DOWNHOLE APPARATUS AND METHODS FOR CASING

Abstract

A well construction method, and corresponding apparatus, in which a drilled bore (106) is lined with a plurality of successively smaller diameter sections of bore-lining tubing includes at least one casing (108, 110, 112) and at least one liner (120). The well construction method comprises: drilling a final section of a bore (106) to intersect a hydrocarbon-bearing formation (130); providing a shoe (134) at a distal end of a liner and a running tool (150) at a proximal end of the liner, and coupling an inner string (140) between the shoe (134) and the miming tool (150); running the liner (120) into the final section of the bore (106) such that the liner extends into the hydrocarbon-bearing formation (130); pumping a settable material (116) from surface (104), through the inner string (140), and through the shoe (134) to at least partially fill an outer annulus (114) surrounding the liner (120); and retrieving the inner string (140) and the running tool (150).

Claims

1. A well construction method in which a drilled bore is lined with a plurality of successively smaller diameter sections of bore-lining tubing, the well construction method comprising: providing a shoe at a distal end of a bore-lining tubing, a running tool at a proximal end of the tubing, and an inner string between the shoe and the running tool; running the bore-lining tubing into a fluid-filled drilled bore and displacing the bore fluid from a volume of the bore below the shoe up through the inner string; pumping a settable material from surface, through the inner string, and through the shoe to at least partially fill an outer annulus surrounding the bore-lining tubing; and retrieving the inner string and the running tool.

2. The method of claim 1, wherein the bore-lining tubing is a liner.

3. (canceled)

4. The method of claim 1, further comprising at least one of: (a) directing the displaced fluid between the inner string and an inner annulus between the inner string and the bore-lining tubing; and (b) directing the displaced fluid from a distal end of the inner string into a distal end of the inner annulus, and from a proximal end of the inner annulus into a proximal end of the inner string

5. (canceled)

6. (Canceled)

7. The method of claim 1, further comprising at least one of: (a) directing displaced fluid from the inner string into a portion of the bore above the running tool; and (b) coupling at least one of the inner string and the running tool to a running string, the running string supporting the bore-lining tubing as the tubing is run into the bore, and displacing fluid from the bore volume below the shoe, through the inner string and into the running string, and then from the running string into a volume surrounding the running string.

8. (canceled)

9. (canceled)

10. The method of claim 1, further comprising: drilling a final section of the bore to intersect a hydrocarbon-bearing formation; and running the bore-lining tubing into the final section of the bore such that the tubing extends into the hydrocarbon-bearing formation.

11. The method of claim 10, wherein the hydrocarbon-bearing formation is located above and in close proximity to at least one of: a formation containing high-pressure fluid; and a porous, low pressure formation.

12. The method of claim 10, further comprising reconfiguring at least a portion of the bore-lining tubing extending into or through the hydrocarbon-bearing formation to permit fluid to flow from the hydrocarbon-bearing formation into the tubing.

13. (canceled)

14. The method of claim 1, wherein the bore has been drilled in the seabed and a riser extends from the seabed to a rig floating on the sea surface, and the method further comprises running the bore-lining tubing into the bore through the riser.

15. The method of claim 1, further comprising: filling an inner annulus between the bore-lining tubing and the inner string with fluid; and at least one of: (a) allowing fluid to flow between the an inner string bore and the inner annulus via a port provided in the inner string to equalise pressure between the inner string bore and the inner annulus as the bore-lining tubing is run into the bore; and (b) allowing the fluid to flow between the drilled bore and the inner annulus via the inner string and a port provided in the inner string.

16.-20. (canceled)

21. The method of claim 1, further comprising: providing a port in a distal end of the inner string and circulating fluid through the inner string to flush residual settable material from the inner string.

22. The method of claim 1, further comprising: opening a port in a distal end of the inner string and circulating fluid through the inner string, and controlling the temperature of the fluid to influence the setting of the settable material in the outer annulus.

23. The method of claim 1, further comprising: retaining a volume of the settable material in the distal end of the inner string and retrieving the volume of settable material from the bore for subsequent analysis.

24. The method of claim 1, further comprising: filling an inner annulus between the bore-lining tubing and the inner string with fluid; and prior to running the bore-lining tubing to a final setting depth, hydraulically pressure-testing the bore-lining tubing by pressurising the fluid in the inner annulus.

25. The method of claim 1, further comprising providing a check valve in the shoe and maintaining the check valve open as the bore-lining tubing is run into the bore, and then reconfiguring the check valve to prevent the settable material from flowing from the outer annulus into the inner string

26. (canceled)

27. The method of claim 1, further comprising: running a pilot drill bit of a first cutting diameter into the bore and through the bore-lining tubing; drilling beyond the distal end of the bore-lining tubing with the pilot drill bit to form a pilot bore; retrieving the pilot drill bit; running a larger drill bit of a second cutting diameter larger than the first cutting diameter into the bore; and enlarging the pilot bore with the larger drill bit.

28. (canceled)

29. A well construction method in which a drilled bore is lined with a plurality of successively smaller diameter sections of bore-lining tubing including at least one casing and at least one liner, the well construction method comprising: drilling a final section of a bore to intersect a hydrocarbon-bearing formation; providing a shoe at a distal end of a liner, a running tool at a proximal end of the liner, and an inner string extending between the shoe and the running tool; running the liner into the final section of the bore such that the liner extends into the hydrocarbon-bearing formation; pumping a settable material from surface, through the inner string, and through the shoe to at least partially fill an outer annulus surrounding the liner; and retrieving the inner string and the running tool.

30. The method of claim 29, wherein the hydrocarbon-bearing formation is located above and in close proximity to one of: a formation containing high-pressure fluid: and a porous, low pressure formation.

31. (canceled)

32. Well construction apparatus comprising: bore-lining tubing; a shoe at a distal end of the bore-lining tubing, the shoe including a flow port; a running tool at a proximal end of the bore-lining tubing; an inner string extending between the shoe and the running tool, the inner string being in fluid communication with an exterior of the bore-lining tubing via the flow port in the shoe and whereby an inner annulus is provided between the bore-lining tubing and the inner string; and a first port in the inner string for allowing fluid to flow between an exterior of the bore-lining tubing and the inner annulus via the inner string.

33. The apparatus of claim 32, comprising a second port in the inner string for allowing fluid to flow from a proximal end of the inner annulus into a proximal end of the inner string.

34. The apparatus of claim 33, comprising a running string coupled to at least one of the inner string and the running tool, the running string including a port for allowing fluid to flow from an interior of the running string to an exterior of the running string.

Description

BRIEF DESCRIPTION OF THE DRAWINGS

[0064] These and other aspects of the disclosure will now be described, by way of example, with reference to the drawings, in which:

[0065] FIG. 1 is a schematic of a deep-water oil and gas well illustrating a well construction method and apparatus in accordance with a first aspect of the present disclosure;

[0066] FIG. 2 is a schematic of a deep-water oil and gas well illustrating a well construction method in accordance with a second aspect of the present disclosure; and

[0067] FIGS. 3 and 4 are schematics of a deep-water oil and gas well illustrating a well construction method in accordance with a third aspect of the present disclosure.

DETAILED DESCRIPTION OF THE DRAWINGS

[0068] Referring first to FIG. 1 of the drawings, a deep-water oil and gas well 100 is illustrated. Well construction operations are conducted primarily from a mobile offshore drilling unit 102 on the sea surface 104. A riser 103 extends from the drilling unit 102 to a wellhead 101 on the seabed 113. Work strings, tools and other apparatus may pass between the drilling unit 102 and the wellhead 101 via the riser 103. The well 100 includes a bore 106 which has been drilled in sections and lined with successively smaller bore-lining tubing sections 108, 110, 112, 120.

[0069] The illustrated well 100 includes three casing sections 108, 110 and 112 which extend back to the seabed 113 and serve to support the surrounding bore wall, which may include weak zones which would otherwise be liable to collapse. The casings 108, 110, 112 also isolate any water, gas or oil-bearing zones and provide support for the next casing. An annulus 114 surrounds each casing 108, 110, 112 and is at least partially filled with settable material, typically a cement 116.

[0070] The illustrated well also includes a liner 120 which extends to the end of the bore 106. The liner 120 may have a generally similar form to the casings 108, 110, 112 but does not extend back to the seabed 113. In this example the liner 120 is sealed and secured to a distal portion of the innermost casing 112 with a liner hanger 122. An outer annulus 124 between the liner 120 and the surrounding bore wall is sealed with cement 126.

[0071] In the illustrated example the bore 106 extends into a hydrocarbon-bearing formation 130. Surveys may have indicated to the operator that a formation 132 below the hydrocarbon-bearing formation 130 is potentially problematic, for example the formation 132 may contain fluid at high pressure such that extending the bore 106 and breaching the formation 132 may result in high pressure fluid flooding into the well 100 and creating difficulties for the operator.

[0072] In the illustrated well 100 the first casing 108, sometimes referred to as a conductor, is a 36″ (91.4 cm) casing 108, that is a casing having an external diameter of 36 inches (91.4 cm). The casing 108 may have been placed by jetting, that is by providing a shoe on the lower or distal end of the casing 108 and pumping water through jetting nozzles in the shoe to displace sediment and allow the casing 108 to be lowered into the seabed. In other situations, the casing may have been run into a drilled bore and then sealed and secured in the bore within a cement sheath.

[0073] A 28″ (71.1 cm) casing 110 is next located in the bore 106, followed by a 22″ (55.9 cm) casing 112. A 22″ (55.9 cm) bore is drilled and under reamed beyond the end of the casing 110. An 18″ (45.7 cm) liner 120 is then run into and cemented in the bore 106, as described in detail below.

[0074] The liner 120 is made up from liner sections on the deck of the drilling unit 102. The leading or distal end of the liner 120 is provided with a liner shoe 134. The shoe 134 is a float shoe and allows an end adaptor 142 on the end of an inner string 140 to form a sealing engagement with the shoe 134, as will be described. The inner string 140 will typically be of significantly smaller diameter than the liner 120, and in this example the inner string 140 may have an outer diameter of 5″, 5½″ or 5⅞″ (12.7, 14.0, 14.9 cm). In other examples the inner string 140 may have any appropriate diameter, such as between 2⅞″ and 5⅞″ (7.3 and 14.9 cm).

[0075] Once the liner 120 has been made up and is suspended from the slips on the deck of the drilling unit 102, the inner string 140 is made up and run into the liner 120. The inner string 140 includes an end connector 142 which may be latched into a flow passage 144 in the liner shoe 134. The flow passage 144 features a float or check valve which prevents flow of fluid from below the shoe 134 and into the inner string 140 while permitting flow from the inner string 140 through the flow passage 144 and out of the shoe 134. The end connector 142 may be disengaged from the shoe 134 by rotating the connector 142 relative to the shoe 134.

[0076] The lower or distal end of the inner string 140 includes a valved port 146 including a burst disc or the like. The valve in the port 146 is initially closed. In other examples the port 146 may be provided without a valve, the port remaining open.

[0077] The inner string 140 also includes a telescopic section 148. When the telescopic section 148 is extended, complementary splined portions engage and permit the transfer of torque through the section 148. However, when the section 148 is retracted or compressed an upper portion of the string 140a is rotatable relative to a lower portion 140b. The telescopic section 148 may include features such as described in GB2525148A and GB2545495A, the disclosures of which are incorporated herein in their entirety.

[0078] Once the inner string 140 has been made up to the appropriate length within the liner 120 the end connector 142 may engage and connect with the shoe 134. Pulling back on the string 140 will confirm that the connector 142 and shoe 134 are properly engaged.

[0079] The upper or proximal end of the inner string 140 is then coupled to a liner running tool 150 which includes external left-handed threads configured to cooperate with matching internal threads on the upper or proximal end of the liner 120. In other examples an alternative or supplementary coupling arrangement may be employed between the running tool 150 and the 120, for example cam-actuated load shoulders.

[0080] The inner string 140 is then lowered to compress the telescopic section 148 such that the splined portions disengage. The upper portion 140a may now be rotated to engage the running tool 150 with the upper end of the liner 120, without transfer of the rotation to the liner lower portion 140b.

[0081] An inner annulus 152 between the liner 120 and the inner string 140 may be top filled with drilling fluid before engaging the running tool 150 with the liner 120. Also, the inner string 140 may be top filled, as may a liner running string 154 which is subsequently connected to the liner assembly. The top filling may be achieved simply by locating a hose outlet in the upper end of the annulus 152 or string 140, 154 and pumping drilling fluid into the annulus 152 or string 140, 154, or by use of apparatus such as the Top Jet (trade mark) tool supplied by Churchill Drilling Tools.

[0082] Once the running tool 154 has been coupled and sealed to the upper end of the liner 120, the liner 120 may be hydraulically pressure tested, for example by pumping fluid into the inner annulus via a port 172 in the running tool 154. If the port 146 in the inner string 140 is open, this will require the bore of the inner string 140 to be temporarily isolated. Once the pressure test of the liner 120 is completed, the inner string bore is re-opened, such that, if the port 146 is open, fluid may flow between the open inner string 140 and the inner annulus 152 to equalise pressure as the liner assembly is run into the bore.

[0083] As the liner-running assembly is made up and advanced into the fluid-filled riser 103 and the fluid-filled bore 106, a volume of fluid will be displaced from the riser 103 and the bore 106. The displaced fluid flows upwards through the riser 103 and is collected in an area below the drill-floor of the drilling unit 102. The collected fluid is cleaned and directed to storage, ready for re-use.

[0084] The liner assembly is lowered into the well supported by the liner running string 154 until the liner 120 reaches target depth. The liner hanger 122 provided at the upper end of the liner 120 may be activated and slips 158 in the hanger 122 engage the surrounding casing 112. The hanger 122 also includes seals 160 which are initially inactive.

[0085] Cement slurry 126a is prepared on the mobile offshore drilling unit 102 and is then pumped down through the liner running string 154, the liner running tool 150, the inner string 140, and through the flow port 144 in the shoe 134. Reverse flow of the relatively dense cement slurry 126a from the annulus 124 back into the inner string 140 is prevented by the check valve provided in the port 144.

[0086] The operator will have estimated the volume of cement slurry 126a required to fill the annulus 124 and will typically prepare an excess of cement, for example 115% of this theoretical annular volume, that is a 15% excess, to accommodate, for example, washed-out or collapsed (and therefore larger volume) portions of annulus 124, or losses of cement slurry 126a into porous formations. The cement 126a will fill the annulus to at least the level of the liner hanger 122 and will flow over and past the liner hanger seals 160.

[0087] During the cementing operation the rig personnel will monitor the volume of cement 126a being pumped into the well and the volume of drilling fluid being returned or displaced from the well.

[0088] The volume of cement 126a may be separated from the following displacement fluid 164 by a top plug and or ball 166. The cement 126a is thus pumped through the liner running string 154, the liner running tool 150, the inner string 140, and the flow port 144 in the shoe 134, until the ball 166 lands in and blocks the flow port 144. The ball 166 is locked in the port 144 and acts in combination with the flow port check valve 144 to prevent any possibility of U-tubing, that is the dense cement slurry 126a flowing out of the annulus 124, back through the port 144, and into the inner string 140.

[0089] Once pumping of the cement 126a into the annulus 124 has been completed the operator continues to apply pressure to activate the liner hanger seals 160 to provide a fluid-tight seal between the upper end of the liner 120 and the surrounding casing 112. In particular, a valved port 146 provided with a shear or burst disc is provided in the lower end of the inner string 140, and by continuing to pump, and increasing the pressure within the string 140, the liner hanger 122 and slips 158 and seals 160 are set. A further increase in pressure opens the initially closed valved port 146. The liner running tool 150 also includes an initially closed valved port 172 which controls flow from the inner annulus 152 into the bore volume above the running tool 150. If the valve 172 is closed, fluid may be pumped into the inner annulus 152 through the lower valve 146 to conduct a pressure test of the liner 120. However, with the valve 172 open, fluid may be reverse circulated through the inner annulus 152 and any residual cement 126a in the string 140 is flushed out of the well; fluid may be pumped into the inner annulus 152 from the bore volume above the running tool, and then through the port 146 and up through the inner string 140 to surface.

[0090] As noted above, in other examples the port 146 at the lower end of the inner string 140 may be initially open, and this facilitates pressure equalisation of the inner annulus 152 as the liner assembly is run into the bore. When cement is being pumped, the open port will result in the pressure in the annulus 152 increasing, however cement will not tend to flow into the annulus 152 through the open port 146. Further, in alternative examples the port 146 may feature a different valve arrangement. For example, the port 146 may include a valve which opens in response to a predetermined sequence of pressure pulses or a predetermined flow sequence, such as on/off/on/off. In another example the port 146 may include a valve which operates in response to surface deployed communication, such as RFID tags which may be pumped into the inner string 140 when it is desired to change the configuration of the valve to open or close the port 146.

[0091] When the operator is ready to retrieve the liner running assembly, the liner running string 154 is rotated to disengage the liner running tool 150 from the upper end of the liner 120. The liner running string 154 is then raised to extend the telescopic section 148 in the inner string 140, allowing torque to be transferred between the inner string portions 140a, 140b, to disengage the bottom end of the inner string 140 from the liner shoe 134.

[0092] Once the cement 126 has set, any further operations, for example perforating the liner 120, may be carried out immediately. There is no requirement to drill out a plug of cement, or the associated plugs and float collar, from the distal end of the liner 120, as would be the case with a conventional liner cementing operation. This provides for a considerable saving in time, reduces the equipment required to be provided on the drilling unit 102, avoids the potential for damage to the liner 120 and the cement 126 from the drilling operation, and removes the risk associated with the cement removal bit advancing too far and breaching the problem formation 132.

[0093] Reference is now made to FIG. 2 of the drawings, which illustrates a deep-water oil and gas exploration well 200. The well 200 shares many features with the well 100 described above and, in the interest of brevity, some of the common features will not be described again in any detail. Common features will be labelled with the same reference numerals, incremented by 100.

[0094] The apparatus and methods used in the initial construction of the well 200 are largely the same as those used in the construction of the well 100, however in the present well 200 the intention is to extend the bore 206 beyond the distal end of the cemented liner 220, but equally the method and apparatus described could be used for extending the bore 206 beyond the end of a cemented casing. Thus, after the liner 220 has been cemented and the inner string 240 uncoupled from the liner shoe 234 and retrieved to the drilling unit 202, a drilling assembly 270, in this example a 12¼″ (31.1 cm) drilling assembly 270, is run into the well 200 and utilised to drill through the liner shoe 234 and create a 12¼″ (31.1 cm) open hole 272 extending beyond the end of the liner 220.

[0095] The new open hole 272 will allow geophysical data to be obtained for the formations beyond the liner 220. The operator will then be better informed before drilling a larger diameter hole 274 (for example a 20″ (50.8 cm) diameter bore) beyond the liner 220, using the 12¼″ (31.1 cm) hole as a pilot bore.

[0096] When compared with conventional liner cementing operations, similar advantages to those described above with reference to the first well 100 are available. For example, a conventional liner cementing operation would have resulted in a cement plug extending the length of the shoe track, which would have to be drilled out before drilling the 12¼″ (31.1 cm) hole 272. In deep water this would likely have added 1 to 1½ days to the well construction operation. Alternatively, if the 12¼″ (31.1 cm) drilling assembly was used to drill through the shoe track cement plug an annulus of cement would have remained and there would be a significant risk that the remaining cement would cave in to the drilled bore and jam the drilling apparatus, preventing further drilling and possibly resulting in a stuck drill string.

[0097] Reference is now made to FIGS. 3 and 4 of the drawings, which are schematics of a deep-water oil and gas well 300 illustrating a well construction method in accordance with a third aspect of the present disclosure. The well 300 shares many features with the well 100 described above, and common features are labelled with the same reference numerals, incremented by 200.

[0098] The well 300 includes similar structures to the well 100, including a 36″ (91.4 cm) casing 308, a 28″ (71.1 cm) conductor casing 310, a 22″ (55.9 cm) surface casing 312 and an 18″ (45.7 cm) liner 320. Additionally, the well 300 includes 16″ (40.6 cm) liner 378 that has been cemented in a 20″ (50.8 cm) open hole 374.

[0099] It will be observed that there are close tolerances between the bore-lining casings and liners. This will often be the case where multiple casings and liners are required to cover formations and zones that are, for example, weak, at high pressure, produce water, or even produce hydrocarbons. In the absence of such close tolerances, the final liner would have to be very small, restricting access and hydrocarbon production, or a very large diameter bore would be required, which takes significantly longer to drill with increased risks and requires significantly greater resources to construct.

[0100] An issue with close tolerance casing and liner is that the casings and liners must be run into the bore very slowly, to allow well fluid to be safely displaced from the volume below the casing or liner shoe. The displaced fluid travels up the annulus between the casing or liner and the adjacent casing or liner. Attempting to run the casing or liner into the bore too quickly can result in pressure surging which may, for example, damage the formation surrounding the open hole by forcing well fluid into the formation. Also, if a close tolerance casing or liner is pulled from the bore a swabbing effect (suction or negative pressure) may result, possibly drawing fluid from the surrounding formations or even collapsing the bore walls.

[0101] These affects are minimised or avoided by providing diverter tools or subs 380 in the inner string 340 and in the lower end of the liner running string 354. FIG. 4 illustrates the use of the diverter subs 380 when running in the 18″ (45.7 cm) liner 320. In this example a lower sub 380a is provided directly above the liner shoe 334, an intermediate sub 380b is provided directly below the liner running tool 350, and an upper sub 380c is provided in the lower end of the liner running string 354. The diverter tools 380 include ports provided with valves which are open as the liner 320 is run into the well 300. This allows well fluid displaced from the bore section below the liner shoe 334 to flow through the open shoe port 344, into the lower end of the inner string 340, and then into the inner annulus 352. The shoe port 344 may be provided with a check valve that is initially held open to permit fluid to flow from the well 300 into the inner string 340. The fluid may then flow up through the inner annulus 352 and then flow back into the upper end of the inner string 340 through the intermediate sub 380b. The fluid may then flow through the liner running tool 350 and into the lower end of the liner running string 354, before passing through the upper sub 380c and into the bore volume above the liner running tool 350.

[0102] The open ports in the diverter subs 380 also allows pressure to equalise in the inner annulus 352 as the liner running assembly travels through the well 300.

[0103] The ability of the fluid in the riser 303 and the well 300 to flow into the liner running assembly as the assembly is made up and then run into the well 300 avoids the need to top fill the liner 320, inner string 340 and running string 354. Further, the ability of the liner assembly to self-fill minimises the volume of fluid that is displaced out of the well 300 (from the upper end of the riser 303) as the liner 320 is run into and through the well 300.

[0104] As noted above, running a conventional close tolerance casing or liner into a bore requires that the casing or liner is run into the bore relatively slowly, to allow the fluid in the bore to be displaced safely up through the narrow annulus between the casing or liner and the surrounding bore wall. However, the arrangement described above provides an additional flow path for the displaced fluid, via the inner string 340 and the inner annulus 352. This allows the operator to run the liner into the well 300 relatively quickly and minimises the risk of damage to the bore wall and the surrounding rock formation.

[0105] Once the liner 320 has reached target depth, the valves in the subs 380 are closed. For example, RFID tags may be pumped down through the liner running string 354 and the inner string 340, the tags being detected by sensors which then activate the battery-powered valves to close the ports provided in subs 380. As noted above, the shoe flow port 344 may be provided with a check valve that is initially held open to allow flow into the inner string 340. However, once the liner 320 has reached target depth the valve may be activated, to prevent further flow of bore fluid from the annulus 324 into the inner string 340.

[0106] As noted above in relation to the other aspects, the various valves provided may be activated by any suitable mechanism or method, for example the valves in the subs 380, or the valve in the port 344, may be operated by predetermined pressure pulses or flow sequences.

[0107] Cement 326 may then be circulated to fill the outer annulus 324 as described above with reference to the well 100.

[0108] In other examples, the ports provided in the diverter subs 380, particularly the ports provided in the lower sub 380a and the intermediate sub 380b, may be provided without valves and remain open. When cement is circulated the pressure in the inner annulus 352 may increase, but cement will not tend to flow into the annulus 352 via the open subs 380a and 380b.

[0109] It will be apparent to the skilled person that many of the elements of the various well constructions described above may be modified or omitted. For example, the skilled person would recognise that the number and dimensions of the various casing and liner sections may differ in other wells, for example some wells may be initiated with a 30″ (76.2 cm) casing, and in some jurisdictions the operator will tend to use bore-lining tubing which is specified in metric units, rather than inches.

[0110] to Further, the drawings illustrate methods being utilised in deep-water applications. The skilled person will recognise that the methods and apparatus described may also be utilised in shallower water, and indeed in land wells.

REFERENCE NUMERALS

[0111] deep water well 100

[0112] wellhead 101

[0113] mobile offshore drilling unit 102

[0114] riser 103

[0115] sea surface 104

[0116] bore 106

[0117] casing sections 108, 110 and 112

[0118] seabed 113

[0119] casing section annuli 114

[0120] cement 116

[0121] liner 120

[0122] liner hanger 122

[0123] outer annulus 124

[0124] outer annulus cement 126

[0125] outer annulus cement slurry 126a

[0126] hydrocarbon-bearing formation 130

[0127] problem formation 132

[0128] liner shoe 134

[0129] inner string 140

[0130] upper string portion 140a

[0131] lower string portion 140b

[0132] end connector 142

[0133] shoe flow passage/port 144

[0134] valved port 146

[0135] telescopic section 148

[0136] liner running tool 150

[0137] inner annulus 152

[0138] liner running string 154

[0139] liner hanger slips 158

[0140] liner hanger seals 160

[0141] displacement fluid 164

[0142] top plug/ball 166

[0143] liner running tool valve 172

[0144] deep water exploration well 200

[0145] wellhead 201

[0146] mobile offshore drilling unit 202

[0147] riser 203

[0148] bore 206

[0149] liner 220

[0150] liner shoe 234

[0151] inner string 240

[0152] drilling assembly 270

[0153] 12¼″ open hole 272

[0154] 20″ hole 274

[0155] deep water well 300

[0156] wellhead 301

[0157] riser 303

[0158] 36″ casing 308

[0159] 28″ conductor casing 310

[0160] 22″ surface casing 312

[0161] 18″ liner 320

[0162] outer annulus 324

[0163] cement 326

[0164] liner shoe 334

[0165] inner string 340

[0166] shoe flow port 344

[0167] liner running tool 350

[0168] inner annulus 352

[0169] liner running string 354

[0170] 20″ open hole 374

[0171] 16″ liner 378

[0172] lower diverter sub 380a

[0173] intermediate diverter sub 380b

[0174] upper diverter sub 380c