent operation of whipstock 58 may then allow drilling of wells 59c, 59d or other wells.
  • sacrificial inner strings can be run to protect segments of a horizontal tubular conductor or casing, as illustrated in FIG. 6.
  • Segments 62, 64 and 66 have been placed in casing 60.
  • Segment 62 has been placed in the curved section near the proximal end of the casing, where it transitions from vertical to horizontal.
  • Segment 64 has been placed at an intermediate location where curvature has been measured in the casing.
  • Segment 66 has been placed near the distal end of the casing. These segments may be placed before the casing is put in place or they may be placed after the casing is in place using well-known techniques such as those used for casing patches. These inner segments may be removed prior to completing the well or may be replaced during drilling.
  • the upper section of offshore well 70 is partially drilled (e.g., the first one or two intervals) conventionally from floating drilling vessel 72, as illustrated in FIG. 7.
  • the lower section(s) then may be drilled using horizontal tubular drilling.
  • Well 70 has been drilled and cased to an intermediate depth.
  • Horizontal tubular 75 has also been placed along seafloor 79 from drilling rig 76 on platform 77.
  • a mud return line (not shown) as shown in FIG. 2a will also be installed before drilling of a lower section begins.
  • Simultaneous activities from vessel 72 and rig 76 can decrease the overall time for well construction due to the use of simultaneous operations (SIMOPS).
  • SIMOPS simultaneous operations
  • this method would allow a smaller-diameter (e.g., 9-5/8-inch) seafloor conductor and subsea wellhead to be used.
  • the smaller diameter conductor would typically have a higher pressure rating.
  • the risk associated with running multiple casing strings through the long horizontal tubular conductor would be decreased.
  • FIG. 8 A variation of the exemplary illustration of Fig. 7 is illustrated in exemplary Fig. 8, exhibiting joining horizontal tubular conductor 82 and well 86 in the subsurface 84 (e.g., below the seafloor) at junction 85 by adapting traditional concepts, methods, and techniques for constructing multilateral wells.
  • This approach enables use of a less complex subsea tree 87.
  • the joining is performed by intersecting the separate well paths performed by the service or drilling vessel 89 and the remote (e.g., jack-up, floating, ice-pack based or land- based) vessel or facility 80 respectively.
  • a retrievable whipstock 90 may be run into the vertical section of the well 86 to guide entry of the drillstring run through the horizontal tubular conductor to permit drilling of additional sections or intervals of the well.
  • a permanent junction may be created by utilizing traditional techniques for running, cementing, and milling tubulars and equipment for multilateral wells.
  • the invention may include a system for connecting a well with a drilling vessel for extended reach drilling operations comprising: a drilling rig; a horizontal tubular disposed to receive a drillstring from the drilling rig and extending from the drilling rig to a selected location; a mud return line connected to the horizontal tubular at a selected location along the horizontal tubular; a pump connected with the mud return line; and an inverted whipstock in the well; wherein the horizontal tubular connects with the well at a location in the well substantially at or below the whipstock.
  • the inventions may include the systems and methods discussed above, wherein 1 ) the horizontal member is connected to the well in proximity to a surface end of well, 2) the horizontal member is connected to the well at a location below a seafloor mudline; or 3) the horizontal member is connected to the well at a location below a seafloor mudline, and at or below a whipstock (e.g., an inverted whipstock, either retrievable or permanent) positioned within the well.
  • a whipstock e.g., an inverted whipstock, either retrievable or permanent
  • TD Total Depth
  • casing or liner is sealed in place in a borehole by cement or packers or both
  • the well is normally then "completed” so that production of hydrocarbons from the well can begin.
  • Completion of wells usually includes the steps of perforating the casing or liner at depths where hydrocarbons are believed to be present, placing tubing and packers in the wells and placing a Christmas tree on the well for connection to a flow line.
  • Such techniques are well known in industry.
  • the wells can be equipped with vertical access-trees. This would allow access to the well via a floating drilling unit, thus avoiding the requirement that completion and workover tools and fluids pass through the entire length of a horizontal tubular conductor.
  • the present invention may include: 1.
  • a system for extended reach drilling of a well comprising:
  • a horizontal tubular disposed to receive a drillstring from the drilling rig and extending from the drilling rig to a selected location;
  • the system of paragraph 1 further comprising a casing string inside the horizontal tubular, the casing string having a port disposed in proximity to a mud return line port in the horizontal tubular, and extending from a distal end of the horizontal tubular into the earth and a packer disposed outside the casing string at a location between the mud return line port in the horizontal tubular and a proximal end of the horizontal tubular.
  • a method for drilling a well having a surface location and a bottomhole location horizontally offset from the surface location comprising:
  • a horizontal tubular having a proximal end disposed to receive a drillstring from the drilling rig and extending to a selected location, the horizontal tubular having a port in proximity to a distal end;
  • a method for producing hydrocarbons from an oil and gas reservoir comprising:
  • a method for drilling a well comprising:
  • a method for drilling multiple wells comprising:
  • a horizontal tubular disposed to receive a drillstring from the drilling rig and extending from the drilling rig to a selected location, the horizontal tubular having a whipstock at a distal end oriented to direct tubulars in a first direction from the distal end of the horizontal tubular;
  • a method for drilling a lower section of a well comprising:
  • a mud return line having a pump therein and power for the pump, from the second drilling rig to a selected location along the horizontal tubular and connecting the mud return line through a port in the horizontal tubular;
  • a system for connecting a well with a drilling vessel for extended reach drilling operations comprising:
  • a horizontal tubular disposed to receive a drillstring from the drilling rig and extending from the drilling rig to a selected location;
  • a mud return line connected to the horizontal tubular at a selected location along the horizontal tubular;

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  • Life Sciences & Earth Sciences (AREA)
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Abstract

Cette invention concerne un procédé et un appareil permettant d'accroître la distance horizontale de forage de puits. Une colonne de tubage horizontale est utilisée pour acheminer un train de tiges de forage d'une installation de forage à un emplacement cible. Une conduite de retour des boues et une pompe sur la surface sont utilisées pour pomper les boues de forage du trépan vers l'installation de forage.
PCT/US2010/050534 2009-12-10 2010-09-28 Système et procédé de forage d'un puits qui s'étend sur une grande distance horizontale Ceased WO2011071586A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
US13/505,217 US9163465B2 (en) 2009-12-10 2010-09-28 System and method for drilling a well that extends for a large horizontal distance
RU2012153778/03A RU2012153778A (ru) 2010-05-13 2011-05-04 Способ и система для доступа в скважину в подземных пластах
US13/642,084 US20130037272A1 (en) 2009-12-10 2011-05-04 Method and system for well access to subterranean formations
CA2798806A CA2798806A1 (fr) 2010-05-13 2011-05-04 Procede et systeme d'acces a des puits de formations souterraines
PCT/US2011/035202 WO2011143034A1 (fr) 2010-05-13 2011-05-04 Procédé et système d'accès à des puits de formations souterraines

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US28541009P 2009-12-10 2009-12-10
US61/285,410 2009-12-10
US33433310P 2010-05-13 2010-05-13
US61/334,333 2010-05-13

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US13/642,084 Continuation US20130037272A1 (en) 2009-12-10 2011-05-04 Method and system for well access to subterranean formations

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WO2011071586A1 true WO2011071586A1 (fr) 2011-06-16

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Cited By (2)

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WO2013123141A3 (fr) * 2012-02-14 2014-04-17 Chevron U.S.A. Inc. Systèmes et procédés de gestion de pression dans un puits de forage
WO2014062664A3 (fr) * 2012-10-15 2014-10-30 National Oilwell Varco, L.P. Système de forage à deux gradients

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