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Publication numberUS3248130 A
Publication typeGrant
Publication dateApr 26, 1966
Filing dateApr 2, 1965
Priority dateApr 2, 1965
Publication numberUS 3248130 A, US 3248130A, US-A-3248130, US3248130 A, US3248130A
InventorsKnight Warner P
Original AssigneeKnight Warner P
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
System and method for running and hanging tubing in a well
US 3248130 A
Abstract  available in
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Claims  available in
Description  (OCR text may contain errors)

April 26, 1966 w. P. KNIGHT SYSTEM AND METHOD FOR RUNNING AND HANGING TUBING IN A WELL Filed April 2, 1965 2 Sheets-Sheet 1 n Mm w miw L MM WW W April 26, 1966 w. P. KNIGHT 3,243,130

SYSTEM AND METHOD FOR RUNNING AND HANGING TUBING IN A WELL Filed April 2, 1965 2 Sheets-Sheet 2 II E F' i 70 Q II 71 INVENTOR United States Patent 3,248 130 SYSTEM AND METHOli FOR RUNNING AND HANGING TUBING IN A WELL Warner P. Knight, Rte. 9, Box 236, Fort Worth, Tex. Filed Apr. 2, 1965, Ser. No. 463,414 1 Claim. (Cl. 285- 27) This application is a continuation-in-part of copending application, Serial No. 86,892, filed February 3, 1961, now abandoned.

This invention relates to a method and system for running tubing into a well and for suspending this tubing under tension in a sealed relationship in a tubing head so as to permit raising or lowering of the tubing relative to the tubing head while maintaining a well under control.

In-a more specific aspect, the invention is particularly useful for installing a plurality of strings of tubing in a given well. Dual completions and other multiple completions involving more than two strings of tubing in a Well have been found highly desirable in order to provide separate communication to each of a plurality of different producing zones. Multiple strings of tubing are installed in a well with packers sealing the annulus between the tubing strings and the casing in the well in order to maintain separately the production from each of the producing zones.

By way of example, where two strings of tubing are employed for producing two vertically spaced zones, general practice is to set a first packer above the lower of the zones and then to run a second packer into the well on the first string of tubing. Thereafter a second string of tubing is run into the well and connected into the second packer. Production through the first string of tubing is from a zone below the first packer, and production through the second string of tubing is from a zone between the first or lower packer and the second or upper packer.

In such installations, it has been found desirable to maintain all tubing strings in tension, that is, stretched in a manner similar to an elastic band. Diificulty has been encountered with existing equipment in setting dual or multiple tubing strings in tension not only because they may not be manipulated while the well is under pressure, but because in the initial installation it is often found necessary to cut and thread the upper end of tubing at the tubing head so that tubing hangers may be suited with the proper tension on the tubing. Particular difficulty is encountered installing tubing in wells which are under pressure.-

It isan object of the present invention to provide a system and method for hanging tubing in a well which permits operation'with the well under positive control at all times during the installation, and which permits ready adjustment of well head equipment after initial installation while maintaining the well under control.

More particularly in accordance 'with the present invention, well head equipment is provided for a tubing installation which includes a tubing head having an opening extending'therethrough with an intermedaite element adapted to be supported and sealed in the tubing head and having a plurality of openings therethrough. A tubing hanger in each opening is cooperable with the intermediate element and to be supported by the intermediate element. At least one nipple connected to the bottom of each tubing hanger supports a section of tubing extending into the well. Provision is made for maintaining a pressure seal between the nipple exterior and the interior of the intermediate element below each tubing hanger.

In a more specific aspect, the invention relates to a system for installing and maintaining a string of tubing in a well under tension while maintaining the well under 3,248,130 Patented Apr. 26, 1966 control, and includes a tubing head having a reentrant bore therethrough with a first upfacing' shoulder therein. A sealing bowl seats on said upfacing shoulder. Means carried by the sealing bowl engages the wall of the reentrant bore to maintain a pressure tight seal therebetween. The sealing bowl has at least one reentrant aperture extending therethrough with an intermediate upfacing shoulder. A tubing hanger in the sealing bowl aperture is seated on the intermediate upfacing shoulder. At least one nipple is provided to interconnect the bottom of the hanger and tubing extending into the well with the nipple extending through the sealing bowl. Sealing means carried by the nipple is adapted to engage the walls of the aperture to maintain a pressure-tight seal therebetween and to permit movement through the sealing bowl of the v nipple for manipulation of the tubing string while mainthe lines IIIIII of FIG. 2;

FIG. 4 is a cross sectional view taken along the line IVIV of FIG. 1;

FIG. 5 is a fragmentary cross sectional view taken along the line V-V of FIG; 1;

FIG. 6 is a perspective exploded view of one of the tubing hangers and one of the sealing nipples provided in accordance with the present invention; and

FIG. 7 is a schematic elevational view of a back pressure valve which may be used in connection with the invention. I Referring now to FIG. 1, a pair of nipples 10 and 11, each having a substantially cylindrical exterior surface and a longitudinal bore, are connected at the lower ends thereof to like nipples 12 and 13 which in turn are connected to additional similar nipples (not shown) at the lower ends thereof and thence to support a pair of strings of tubing (not shown). The bores extending through the respective sets of nipples provide for separate flow of production from two zones penetrated by the well in which said tubing is installed.

The nipples 10 and 11 are supported at the upper ends thereof by tubing hangers 14 and 15, respectively. The

manner in which the nipples-1043 function with associated elements to permit raising and lowering of tubing hangers 14 and 15 to install tubing under tenison is a significant contribution to the petroleum producing art.

As illustrated in FIG. 1, a tubing head 20 is affixed to the casing head 21 by bolts coupling the upper radial flange on the casing head 21 and the lower radial flange on the tubing head 20. Tubing head 20 is provided with an upper radial flange 22 to which there is connected upon the completion of the installation, a flanged coupling element 23 which accommodates connections to production control equipment commonly known as a Christmediate portion of the tubing head. 7 The bores 26 and 27 may thus be understood to form a reentrant opening An intermediate element hereinafter referred to as a.

sealing bowl 32 is adapted to be inserted into bore 26 in the upper portion of the tubing head 20. The diameter of the sealing bowl 32 is slightly less than the diameter of the bore 26 so that it may readily be inserted- The O-rings 33 mounted in grooves in the exterior surface of the sealing bowl 32 near the upper end and the O-rings 34 mounted in grooves on the exterior surface of the sealing bowl 32 near the lower end thereof engage the inner wall of the bore 26 to maintain a pressure-tight seal therein. When the sealing bowl 32 is inserted into the bore 26 to rest upon shoulder 28, the hold down screws 31 are tightened to engage the exterior surface of the sealing bowl 32 preferably on milled flat areas provided at circumferentially spaced points.

The sealing bowl 32 is provided with a pair of re entrant bores. The right hand bore has a lower section 40 constituting a cylindrical inner surface of diameter smaller than the diameter of the upper section 41. Similarly, the left hand bore has a lower section 42 constituting a cylindrical inner surface of diameter smaller than the diameter of the upper section 43. Lower sections 40 and 42 are both of sufficient diameter to permit tubing strings to be fed therethrough (including the tubing collars). An upfacing shoulder such as shoulder 44 having a sloping face is provided between lower bore 40 and upper bore 41. In a similar manner, a shoulder 45 having a sloping face is provided between the lower bore 42 and the upper bore 43 in the left hand channel.

Tubing hanger -14 connected to the upper end of nipple' '10 is provided with a shoulder which seats on the shoulder 44 in order to provide a positive support for the nipples and tubing extending therebelow. Tubing hanger 15 similarly seats on the shoulder 45.

The upper end of the sealing bowl 32 is provided with atleast one radial port for each bore therethrough in order to permit hold down screws such as screws 50 and 51 to extend through the walls of the sealingbowl 32 near the upper end into engagement with the exterior surface of tubing hangers 14 and 15, respectively. Hangers 14 and 15 are provided with circumferential grooves into which the hold down screws 50 and 51 extend.

As above stated, the cylindrical inner surfaces or bores 40 and 42 are of suflicient size to permit the free movement of the tubing and tubing collars therethrough and are larger than the diameter of the nipples 13. However, each of the nipples is provided with a plurality of O-rings, the latter being spaced along the length of each such nipple and so dimensioned as to provide a pressuretight seal between the nipple and the cylindrical inner surfaces 40 and 42.

More particularly, a pair of O-rings60 carried in grooves around the upper end of the nipple 10 contact the inner wall of the bore 40. Immediately below the O-rings 60 there is provided a milled zone 61, preferably providing four flat surfaces in the periphery of the nipple 10. Below the zone 61 there are provided additional O-rings such as rings 62, 63 and 64. O-rings or packing elements are sized for sealing engagement with therespective cylindrical inner surfaces 40 and 42 and62-64 are provided in number suflicient to permit the tubing hanger '14 and nipples 10 and 12 to be raised in the well while maintaining at all times a positive pressure seal between at least one nipple below a tubing hanger 14 and the wall of the bore 40 through which the nipples pass.

For example, as shown in the fragmentary sectional view of FIG. 2, tubing hanger of FIG. 1 has been raised relative to the upper flange 22 of the tubing head 20 and removed. The nipple 11 is shown extending slightly above the surface of flange 22 and supported by.

a special wrench-like tool 70 sometimes herein called a hanging tool which rests upon the upper surface of l the flange 22 and which engages the flats in the zone 61 of FIG. 1. In this case, a seal between the nipple 11 and the bore 42 is maintained by the O-rings carried by the lower portion of the nipple 11. 11 in the position shown in FIG. 2, additional nipples may be secured thereto to permit the tubing string to be lowered to even greater depths. Alternatively, the nipple may be further elevated in the well to apply further tension on the tubing.

The use of the hanging tool 70 for supporting the i The tool has a nipple 1-1 is best shown in FIG. 3. rectangular opening 71 which in dimensions corresponds with the cross section of the nipple 11 at the milled zone I 61. It is understood that the hanging tool 70 could take any convenient form that would be compatible with its function, and also, the milled zone 61 could take any convenient form that would provide a suitable means on the outer periphery of each nipple intermediate the ends thereof to accommodate the hanging tool.

FIG. 4 illustrates a sectional view taken along the line IV--IV of FIG. 1 more clearly to show the cross seci tional configuration of the nipples 10 and 11 together with the flat zones on the surface of the sealing bowl 32 provided to. receive the hold down screws 31.

ring 62a.

FIG. 5 illustrates structure for positioning the sealing lbowl 32 in the bore 26. In this regard reference should first be had to orienting depressions 28a and 28b shown in FIG. 1, milled in diametrically opposed portions of the shoulder 28a.

depression 28b. When the sealing bowl is inserted into i the bore 26, it is rotated until the projections, such as projection 32b, register with the depressions, such as the depression 281;. Whenthis is accomplished, the hold down screws 31 are in alignment with the flat Zones on the exterior surface of the sealing bowl 32 and at the same time the hold down screws 51 are in alignment with the radially extending holes in the upper end of the sealing bowl 32.

FIG. 6 illustrates an exploded view showing the tubing hanger 14 and the upper nipple 10. The tubing hanger 14 has the radial groove 14a into which the hold down screw 51 of FIG. 1 extends. The upper end of the tubing hanger 14 is provided with a pair of sealing rings 14b which serve to maintain a seal between the tubing hanger and the Christmas tree structure 23 (FIG. 1).

In operation, a dual completion may be carriedout as follows:

(a) Upon completion of drilling operation and the setting and cementing of easing, the well is drilled in and a [blow-out preventer is installed on the upper flange 22 of the tubing head 20. The tubing head 20 is then fastenedto the casing head 21.

(b) The well casing is then perforated at two zones of interest and a first packer set at a selected depthbetween the perforated zones.

(c) A first string of tubing is introduced into the well through the blow-out preventer.

of tubing and lowered below the tubing head.

With the nipple It will be seen that the annulus 32a between the sealing bowl 3-2 and bore 26 is sealed by the O-ring 34 while the i annulus between the nipple 10 and the bore 40 is sealed 1 by the O-ring 62.. In a similar manner the annulus bea tween the nipple 11 and the bore 42 is sealed by .O- a

The depressions 28a and 28b are. adapted to mate with projections formed on the lower end of the sealing bowl 32. More particularly the seal: a

(e) The sealing bowl 32 is installed in the tubing head through the blow-out preventer, over the first string of tubing, and the hold down screws 31 are tightened to maintain the tubing bowl in a fixed position in the tubing head 20 with the projections, such as projection 32b, in the depressions, such as 2812, FIG. 5.

(f) The first tubing string is then lowered to locate the second or upper packer above the upper set of perforations and to couple the lower end of the tubing into the first or lower packer.

(g) Nipples, such as nipples and 12, are connected to the upper end of the first string of tubing along with a tubing hanger 14. The sealing bowl 32.

(h) The second string of tubing isthen lowered through the bore 42 by way of the blow-out preventer until the bottom end of the second string of tubing touches the upper'packer. The second string is then raised and nipples 11 and 13 are installed in the second string thereof along with an intermediate length of tubing, if necessary. The twbing hanger is added and is seated in the bore 43 with the lower end adjacent to the upper packer.

(i) Tubing hangers 14 and 15 are locked in place by the hold down screws 50 and 51.

(D At this point the blow-out preventer may be removedsince'the'sealing bowl is locked'in position by hold down screws 31, the tubing hangers 14 and 15 are locked in position by hold down screws 50 and 51, and the head of the well is sealed by O-rings 33 and 34 belatter is then lowered into the tween the sealing bowl 32 and the tubing head and by O-rings on each of the nipples.

When necessary, back pressure valves such as shown in'FIGJ7 may be installed in one of the nipples 1013 or'may be installed in the tubing strings'near the lower ends thereof to close the tubing channels.

(k) The tubing hangers 14 and 15 are raised and while in raised position such as illustrated in FIG. 2 are removed so that additional nipples may be added to each of the strings of tubing to permit the lowering of the first string sutficient to lock said first string in the lower packer and to permit the first string to be raised to set the upper packer and to place the first string in tension. The desired tension may stretch the tubing in some cases as much as 50 inches so that nipples sufficient in number to accommodate the setting of the upper packer and tensioning the first tubing string will be necessary. Similarly, nipples suflicient in number are installed on the second string to permit it to be stabbed into and secured to the upper packer for production from the zone between the lower and upper packers. The second string of tubing must also be tensioned, nipples in number sufficient to permit the tensioning operation being included.

(1) The tubing strings are raised successively by applying tension thereto to pull one or several of the nipples.

10-13 on each string above the tubing head flange 22.

(in) When suflicient tension has been registered on a first of the string of tubing, hanging tool 70 is fixed to the flat surfaces on the nipple positioned immediately above the top of the flange 22.

(n) The first string of tubing is lowered so that the wrench or hanging tools 70 take the weight of the string and the tensile force therein while the nipples above the flange 22 are removed and replaced by a tubing hanger.

(o) The strings of tubing are raised slightly to permit removal of the hanging tools 70 and the tubing hanger is lowered into the sealing bowl.

(p) Steps (m) and (o) are'repeated for the second string.

(q) The Christmas tree structure 23 is added for producing through the strings of tubing, and back pressure valves are removed from the tubing or nipples.

It will be understood that the foregoing operations permit the reworking of the tubing strings while maintaining the well under control. Greater or less tension can be set into the tubing strings by merely raising the tubing hanger out of the sealing'bowl and adding or removing nipples as desired. In each case, however, the nipples employed maintain a pressure-tight seal between the exterior of the nipples and the interior of the sealing bowl 3-2.

It will be clear from the foregoing that the minimum eflective increment that the tubing string may be lengthened or shortened is the length of one nipple. This is also the distance between the hanging tool accommodating means on adjacent nipples. Further, the minimum effective length for a nipple is the length of the intermediate element cylindrical inner surface. There must always be at least one nipple below each tubing hanger.

The minimum spacing between adjacent packing elements, whether on one nipple or on adjacent nipples, must not exceed the length of an intermediate element cylindrical inner surface.

The term packing element as used herein is intended to encompass a sealing element such as an O-ring as well as any suitable sealing element means well known to those skilled in the art that will accomplish the requisite pressure seal. The packing elements Could also make up a solid longitudinally extending seal on each nipple of length exceeding that of the intermediate element inner cylindrical surface, if that were desired.

While the foregoing has dealt specifically with a dual completion system, it is to be understood that features of the invention may :be employed for hanging as many strings of tubing as can be accommodated by the casing in a tubing head in the manner above described by use of a sealing bowl with additional channels extending therethrough.

Components discussed and not illustrated, but used as adjuncts to hanging plural strings of tubing in carrying out the present method are well known in the art. The blowout preventer, packers, back pressure valves, and other conventional apparatus used in connection with the invention may all be of any suitable make or type as will be readily understood by those familiar with the petroleum production art.

Applicant has, however, devised a new system and a new method for the handling and manipulation of multiple completion well head equipment. The tubing head with a reentrant bore therethrough is of size suflicient to admit as many strings of tubing as desired. The intermediate sealing bowl element is adapted to be supported and sealed in the tubing head and is provided with as many openings therethrough as tubing strings to be placed in the well.' A tubing hanger is provided in each opening in the sealing bowl and cooperates with means in the sealing bowl for supporting the hanger. At least one nipple is connected to the bottom of each tubing hanger and is adapted to support a section of tubing in each string in the well. Pressure seal means are provided to seal the annulus between the sealing bowl and the tubing head and between the nipples and the channels through the sealing bowl.

It will be seen that the invention relates not only to construction of the well head equipment, but also to a new method of hanging tubing in a well involving operations-extending into the hole itself and particularly the cooperation between the well head equipment and the packers in the well.

In carrying out the method of the present invention to set a pair of tubing strings through the bore of a well 1 head below which a first packer is installed, the steps set forth above will be followed. One of the tubing strings carrying a second packer is inserted through the bore of the tubing head. The bore of the tubing head is then stopped V except for two passages therethrough, the first of which is an annular passage concentric with the first string of tubing and the second of which is a cylindrical passage parallel to the first annular passage for introduction of a second string of tubing.

The first string of tubing is then lowered until the second packer is at a predetermined depth. The second string of tubing is then introduced through the cylindrical passage until the'lower end thereof is adjacent the top of the second packer. There are then established slidable annular seals in the first annular passage, and also in a second annular passage between the second string of tubing and the cylindrical passage through which it extends. The strings of tubing, the second packer and the first packer are then interconnected below the well head and coupled to the wall of the well while maintaining the annular seals in the tubing head. Tension is then applied to stretch the strings of tubing while maintaining the annular seals. The tubing strings are then hung in the well head while maintaining tension on the strings of tubing through the annular seals. Thus at all times the well pressure is sealed by the O-rings or packing elements carried by the sealing bowl and by the nipple-formed tubing sections.

Having described the invention in connection with certain embodiments thereof, it is to be understood that further modifications may now suggest themselves to those skilled in the art, and it is intended to cover such modifications as fall within the scope of the appended claim.

I claim:

Well head equipment for tubing installation which comprises:

(a) a tubing head having a bore therethrough;

(b) an intermediate element supported and sealed in said tubing head and having a plurality of axial openings therethrough; I

(c) a tubing hanger in each said opening;

(d) cooperable means in said intermediate element for supporting each said hanger;

(e) at least one nipple connected to the bottom of 1 two adjacent packing elements not exceeding the,

length of saidinner surface; (i) and means on the outer periphery of each said nipple intermediate the ends thereof to accommo- Y date a hanging tool;

(j) whereby nipples may be moved longitudinally through the intermediate element to manipulate a tubing string while maintaining Well control.-

References Cited by the Examiner UNITED STATES PATENTS 1,557,915 10/1925 York- 166 84 1,849,374 3/1932 McEvoy 285-431 2,075,899 4/1937 Humason 2 2 5-1 2,103,586 12/1937 Kitchel 2 285-443 2,780,291 2/1957 wresni h 16 439 2,889,886 6/1959 Gould 166-89 2,905,099 9/1959 Turner 1 649 3,011,804 12/1961 .Burns 1 285-437 3,041,090 6/1962 Ashe 3,2 285 -437; 3,080,180 3/1963 Rector 285-137,

CARL W. TOMLIN, Primary Examiner.

D. W. AROLA Assistant Examiner. I

Patent Citations
Cited PatentFiling datePublication dateApplicantTitle
US1557915 *Aug 28, 1922Oct 20, 1925Walter G BlackPressure controller for oil wells
US1849374 *Feb 3, 1930Mar 15, 1932Johnson Edwin APipe supporting means
US2075899 *Sep 12, 1933Apr 6, 1937Humason Granville ADrilling head
US2103586 *Jan 24, 1936Dec 28, 1937Beaumont Iron Works CompanyTubing head
US2780291 *Feb 28, 1955Feb 5, 1957Gulf Oil CorpStorm choke and packer for dual-zone completion
US2889886 *Jan 23, 1956Jun 9, 1959Gould Jay PWell head
US2905099 *Oct 25, 1954Sep 22, 1959Phillips Petroleum CoOil well pumping apparatus
US3011804 *Jul 9, 1956Dec 5, 1961Mcevoy CompanyDual well completion apparatus
US3041090 *Apr 28, 1959Jun 26, 1962Shell Oil CoPivoted tubing well connection
US3080180 *Jun 30, 1958Mar 5, 1963Rector Well Equipment CompanyTubing hangers
Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US3526418 *Jul 25, 1968Sep 1, 1970Rockwell Mfg CoWellhead completion apparatus
US4183562 *Apr 1, 1977Jan 15, 1980Regan Offshore International, Inc.Marine riser conduit section coupling means
US4458903 *Dec 27, 1982Jul 10, 1984W-K-M Wellhead Systems, Inc.Control line sealing connection
US4695190 *Mar 4, 1986Sep 22, 1987Smith International, Inc.Pressure-balanced stab connection
US4756656 *Mar 3, 1986Jul 12, 1988The United States Of America As Represented By The United States Department Of EnergySectional device handling tool
US4962952 *Mar 29, 1989Oct 16, 1990Vetco Gray Inc.Pressure tube with deflecting section
US5197766 *Oct 28, 1991Mar 30, 1993General Electric CompanyFluid-carrying tube coupling assembly with internal seal and drain arrangement
US7950466Feb 5, 2008May 31, 2011Stream-Flo Industries Ltd.Wellhead system and connector for wellheads
WO2008098006A1 *Feb 5, 2008Aug 14, 2008Stream Flo U S AWellhead system and connector for wellheads
Classifications
U.S. Classification285/27, 285/123.1, 285/351, 285/347
International ClassificationE21B33/047, E21B33/03
Cooperative ClassificationE21B33/047
European ClassificationE21B33/047