EP1295006B1 - Pipe handling apparatus and method of landing items at a well location - Google Patents

Abstract

A drill pipe (18) and drill pipe handling apparatus for oil and gas drilling rigs, the drill pipe (18) having an enlarged diameter section (21) positioned between the ends of the drill pipe (18). The enlarged diameter section (21) of drill pipe (18) has a shoulder (21a and b) which corresponds with and is engaged by a shoulder (109 or 209) located on wedge members (106 or 206) of a holder (100 or 200) on a drilling rig (10) for supporting the drill pipe (18) without crushing or otherwise damaging the drill pipe (18) during and after addition or removal of joints of drill pipe (18). A method of lowering items from a drilling rig (10) to a well (14) located below it through the use of a landing string (19) comprised of drill pipe (18) having an enlarged diameter section (21) with a shoulder (21a and b), in combination with upper and lower holders (100 and 200) having wedge members (106 and 206) with shoulders (109 and 209) that engage and support the drill pipe (18) at the shoulder (21a and b) of the enlarged diameter section (21).

Description

BACKGROUND OFINVENTION1. Field of the Invention
• The present invention relates to a drill pipe and drill pipe holder used in the oil and gas well drilling industry. More particularly, the present invention relates to a drill pipe holder that holds a joint of drill pipe in a landing string during the addition or removal of a joint of drill pipe to or from the landing string, wherein the holder and the joint of drill pipe held by the holder are configured to support the load of the landing string with correspondingly shaped shoulders that engage when the holder holds the joint of drill pipe.
2. General Background of the Invention
• Oil and gas well drilling and production operations involve the use of generally cylindrical tubes commonly known in the industry as "casing" which line the generally cylindrical wall of the borehole which has been drilled in the earth. Casing is typically comprised of steel pipe in lengths of approximately 40 feet, each such length being commonly referred to as a "joint" of casing. In use, joints of casing are attached end-to-end to create a continuous conduit. In a completed well, the casing generally extends the entire length of the borehole and conducts oil and gas from the producing formation to the top of the borehole, where one or more blowout preventors may be located on the sea floor.
• Casing is generally installed or "run" into the borehole in phases as the borehole is being drilled. The casing in the uppermost portion of the borehole, commonly referred to as "surface casing," may be several hundred to several thousand feet in length, depending upon numerous factors including the nature of the earthen formation being drilled and the desired final depth of the borehole.
• After the surface casing is cemented into position in the borehole, further drilling operations are conducted through the interior of surface casing as the borehole is drilled deeper and deeper. When the borehole reaches a certain depth below the level of the surface casing, depending again on a number of factors such as the nature of the formation and the desired final depth of the borehole, drilling operations are temporarily halted so that the next phase of casing installation, commonly known as intermediate casing, may take place.
• Intermediate casing, which may be thousands of feet in total length, is typically made of "joints" of steel pipe, each joint typically being in the range of about 38 to 42 feet in length (11.58 to 12.80 meters). The joints of intermediate casing are attached end-to-end, typically through the use of threaded male and female connectors located at the respective ends of each joint of casing.
• In the process of installing the intermediate casing, joints of intermediate casing are lowered longitudinally through the floor of the drilling rig. The length of the column of intermediate casing grows as successive joints of casing are added, generally one at a time, by drill hands and/or automated handling equipment located on the floor of the drilling rig.
• When the last intermediate casing joint has been added, the entire column of intermediate casing, commonly referred to as the intermediate "casing string", must be lowered further into its proper place in the borehole. The task of lowering the casing string into its final position in the borehole is accomplished by adding joints of drill pipe to the top of the casing string. The additional joints of drill pipe are added, end-to-end, by personnel and/or automated handling equipment located on the drilling rig, thereby creating a column of drill pipe known as the "landing string." With the addition of each successive joint of drill pipe to the landing string, the casing string is lowered further and further.
• During this process as practiced in the prior art, when an additional joint of drill pipe is being added to the landing string, the landing string and casing string hang from the floor of the drilling rig, suspended there by a holder or gripping device commonly referred to in the prior art as "slips." When in use, the slips generally surround an opening in the rig floor through which the upper end of the uppermost joint of drill pipe protrudes, holding it there a few feet above the surface of the rig floor so that rig personnel and/or automated handling equipment can attach the nextjoint(s) of drill pipe.
• The inner surface of the prior art slips has teeth-like grippers and is curved such that it corresponds with the outer surface of the drill pipe. The outer surface of prior art slips is tapered such that it corresponds with the tapered inner or "bowl" face of the master bushing in which the slips sit.
• When in use, the inside surface of the prior art slips is pressed against and "grips" the outer surface of the drill pipe which is surrounded by the slips. The tapered outer surface of the slips, in combination with the corresponding tapered inner face of the master bushing in which the slips sit, cause the slips to tighten around the gripped drill pipe such that the greater the load being carried by that gripped drill pipe, the greater the gripping force of the slips being applied around that gripped drill pipe. Accordingly, the weight of the casing string, and the weight of the landing string being used to "run" or "land" the casing string into the borehole, affects the gripping force being applied by the slips, i.e., the greater the weight the greater the gripping force and crushing effect.
• It is known from US 5,732,909 and US 5,351,767 to provide drill pipe handling apparatus in which a drill pipe is held by pipe slips having teeth adapted to grip the pipe and, in the case of US 5,732,909, and additional smooth pipe slips made of a malleable material and adapted to grip the pipe by applying a force perpendicular to the axis of the pipe.
• As the world's supply of easy-to-reach oil and gas formations is being depleted, a significant amount of oil and gas exploration has shifted to more challenging and difficult-to-reach locations such as deep-water drilling sites located in thousands of feet ofwater. In some of the deepest undersea wells drilled to date, wells may be drilled from a rig situated on the ocean surface some 5,000 to 10,000 feet (1.524 to 3.048 kilometers) above the sea floor, and such wells may be drilled some 15,000 to 20,000 feet (4.572 to 6.096 kilometers) below the sea floor. It is envisioned that as time goes on, oil and gas exploration will involve the drilling of even deeper holes in even deeper water.
• For many reasons, including the nature of the geological formations in which unusually deep drilling takes place and is expected to take place in the future, the casing strings required for such wells must be unusually long and must have unusually thick walls, which means that such casing strings are unusually heavy and can be expected in the future to be even heavier. Moreover, the landing string needed to land the casing strings in such extremely deep wells must be unusually long and strong, hence unusually heavy in comparison to landing strings required in more typical wells.
• For example, a typical well drilled in an offshore location today may be located in about 300 to 2000 feet (91.44 to 609.6 meters) of water, and may be drilled 15,000 to 20,000 feet (4.572 to 6.096 kilometers) into the sea floor. Typical casing for such a typical well may involve landing a casing string between 15,000 to 20,000 feet (4.572 to 6.096 kilometers) in length, weighing 40 to 60 pounds per linear foot (59.52 to 89.28 kilograms per meter), resulting in a typical casing string having a total weight of between 600,000 to 1,200,000 pounds (272,160 to 544,320 kilograms). The landing string required to land such a typical casing string may be 300 to 2000 feet (91.44 to 609.6 meters) long which, at about 35 pounds per linear foot (52.08 kilograms per meter) of landing string, results in a total landing string weight of 10,500 to 70,000 pounds (4,762.8 to 31,752 kilograms). Hence, prior art slips in typical wells have typically supported combined landing string and casing string weight in the range of between about 610,500 to 1,270,000 pounds (276,922.8 to 576, 072 kilograms).
• By way of contrast, extremely deep undersea wells located in 5,000 to 10,000 (1.524 to 3.048 kilometers) feet of water, uncommon today but expected to be more common in the future, may involve landing a casing string 15,000 to 20,000 feet (4.572 to 6.096 kilometers) in length, weighing 40 to 80 pounds per linear foot (59.52 to 119.04 kilograms per meter), resulting in a total casing string weight of 600,000 to 1,600,000 pounds (272,160 to 725,760 kilograms). The landing string required to land such casing strings in such extremely deep wells may be 5,000 to 10,000 feet (1,524 to 3,048 meters) long which, at 70 pounds per linear foot (104.16 kilograms per meter), results in a total landing string weight of about 350,000 to 700,000 pounds (158,760 to 317,520 kilograms). Hence, the combined landing string and casing string weight for extremely deep undersea wells may be in the range of 950,000 to 2,300,000 pounds (430,920 to 1,043,280 kilograms), instead of the 610,500 to 1,270,000 pound (276,696 to 576,072 kilograms) range generally applicable to more typical wells. In the future, as deeper wells are drilled in deeper water, the combined landing string and casing string weight can be expected to increase, perhaps up to as much as 4,000,000 pounds (1,814,400 kilograms) or more.
• Under certain circumstances, prior art slips have been able to support the combined landing string and casing string weight of 610,500 to 1,270,000 pounds (276,696 to 576,072 kilograms) associated with typical wells, depending upon the size, weight and grade of the pipe being held by the slips. In contrast, prior art slips cannot effectively and consistently support the combined landing string and casing string weight of 950,000 to 2,300,000 pounds (430,920 to 1,043,280 kilograms) associated with extremely deep wells, because of numerous problems which occur at such extremely heavy weights.
• For example, prior art slips used to support combined landing string and casing string weight above the range of about 610,500 to 1,270,000 pounds (276,696 to 576,072 kilograms) have been known to apply such tremendous gripping force that (a) the gripped pipe has been crushed or otherwise deformed and thereby rendered defective, (b) the gripped pipe has been excessively scored and thereby damaged due to the teeth-like grippers on the inside surface of the prior art slips being pressed too deeply into the gripped drill pipe and/or (c) the prior art slips have experienced damage rendering them inoperable.
• A related problem involves the uneven distribution of force applied by the prior art slips to the gripped pipe joint. If the tapered outer wall of the slips is not substantially parallel to and aligned with the tapered inner wall of the master bushing, that can create a situation where the gripping force of the slips in concentrated in a relatively small portion of the inside wall of the slips rather than being evenly distributed throughout the entire inside wall of the slips. Such concentration of gripping force in such a relatively small portion of the inner wall of the slips can (a) crush or otherwise deform the gripped drill pipe, (b) result in excessive and harmful strain or elongation of the drill pipe below the point where it is gripped and (c) cause damage to the slips rendering them inoperable.
• This uneven distribution of gripping force is not an uncommon problem, as the rough and tumble nature of oil and gas well drilling operations cause the slips and/or master bushing to be knocked about, resulting in misalignment and/or irregularities in the tapered interface between the slips and the master bushing. This problem is exacerbated as the weight supported by the slips is increased, which is the case for extremely deep wells as discussed above.
BRIEF SUMMARY OF INVENTION
• The present invention does away with prior art slips and provides for a drill pipe holder which supports the drill pipe without crushing, deforming, scoring or causing elongation of the drill pipe being held. The holder of the present invention includes wedge members which can be raised out of and lowered into the holder.
• The holder is used in combination with an enlarged diameter section of the drill pipe which is spaced apart from the ends of the drill pipe. The enlarged diameter section has a tapered shoulder which corresponds to a tapered shoulder on the movable wedge members of the holder, and the engagement of such shoulders provides support for the drill pipe being held without any of the problems associated with the prior art slips, regardless of the weight of the landing string and casing string.
BRIEF DESCRIPTION OF DRAWINGS
• Figure 1 is an overall elevational view of a drilling rig situated on a floating drill ship, said drilling rig supporting a landing string and casing string extending therefrom in accordance with the present invention toward the borehole that has been drilled into the sea floor.
• Figure 2 is an elevational view of drill pipe in accordance with the present invention.
• Figures 3 and 4 are fragmentary, sectional, elevational views of drill pipe in accordance with the present invention.
• Figure 5 is a perspective view of the wedge members of the lower and upper holders of the present invention, hinged together and closed.
• Figure 6 is a cross sectional view taken along lines 6 - 6 in figure 5.
• Figure 7 is a perspective view of the individual, unconnected wedge members of the lower and upper holders of the present invention.
• Figure 8 is a perspective view of the wedge members of the lower and upper holders of the present invention hinged together in an open position.
• Figure 9 is a fragmentary, sectional, elevational view of an alternative embodiment of drill pipe in accordance with the present invention, along with a side view of a wedge member used with the alternative embodiment in both the upper and lower holders of the present invention.
• Figure 10 is an elevational view of the drill pipe and upper and lower holders in accordance with the present invention, in which the lower holder is supporting the landing string extending from the drilling rig, and the auxiliary upper holder is supporting the weight of the joints of drill pipe being added to or removed from the landing string.
• Figure 11 is an elevational view of the drill pipe and holders in accordance with the present invention, wherein the landing string is being supported by the lower holder, and wherein additional joints of drill pipe have either been just added to or are about to be removed from the landing string being held by the lower holder.
• Figure 12 in an elevational view of the drill pipe and holders in accordance with the present invention, wherein the landing string is supported by the upper holder, and wherein the upper holder and the wedges of the lower holder are being raised slightly so as to clear the wedge members of the lower holder from around the drill pipe prior to lowering the joints of drill pipe which have been added, or, alternatively, where the upper holder has just been used to pull several joints of landing string up as in "tripping out" of the hole.
• Figure 13 is a perspective view showing the upper holder without its wedge members and without the auxiliary upper holder.
• Figure 14 is a cross sectional view taken along lines 14 - 14 of figure 13.
• Figure 15 is an elevational view of the drill pipe and upper and lower holders of the present invention wherein the upper holder has just lowered the drill pipes that were added and wherein the weight of the landing string is about to be transferred from the upper holder to the lower holder.
• Figure 16 is an elevational view of the drill pipe and upper and lower holders of the present invention wherein the lower holder is supporting the weight of the landing string and wherein the upper holder is about to be hoisted up so that additional joints of drill pipe may be added to the landing string or, alternatively, wherein the upper holder is about to engage and support the landing string in preparation for "tripping out" of the hole.
• Figure 17 is an elevational view of an alternative embodiment of the drill pipe in accordance with the present invention.
• Figure 18 is a cross sectional view taken along lines 18 - 18 of figure 17.
• Figure 19 is an elevational view of an alternative embodiment of drill pipe in accordance with the present invention.
• Figure 19A is a cross sectional view taken alonglines 19A-19A of figure 19.
• Figure 20 is an elevational view of an alternative embodiment of the present invention in which the joints are run with the female end down and the male end up.
• Figure 21 is an elevational view of another alternative embodiment of drill pipe in accordance with the present invention.
• Figure 21A is a cross sectional view taken alonglines 21A-21A of figure 21.
• Figure 22 is an elevational view of yet another alternative embodiment of the present invention.
• Figure 23 is an elevational side view of a further alternative embodiment of wedge members in accordance with the present invention.
• For a further understanding of the nature, objects and advantages of the present invention, reference should be had to the following detailed description, read in conjunction with the following drawings, wherein like reference numerals denote like elements and wherein:
DETAILED DESCRIPTION OF THE INVENTION
• Figure 1 depicts generally thepresent invention 5 in overview. As shown in figure 1,drilling rig 8 is situated aboveocean surface 12 over the location ofundersea well 14 that is drilled below sea floor 16. Numerous lengths or "joints" ofdrill pipe 18 in accordance with the present invention, attached end-to-end and collectively known as "landing string" 19, extend fromrig 8. Numerous lengths or "joints" ofcasing 34, attached end-to-end and collectively known as "casing string" 35, extend below landingstring 19 and are attached to landingstring 19 viacrossover connection 36. The landingstring 19,crossover connection 36 andcasing string 35 are situated longitudinally withinriser 17 which extends from therig 8 toundersea well 14.
• Figure 2 shows adrill pipe 18 in accordance with the present invention. In addition to a female or "box"end 20 and a male or "pin"end 22,drill pipe 18 of the present invention also has an enlargediameter section 21 which is spaced apart frombox end 20 andpin end 22.Enlarged diameter section 21 has ashoulder 21 a which is preferably tapered as shown in figures 2 and 3.Shoulder 21 a surrounds at least a part and preferably all of the circumferential perimeter ofdrill pipe 18.
• Also in accordance with the present invention, figure 10 shows drill pipelower holder 100 for supporting thelanding string 19 during the addition or removal of one or more joints ofdrill pipe 18 to or from landingstring 19.Lower holder 100 is preferably located at the drilling rig floor 9, where it may be situated in or adjacent to the floor.
• As also shown in figure 10,lower holder 100 includesmain body 104 which generally surrounds an opening 11 in rig floor 9 through which landingstring 19 protrudes.Main body 104 has anopening 103 and a taperedinner face 105 which defines a tapered bowl generally surrounding landingstring 19 which protrudes therethrough.
• Lower holder 100 also includes one ormore wedge members 106, as depicted in figures 10, 11 and 12. As shown in figure 7, thewedge members 106 of the present invention are preferably three in number and are preferably connected byhinges 108 as shown in figures 5 and 8.Wedge members 106 have a tapered outer face 107, as shown in figures 5 and 7, which corresponds with the taperedinner face 105 ofmain body 104, as shown in figures 11 and 12. The tapered bowl inmain body 104 which is defined by its taperedinner face 105 receiveswedge members 106 as best depicted in figures 10 and 11.
• As shown in figures 6 and 7, the inner side ofwedge member 106 has a taperedshoulder 109.Tapered shoulder 109 corresponds with taperedshoulder 21a ofenlarged diameter section 21 ofdrill pipe 18, as best shown in figures 12 and 11.Tapered shoulder 109 ofwedge member 106 is curved, as shown in figures 7 and 8, to correspond with the curved, circumferential shape ofshoulder 21a ofenlarged diameter section 21. The inner side ofwedge member 106 also has a curved surface 106a, as best shown in figures 7 and 8, which corresponds with and accommodates the curvedouter surface 18a ofdrill pipe 18. The inner side ofwedge member 106 also has curved surface 106b, as best shown in figures 7 and 8, which corresponds with and accommodates the curved outer surface 21b ofenlarged diameter section 21 ofdrill pipe 18.
• Whenwedge members 106 are in place inmain body 104, as shown in figures 10 and 11, the wedge members form an interface betweenbody 104 and the joint ofdrill pipe 18 being held byholder 100, the engagement betweenshoulder 109 ofwedge member 106 andshoulder 21 a ofenlarged diameter section 21 providing support for thedrill pipe 18 being held by theholder 100.
• It should be understood thatlower holder 100 of the present invention provides support for landingstring 19 by the engagement ofshoulder 109 ofwedge member 106 withshoulder 21 a ofenlarged diameter section 21 ofdrill pipe 18. Accordingly, unlike prior art slips, it is not necessary for the curved inner surface 106a ofwedge member 106 to have teeth-like grippers or bear against thedrill pipe 18 being supported by the holder. Hence, the present invention overcomes the problems associated with crushing, deformation, scoring and uneven distribution of gripping force associated with prior art slips.
• It should be understood thatdrill pipe 18 depicted in figure 10 as being supported bylower holder 100 is the uppermost length or "joint" of drill pipe in landingstring 19 depicted in figure 1. It should also be understood thatlower holder 100 of the present invention supports not only drillpipe 18 which appears in figure 10, but also the entire attached landingstring 19 andcasing string 35 extending fromrig 8, as best shown in figure 1. In extremely deep wells drilled in extremely deep water for which the present invention is particularly suited, the combined weight of landingstring 19 andcasing string 35 may range from 950,000 to 2,300,000 pounds. In the future, as deeper wells are drilled in deeper water, it is expected that the present invention may be supporting combined landing string and casing string weight of 4,000,000 pounds or more.
• Figure 1 depicts the installation or "running" ofintermediate casing string 35, which will be lowered longitudinally, through blowout preventors 15 andsurface casing 32, into position inborehole 24. Although figure 1 shows surface casing 32 already cemented into position inborehole 24, it should be understood that the present invention may not only be used to run intermediate casing, but surface and production casing as well. It should also be understood that the present invention, in addition to being used to land casing strings, may also be used to land any other items on or below the sea floor such as blow out preventors, subsea production facilities, subsea wellheads, production strings, drill pipe and drill bits. It should be specifically understood thatdrill pipe 18 of the present invention may be used in the drilling operation, with drilling fluid being circulated through thelumen 23 ofdrill pipe 18.
• In order to lower casingstring 35 from the position shown in figure 1 intoborehole 24, additional joints ofdrill pipe 18 are added, usually 1 to 4 at a time, above the joint ofdrill pipe 18 being held byholder 100, as shown in figure 10. Figure 10 shows three additional joints ofdrill pipe 18 about to be added, although it should be understood that the number of joints of drill pipe added at a time may vary.
• After the additional joint or joints ofdrill pipe 18 have been attached, as shown in figure 11, landingstring 19 and attachedcasing string 35 may be lowered by a distance roughly equivalent to the length of the newly added joints of drill pipe. This is accomplished viaupper holder 200 of the present invention, as depicted in figure 11.Upper holder 200 is supported by elevator bails or "links" 210 which in turn are attached to the rig lifting system (not shown).Upper holder 200 includesamain body 204 having anopening 203 which may accommodate the passage ofdrill pipe 18 therethrough. Theopening 203 ofmain body 204 has a taperedinner face 205 which defines a tapered bowl, as best shown in figure 13.
• Upper holder 200 also includes one ormore wedge members 206 having a taperedouter face 207 which corresponds with the taperedinner face 205 ofmain body 204. The tapered bowl inmain body 204 defined by its taperedinner face 205 receiveswedge members 206 as shown in figures 11 and 12.Wedge members 206 of the present invention are preferably three in number and are preferably connected by hinges, similar towedge members 106 as depicted in figures 5 and 7.
• Wedge members 206 ofupper holder 200 are preferably shaped and configured similar towedge members 106 oflower holder 100, although there may be slight variations in size and/or dimensions betweenwedge members 106 and 206. Similar to taperedshoulder 109 ofwedge member 106 as depicted in figures 6 through 8, the inner side ofwedge member 206 has a taperedshoulder 209. As shown in fig. 11, taperedshoulder 209 ofwedge member 206 corresponds with taperedshoulder 20a ofbox end 20ofdrill pipe 18. Similar to taperedshoulder 109 ofwedge member 106, taperedshoulder 209 ofwedge member 206 is curved to correspond with and accommodate the curved, circumferential shape ofshoulder 20a ofbox end 20.
• Whenwedge members 206 are in place inmain body 204, as shown in figure 12, the engagement betweenshoulder 209 ofwedge member 206 andshoulder 20a ofbox end 20 ofdrill pipe 18 being held byholder 200 provides support for saiddrill pipe 18 being held byholder 200.
• Similar to curved surface 106a on the inner side ofwedge member 106 as shown in figures 7 and 8, the inner side ofwedge member 206 also has a curved surface 206a which corresponds with and accommodates the curvedouter surface 18a ofdrill pipe 18. Similar to curved surface 106b on the inner side ofwedge member 106 as best shown in figures 7 and 8, the inner side ofwedge member 206 also has a curved surface 206b which corresponds with and accommodates the curved outer surface 20b ofbox end 20 ofdrill pipe 18.
• Whenwedge members 206 are in place inmain body 204 ofupper holder 200, as shown in figure 12, said wedge members form an interface betweenbody 204 and the joint ofdrill pipe 18 being held byholder 200. In that position, as depicted in figure 12, the rig lifting system (not shown) can be used to slightly liftupper holder 200. When that happens,upper holder 200 is supporting the entire load including thelanding string 19 andcasing string 35, thereby taking theload offwedge members 106 oflower holder 100.Wedge members 106 can then be disengaged, i.e., wholly or partially moved up and away fromdrill pipe 18, providing sufficient clearance for thelanding string 19 to pass unimpeded through theopening 103 inmain body 104 oflower holder 100.
• The rig lifting system may then be used to lowerupper holder 200, along with the landing string and casing string it is supporting, by a distance roughly equivalent to the length of the newly added joints of drill pipe. More specifically,upper holder 200 is lowered until the uppermostenlarged diameter section 21 of newly addeddrill pipe 18 is located a distance abovemain body 104 ofholder 100 sufficient to provide the vertical clearance needed for reinsertion ofwedge members 106 inmain body 104, as shown in fig. 15. At that point,wedge members 106 oflower holder 100 may be placed back into position inmain body 104 ofholder 100.Upper holder 200 may then be slightly lowered further so as to bring into supportingengagement shoulder 109 ofwedge members 106 withshoulder 21 a of the uppermostenlarged diameter section 21 of newly addeddrill pipe 19, as shown in fig. 16. In this fashion, the entire load including the landing string and the casing string is transferred fromupper holder 200 tolower holder 100.
• Upper holder 200 can then be cleared away from the uppermost end of the landing string. This is accomplished by loweringholder 200 slightly such thatwedge members 206 can be disengaged, i.e., moved up and away frombox end 20 that was previously being held byholder 200, as shown in fig.16.Holder 200 can then be hoisted up by the rig lifting system, permitting clearance for yet additional joints of drill pipe to be added to the upper end of the landing string.
• As this process is repeated over and over again, casingstring 35 is lowered further and further. This process continues until such time ascasing string 35 reaches its proper location inborehole 24, at which point the overall length of landingstring 19 spans the distance betweenrig 8 andundersea well 14.
• It should be understood that the rig lifting system referenced herein may be a conventional system available in the industry, such as a National Oilwell 2040-UDBE draworks, a Dreco model "872TB-1250" traveling block and a Varco-BJ "DYNAPLEX" hook, model 51000, said system being capable of handling in excess of 2,000,000 pounds (907,200 kilograms).
• Some rigs have specialized equipment to hold aloft additional joints of drill pipe as they are being added to the landing string. However, for those rigs that do not have such specialized equipment, the present invention provides for auxiliaryupper holder 300, as shown in figures 10 and 11.Auxiliary holder 300 is suspended belowupper holder 200 byconnectors 301.Connectors 301 may be cables, links, bails, slings or other mechanical devices which serve to connectauxiliary holder 300 toupper holder 200.
• Auxiliary holder 300 has amain body 304 which can be moved from an opened to a closed position, allowing it to capture and hold aloft the joints ofdrill pipe 18 to be added to the pipe string, as shown in fig. 10. The inner surface ofmain body 304 includes a tapered shoulder which corresponds with taperedshoulder 21a. The inner surface ofmain body 304 is sized to accommodatedrill pipe 18 such that whenmain body 304 is in its closed position and supporting the joints of drill pipe to be added, as shown in figure 10, the tapered shoulder ofmain body 304 engages taperedshoulder 21a, providing support for the joints of drill pipe being added. Whenupper holder 200 is to be used to lower the entire load to the position shown in figure 15,auxiliary holder 300 can be swung back, up and out of the way, so that it does not interfere withlower holder 100. Because the combined weight of the relatively few joints of drill pipe being added at any one time is significantly less than the combined weight of the landing string and the casing string extending below the rig, the size and strength of auxiliaryupper holder 300 may be substantially less than that ofupper holder 200.Auxiliary holder 300 may be a conventional elevator available in the industry, such as the 25-ton model "MG" manufactured by Access Oil Tools.
• It should be understood that while the present invention is particularly useful for landing casing strings and other items, the invention may also be used to retrieve items. For example, the invention may be employed to retrieve the landing string and any items attached thereto, such as a drill bit, in an operation commonly referred to as "tripping out of the hole," wherein the operations described hereinabove are essentially reversed. While the landing string is being supported bylower holder 100, as shown in figure 16,upper holder 200 is lowered to the position shown in figure 16.Wedge members 206 may then be lowered intomain body 204 ofupper holder 200 so thatshoulder 209 ofwedge member 206 is brought into supporting engagement withshoulder 20a ofbox end 20.
• At that point, the rig lifting system may be used to liftholder 200, thereby transferring the landing string load fromlower holder 100 toupper holder 200. This allowswedge members 106 oflower holder 100 to be wholly or partially moved up and away fromdrill pipe 18, providing sufficient clearance forpipe string 19 to pass unimpeded through theopening 103 inmain body 104.
• When tripping out of the hole, it is common practice to pull up two or more joints at a time, as would be the case shown in figure 12. The landing string would be pulled up byupper holder 200 such that theenlarged diameter section 21 of the drill pipe to be held bylower holder 100 is slightly abovewedge members 106, as is shown in figure 12. At that point,wedge members 106 would be lowered into position inmain body 104.Upper holder 200 may then be slightly lowered further so as to bring into supportingengagement shoulder 109 ofwedge member 106 withshoulder 21 a ofenlarged diameter section 21 of the drill pipe being held inholder 100. In this fashion, the entire load is transferred tolower holder 100, permitting the drill pipe that has been pulled up aboveholder 100 to be detached from the landing string, as would appear in figure 10. The removed joints of drill pipe would then be cleared from the upper holder and placed on the drilling rig, permittingupper holder 200 to be lowered again so that more joints of drill pipe could be pulled up, as this process is repeated over and over again until all of the landing string and the items attached thereto have been retrieved.
• As shown in figures 2 - 4,drill pipe 18 of the present invention has the following exemplary dimensions:
• The end outside diameter (E.O.D.) ofpin end 22 andbox end 20 is preferably in the range between about 6 ½ to 9 7/8 inches (16.51 to 25.0825 centimeters), and most preferably between 7 ½ and 8 inches (19.05 to 20.32 centimeters).
• The end wall thickness (E.W.T.) ofpin end 22 andbox end 20 is preferably in the range between about 1 1/2 to 3 inches (3.81 to 7.62 centimeters), and most preferably between 2 1/4 and 2 3/8 inches (5.715 to 6.0325 centimters).
• The pipe inside diameter (P.I.D.), i.e., the diameter of the uniform bore orlumen 23 extending throughout the length ofdrill pipe 18, is preferably in the range between about 2 to 6 inches (5.08 to 15.24 centimeters), and most preferably between 2 1 /3 and 3 1/2 inches (5.9267 to 8.89 centimeters).
• The pipe wall thickness (P.W.T.), i.e., the thickness of the pipe wall throughout the length ofdrill pipe 18, except at the ends and at the enlarged diameter section, is preferably in the range between about 5/8 to 2 inches (1.5875 to 5.08 centimeters), and most preferably between 1 and 1 1/2 inches (2.54 to 3.81 centimeters).
• The pipe outside diameter (P.O.D.), i.e., the outside diameter ofdrill pipe 18 throughout its length, except at the ends and atenlarged diameter section 21, is preferably in the range between about 4 1/2 to 7 5/8 inches (11.43 to 19.3675 centimeters), and most preferably between 5 and 6 5/8 inches (12.7 to 16.8275 centimeters).
• The enlarged diameter wall thickness (E.D.W.T.), i.e., the thickness of the pipe wall atenlarged diameter section 21, is preferably in the range between about 1 1/2 to 3 inches (3.81 to 7.62 centimeters), and most preferably between 2 1/4 and 2 3/8 inches (5.715 to 6.0325 centimeters).
• The length "L" ofdrill pipe 18 is preferably in the range between about 28 to 45 feet (8.5344 to 13.716 meters), and most preferably between 28 and 32 feet (8.5344 to 9.7536 meters). It should be understood that length "L" may be any length that can be accommodated by the vertical distance between the rig floor and the highest point of the rig.
• The length of the enlarged diameter section (L. E.) is preferably in the range between about 1 to 60 inches (2.54 to 152.4 centimeters), and most preferably between 6 and 12 inches (15.24 to 30.48 centimeters).
• The distance "D" betweenshoulder 21a andshoulder 20a is preferably in the range between about 2 to 11 feet (0.6096 to 3.3528 meters), most preferably between 3 to 5 feet (0.9144 to 1.524 meters). The design criteria for distance "D" include the following: (a) the distance "D" should be sufficient to provide adequate clearance, and thereby avoid entanglement, between the bottom ofholder 200 and the top ofholder 100 when said holders are in the position depicted in fig. 16; (b) the distance "D" should also be sufficient to permit insertion and removal ofwedge members 206 into and out of the tapered bowl ofupper holder 200; and (c) the distance "D" should preferably be such that the uppermost end of the drill pipe being supported bylower holder 100 is a reasonable working height (R.W.H.) above rig floor 9, as shown in fig. 10, so as to permit rig personnel and/or automated handling equipment to assist in attaching or removing joints of drill pipe to or from said uppermost end.
• The angle of taper "A" ofshoulders 21a, 20a and 22a, which appear in figures 3 and 4, can be any angle greater than 0° and less than 180°, preferably between 10 degrees and 45 degrees, and most preferably 18 degrees. The same angle "A" applies to the angle of taper ofshoulder 109 ofwedge member 106 andshoulder 209 ofwedge member 206, as shown in fig. 6.
• As shown in figures 6 and 7,wedge members 106 and 206 of the present invention have the following exemplary dimensions:
• The height ("H-1") of the wedge members is preferably in the range of about 5 to 20 inches (12.7 to 50.8 centimeters), and most preferably between 8 and 16 inches (20.32 to 40.64 centimeters).
• The distance ("H-2") between the top of the wedge members andshoulders 109, 209 is preferably in the range of about 2 to 10 inches (5.08 to 25.4 centimeters), and most preferably between 3 and 8 inches (7.62 to 20.32 centimeters).
• The distance ("H-3 ") between the bottom of the wedge members andshoulders 109, 209 is preferably in the range of about 3 to 10 inches (7.62 to 25.4 centimeters), and most preferably between 5 and 8 inches (12.7 to 20.32 centimeters).
• The top thickness ("T-1") of the wedge members is preferably in the range of about 1 to 8 inches (2.54 to 20.32 centimeters), and most preferably between 2 and 6 inches (5.08 to 15.24 centimeters).
• The thickness ("T-2") of the wedge members atshoulders 109, 209 is preferably in the range of about 1 1/2 to 8 1/2 inches (3.81 to 21.59 centimeters), and most preferably between 2 1/2 and 6 1/2 inches (6.35 to 16.51 centimeters).
• The bottom thickness ("T-3") of the wedge members is preferably in the range of about 1/2 to 6 inches (1.27 to 15.24 centimeters), and most preferably between 1 and 4 inches (2.54 to 10.16 centimeters).
• The angle of taper ("A.T.") of outer face 107,207 of the wedge members can be any angle greater than 0° and less than 180°, preferably between 10 degrees and 45 degrees.
• As shown in figure 14,upper holder 200 of the present invention has the following exemplary dimensions:
• The height of holder 200 ("H.H.") is preferably in the range of about 18 to 72 inches 45.72 to 182.88 centimeters), and most preferably between 24 and 48 inches (60.96 to 121.92 centimeters).
• The width of holder 200 ("W-1") is preferably in the range of about 24 to 72 inches (60.96 to 182.88 centimeters), and most preferably between 36 and 60 inches (91.44 to 152.4 centimeters).
• The width of the top of opening 203 ("W-2") ofholder 200 is preferably in the range of about 12 to 24 inches (30.48 to 60.96 centimeters), and most preferably between 16 and 21 inches (40.64 to 53.34 centimeters).
• The width of the bottom of opening 203 ("W-3") ofholder 200 is preferably in the range of about 6 to 18 inches (15.24 to 45.72 centimeters), and most preferably between 9 and 15 inches (22.86 to 38.1 centimeters).
• Figure 9 depicts an alternative embodiment of the present invention wherein the shoulders, forexample shoulders 21a and 20a, are square, i.e., wherein angle "A" measures 90 degrees. In that alternative embodiment as depicted in figure 9, theshoulders 109 and 209, respectively, ofwedge members 106 and 206, respectively, are also square.
• In the preferred embodiment of the invention as depicted in figure 12,wedge members 106 are lifted out of position by a lifting apparatus which includes liftingarms 112. Liftingarms 112 may be raised and lowered by way of anactuator 114, preferably a pneumatic or hydraulic piston-cylinder arrangement. Liftingarms 112 may be attached directly to wedgemembers 106 or via connectors 111 as shown in figure 12. Connectors 111 may be cables, links, bails, slings or other mechanical devices which serve to connect liftingarms 112 to wedgemembers 106.Wedge members 106 preferably include liftingeye 115 to facilitate the connection to liftingarms 112. It should be understood that the raising and loweringwedges 106 out of and into position inbody 104 can be accomplished in a variety of ways, including manual handling by rig personnel. It should also be understood that the lifting apparatus for raising and loweringwedge members 106 must be sized and configured so as to permit sufficient clearance forupper holder 200 when it is in the position shown in figures 15 and 16.
• As depicted in figures 11 and 12,upper holder 200 preferably includes a lifting apparatus for raising and loweringwedge members 206 out of and into position inmain body 204. In the preferred embodiment of the invention as depicted in figure 12, the lifting apparatus includes liftingarms 212. Liftingarms 212 may be moved up and down byactuator 214, preferably a hydraulic or pneumatic piston-cylinder arrangement. Liftingarms 212 may be attached directly to wedgemembers 206 or viaconnectors 211.Connector 211 may be cables, links, bails, slings or other mechanical devices which serve to connect liftingarms 212 to wedgemembers 206.Wedge members 206 preferably include lifting eyes 215 to facilitate the connection to liftingarms 212.
• In the preferred embodiment of the invention as shown in figure 13,upper holder 200 is removably attached to elevator links 210.Main body 204 ofupper holder 200 is preferably comprised of steel having recessedareas 220 to accommodate therein placement of elevator linkeyes 221.Elevator link eyes 221 are retained in the position shown in figures 13 and 14 bylink retainers 222.Link retainers 222 may be moved from the closed position shown in figure 14 to an open position by lifting release pins 224, thereby permittingretainer links 222 to pivot abouthinge pin 225 to an open position, thus permitting removal ofupper holder 200 from elevator links 210. As best depicted in figure 12,upper holder 200 is also provided with liftingeyes 230 to whichconnectors 301 may be attached.
• Figures 17 and 18 depict an alternative embodiment of the present invention in which enlargeddiameter section 21 is not enlarged completely around the circumference ofdrill pipe 18. In this alternative embodiment ofenlarged diameter section 21, shown in cross section in figure 18, there may be one or more cross sectional gaps insection 21 where the diameter is not enlarged.
• In the preferred embodiment of the invention,drill pipe 18, includingbox end 20, enlargeddiameter section 21 andpin end 22, is made from a single piece of pipe of uniform wall thickness having the dimension E.W.T. in figure 4, said thickness being reduced at intervals along the pipe by milling betweenbox end 20 andenlarged diameter section 21, and by milling betweenpin end 22 andenlarged diameter section 21. It should be understood that in such preferred embodiment of the invention, box and pin ends 20 and 22 andenlarged diameter section 21 are integral with the pipe, i.e.,box end 20 and pin end 22 are not created by welding or otherwise attaching said ends to drillpipe 18, nor isenlarged diameter section 21 created through welding or other means of attachment. In the preferred embodiment of the invention, each joint ofdrill pipe 18 is made of steel and weighs between 800 to 5,000 pounds (362.88 to 2,268 kilograms), most preferably between 1,000 to 2,000 pounds (453.6 to 907.2 kilograms), or approximately 29 to 110 pounds per linear foot (43.152 to 163.68 kilogram per meter), most preferably 32 to 75 pounds per linear foot (47.616 to 111.6 kilograms per meter).
• Alternatively,drill pipe 18 of the present invention may be made of a piece of pipe of uniform thickness, referenced as P.W.T. in fig. 4, with attached box and pin ends, and with an attachedenlarged diameter section 21. In this alternative embodiment, the box end, pin end and enlarged diameter section may be attached to the pipe by welding, bolting or other means.
• In a further alternative embodiment of the present invention,drill pipe 18 may be made from titanium or from a carbon graphite composite.
• Figures 19 and 21 show further alternative embodiments of the present invention in whichdrill pipe 18, having a length "L", is comprised of two separate drill pipes, 18S and 18L, the former being shorter than the latter, each one having afemale end 20 and amale end 22. As shown in figures 19 and 21, 18S is attached end-to-end with 18L. In the alternative embodiment depicted in fig. 19, the matedmale end 22 andfemale end 20 combine to formenlarged diameter section 21, having a taperedshoulder 21 a defined by the tapered shoulder of matedfemale end 20. In the alternative embodiment depicted in figure 21, the matedfemale end 20 serves asenlarged diameter section 21, with the shoulder of said mated female end serving asshoulder 21 a.
• In yet a further alternative embodiment of the present invention shown in figure 22, an extratapered shoulder 25 is provided ondrill pipe 18 betweenenlarged diameter section 21 and the end of the drill pipe. In this embodiment of the invention, extra taperedshoulder 25 has an angle of taper "A" that corresponds with and is engaged byshoulder 209 ofwedge members 206, thereby providing support for the drill pipe being held byupper holder 200. In this embodiment, "D" is the distance betweenshoulder 21 a andshoulder 25.
• The distance "D", the angle "A" and the length "L" in the alternative embodiment shown in figures 17, 19, 21 and 22 are comparable to those of the preferred embodiment as shown in figure 3.
• Figure 23 depicts a further alternative embodiment ofwedge members 106, 206 in accordance with the present invention. The dimensions H-1, H-2, H-3, T-1, T-2 and T-3, and the angles A and A.T. in the alternative embodiment shown in figure 23 are comparable to those of the embodiment as shown in figure 6.
• It should be understood that in an alternative embodiment of the present invention, the drill pipe may be run with the male or pinend 22 up and the female orbox end 20 down, as depicted in fig. 20. In this alternative embodiment of the invention, taperedshoulder 209 ofwedge member 206 corresponds with taperedshoulder 22a ofpin end 22 ofdrill pipe 18;shoulder 209 is curved to correspond with and accommodate the curved, circumferential shape ofshoulder 22a; and curved surface 206b ofwedge member 206 corresponds with and accommodates the curved outer surface 22b ofdrill pipe 18.
• Crossover connection 36 depicted in figure 1 may include an "SB" Casing Hanger Running Tool in conjunction with an "SB" Casing Hanger, all manufactured by Kvaerner National Oilfield Products.
• It should be understood thatdrilling rig 8 includes a drill platform having floor 9 with a work area for the rig personnel who assist in the various operations described herein. Although figure 1 showsdrilling rig 8 situated on adrill ship 10, it should be understood that the present invention may be used on drilling rigs situated on platforms that are permanently affixed to the sea floor, or on semi-submersible and other types of deep water rigs. Moreover, although the invention is particularly useful for rigs drilling in deep water, the invention may also be used with shallow-water rigs and with rigs drilling on land.
• The following table lists the part numbers and part descriptions as used herein and in the drawings attached hereto:
PARTS LIST

• PART NUMBER	DESCRIPTION
  5	invention in general overview
  8	drilling rig
  9	drilling rig floor
  10	drill ship
  11	opening in drilling rig floor
  12	surface of ocean
  14	undersea well
  15	blowout preventors
  16	sea floor
  17	riser
  18	drill pipe
  18a	curved outer surface of drill pipe
  18S	shorter joint of drill pipe of alternative embodiment
  18L	longer joint of drill pipe of alternative embodiment
  19	landing string
  20	box (female) end of drill pipe
  20a	tapered shoulder of box end
  20b	curved outer surface of box end
  21	enlarged diameter section of drill pipe
  21a	supporting shoulder of enlarged diameter section
  21 b	curved outer surface of enlarged diameter section
  22	pin (male) end of drill pipe
  22a	tapered shoulder of pin end
  22b	curved outer surface of pin end
  23	lumen of drill pipe 18
  24	borehole
  25	extra tapered shoulder
  26	earthen formation
  28	wall of borehole
  32	surface casing
  34	intermediate casing
  35	casing string
  36	crossover connection
  100	lower holder
  103	opening in main body 104
  104	main body of lower holder
  105	tapered inner face of main body 104
  106	wedge members of lower holder
  106a	curved inner surface of wedge member 106 accommodating drill pipe
  106b	curved inner surface of wedge member 106 accommodating enlarged diameter section 21
  107	tapered outer face of wedge members 106
  108	hinges connecting wedge members
  109	tapered shoulder of wedge members 106
  111	connectors between wedge members 106 and lifting arms 112
  112	lifting arms for lifting wedge members 106
  114	actuator for moving lifting arm 112
  115	lifting eye on wedge member 106
  200	upper holder
  203	opening in main body of upper holder
  204	main body of upper holder
  205	tapered inner face of main body 204
  206	wedge members of upper holder
  206a	curved inner surface of wedge member 206 accommodating drill pipe
  206b	curved inner surface of wedge member 206 accommodating end of drill pipe
  207	tapered outer face of wedge member 206
  209	tapered shoulder of wedge member 206
  210	elevator links
  211	connectors between wedge member 206 and lifting arms 212
  212	lifting arm for lifting wedge member 206
  214	actuator for moving lifting arm 212
  215	lifting eye on wedge member 206
  220	recessed area of upper holder
  221	eye of elevator link
  222	elevator link retainer
  224	release pin
  225	hinge
  230	lifting eyes to support auxiliary upper holder
  300	auxiliary upper holder
  301	connectors for auxiliary holder 300
  304	main body of holder 300

• The following table lists and describes the dimensions used herein and in the drawings attached hereto:
DIMENSION LIST

• DIMENSION	DESCRIPTION
  E.O.D.	end outside diameter of pin end and box end of drill pipe
  E.W.T.	end wall thickness of pin end and box end of drill pipe
  P.I.D.	pipe inside diameter
  P.W.T.	pipe wall thickness
  P.O.D.	pipe outside diameter
  E.D.W.T.	enlarged diameter wall thickness
  R.W.H.	reasonable working height of box end above rig floor
  L	length of drill pipe
  D	distance between supporting shoulders
  A	angle of shoulder taper
  LE	length of enlarged diameter section
  T-1	top thickness of the wedge member
  T-2	thickness of the wedge member at the shoulder
  T-3	bottom thickness of the wedge member
  H-1	height of the wedge member
  H-2	distance between the top of the wedge member and the shoulder
  H-3	distance between the bottom of the wedge member and the shoulder
  A.T.	Angle of taper of the outer face of the wedge member
  H.H.	Height of upper holder
  W-1	width of upper holder
  W-2	width of top of opening of upper holder
  W-3	width of bottom of opening of upper holder

• The foregoing embodiments are presented by way of example only; the scope of the present invention is to be limited only by the following claims:

Claims (61)

1. A drill pipe support apparatus, comprising:

   a) a landing string (19) comprised of a number of joints of drill pipe (18) connected end to end; and

   b) a drill pipe holder (100) that supports a joint of drill pipe (18) in the landing string (19) and supports the landing string (19);

   characterised in that:

   each joint of pipe (18) has pin (22) and box (20) end portions, and at least a plurality of the joints have an enlarged diameter section (21) spaced in between the pin and box end, the enlarged diameter section (21) having an annular shoulder (21a);

   the holder (100) and the joint of drill pipe (18) that is held by the holder (100) are configured to support the load of the landing string (19) at the enlarged diameter section (21) during the addition or removal of a joint of drill pipe (18) by way of the annular shoulder (21a) abutting a correspondingly shaped annular shoulder (109) of the holder (100) when the holder (100) holds the joint of drill pipe (18); and

   the holder (100) includes a main body (104) and a plurality of wedge members (106), the wedge members forming an interface between the body (104) and the joint of drill pipe (18) being held by the holder (100 or 200).
2. The drill pipe support apparatus of claim 1, wherein each of the joints of pipe (18) has an enlarged diameter section (21).
3. The drill pipe support apparatus of claim 1 or 2, further comprising a drilling rig (8) having a floor (9), wherein the drill pipe holder (100) is located on the floor (9).
4. The drill pipe support apparatus of claim 1 or 2, further comprising a drill platform having a floor with a work area, wherein the drill pipe holder (100) is located on the floor and wherein the shoulders (109) are tapered.
5. The drill pipe support apparatus of any preceding claim, wherein each joint of pipe (18) includes enlarged diameter pin (22) and box (20) end portions, the enlarged diameter section (21) is spaced in between the pin and box end portions, but closer to the box end portion (22), and the shoulder (21a) of the enlarged diameter section (21) has a taper which corresponds to a taper in the holder.
6. The drill pipe support apparatus of any preceding claim, wherein the drill pipe holder (100) holds and supports a joint of drill pipe (18) in the landing string (19).
7. The drill pipe support apparatus of any preceding claim, further comprising a second holder (200) that provides support for the landing string (19), wherein the holder (100) is a lower holder (100) positioned near the rig floor (9) that holds a joint of drill pipe (18) in the landing string (19) and supports the landing string (19) during the addition or removal of a joint of drill pipe (18) to or from the landing string (19), and the second holder (200) being an upper holder (200) that can hold a joint of drill pipe (18) in the landing string (19) and support the landing string (19) after ajoint of drill pipe (18) has been added to or removed from the landing string (19); the second holder (200) including a main body (204) and a plurality of wedge members (206), the wedge members (206) of the second holder (200) forming an interface between the body (204) of the second holder (200) and the joint of drill pipe (18) being held by the second holder (200), each wedge member (206) of the second holder (200) having a shoulder (209) that corresponds in shape to the shoulder (219) of the enlarged diameter section (21) of the joint of drill pipe (18) being held by the second holder (200).
8. The drill pipe support apparatus of any one of claims 1 to 6, further comprising a second holder (200) vertically spaced apart from the holder (100), the second holder (200) can support the landing string (19) after a joint of drill pipe (18) has been added to or removed from the landing string (19); the second holder (200) including a main body (204) and a plurality of wedge members (206), the wedge members (206) of the second holder (200) forming an interface between the body (204) of the second holder (200) and the joint of drill pipe (18) being held by the second holder (200), each wedge member (206) of the second holder (200) having a shoulder (209) that corresponds in shape to the shoulder (219) of the enlarged diameter section (21) of the joint of drill pipe (18) being held by the second holder (200) and wherein each joint of pipe (18) having generally cylindrically shaped pin (22) and box (20) end portions, and a generally cylindrically shaped smaller diameter portion that extends over a majority of the length of each joint (18).
9. The drill pipe support apparatus of claim 8, wherein one of the holders (100, 200) has a body (104, 204) that is movable in a vertical direction during use.
10. The drill pipe support apparatus of any preceding claim, wherein at least one holder (100, 200) does not have teeth.
11. The drill pipe support apparatus of any preceding claim, further comprising a casing string (35) supported by the landing string (19).
12. The drill pipe support apparatus of claim 11, wherein the landing string (19) and casing string (35) are configured so that the overall combined length of the landing string (19) and casing string (35) spans the distance between the drilling rig (8) and the well (14) location.
13. The drill pipe support apparatus of claim 11 or 12, wherein the combined weight of the landing string (19) and casing string (35) is between about 430,000 and 1,050,000 kilograms.
14. The drill pipe support apparatus of claim 11 or 12, wherein the combined weight of the landing string (19) and casing string (35) is between about 360,000 and 1,820,000 kilograms.
15. The drill pipe support apparatus of any preceding claim, wherein the wedge members (106, 206) do not have teeth that bite into the surface of the drill pipe (18).
16. The drill pipe support apparatus of any preceding claim, wherein each joint of pipe (18) has a pin end (22) and a box end (20), and wherein the holder (100) has a tapered bowl that receives the wedge members (106) and each of the wedge members (106) has an interior surface with a curved shoulder (109) that engages a correspondingly shaped curved shoulder (21 a) on the drill pipe (18) being held by the holder (100) at a position spaced apart from the box (20) or pin end (22) of the drill pipe (18).
17. The drill pipe support apparatus of any preceding claim, wherein each wedge member (106) has a shoulder (109), the shoulders of the wedge members (106) engaging the shoulder (21 a) of the drill pipe (18) being held by the holder (100).
18. The drill pipe support apparatus of any preceding claim, wherein each pipe joint has a pin end (22) and a box end (20) and an enlarged diameter section (21), and wherein the enlarged diameter section (21) is spaced between 30 and 250 centimetres from the box (20) or pin (22) ends.
19. The drill pipe support apparatus of claim 18, wherein at least one of the ends (20, 22) of the pipe joint and the enlarged diameter section (21) have correspondingly shaped shoulders (20a, 22a, 21 a).
20. The drill pipe support apparatus of claim 18, wherein both of the ends (20, 22) of the pipe joint and the enlarged diameter section (21) have correspondingly shaped shoulders (20a, 22a, 21a).
21. The drill pipe support apparatus of any preceding claim, wherein each joint of pipe has a weight of between about 43 and 164 kilograms per linear metre.
22. The drill pipe support apparatus of any preceding claim, wherein the shoulders (21a) on the enlarged diameter section (21) form an angle of between about 10 and 45 degrees with the central longitudinal axis of each joint of pipe.
23. The drill pipe support apparatus of claim 7 or 8 or any claim depending therefrom, wherein the shoulders (109) on the wedge members (106) form an angle of between about 10 and 45 degrees with the central longitudinal axis of the joint of pipe (18) being held by the holder (100).
24. The drill pipe support apparatus of any preceding claim, wherein each joint (20, 22) of pipe (18) has a pipe outside diameter of between about 11 and 20 centimetres.
25. The drill pipe support apparatus of claim 11 or any claim depending therefrom, wherein the drilling rig (8) is a drill ship (10) and the combination of landing string (19) and casing string (35) are configured so that at least a majority of the combined overall length of the landing string (18) and casing string (35) spans the distance between the drill ship (10) and the undersea well (14) location at the seabed (16) during use.
26. The drill pipe support apparatus of claim 2 or any claim depending therefrom, wherein the enlarged diameter section is spaced between about 30 and 92 centimetres from one of the pin (22) or box (20) end portions.
27. The drill pipe support apparatus of claim 11, wherein the combined mass of the landing string (19) and the casing string (35) exceeds 450,000 kilograms.
28. The drill pipe support apparatus of claim 7 or any claim depending therefrom, wherein the upper holder (200) has a lifting apparatus for moving the wedges (206) relative to the main body (204) of the holder (200).
29. The drill pipe support apparatus of claim 7 or any claim depending therefrom, wherein the lower holder (100) has a lifting apparatus for moving the wedges (106) relative to the main body (104) of the holder (100).
30. The drill pipe support apparatus of claim 28 or 29, wherein the lifting apparatus is powered with pressurized fluid.
31. The drill pipe support apparatus of any preceding claim, wherein each wedge member (106) has an inner curved surface (106a, 106b, 109) that corresponds with and accommodates the outer curved surface of the drill pipe (18) being held by the holder (100).
32. The drill pipe support apparatus of any preceding claim, wherein the plurality of wedges (106) in an engaged position define a shape that corresponds with and accommodates the shape of the enlarged diameter section (21) of the drill pipe being held by the holder (100).
33. The drill pipe support apparatus of claim 32, wherein the plurality of wedges (106) in an engaged position define a shape that corresponds with and accommodates the shape of the held drill pipe (18) below the enlarged diameter section (21).
34. The drill pipe support apparatus of any preceding claim, wherein there are three wedges (106) included with each holder (100).
35. The drill pipe support apparatus of any preceding claim, wherein the drill pipe (18) wall thickness is between about 1.5 and 5.1 centimetres.
36. The drill pipe support apparatus of any preceding claim, wherein the enlarged diameter (21) wall thickness is between about 3.8 and 7.7 centimetres.
37. The drill pipe support apparatus of any one of claims 1 to 35, wherein the enlarged diameter (21) wall thickness is between 3.3 and 7.7 centimetres.
38. The drill pipe support apparatus of any preceding claim, wherein at least one holder (100) has a main body (104) that has an opening through which a joint of the drill pipe (18) can pass when the wedge members (106) are disengaged.
39. A method of landing items at a well (14) location, comprising the steps of:

    a) positioning a drilling rig (8) above a well (14) location, the drilling rig (8) having a landing string (19) that is comprised of a number of joints of drill pipe (18), and a holder (100) that holds the drill pipe (18) in the landing string (19) for supporting the landing string (19); and

    b) lowering the landing string (19) such that it spans at least a majority of the distance between the drilling rig (8) and the well (14) location;

    characterised in that:

    each joint of pipe (18) is provided with pin (22) and box (20) end portions, and at least a plurality of the joints is provided with an enlarged diameter section (21) spaced in between the pin and box end, the enlarged diameter section (21) having an annular shoulder (21a);

    the holder (100) is assembled by locating a plurality of wedge members (106) in an opening (103) of a main body (104), the wedge members (106) forming an interface between the main body (104) and the joint of drill pipe (18);

    the wedge members (106) have shoulders (109) which together form an annular shoulder against which the annular shoulder (21a) of the enlarged diameter section (21) abuts so as to support the joint of drill pipe (18).
40. The method of claim 39, further comprising the step of attaching an item to a lower end of the landing string (19).
41. The method of claim 39 or 40, further comprising the steps of:

    (c) lowering a plurality of connected joints of casing to the well (104), said plurality of connected joints of casing defining a casing string (35), the casing string (35) being supported by a lower end portion of the landing string (19); and

    (d) configuring the combination of landing string (19) and casing string (35) so that the overall, combined length of the landing string (19) and casing string (35) spans at least a majority of a distance between the drilling rig (8) and well (14) location.
42. The method of any one of claims 39 to 41, wherein the drilling rig (8) includes a lifting device and further comprising the step of supporting the landing string (19) with the lifting device.
43. The method of claim 41 or any claim depending therefrom, wherein the combined weight of landing string (19) and casing string (35) is between about 430,000 and 1,050,000 kilograms.
44. The method of claim 41 or any claim depending therefrom, wherein the landing string (19) in step (a) has upper and lower end portions, the casing string (35) being supported by the lower end portion of the landing string (19).
45. The method of claim 41 or any claim depending therefrom, wherein the landing string (19) in step (b) spans a distance between the drilling rig (8) and the well (14) location, and wherein an uppermost joint of drill pipe (18) that is supported by the holder (100) are configured to support the load with correspondingly shaped tapered annular shoulders (21a) that engage when the holder (100) supports the uppermost joint of drill pipe (18).
46. The method of any one of claims 39 to 45, wherein the holder (100) does not have teeth.
47. The method of any one of claims 39 to 45, wherein the holder (100) does not have teeth that bite into and deform the surface of the drill pipe (18).
48. The method of any one of claims 39 to 47, wherein the holder (100) includes a main body (104) and a plurality of wedge members (106), the wedge members (106) forming an interface between the body (104) and the joint of drill pipe (18) being held by the holder (100).
49. The method of any one of claims 39 to 47, wherein the holder (100) includes a main body (104) and a plurality of wedge members (106), the wedge members (106) forming an interface between the body (104) and the joint of drill pipe (18) being held by the holder (100), each wedge member (106) having a shoulder (109), the shoulders (109) of the wedge members (106) engaging the shoulder (21a) of the drill pipe being held by the holder (100).
50. The method of any one of claims 39 to 49, wherein each joint of drill pipe (18) has a pin end (22) and a box end (20) and an enlarged diameter section (21), and wherein the enlarged diameter section (21) is spaced between 30 and 245 centimetres from the box (20) or pin (22) ends.
51. The method of claim 50, wherein at least one of the ends of the drill pipe (18) and the enlarged diameter section (21) have correspondingly shaped shoulders (21a).
52. The method of claim 51, wherein each joint of pipe (18) has a weight of between about 43 and 164 kilograms per linear metre.
53. The method of any one of claims 39 to 49, wherein each joint of pipe (18) has pin (22) and box (20 end portions, each with a shoulder (22a, 20a), and an enlarged diameter section (21) that is positioned between about 30 and 245 centimetres from the box (20) and pin (22) end portions.
54. The method of any one of claims 39 to 49, wherein each joint of pipe (18) has pin (22) and box (20) end portions, each with a shoulder (21 a, 20a), and an enlarged diameter section (21) that is positioned between about 61 and 92 centimetres from the box (20) and pin (22) end portions.
55. The method of claim 53 or 54, wherein the shoulder (22a, 20a) forms an angle of between 10 and 45 degrees with the central longitudinal axis of its joint of pipe (18).
56. The method of any one of claims 39 to 49, wherein each pipe joint (18) has a pin end portion (22) and a box end portion (20) and an annular enlarged diameter section (21) spaced between about 30 and 92 centimetres from one of the box (20) or pin (22) end portions.
57. The method of any one of claims 39 to 49, wherein each joint of pipe (18) has pin (22) and box (20) end portions, each with a tapered annular shoulder (22a, 20a), and the annular enlarged diameter section (21) is positioned between about 30 and 183 centimetres from the box end portion (20).
58. The method of any one of claims 39 to 49, wherein each pipe joint (18) has a pin end portion (22) and a box end portion (20) and an annular enlarged diameter section (21) spaced between 30 and 305 centimetres from one of the box (20) or pin end (22) portions.
59. The method of any one of claims 39 to 58, further comprising the step of separating the holder (100) from an engaged position with the landing string (19) after step (b).
60. The method of claim 48 or 49 or any claim depending therefrom, wherein the wedge members (106) are movable between pipe engaging and released positions, and further comprising the step of powering the wedge members (106) to move using pressurized fluid.
61. The method of claim 41 or any claim depending therefrom, wherein the plurality of joints of casing include joints of casing of differing diameters.

Images