67992588 Wellhead Equipment and Flow Control Devices

between strings, and control production from the well. Since the American Petroleum Inst. (API) is an active

organization set up to establish standards in sizes. grades, designs, dimensions, and quality, to provide safe interchangeable equipment for the industry, this section is conlined to equipment covered by API Spec. 6A for wellhead equipment.

temperature variations are impossible to predict. Equip- ment should never be subjected to pressures above the recommended working pressure. If, for any reason, the equipment is to be used at unusually high or extreme working pressure, manufacturers will insist that a disclaimer clause be written and properly worded to relieve them of legal responsibility. The disclaimer

tate possible results that are expected because of ent failure. 3.1 shows the standard API working pressure nd their respective body test pressures.

Limitation

of the complex mechanics involved in sealing essure threaded connections, it is recommended installations be adequately supervised and that

5Cl be followed with regard to lubricants, , etc., of API threads. API Flanged or Clamped Wellhead Equipment Fig. 3.1 shows a typical wellhead assembly.

Working- and Test-Pressure Terminology

The maximum working pressure is the maximum operating pressure at which the equipment should be used. The hydrostatic test pressure is the static-body test pressure for ensuring a margin of safety above the rated working pressure. It is the test pressure imposed by the

should sequipm

Tableratings a

Thread

In viewhigh-prthat fieldAPI RPmakeupChapter 3

Wellhead Equipment aFlow Control DevicesJames H. Foster, Foster Oil Field Equipment Co.* John Beson, Foster Oil Field Equipment Co. W.G. Boyle, Otis Engineering Corp.**

Introduction Wellhead equipment is a general term used to describe equipment attached to the top of the tubular goods used in a well-to support the tubular strings, provide seals manufacturer to prove adequacy in design, materials, and workmanship of the body or shell member and should not be applied as a differential pressure across internal hanger-packer mechanisms or closure mechanisms.

Occasionally wellhead equipment and valves are ac- cidentally or purposely subjected to pressures in excess of design working pressures during high-pressure remedial work. Although the equipment often withstands the mistreatment, such practices should be avoided.

James ti Foster wrote the orlglnal chapler on this loplc in the 1962 edwn W G Boyle is author of the Safety Shut-In Systems section of th!s chapter nd

All manufacturers build safety factors into their prod- uct based on sound engineering and past experience, but stresses caused by vibration, impact loads, and The working pressure of a properly assembled threaded connection joining a wellhead or flowline component and a tubular member often is determined by the rating of the tubular element. In such a case, the maximum working pressure rating of the connection is taken as the internal yield pressure at minimum yield as stipulated in API Bull. SC2 for the particular size and type of thread and weight and grade of tubing or casing, reduced by a suitable factor of safety. However, this pressure rating shall not exceed the maximum working pressure rating shown in Table 3.2. In-plant hydrostatic test pressures of components using tubing or casing threads are shown in Table 3.1

EST

Physical Properties

API body and bonnet members are made from steel with

la. 1d l

g T

tolo

Fig. 3.1-Typical wellhead assembly.

Working Pressure

Flanges (14 in. 1355.6 mm]

and smaller)

TABLE 3.1-T

(Psi) (bar) 1,000 69

1,500 103 2,000 138 3,000 207 5,000 345

10,000 690 15,000 1,035 20,000 1,380

(Psi) (bar) 2,000 138 - -

4,000 276 6,000 414

10,000 690 15,000 1,035 22,500 1,551 30,000 2,070

F(16% In

an

(Psi) 1,500 -

3,000 4,500

10,000 15,000

- -

Casin

4%- t0 l&%-in. 11%[114.3- to 273.1-mm] [298.5-

(Psi) (bar) (Psi)

2,000 138 2,000- -

4,000 276 4,0006,000 414 4,5007.500 517 *Working pressure of lhread When threads are used as end or outlet connectwns of wellhead or flowlsllpulated in Table 3.2 and the test pressure shall be as tabulated !n Table 3 PRESSURE

properties equal to or exceeding these specified in Tables 3.3 and 3.4.

Lowermost Casing Heads

The lowermost casing head is a unit or housing attached to the top end of the surface pipe to provide a means for supporting the other strings of pipe, and sealing the annular space between the two strings of casing. It is composed of a casing-hanger bowl to receive the casing hanger necessary to support the next string of casing, a top flange for attaching blowout preventers (BOPs), other intermediate casing heads or tubing heads, and a lower connection.

nges 425.5 mm] arger)

(bar) 103 -

207 310 690

1,035 - -

Clamp-Type Connectors

(Psi) (bar) - - - -

4,000 276 6,000 414

10,000 690 15,000 1,035

- -

hreads* l

13%in. 16-to 2&n. 339.7.mm] [406.4- to 508.0-mm]

(bar) (Psi) (bar)

138 2,000 138 - 2,250 155

276 - - 310 - -

-

Line Pipe and Tubing Threads

(Psi) 0-W

2,000 138 -

4,000* 276 6.000* l 414

10,000* 690 15,000* * 1,035

- - 3-2 PETROLEUM ENGINEERING HANDBOOK

Tubmg

When line pipe threads are used as end or outlet connections of wellhead or flowlinr components. the maximum working pressure rating of the assembled joint is stipulated in Table 3.2. The in-plant hydrostatic testpressure of components using line pipe threads is shown in Table 3.1.

In many cases the OD of these female threadedmembers will be greater than API-tabulated coupling or joint diameter to ensure that the structural integrity of the threaded member will not be less than that of the com- patible mating API male tubular member.

In addition to the API threads listed in Specs. 5A and 5L, there are a number of proprietary threads available in the same sizes as the API tubing and casing threads. J.5 Some of the proprietary threads offer advantages over the API threads, such as maximum clearance for multiple completions, special corrosion protection from internal fluids, low torque requirements, superior internal and external pressure integrity, and high joint strength. lne components, the maximum working pressure of the assembled low shall be 1

WELLHEA 3-3

external upset (API round thread)

1,050 t0 4h 26.7 to 114.3 5,000 345

%%

load-supporting connection in an API wellhead assembly. The boworking-pressurelosupport the most exnot necessary to inhead because heav

Lowermost casing heads are available with or without ck screws usually are hanger down against ipple-up operations or too light to effect an crew to effect the seal.

pe 4*

Tensile 00 [483] Yteld st 00 [31 O] Elongati 19 Reductio 32 Carbon, Mangane

0.35 0.90

Sulfur, 0.05 Phospho 0.05

The des lon of Valves and Wel

FlangesdewabletChemlcaw,th comdy-wall thickness of the lowest- wermost casing head is sufficient to treme casing loads. Therefore, it is crease the working pressure of the y casing loads are anticipated.

lock screws in the top flange. Loused only to hold the casing pressures that may occur during nwhen casing-string weights are automatic seal and require a locks

TABLE 3.3-PHYSICAL AND CHEMICAL PROPERTIES

Type 1 Type 2 Type 3 Tystrength, minimum, psi [MPa] 70,000 [483] 90,000 [621] 100,000 [690] 70,0rength, minimum, psi [MPa] 36,000 [246] 60,000 [414] 75,000 [517] 45,0on in 2 in., minimum, % 22 18 17 n In area, mimmum, % 30 35 35 maximum, % se, maximum, % : : :

maximum, %

: : t

rus, maximum, % t

~~natw Type 1, Type 2 Type 3. and Type 4 IS a nomenclature selected by the API Committee on Standarduatlhead Equlpmenl to ldentlfy material falling wllhm ihe ranges of tensile requ~remenls losted above Casing (eight round, buttress and

4% to 1011 s/4 to 13

extreme line) 16to20

The lower connection may be a female or male thread or a slip-on socket for welding. Most common is the female-threaded lower connection, although the slip-on socket connection provides the strongest joint unless the surface casing is of such composition that welding causes serious weakening. The male lower thread is the weakest of the three connections because of the thin cross section necessary to provide full opening. It is used in most cases only to prevent removing the coupling on the surface pipe. The welded connection is most frequently used on deep wells to give the additional strengthneeded to suspend heavy casing loads without overstressing the threads on the surface pipe.

A landing base is sometimes used with the lowermost casing head to provide additional support for extremely heavy casing strings. The landing base is a separate unit welded to the lowermost casing head and to the surface pipe with a lower flange or skirt to transfer part of the weight to conductor strings, pilings, or a concrete foundation.

The lower connection is usually the weakest vertical made lrom Type 4 steel are recognlred as readily weldab under all condlllons and IS necessary II welding IS done al analyses of Types 1 2. and 3 materials are purposely omplete freedom lo develop ~leels mw.t sLxble lor the mul 114.3 to 273.1 5,000 345 298.5 to 339.7 3,000 207

406.4 to 508.0 1,500 103

Most lowermost casing heads are furnished with two 2-in. line-pipe threaded side outlets, although studded or extended flanged outlets are sometimes used to provide additional strength for attaching valves. Internal valve- removal threads should be included in the studded or extended flanged outlets to provide a means for seating a valve-removal plug to seal the outlet while installing or removing a valve under pressure.

In the event a valve on the side outlet of a casing head cuts out or it is desirable to install or remove a valve under pressure, after the well is completed a special tool can be attached to the outlet or the valve and a valve- removal plug can be inserted into the valve-removal thread to seal the pressure while necessary adjustments are made. A full&opening valve must be used for this application to provide clearance for the plug.

In case threaded outlets are used, a valve-removal nipple may be used to provide the same facility. Internal threads inside the valve-removal nipple provide a recep- tacle to seat the plug for removing, installing, or replac- ing the valve. D EQUIPMENT AND FLOW CONTROL DEVICES

TABLE 3.2-API MAXIMUM WORKING PRESSURE RATINGS FOR WELLHEAD MEMBERS HAVING FEMALE THREADED END

OR OUTLET CONNECTIONS

Thread

Type (in.)

Size

[mm1

Maximum Working Pressure

Rating

(Psi) (bar) Line Pipe

(nominal sizes)

Tubing, nonupset and

12 12.7 -690 10,000 z/i to 2 19.1 to 50.8 5,000 345

2/2 to 6 63.5 to 152.4 3,000 207 le, however, expeilence lndlcates that a moderate preheating 1s t amblent temperatures below 40F (4%) llled from lhls speclllcatlon m order to provide the manulaclurer ,~pkQ of reqwemenls encountered I lh,s cN,cal service

Surface ToSuppoPipe Pipe

Size Size

7 4%,5

8% 4%,5.5'g5/8 4'/2,5.5'/2.

10% 5'/2,6=/,,7

11% 5'/2.6%.7.

1 1% 7%

11% 8%

13% 0%

13% 9 516 8 5

16 9=

16 10%16 10 3

16 13%

16 13%20 13%

20 13%20 16

20 16

Tubtng-Head

Flange Stze

Bottom Top'

7x6 7% 9 7%

11 7%

11 7% 13% 7%

11or9 7l&

ii or9 7% 11 or9 7x6 11 7 ',,,', 6

llor9 7% 6 11 7 I,,,: 6

13% or 11 7x6 11 or9 7'h 6

11 or9 7'/

NSize

of For C(in.)

13/WIWl3'h

4%7%9

11 13%135/16%163/21%20% 527.1 20 20 -

.8

20 508.0

WELLHE 3-5

nugs min

beI

surface pipe. Maximum working pressure should be at Casing Hangers

least equal to the formation pressure at the bottom of the next smaller casing string.

Lock Screws. Lock screws in the casinghead flange may be used as an added safety precaution if the annulus pressures are expected during nipple-up or if a very light casing load is to be suspended.

A casing hanger is a device that seats in the bowl of a lowermost casing head or an intermediate casing head to suspend the next smaller casing string securely and provide a seal between the suspended casing and the casinghead bowl.

TABLE 3.7--MATCHING TUBULAR GOODS SIZES FOR USE WITH lO,OOO- 15,000-, AND 20,000-psi FLANGES AND lO,OOO-psi CLAMP-TYPE CONNECTORS

Nominal Flange or

Clamp Hub Size of Tubular Material

Size Tubing OD Casing OD

(in.) [mm1 (In.1 [mm1 (in.) lmml 1 A 6 * 42.9 1.900 48.3 1% 46.0 2.063 52.4 WI6 52.4 2% 60.3 29/l 6 65.1 2% 73.0 3% 77.8 3'/3 88.9 4x6 103.2 4 and 41/z 101.6 and 114.3 7x6 179.4 - -

9** 228.6 11" 279.4 - - 13vet 346.1 - -

16Qf 425.5 183/h 476.3 - - 21'/4 539.8 - -

-

- - - 4%

4% through 7 7% and 8% 8% and 9%

10% and 11 a/4 16 18 20

-

114.3 114.3 through 177.8

193.7 and 219.7 219.7 and 244.5 273.1 and 298.5

406.4 473.1 508.0 'Generally nonstock s,ze Begmmng wih the eleventh edlflon of API Spec 6A. the tradmonal 66 flange nomlwll be retamed for mformatlon unf~l mdusiry becomes accustomed to the new throreplace old nominal sues 1% in through IO m The 5,000 PSI (345 bar) flangeS~?S apply only to 2.000 and 3.000 PSI (138 and 207 bar) 68 flanges The new 20%21Va-fn ,539 6.mm1 deslgnatmn applies only to 2,000-PSI (13%bar) 6B flanges

tThis 66 flange 1s limtted 10 a maximum worktng-pressure rallng of 3,000 PSI (207*Type 6EX flanges are required for 5,000.PSI (345bar) maximum workmg pressur

ing load with a packoff pressure equal to the minimum yield of the supported casing or the working pressure of the casing head, whichever is smaller.

Working Pressure. The minimum working pressureshould be at least equal to the anticipated formation breakdown pressure at the bottom of the surface pipe. or equal to or greater than the internal pressure rating of the Th,s flange IS ~nacl~ve; available on special order only Avatlable I 10,000 and 15 000.PSI (690. and 1,035.bar) rated fltAvallable I 10.000.psi (690-b@ rated flanges only al sue designation was changed 10 a through-bare deslgnalton Old normnaf sizes h-bore deslgnatlons New nominal sizes i13/,& m [46 0 mm] through 11 m [279 4 mm] the larger sizes are 66X flanges, and the new 6B flange deslgnatlons for the larger 1527 i-mm] deslgnallon apples only 10 3000 PSI (207 bar] 6B flanges and fhe new

ar) when used Over 11 %-ln [P98.5-mm] and 13Wn 1339 7.mm] casmg these sizes

Size. Nominal flange size should normally be the smallest permissible size to provide full-opening access to the surface pipe (Tables 3.6 and 3.7) and should fit a standard out-of-stock intermediate head or tubing head and BOP. It should have the necessary size and type of lower connection to fit the surface pipe. ominal Old Size of Tubular Material and Bore Nominal Line lange* lamp Hub

Flange Pipe, Size Nominal Tubing OD Casing OD

[mm1 (in.) (In.) (in.) [mm1 (in.) [mm1 42.2 and 48.3 - - 16

6 6

6 6

s i

46.0' 52.4 65.1 79.4

103.2 179.4 228.6 279.4 346.17 346.1$ 425.5 425.5$ 539.8$

1% 2 2/2 3 4 6 8

IO 12 13% 16 16% 20

1% 1.660 and 1.900 2 1.600 through 2% 2% 2% 3 3% 4 4 and 4% 6 - 8 -

10 - 12 -

- 16 - -

20 -

42.2 through 60.3 73.0 88.9

101.6 and 114.3

-

-

- - -

- - 4% 114.3

4% through 7 114.3 through 1777% and 8% 193.7 and 219.19% and 103/4 244.5 and 273.1

11 % and 13% 298.5 and 339.711 % and 13% 298.5 and 339.7

16 406.4 16 406.4 20 508.0

AD EQUIPMENT AND FLOW CONTROL DEVICES

TABLE 3.6-MATCHING TUBULAR GOODS SIZES FOR USE WITH 2,000., 3,000-, and 5,000-psi FLANGES OR 5,000-psi CLAMP-TYPE CONNECTORS anges only

3-6

Sizes and Sizing. The size of a casing hanger is deter-mined by the nominal OD. which is the same as thenominal size of the mating casinghead flange. The nominal inside diameter is the same as the nominal outside diameter of the casing it is designed to suspend.Sizes range from nominal 7x6 through 21 5/4 in. to support 4%- through 16-in. casing. Popular sizes arenominal 9 in. for 4% through 5%-in. casing: nominalI I in. for 4%- through 75/s-in. casing: nominal 13% in. for 5% through 95/R-in. casing, as indicated in Table 3.5.

Casing hangers are generally available for all casingsizes in the following types.

Automatic (most popular type). The automatic casinghanger is a unitized assembly composed of a set of slips and a sealing mechanism. It can be latched around thecasing and dropped through the BOPs to set and sealautomatically when the casing is slacked off to set. This type is normally used when annulus pressures are ex- petted during nipple-up operations.

Manual. The manual casing hanger is normally used in preference to the automatic type only as a matter of economics when pressure is not expected in the annulusduring nipple-up. It is composed of a set of slips and a separate packoff element. The slips can usually be latched around the casing and dropped through the BOPs, but the packoff is installed after the preventershave been removed and the casing cut off.

Slip-Weld. The slip-weld hanger usually is composed of a set of slips to support the casing weight and a spider or ring that can be welded to the casing to seal the hanger to the casing. The hanger usually is sealed in the head by a resilient compression-type seal. The hanger can be dropped through the BOPs to support casing weight. but the final seal is made by welding after the preventershave been removed and the casing cut off. Particular caremust be taken in preheating the casing and the casinghead to ensure an adequate weld. Some casing is permanently damaged by improper welding.

Boll-Weevil. The boll-weevil casing hanger is a simple mandrel-type hanger which screws onto the casing to be supported and seats in the casinghead bowl. This type of hanger is not recommended if there is any question aboutgetting the casing to bottom and obtaining the accuratespacing required.

Casing hangers are rated by their capacity to supportcasing weight rather than by working pressure. Some manufacturers furnish actual pull curves showing the deformation that can be expected in the slip area, for any casing load, up to joint strength, for all standard casingsizes, weights, and grades. Fig. 3.2 shows acceptablepull curves for a heavy-duty casing hanger with a 5.000-psi pressure on the packoff.

Selection. In selecting a casing hanger, after establishingwhich type of hanger is most practical, the following factors should be considered.

1. The hanger should be capable of hanging the full

joint strength of the casing to be used without sufficient reduction in diameter to obstruct full-sized downhole tools. PETROLEUM ENGINEERING HANDBOOK

2. The packoff or primary seal should be of such con- struction that well pressure. flange test pressure, or frac- ture pressure cannot force the packoff down and reduce the casing-hanger capacity.

3. The hanger should be of the proper design and size to fit the mating casinghead bowl, and properly sized to support the casing to be used.

Intermediate Casing Heads

An intermediate casing head is a spool-type unit or housing attached to the top flange of the underlying casing head to provide a means of supporting the next smaller casing string and sealing the annular space between the two casing strings. It is composed of a lower flange, one or two side outlets, and a top flange with an internal casing-hanger bowl.

The lower flange of an intermediate casing head is counterbored with a recess to accommodate a removable bit guide, or a bit guide and secondary-seal assembly. The purpose of the bit guide is to protect the top end of the intermediate casing string from damage by bits and tools going into the hole. The counterbore is usually constructed to provide a fixed internal bit guide for the largest-sized intermediate casing string that can be suspended beneath that particular flange size. A removable bit guide must be used to protect smaller- sized intermediate casing.

A removable bit guide and secondary-seal assembly may also be used in place of a removable bit guide to seal the annular space between the intermediate casing and the lower flange of the intermediate casing head. By using a secondary seal, well fluids are confined to the body of the intermediate casing head and not allowed to con- tact the ring gasket or the packoff on the casing hanger below. If the well fluids are corrosive. use of a dependable secondary seal is particularly important to protect the ring gasket.

Use of a secondary seal and confining well fluids to a diameter approximately equal to the intermediate casing OD greatly reduces piston load or thrust on the flanges and flange studs. This permits use of an intermediate casing head with a top flange one working pressure rating higher than the lower flange. Of course, the body, the top flange, and the outlets must be sized for the higher pressure rating.

Available secondary seals are generally of three types: (I) unitized pressure-energized, (2) plastic-packed, and (3) externally adjustable. The externally adjustable type offers the advantage of being adjustable to stop a leak at any time during the life of a well. A leak in the pressure- energized type or the plastic-packed type may be scaled by injecting a plugging material into the seal under pressure or by replacement.

Intermediate casing heads are available with one or two side outlets, which may be threaded, studded, or extended flanged, depending on the working pressure and particular application. The side outlets should be equipped with valve-removal provisions as discussed in connection with the lowermost casing heads. Like a lowermost casing head, the top flange of an intermediate

casing head may be equipped with lock screws if needed because of expected annulus pressures during nipple-up or very light suspended casing loads.

IO

The design fbowl are identcasinghead bowreceive a casinsmaller casing sa relatively shosometimes deshanger with a lhigh-capacity cathe next smalle

Sizes and Worflanges on interfrom nominal 7Xing in sizes frovarious intermcasing sizes. Tnominal flangedard casing.

Intermediatecpressures of 1,0Generally, the termediate head

break down the iate casing string head. The max- qual the shut-in casing string to head.

asing head. the r size and work- on the casing

ched to the cas- through 3.7).

ide. or bit guide sing suspended

ize and working ng string and fit e (see working- ugh 3.7). z

J if

200

a

250 7 --

150

100

9$-40*

CASlbG

50

0 010

DIDC

L-L 020 030

?nLLAPSE DIAMETER)

8, L L.

(INCHES ON

010 020 030 DDF rOLLAPSE

N DIAMETER) I II L UC

IINCHES 0

Fig. 3.2-Casing-hanger pull curves

eatures for an intermediate casinghead ical to those discussed for a lowermost l. The bowl should be designed to g hanger which will suspend the next tring without damage to the pipe. When rt intermediate casing string is used, it is irable to use a less-expensive casing ower load capacity for support. but a sing hanger may be required to suspend r casing string.

king Pressures. The lower and upper mediate casing heads may range in size 6 in. to nominal 2 1 l/4 in. to support cas-

m 4% to 13 3/s in. Table 3.5 shows the ediate head sizes required for standard ables 3.6 and 3.7 give the minimum size to give full-opening access to stan-

asing heads are available in working 00. 2,000, 3,000. 5,000, and 10,000 psi.

maximum surface pressure required to formation at the bottom of the intermedsuspended below the intermediate casingimum working pressure should at least eformation pressure at the bottom of thebe suspended in the intermediate casing

Selection. In selecting an intermediatecfollowing factors should be considered.

I. Lower flange must be of the propeing pressure to fit the uppermost flangehead below, or the crossover flange attainghead flange if one is used (Tables 3.5

2. It must have a properly sized bit guand secondary-seal assembly, to fit the cabeneath it.

3. Top flange must be of the proper spressure to suspend the next smaller casithe mating flange to be installed abovpressure discussion and Tables 3.5 throWELLHEAD EQUIPMENT AND FLOW CONTROL DEVICES

LONG JOINT

COUPLING SlAENGTHS

I ,010 ,020 030

PIPE COLLAPSE (INCHES ON DIAMETER)

LONG JOINT

COUPLING STRENGTHS 8Z

so 1

2% minimum working pressure of the in- should be equal to or greater than the 3-7

LCNG JCINT

rOUPLlNG STRENGTHS 7 _ -0

0 84 24

cl0 020 030 PIPF COI I APSE

(INCHES ON DlAMi TER)

J LONG 4. It should have the proper size, type. and working pressure side outlets.

3-8

plates. The hanger can be latched around the tubing, 5. It must include a casing-hanger bowl designed to receive a casing hanger with an effective packoff mechanism that will support joint strength of the casing to be suspended without damage to the casing.

Intermediate Casing Hangers

Intermediate casing hangers are identical in every respect to casing hangers used in lowermost casing heads and are used to suspend the next smaller casing string in the intermediate casing head. These hangers are selected on the same basis as casing hangers used in lowermost casing heads, as previously discussed. Sizes are specified by the nominal diameter of the flange in which the hanger is to be used and the nominal size of the casing to be supported.

Tubing Heads

A tubing head is a spool-type unit or housing attached to the top flange of the uppermost casing head to provide a support for the tubing string and to seal the annular space between the tubing string and production casing string. It also provides access to the casing/tubing annulus through side outlets. It is composed of a lower flange, one or two side outlets, and a top flange with an internal tubing hanger bowl.

Tubing heads are generally of two types: (1) a unit with flanged top and bottom and (2) one with flanged top and threaded bottom. The unit with the threaded bottom is usually screwed directly on the production casing string, and the top flange is used for the same purpose as the double-flanged head. The lower flange, on the double-flanged type, is constructed in much the same way as the lower flange on an intermediate casing head in that a recess is provided to accommodate a bit guide or a bit guide and secondary seal. The design, purpose, types, and application of bit guides and secondary seals are explained in the discussion of the intermediate casing head. Lock screws normally are included in the top flange to hold the tubing hanger in place and/or to compress the tubing hanger seal, which seals the annular space between the tubing and the casing.

Tubing heads are available with one or two side outlets, which may be threaded, studded, or extended flanged. Usually studded-side outlets are used on units with a body working pressure of 3,000 psi and higher. Threaded side outlets are commonly used on units of 2,000-psi working pressure and lower. Extended flanged outlets are used when large-size side outlets are desired. All outlets should be equipped for valve-removal service, as explained in the discussion of the lowermost casing head. The top flange of a tubing head must be equipped with an internal bowl of the proper design to receive the required tubing hanger.

Most available tubing heads will receive any of the various types of single-completion tubing hangers of the same manufacturer. If multiple tubing strings are to be installed, a tubing head with a special bowl may be required. This subject is explained in greater detail under the discussion on multiple completion.

Sizes and Working Pressures. The lower flange on a tubing head may range in size from a nominal 7x6 in. to

13% in. The upper flange may vary from nominal 7x6 PETROLEUM ENGINEERING HANDBOOK

in. to 11 in. for installation over production strings vaty- ing in size from 4% to 9% in. Table 3.5 gives the various standard tubing-head sizes used over common casing sizes.

Tubing heads are available in working pressures of 1,000, 2,000, 3,000, 5,000, 10,000, 15,000, and 20,000 psi. By using a secondary seal in the lower flange to reduce the piston area exposed to well pressure, a top flange may be used with a working pressure one rating above the lower flange, provided the body and outlet dimensions also correspond to the higher rating.

The working pressure of a tubing head for particular application should be at least equal to the anticipated surface shut-in pressure of the well. In most cases, it is considered more economical to install a tubing head with a working pressure equal to the formation breakdown rather than to replace the tubing head with higher pressure equipment during high-pressure treatment.

A standard tubing head with a 7X,-in. top flange has a minimum bore of approximately 6%. in., which is considered full-opening for a 7-in. or smaller production string. If a 7%in. production string is used, special care should be taken to select a full-opening tubing head for 75/s-in. casing. Special tubing heads are available for this purpose.

Backpressure Valves

Selection. In selecting a tubing head, the following factors should be considered to maintain positive control over the well at all times.

1. The lower flange must be of the proper size and working pressure to fit the uppermost flange on the casing head below or the crossover flange attached to the casinghead flange, if one is used (Table 3.5).

2. The bit guide, or bit guide and secondary-seal assembly, must be sized to fit the production casing string.

3. The size outlets must be of the proper design, size, and working pressure.

4. The working pressure of the unit must be equal to or greater than the anticipated shut-in surface pressure.

5. The top flange must be sized to receive the required tubing hanger, and of the correct working pressure to fit the adapter flange on the Christmas-tree assembly. Lock screws should also be included in the top flange.

6. The tubing head should be full-opening to provide full-sized access to the production casing string below and be adaptable to future remedial operations as well as to artificial lift.

Tubing Hangers

A tubing hanger is a device used to provide a seal between the tubing and the tubing head, or to support the tubing and to seal between the tubing and tubing head.

Types. Several types of tubing hangers are available, and each has a particular application. A brief discussion of the most popular types follows.

Wrap-Around. The popular wrap-around hanger is composed of two hinged halves, which include a resilient sealing element between two steel mandrels or dropped into the tubing-head bowl, and secured in place

-

WELLHEAD EQUIPMENT AND FLOW CONTROL DEVICES

by the tubing-head lock screws. The lock screws force the top steel mandrel or plate down to compress the sealing element and form a seal between the tubing and tubing head. Full tubing weight can be temporarily supported on the tubing hanger, but permanent support is provided by threading the top tubing thread into the adapter flange on top of the tubing head. The hanger thenacts as a seal only.

The tubing can be stripped through the hanger, between upsets, under pressure. After the Christmas-treeassembly has been attached to the adapter flange, the well can be circulated and a packer set under full control. This type of hanger is frequently used as a BOP when running tubing in a low-pressure well loaded with mud. If the well kicks, the tubing hanger can be latched aloundthe tubing and lowered into the tubing-head bowl. A sealis made by tubing weight and by use of the lock screws.After circulation, it can be lifted out of the bowl with the first upset below the hanger.

Polished-Joint. This type of hanger is slipped over or assembled around the top tubing joint, and the internalseals are adjusted to provide a seal on the tubing body. The hanger is sealed against the tubing head with a resilient seal. After the hanger is set, the Christmas treecan be attached to the top tubing thread and the well circulated under full control. The top tubing joint can be stripped through the hanger, between upsets, underpressure.

Boll-Weevil. This is a doughnut- or mandrel-typehanger attached to the top tubing thread and supported in the tubing-head bowl. A seal between the mandrel and tubing head is provided by hydraulic packing or 0 rings. It is the only hanger designed to support the tubing weight permanently.

Stripper Rubber. A stripper rubber is a pressureactuated sealing element used to control annuluspressures while running or pulling tubing in a low- pressure well. Tubing weight is supported by the adapterflange, a boll-weevil hanger, or slips located above the stripper rubber. In most cases, the stripper rubber shouldbe used in conjunction with a BOP and is not intended to replace the BOP.

Selection. In selecting a tubing hanger, the particular application should dictate the type required. In general, the hanger should provide an adequate seal between the tubing and tubing head and should be of standard size suitable for lowering through full-opening drilling equipment.

A backpressure valve is a check valve that is installed in the vertical run of the Christmas tree, usually in the tubing hanger or tubing head adapter. A backpressurevalve serves two main purposes: (1) to seal the bore of the tubing when removing the BOP and installing the Christmas tree when completing a well and (2) to seal the bore of the tubing when removing the Christmas tree or doing remedial work on the lower master valve. For the backpressure to pass through the Christmas tree the valves and other vertical-run fittings must be full- opening.

AvaIlable backpressure valves are generally of two types. One type is secured in place with threads, the

other is secured in place with an expanding-lock mechanism. 3-9

Adapter

An adapter is a unit used to join connections of different dimensions. The adapter may be used to connect two flanges of different dimensions or connect a flange to a thread. An adapter used to connect two flanges with different dimensions may be studded and grooved on one side for a certain flange size, and studded and grooved on the other side for a different flange size. A unit of this type is called a double-studded adapter.

Crossover Flange

A crossover flange is an intermediate flange used to connect flanges of different working pressures. Crossover flanges are usually available in two types.

1. A double-studded crossover flange is studded and grooved on one side for one working pressure, and studded and grooved on the other side for the next higher working-pressure rating. The flange must also include a seal around the inner string of pipe to prevent pressure from the higher-working-pressure side reaching the lower-working-pressure side. The seal may be of the resilient type, plastic-packed type, or welded type.

2. Another type of crossover flange includes a restricted-ring groove in the top side of the flange to fit a corresponding restricted-ring groove in the mating head. The restricted-ring groove and the seal between the flange and the inner casing string act to restrict the pressure to a smaller area, thereby allowing a higher pressure rating.

Christmas-Tree Assembly

A Christmas tree is an assembly of valves and fittings used to control production and provide access to the pro- ducing tubing string. It includes all equipment above the tubing-head top flange. A typical Christmas tree is shown in Fig. 3.3. Many variations in arrangement of wellhead and Christmas-tree assemblies are available to satisfy the needs of any particular application. Fig. 3.4 shows several typical assemblies.

Tubing-Head Adapter Flange

The tubing-head adapter flange is an intermediate flange used to connect the top tubing-head flange to the master valve and provide a support for the tubing. Standard adapter flanges of the following three types are available.

Studded Type. This unit consists of a lower flange with a ring groove and bolt holes to fit the top tubing-head flange, an internal thread in the bottom of the flange to receive and support the tubing weight, and a studded top connection to accommodate a flanged master valve.

Spool Type. This type is similar to the studded type except that the top connection is a flange to accommodate the master valve, and a top internal thread may be provided to act as a tubing landing or lift thread. It is also available with internal provisions for a backpressurevalve mandrel.

Threaded Adapter Flange. This type of adapter flange

is used to connect the top tubing-head flange to a threaded master valve. It is composed of a lower flange with a

3-10 PETROLEUM ENGINEERING HANDBOOK GAUGE VALVE

FLOWLINE VALVE)

& jgiqz$

(FLOWLINE VALVE)

I I wwc CHOKE VALVE

(FLOWLINE VALVE)

i hIASTER ULE

(FLOWLINE VALVE)

Fig. 3.3-Typical Christmas tree

TEE SINGLE WING - SINGLE COMPLETION THREADED MANIFOLD

DUAL TUBIN HANGER

DUAL TUBING HEAD

THREADED PARPLLEL STRING DUAL (OR TRIPLE) COMPLETION

SINGLE WING - SINGLE COMPLETION

INTERMEDIAT CASING HEAD

ALL FLANGED PARALLEL STRING DUAL COhlPLETlON

HIGH PRESSURE SINGLE WING- SINGLE COMPLETION

THREADED INDEPENDENT WELLHEAD

Fig. X4-Typical Christmas tree assemblies.

ring groove and bolt holes to fit the top tubing-head flange, an internal thread in the bottom to support the tubing string, and a male thread on top to connect the threaded master valve. The top male thread is usually an upset thread to give added strength.

A tubing-head adapter flange is described by specify- ing the lower flange size and working pressure, the bottom internal thread size and type, and the top-connection type, size. and working pressure. The lower flange must

flange on the adapter and the vertical run of the Christmas tree must be sized to provide full-opening access to the tubing. Tables 3.6 and 3.7 show the flange sizes that will provide full-opening bores for tubular goods.

Valves

API valves, like API wellhead equipment, are made of high-strength alloy steels to give safe dependable serv- WELLHEAD EQUIPMENT AND FLOW CONTROL DEVICES be of the same size and working pressure as the tubing- head top flange. The top connection must be of the same size and working pressure as the master valve. The top Y W ING VALVE

TEE ice. ASA valves are made of carbon steel and should not be used for wellhead service. Valves used on wellheads are basically of two types-gate valves and plug valves.

3-12 PETROLEUM ENGINEERING HANDBOOK

TABLE 3.8-FLANGED AND CLAMPED PLUG AND GATE VALVES,

2,000-psi MAXIMUM WORKING PRESSURE

Nominal Size

Old Nominal

Size

(in.) [mm1 (in.)

2h.x 13/16 52.4 x 46.0 2x13/4 2% 52.4 2 2%6 65.1 2% 3% l l 79.4 3 4x6* l 103.2 4 5% 130.2 5

7/BX6** 179.4x 152.4 6 7%6* l 179.4 6x7

Full-Bore Flowline Valves

(+/a -0) ] +0.60, - 01

(in.) [mm] --

1% 46.0

wl6 52.4 2s/16 65.1 3% 79.4 4h,j 103.2 5/8 130.2 6 152.4 7/15 179.4

Drift Diameter

(in.) [mm1 1 Y32 45.20 w32 51.60 2%2 64.30 3% 78.60 4% 102.40 5% 129.40 53% 151.60 7x2 178.60

End-to-End, Flowline Valves, ( * A6 in.) [r 1.6 mm]

Plug Valves

Reg. Full-Bore and

Gate Valves Full-Bore Venturi

(in.) [mm] (in.] [mm] (in.) [mm] --~ T ~ 11% 295.3 - 11% 295.3

11% 295.3 13h 333.4 11% 295.3 13% 333.4 15h 384.2 13% 333.4 141~ 358.8 1751~ 447.7 141~ 358.8 17% 435.0 2Oh 511.2 17% 435.0 22% 562.0 25h 638.2 - - 22% 562.0 28% 727.1 22% 562.0 26%~ 663.6 29% 739.8 - -

138 bar maximum workmg pressure. Maxnun through bores of 33h6, 4h, and 7% tn. [81.0, 106 0. and 161 0 mm] are permissible for nominal Sizes 3%. 4Ks, and 71& in. 179.4, 103.2, and 179 4 mm]-flanged end connection9 only

TABLE 3.9-FLANGED AND CLAMPED PLUG AND GATE VALVES, 3,000-psi MAXIMUM WORKING PRESSURE

Nominal


Old Bore Nominal (+ %. -0) Drift

End-to-End, Flowline Valves, (+A6 in.) [kl.S mm]

Plug Valves

Reg. Full-Bore and

Size Size [+0.80, -01 Diameter Gate Valves Full-Bore Venturi

(in.) [mm1 (in.) (in.) [mm] (in.) [mm] (in.) [mm] (in.) [mm] (in.) [mm] 2x13/4 13/16 - ~

~- -- -- 2%6x I%6 52.4 x 46.0 46.0 1732 45.20 14% 371.5 - - 14% 371.5

2x6 52.4 2 wl6 52.4 w32 51.60 14% 371.5 15% 384.2 145/a 371.5 29h 65.1 2% 2% 65.1 2 %2 64.30 16% 422.3 17% 435.0 16% 422.3 3% * * 79.4 3 3% 79.4 3% 78.60 17% 435.0 18% 473.1 15% 384.2 4x6* * 103.2 4 4h6 103.2 4x2 102.40 20% 511.2 22% 562.0 18% 460.4 5h 130.2 5 5 /a 130.2 5% 129.40 24% 612.8 26% 663.6 - -

7h6x6 179.4x 152.4 6 6 152.4 53% 151.60 24% 612.8 30% 765.2 24% 612.8 7x6** 179.4 6x7 7/j6 179.4 7% 178.60 28% 714.4 31% 803.3 - -

207 bar Maxrnum through bores of W6, 4/4, and 7% m 181 0, 06 0. and 181.0 mm] are permlsslble for nommalsizes 3%. 4A., and 7%, in. [79 4. 03 2, and 173 4 mm]-flanged end connect~ns only

TABLE 3.1 O-FLANGED AND CLAMPED PLUG AND GATE VALVES, 5,000-psi MAXIMUM WORKING PRESSURE

End-to-End, Flowline Valves, (& 1/l6 in.) [ + 1.6 mm]

Full-Bore Flowline Valves Plug Valves

Old Bore Reg. Nominal Drift Full-Bore and

Size Nos-nn;al (+%2, -0)

[+0.80. -01 Diameter Gate Valves Full-Bore Venturi

(in.) [mm1 (in.) (in.) [mm] (in.) [mm] (in.) [mm] (in.) [mm] (in.) [mm] -- -- 2%6X I%6 52.4 x 46.0 2x1-Y I%6 46.0 1% 45.20 14% 371.5 - - 14% 371.5

2x6 52.4 2 wl6 52.4 a2 51.60 14% 371.5 15% 393.7 14% 371.5 2%6 65.1 2% 2%6 65.1 2 %2 64.30 16% 422.3 18 457.2 16% 422.3 3% l l 79.4 3 3% 79.4 3?&2 78.60 18% 473.1 20% 527.1 18% 473.1 4x6** 103.2 4 4h6 103.2 4% 102.40 21% 549.3 24% 628.7 21% 549.3 5% 130.2 5 5% 130.2 53/x 129.40 28% 727.1 31% 790.6 - -

7/,sx6 179.4x 152.4 6 6 152.4 53h 151.60 28 711.2 36% 917.6 28 711.2 7x6* l 179.4 6x7 7/18 179.4 7x2 178.60 32 812.8 38% 968.4 - -

345 bar Mawmum through bores of 33& 4%. and 7% in. [El.O, 106 0, and 161 0 mm] are permeable for nominal sizes 3/s. 4& and 71/c in [79 4, 103 2, and 179 4 mm]-flanged and connectlon9 only

WELLHEAD EQU 3-13

Both are availavalves can be dwedging and n

Full-openingthe Christmasing. Full-openhead outlets anremoval servsometimes usecy or utility, to

Threaded valves are available in sizes from I /4 to 4 in.. with working pressures from 1,000 through 5,000 psi. Upset tubing threads are usually used on valves in

PED PLUG AND WORKING PRESSURE

Line Valves

t End-to-End ter (+ %rJ[ t 1.61 [mm] (in.) [mm]

5.20181/4 463.6

51.60 20% 520.7 64.30 22% 565.2

wl6 77.8 3%~ 77.8 3/32 77.00 24% 619.1 4lA.5 103.2 4/j6 103.2 4,& 102.20 26% 669.9

LUW

e

t te

[m

4551the vertical run of a Christmas tree to provide maximum strength. Valves with line-pipe threads are used on tubing wings, threaded tubing-head side outlets, and threaded casinghead side outlets. Most users prefer flanged valves on applications of 3.000-psi working pressure and above. Flanged valves are available in sizes from 1x6 through 7!,J6 in. with working pressure ratings from 2,000 to 20.000 psi as shown in Tables 3.8 through 3.14.

Christmas-Tree Fittings

Other Christmas-tree fittings include tees, crosses. and other connections necessary to provide the most desirable arrangement for the particular application.

The size of the vertical run may vary from 2x6 to 4N6 in. but must be consistent with the master-valve and tubing-head adapter-flange size to give full-opening access to the tubing for wireline tools and instruments. The outlet on the tee or cross and wing assembly must be of sufficient size to handle the production requirementswithout undue restriction. Outlets vary in size from I I&, to 4x6 in., although the 2x;,-in. size is normally adequate and is most commonly used in the U.S.

All Christmas-tree assemblies should be assembled,pressure-tested to hydrostatic test pressure, and checked with a drift mandrel to ensure full opening before installation. Table 3.15 shows the through-bores and drift diameter for each standard tubing size.

Bottomhole Test Adapter

A bottomhole test adapter is a device attached to the top of a Christmas-tree assembly to provide fast and safe adaptation of a lubricator for swabbing or testing. It may also include an internal thread to act as a lift thread for

TABLE 3.12-FLANGED P15,000-psi MAXIMUM

Full-Bor

Bore Nominal (+,& -0) Drif

Size [+0.80, -01 Diame

(in.) [mm] (in.) [mm] (in.)

- ~ - ~,13,,6 46.0 13/1~ 46.0 12%~ 2h 52.4 wl6 52.4 2h2

2% 6 65.1 wl6 65.1 21%2 64

*1.035 bar 690 bar

setting or raising the Christmas tree and tubing. It is available in sizes from 2%, to 4x6 in. and in working pressures from 1,000 to 20,000 psi.

Multiple-Completion Equipment

Multiple completions or multiple-tubing-string completions require the same lowermost casing head, intermediate casing head, and tubing-head equipment as single-tubing-string completions with one exception. The tubing-head bowl must be designed and sized to accommodate the required size and number of tubing strings and provide a means for properly orienting the tubing strings. Fig. 3.4 illustrates two types of dual parallel-string installations, and Tables 3.16 and 3. I7 give a listing of common multiple-string applications and specifications. The following equations, used with Fig. 3.5, may be used to determine the minimum casing size necessary for any combination of multiple-parallel- tubing-string completions.

Duals and quadruples:

dc(m;n)A+d,. . . . . . . . . . . . . . . . . . . (I)

Triples:

d&i,,) =2(Lt9, .

where d,.(,,;,) = minimum casing size,

d, = tubing diameter, L = distance (A, B, or C, whichever is

greatest, see Fig. 3.5).

G AND GATE VALVES, ORKING PRESSURE

Flow Line Valves End-to-End

(~/1d~1.61

Short Long r Pattern Pattern

m] (in.) [mm] (in.) [mm]

- - - - .20 18 457.2 - - .60 19 482.6 23% 596.9 IPMENT AND FLOW CONTROL DEVICES

ble with flanged end connections. Gate ivided into lubricated and nonlubricated, onwedging types. valves must be used in the vertical run of -tree assembly to provide access to the tubing valves must also be used on tubing- d casing-head outlets equipped for valve- ice. Restricted-opening valves are d as wing valves, without loss of efficien- effect an economic saving.

TABLE 3.1 l-FLANGED AND CLAMGATE VALVES, iO,OOO-psi MAXIMUM

Full-Bore Flow

Bore Nominal (+/32. -0) Drif

Size [+OBO, -01 Diame

(in.) [mm] (in.) [mm] (in.)

1%6 46.0 13& 46.0 I=/& 4

2%6 52.4 2/,6 52.4 2%2 29% 65.1 29h6 65.1 2h2 .30 21 533.4 25 635.0


Bore

Nominal (+/a. -0) Drift End-to-End

considered as previously suggested for selecting a single-

E

End Flange or Clamp Hub Minimum

Nominal Old Vertical t Mandrel meter l l

.) [mm1 6 32.72 6 3852 1 48.22 7 59.62 7 72.82 1 85.12 3 97.32 6 38.52 7 42.12 1 48.22 7 59.62 7 72.82 3 97.32 Stze and Nominal Workinq-Pressure Throuqh- Tubing Size DrifBore Size Rating Bore OD Weight Dia

(in.) [mm] (in.) (Psi) (bar) (in.) [mm] (in.) [mm] (Iblft) (in- - - - - - - TiG- 42.2 2.4- 1.28

1%6 46.0 1% 2.. 3-, and 5,000 138, 207, and 345 1/6 42.9 1.900 48.3 2.9 1.512% 52.4 2 2-, 3-, and 5,000 138, 207, and 345 2h6 52.4 2% 60.3 4.7 1.90846 65.1 2% 2-, 3-, and 5,000 138, 207, and 345 29h6 651 2% 73.0 6.5 2.343% 79.4 3 2-, 3-, and 5,000 138, 207, and 345 3% 79.4 3% 88.9 9.3 2.86- - - - - - 4 101.6 11 .o 3.35

4x6 103.2 4 2-. 3-, and 5,000 138, 207, and 345 41/1@ 103.2 4% 114.3 12.75 3.83lh 42.9 l%S lo- and 15,000 690 and 1035 I/16 42.9 1.900 48.3 2.9 1.51I%6 46.0 I%6 IO- and 15,000 690 and 1035 1% 46.0 2.063 52.4 3.25 1.65256 52.4 2x6 lo- and 15,000 690and1035 2x6 52.4 23% 60.3 4.7 1.9029/,6 65.1 2% 6 IO- and 15,000 690 and 1035 2?46 65.1 2% 73.0 6.5 2.343x6 77.8 3x6 IO- and 15,000 690 and 1035 3x16 77.8 3/2 88.9 9.3 2.864%6 103.2 4% 10,000 690 4% 103.2 4% 114.3 12.75 3.83Size [+0.80, -01 Diameter ( k /d + I.61 (in.) [mm] (in.) [mm] (in.) [mm] (in.) [mm]

13/1646.0113/ls- ~- - ~

46.0 12%2 45.20 21 533.4 wl6 52.4 2%~ 52.4 2/32 51.60 23 584.2 WI 6 65.1 WI6 65.1 2%2 64.30 26% 673.1 3x6 77.8 3/6 77.8 3/32 77.00 30% 774.7

1,380 bar

TABLE 3.15-THROUGH-BORESOF CHRISTMAS-TRENominal (+ %23 - 0) Drift End-to-End Size [ +0.80, -01 Diameter (~%~,)[+1.61

(in.) [mm] (in.) [mm] (in.) [mm] (in.) Imml ~-- 3% 77.8 3/, 77.8 3/3, 77.00 23% 6 598.5 4/6 103.2 4%6 103.2 4%~ 102.4 29 736.6

* 1,035 bar All dlmenslons in in [mm]

TABLE 3.14-FLANGED GATE VALVES, 20,000-psi MAXIMUM WORKING PRESSURE RATING


Bore Bar = 100 kPa **Drib mandrel dnmeters conform to the requrements for drifi mandrels for external ups

in. 152 4 mm] tubmg. which IS integral-lolnt. internal upset wth 1% EUE threads.completion tubing head, with the following additions. The tubing-head bowl should (1) be of the required size and internal design to receive the desired tubing hanger, (2) have the necessary nonrestrictive positioning or in- dexing devices to orient the tubing hanger accurately, (3) be designed to receive an available tubing hanger, which will suspend the desired number of tubing strings or a single tubing string, and (4) be so designed that removal of the BOPs is not necessary until all tubing strings have been landed and sealed.

Tubing Hangers. Multiple-completion tubing hangers perform the same function as single-completion tubing hangers, and as many types and variations in design are available. A brief description of common available types and designs follows.

Multiple-Bore Mandrel. This type of hanger consists of a large mandrel or doughnut with a separate bore for each tubing string. The individual tubing strings are landed in the large mandrel on landing collars. Backpressure valves can be installed in the individual

AND MANDREL SIZE EQUIPMENT 3-14 PETROLEUM ENGINEERING HANDBOOK

@-. f pt~R;~oE

dc ---b DUAL TRIPLE

Fig. 3.5-Multiple-parallel tubing strings (see Eqs.

TABLE 3.13-FLANGED GATE VALVES, 15,000-psi MAXIMUM WORKING PRESSURE RATING

1 and 2).

QUADRUPLE

Tubing Heads. In selecting a tubing head for multiple parallel-tubing-string service, the same factors should be et tubing as specified in API Spec. 5A: Casmg Tubing and DnN Rpe, excepl2.063

WELL -15

that the user select the lmnt of tubing to be mstalled at the top of the tubing string Note Drift size for the 111/,6 m 142 9 mm] nomlnal size is 1% in. [42 1 mm]

TABLE 3.17-CENTER DISTANCES OF CONDUIT BORES FOR TRIPLE, QUADRUPLE, AND QUINTUPLE PARALLEL BORE VALVES

Nominal Nominal Basic Size and

Basic Casing Size7 Radii End Flange

Minimum to Size and Bore OD Weight Bores Bore

(in.) [mm1 (in.) [mm] (Ibm/ft) (in.) [mm1 (in.) [mm] ~ - - - - - 2,000-, 3,000-, and 5,000-psi [13a-, 207-, and 345bar] Maximum Working Pressure

Triple 13/,f, 46.0 Valve 2x6 52.4

2% 52.4 2% 65.1

Quadruple 1 13/16 l 46.0 Valve I%6 46.0

2% 52.4 W6 65.1 T/16 65.1

Quintuple Valve 2x6 52.4

168.3 177.8

193.7 244.5

219.1 244.5

244.5 273.1

298.5

244.5

24 1%

26 I%6

39 2%

53.5 2s

36 2% All 3x6

53.5 3X6 55.5 3736

54 4

53.5 3%

47.63 49.21

53.98 71.44

73.03 77.79

77.79 87.31

101.60

77.79

lO,OOO-psi [6SO-bar] Maximum Working Pressure

Triple l?& 46.0 65% 168.3 24 1% 47.63 Valve 2/16 52.4 7 177.8 26 176 49.21

2x6 52.4 7% 193.7 39 2% 53.98 2% 6 65.1 9% 244.5 53.5 2%6 71.44

Quadruple Valve 2% 6 65.1 103/4 273.1 55.5 3%6 87.31

7hlj 179.4 9 228.6

9 228.6 11 279.4

11 279.4 11 279.4

11 279.4 11 279.4

13% 346.1

11 279.4

7hfj 179.4 9 228.6

9 228.6 11 279.4

11 279.4

Basic end connecbon SG% is determned by the size of tubing-head top connecbon, whach suspends the sweral tubing strings If an adapter flange IS used. a smaller valve end flange is sometimes permitted. HEAD EQUIPMENT AND FLOW CONTROL DEVICES 3

TABLE 3.16-CENTER DISTANCES OF CONDUIT BORES FOR DUAL PARALLEL BORE VALVES

Nominal Basic Casing Sizet

Basic End Size and Large Bore Small Bore Flange Minimum Bore to to Flange to Flange Size and

Bore OD Weight Bore Center Center Bore

(in.) [mm1 (in.) [mm] (Ibmlft) (in.) [mm] (in.) [mm1 (in.) [mm] (in.) [mm] ---- -~ 2,000-, 3,000-, and 5,000-psi [138-, 207-, and 345bar] Maximum Working Preure

l%s 42.9 5% 139.7 23 wi2 70.64 1.3905 35.319 1.3905 35.319 7/j, 179.4 46.0

52.4 65.1 x 52.4

65.1 x 52.4 65.1

65.1 79.4 x 52.4

79.4x65.1 79.4

46.0 5%

139.7 17 1 v32 70.64 1.3905 35.319 1.3905 35.319 7$ 179.4

177.8 38 3=/&l 90.09 1.7735 45.047 1.7735 45.047 7h6 179.4 177.8 29 33% 90 09 1.650 41.910 I .a97 48.184 7hG 179.4

193.7 39 4 101 60 1.875 47.625 2.125 53.975 9 228.6 193.7 29.7 4 101.60 2.000 50.800 2.000 50.800 9 228.6

219.1 49 4% 114.30 2.250 57.150 2.250 57.150 9 228.6 219.1 49 43~~ i 16.28 2.008 51.003 2.570 65.278 9 228.6

244.5 53.5 5% 126.19 2.5235 64.097 2.5235 64.097 11 279.4 244.5 53.5 53/s, 128.19 2.5235 64.097 2.5235 64.097 11 279.4

lO,OOO-psi [690-bar] Maximum Working Pressure

139.7 17 w32 70.64 1.3905 35.319

a16 52.4 7 177.8 38 33% 90.09 1.7735 45.047 29/,6x 2& 65.1 x 52.4 7 177.8 29 33% 90.09 1.650 41.910 236x2h6 65.1 x52.4 7% 193.7 39 4 101.60 1.875 47.625

Wl6 65.1 7% 193.7 29.7 4 101.60 2,000 50.800 WI6 65.1 8% 219.1 49 4% 114.30 2.250 57.150 3% 77.8 9% 244.5 53.5 5% 128.19 2.5235 64.097

1.3905 35.319 7,,6 179.4 1.7735 45.047 7/16 179.4

I ,897 48.184 7/16 179.4 2.125 53.975 9 228.6

2.000 50.800 9 228.6 2.250 57.150 9 228.6 2.5235 64.097 11 279.4

!&.s,c end connecton s,ze IS determ,ned by the s,ze of tubmg-head top conect~on, which suspends the several tub,ng strmgs. If an adapler llange IS used, a smaller valve end flange IS sometvnes permtlted. Center distances based on 2% [52.4 mm] OD tubing. tCAUTION: Due to the permwble tolerance on the OD lmmedtately behind the tubing upset, the user is cautioned that dlfflculties may occur It is recommended Center distances based on Z&-in. 152 4.mm] OD tubmg. tCAUTION Due to the permwble tolerance on the OD lmmedlately behlnd the tubmg upset. the user is cautioned that dlfficuttles may occur. It IS recommended that the user select the jomt of tubing to be installed at the top of the iub!ng string

OII 279.4 20 508 2'3& 71 4 2% 63 5

teub

l

86 11

1

273 1

13% 342 9

349.3 12 1 /a 1 25 32 a 203

431.8 16 1 '14 138 35 8% 222 489.0 20 1 '14 138 35 9 229

49

53 57 13% 346 1

16% 425.5 "17U 4509 21% 539 8

22 559 27 686 29% 743 32 813

2'5As 74 6 3% 84 1 39/M 90 5 3% 98 4

2% 66 7 3 76.2 3'h a2 6 3 '12 88 9

15% 400 1 19% 495 3 2l'h 5461 24 609 6

603.3 20 I'!> 162 42 10% 260 6541 20 I 5% 1 75 45 11 279 7239 24 I 5% 175 45 IIU 298

65 69 73

RING GROOVE

MUST BE CONCENTdlC

WITH BORE WITHIN 0010 TOTAL INDICATOR RUNOUT

landing collars. This is the most simple and easily installed hanger but is limited to applications where gas-lift valves or tubing accessories with external diameters greater than tubing-joint diameters are not needed.

Multiple-Segment. This type of hanger is composed of an individual hanger segment for each tubing string. Each segment seats in and occupies a part of the bowl when landed. Gas-lift valves and other tubing accessories may be installed on the tubing string. Each hanger segment may be equipped with provisions for backpressure valves.

Combination Mandrel and Boll-Weevil. This type of

i

DETAIL A L SEE DETAIL A

00 T AOLE CEN TEPLINE LOCATED WITHIN 0.03 OF THEORETICAL a.C. TOP VIEW AND EGUA SPAC,NG

Tension-Type. This type of hanger is constructed similar to the multiple-bore mandrel hanger and consists of a landing collar for each individual tubing string. The individual landing collars may be lowered through and lifted back up into the hanger mandrel, enabling the tubing strings to be set in tension through the BOPs. Backpressure valves may be installed in the landing collars.

Selection. In selecting a multiple-completion tubing hanger, the following factors should be considered. 3-16

TABLE 3.18-API TYPE 6B FLANGES FOR P,O

Bax Flange Dlmensmns

Nommal Old Size and Nommal

Bore of of Flange

__~

w ) [mm1

-460 ** IS/?/16

2!46 52 4

2% 651 3% 79 4

4'/;8 1032 ' * 5% 1302

7%6 1794 9 2286

SW3 Of Flange

11n /

OD of Flange

On) [mm1

6 18 156 6 % 165 7'!z 191 8 14 210

10% 273 13 330 I4 356 16% 419

Total Thickness of Flange

(1n.l [mm1 1 18 266 l%f, 33.3 1% B 36 5 1v,6 397

11%~ 46 0 2516 52 4 2% 55 6 2 % 63 5

BaSlC Thtckness of Flanqe

1 254 1 '/B 286 1 '14 31 a

I 'iz 38 1 1 36 445 I '/8 476 231,~ 55 6

Diameof H

IIn 1 2% 3iA6 3'5/,4 V8

6

10% hanger is similar to the multiple-bore mandrel hanger except that one string of tubing is supported by threading into the large mandrel. PETROLEUM ENGINEERING HANDBOOK

O-psi MAXIMUM WORKING PRESSURE

r

mml 69 9 4 1 00 0 175

52.4

Diameter Diameter Ring

of Bolt Number Diameter Of Bolt Length of Number ClrCk of Bolts of Bolts Holes Stud Bolts R or RX

(in ) (mm1 On ) Imml On 1 Imml 4% 1143 4 314 088 23 4% 108 20

1270 8 M 075 20 4% 114 1492 6 314 088 23 5 127 1683 8 34 088 23 5'/4 133

2159 8 7/B 100 26 6' I52 2667 8 1 112 29 6 1% 1 7 I 292.1 I2 I 112 29 7 I78

23 26 31

37 41 45 1. Seals on the individual hangers should not be exposed to damage by successive running of remaining tubing strings.

WELLHEAD EQUIPMENT AND FLOW CONTROL DEVICES

si

16% 425 5 18% 469.90 ' %> 11.91 % 6 7 94

l

31% 100 31% 100 4 'h 114 4 '12 114 20 508

1 The contour of the flange face wtsrde the d, diameter IS optronal wrth the manulacturer unless ratsed or full face IS specrfied on the purchase order

2 Rmg-groove radrus r,l shall be %z rn [0 79 mm] for groove wrdths ll& 18.73 mm] and '% [11 91 mm] 'A. in [I 59 mm] for width '%. [I 3 49 mm] 3 The bore d, 01 weldmg-neck flanges shall be as speofred on the purchase order

NOTE Bore drameter should be the same as ID of prpe to be used, but. because these flangeS are constructed Of Type 4 m&l& the bore shall not exceed valws of d, 4 The wall thrckness ot weldmg-neck flanges shall be not less than 87'!2% of the n0mlrW.l wall thrckness Of the pope to whrch the flange IS to be attached 5 The weldmg end of weldrng-neck flanges shall be cylrndrrcal or shall have a maximum draft at 7' The length shall be Sufficient to ensure a sound weld, but rn no case shall be

less than $14 rn 16 4 mm]

2. Positive packoff elements or seals should be provided.

3. Design should allow passage of gas-lift valves if needed.

4. Center lines should be provided to suspend tubing in the casing without spreading at the top.

5. The hanger should be constructed to accommodate positive seating of backpressure valves that do not require an oversize vertical run.

6. The hanger should be constructed for accurate, dependable pressure testing after tubing strings have been landed and sealed.

all fittings above the tubing-head top flange. Threaded, welded, independently flanged, and integrally flanged Christmas-tree assemblies are available for the installation of multiple tubing strings.

Threaded, welded, and independently flanged assemblies are furnished in working pressures of 2,000 and 3,000 psi, although threaded assemblies are rarely recommended for 3,000-psi applications. Welded assemblies are recommended for 3,000-psi service only on noncorrosive applications when pressures are expected to decline rapidly and economy is of great impor- tance. Integrally flanged assemblies are available in 2,000-, 3,000-, 5,000-. and lO,OOO-psi working pressures. These assemblies are preferred on severe or "17% 4509 21 533.40 7;; 21% 539 8 23 584 20 '732

138 Dar -'These 51zes available on spec,ai order Only

11.91 ?/,e 7 94 1349 % 9 53

4'51% 125 415& 125 5% 137 5 318 137

225/s 575 25 635

THREADED FLANGE WELD NECK

LINE PlPE FLANGE

REQUIREMENTS FOR TABLE 3.16 TABLE 3.18-API TYPE 6B FLANGES FOR 2,000-p

Ring-Joml Groove and Flange Facrng Dimensrons

Nommal Pitch

Size and Drameter Bore of of Tvoe R Wrdth of Death of Flanae

m ) lmml W.1 Imml (In )

46 0 52 4 65 1 79.4

103.2 1302 179 4 228 6

68 26 ' 'h a2 55 ' ?32 101 60 ' 5% i 23.83 '%2

149.23 ' %2 180.98 ' %2 211.14 ' %2 269 88 ' 732

11 279 4 12% 323.85 ' %2 13% 346 1 15 381 .oo %2

~___ [mm1 (1n.1 [mm1 __-__ a 73 'I4 6 35 11 91 %e 7.94 II 91 % 6 794 11 91 % 6 7.94

1 1 9 1 % 6 7.94 11 91 % 6 7 94 11 91 % 6 7.94

11 91 %6 7 94

11.91 % 6 7 94

11.91 %6 794

Dtameter of Raised

Face

On I lmm

3%6 90 4 'A 108 5 127 5 34 146

6% 175 0% 210 9 '12 241 11 I/B 302

14 356 16% 413 Christmas-Tree Assembly. The Christmas-tree assembly for a multiple-parallel-string wellhead includes 3-l 7

MAXIMUM WORKING PRESSURE (continued)

Hub and Bore Drmenstons

Hub Hub Hub Neck Maximum Length Lenqih Length Drameler Bore of

Threaded Threaded Lrne-Prpe Casmg

Flanqe Flanae

(ln 1 [mm1 0n 1 lmml ____-__ 1 % 38 - - 1% 44 - - 1'V,6 49 - - 2% 54 - -

2x6 62 3% 89 2"/16 68 4 102 2'5,& 75 4 % 114 35/,, 84 5 127

31%6 94 5 J/4 133

Weldin&Neck Welding-Neck Lme-Pipe Line-Prpe

Flange Flange

On ) Imml On) [mm1

76 2 1.90 48 3 81.0 238 60 5 87 3 2.88 73 2 90 5 3.50 88 9

109 5 4.50 114.3 122 2 5.56 141.2 1254 6.63 168.4 141 3 a.63 2192

1603 1075 2731

Welding Neck

Flanae

(ln ) [mm1

GE---- 40.89 2.067 52.50 2.469 62 71 3.068 77 93

4.026 102.26 4.813 122 25 5.761 146 33 7813 19845

9750 24765 corrosive 2.000- and 3,000-psi service, and recommended for 5,000- and lO,OOO-psi applications.

,0

terub

[m

69

10

12

12

15

19

235

298

368

419

508

565

622

d, = diameter of raised face, in.

d,g = pitch diameter of ring and groove, in. Failure of the energy source or any component must D, = depth of groove, in.

h, = height of outside bevel, in., or basic

thickness of flange, in.

h, = height of ring, in.

h, = total thickness of flange, in.

Lc = hub length of threaded casing flange, in.

L, = length of hub, in.

L, = hub length of threaded line-pipe flange, in.

L, = hub length of welding-neck line-pipe flange,

in.

L

Lb,

= length of stud bolts, in.

= hub length of tubing flange, in.

fg = radius in groove, in.

rH = radius of hub or radius at hub, in.

rr = radius in octagonal ring, in.

Flange Data

Tables 3,18 through 3.26 show API standard flanges and

cause the system to go to the safe mode. Usually safe mode means the wells are shut in at one or more points.

Safety systems sense conditions on the lease or platform and shut in the well or wells when conditions deviate from the preset limits. Shutting in the well averts further danger due to (1) uncontrolled flow from rup- tured pressure vessels, (2) fueling any fire that has started or may start, or (3) overfilling vessels with fluid and/or pressure.

The systems consist of fail-safe valves (safety valves), sensors, logic control valving and indicators, and a power source. Some systems may be contained in a single valve or they may be very large multiwell, multivalve, multiparameter, multilogic systems in- tegrated into a production control system with telemetry. Severity of consequences usually dictates how elaborate the safety system should be.

Safety valves may be located in the tubing string [subsurface safety valve (SSSV)], on the Christmas tree, or downstream of the well in the process train (surface safety valve) (Figs. 3.6 and 3.7). Most safety valves are controlled with externally applied fluid pressure. Release of 3-18

TABLE 3.19-API TYPE 6B FLANGES FOR 3

&SIC Flange Dlmensrons

Nominal

Size and Old

Nommal Outside Total

Bore of Diameter Thickness Flange

Size of

Flange of Flange of Flange

(In.) mm1 (In.) (in) [mm] (rn.) [mm]

t I%6 46.0 1% 7 178 1% 38.1

P/l, 524 2 w/2 216 1%6 46 0 WI6 65.1 2% 9% 244 ls/,6 49.2 3% 79.4 3 9% 241 1% 46.0

4%6 103.2 4 1 I/2 292 2/,6 52.4

t 5% 130.2 5 13% 349 p/,6 58.7

71/x 1794 6 15 381 2% 63.5

9 228.6 8 18% 470 23/16 71.4

11 279.4 IO 21% 546 3%~ 77.8

13% 346.1 12 24 610 3/,6 87.3

16% 425.5 16 27% 705 35/ls 100.0

t17Y4 450.9 18 31 787 4% 114.3

20% 527.1 20 33% 857 4% 120.7

207 bar See Table 3 le sketch tThese SIZE. ~nactwe. wallable on special order Only

Basic

Thrckness Diameof Flanae of H

(In.) [mm] (in.) --__-

1 A 31.8 2%

1 % 38.1 4/8

1 5/a 41.3 4%

1 /2 38.1 5

1 % 44.5 6A

2 50.8 7%

WI6 55.6 9% 2/2 63.5 11%

2% 69.9 14%

3% 79.4 16%

3% 88.9 20

4 101 6 22%

4 /4 108.0 24%

Nomenclature for Tables 3.18 through 3.29

b, = width of flat of octagonal ring, in.

b, = width of groove, in.

b, = width of ring, in.

d,, = diameter of bolt circle, in.

d bh = diameter of bolt holes, in.

d hCmaxj = maximum bore of welding-neck flange, in.

dt = diameter of flat, in.

d, = pitch diameter of groove, in.

d, = hole size, in.

d, = diameter of hub, in.

d,, = large diameter of hub, in.

dHs = small diameter of hub, in.

d, = neck diameter of welding-neck line-pipe

flange, in.

d, = OD of flange, in.

d

z

= groove OD, in.

= OD of ring, in. arc reproduced with permission of API. These tables cover working pressures of 2,000 to 20,000 psi. API is PETROLEUM ENGINEERING HANDBOOK

00-psi MAXIMUM WORKING PRESSURE

Bolting Dlmenslons

Diameter

Of Bolt Circle

m] (rn.) [mm]

.9 4~0 123.8

4.8 6% 165.1

3.8 7% 190.5 7.0 71% 190.5

8.8 9% 235.0

0.5 11 279.4

.0 12h 317.5

.5 15% 393.7

.3 18% 469.9

.1 21 533.4

.0 24% 616.0

.2 27 685.8

.3 29% 749.3

Number

of Bolts

0

0

12

12

16

20

20

20

20

Diameter

of Bolts

(In.)

?h

Of Bolt

Holes

Length

of Stud Bolts

(In.) mm1 1.12 29

1.00 26

1.12 29

1.00 26

1.25 32

.38 35

1.25 32

1.50 39

1.50 39

1.50 39

1.75 45

2.00 51

2.12 54

(in.) [mm] __- 5h 140

6 152

6% 165 6 152

7 178

7% 197

a 203 9 229

9% 241

10% 260

11% 296

13% 349

14% 368

Ring

Number

R or RX

20

24

27

31

37

41

45

49

53

57

66

70

74

presently standardizing flanges for 30,000-psi working pressure. API has recently standardized a line of clamp- type connectors in sizes 2x6 through 21% in. in the 5,000 and lO,OOO-psi working pressure ranges. The design criteria and detailed dimensional data for these clamp-type connectors are given in API Spec. 6A. Details for API ring-joint gaskets for API flanges and clamp-type connectors are shown in Tables 3.27 through 3.29.

Flow Control Devices: Safety Shut-In Systems

Since the consequences of uncontrolled well flow are so severe, especially offshore, automatic well shut-in safety systems are important enough that they are sometimes mandated by law. 6 Safety systems must be failsafe. the control pressure allows the valve to close.

WELLHEAD EQUIPMENT AND FLOW CONTROL DEVICES 3-19

TABLE 3.19-API TYPE 69 FLANGES FOR 3,000-psi MAXIMUM WORKING PRESSURE (continued) Ring-Joint Groove and Flange Facmg Dlmenslons Hub and Bore Dlmenslons

Pitch Hub Neck

Diameter Hub Hub Length Diameter Maximum

Nominal of Type Diameter Length Length Hub Bore of Size and

Welding Welding

R Ring Of Threaded Threaded Length Neck Neck

Bore of

Welding

and Width of Depth of Raised Lme-Pipe Casmg Tubing Line-Pipe Line-Pipe Neck Flange Groove Groove Groove Face Flange Flange Flange Flange Flange Flange

(in.) [mm] (in.) [mm] (in.) [mm] (in.) [mm] (In.) [mm] (in.) [mm] (In) [mm] (in) [mm] (in.) [mm] (in.) [mm] (in.) [mm] ___~

** I=/,,6 46.0 2/,6 68.26 /& 0.73 /4 6.35 3% 92 2 51 - - 2 51 3% 88.9 1.90 48 3 1.500 38.10

wl.5 52.4 3% 95 25 s/x* 11.91 5& 7.94 4% 124 29/,6 65 - - 2% 6.5 4%~ 1095 2.38 60.5 1.939 4925 WI6 65.1 4% 107.95 %2 11.91 %G 7.94 5% 137 213h6 71 - - 23/6 71 4/,6 112 7 2.813 73.2 2 323 59.00 3% 79.4 4% 123.83 S/52 11.91 S/q6 7.94 6% 156 2"/,6 62 - - 2'5/& 75 4%6 109.5 3.50 88 9 2 900 73.66

4x6 103.2 5% 14923 s/32 11.91 s/,6 7.94 7% 181 3% 76 3'/2 89 3% 69 4's~ 122 2 4.50 114.3 3 826 97.18

* * 5% 130.2 7% 18098 %> 11.91 Y 6 7.94 8% 216 3%, a7 4 102 - - 5%e' 134.9 5.56 141.2 4.813 122.25

7x6 179.4 f3?,8 211 14 %* 11 91 Y,6 7.94 9% 241 31x6 94 4'/2 114 - - 5'j/,s 147.9 6.63 1684 5.761 146.33

9 226.6 10% 269.88 %z 11.91 % 6 7.94 12% 308 45/j6 110 5 127 - - S"/,, 169.9 8.63 219.2 7 439 188.95

11 279.4 12% 323 05 S/3* 11.91 s/,6 7.94 14% 362 43/,6 116 5% 133 - - 7%~ 192.1 10.75 273 1 9.314 236 56

13% 3461 15 361 00 & 11.91 %6 7.94 16% 419 45h6 125 45/,6 125 - - - - - - _

16% 425.5 18% 469 90 2'/,2 16.67 %G 11.11 20% 524 5'1/,, 144 5x'?/,, 144 - - - - - - ~ ~

17% 450.9 21 533.40 25/3* 19.84 A! 12.70 23% 594 6/2 165 6% 165- - - - - - -

20% 527.1 23 564.20 z/32 19.84 l/z 12.70 25% 648 6% 171 63/4 17, _ _ _ - _ - - :

207 bar See Table 3 18 sketch tThese s,zes ,nact,ve wallable an special order only.

RECXJIREMENTS FOR TABLE 3.19

1. 3, 4, and 5 See Table 3 18 2 Rmg-groove radius T.~ shall be A2 I. IO.79 mm] for groove wdlhs & and % [8 73 and 1 I 91 mm] and 1/,6 I [1.59 mm] for widths 2/32 and z:& ]I6 67 and 19 84 mm] 6 Excepl for bore of weldmg neck flanges, dlmerwons for sizes 11%6 10 Z9/ ,,s tn [46 0 10 65.1 mm]. inclusive, are ldentlcal with S.OOO-PSI [345-bar] flanges I Table 3.20 7 MaxImum through bores of 33/,6. 4X, and 716 I [El 0. 108.0, and 181 0 mm] are permwble for nommal sws 3%. 4/ls. and 71,~ [79.4, 103 2, and 179 4 mm]. respectiveiy 8. Flanged end connections of some casing and tubing heads may have entry bevel recesses and/or counterbores greater than d, maximum 10 receive a packer mechanism The

s,~es and shapes of these bevels. recesses, and/or counterbores are prapriefary and are 01 covered by this speclflcatlon

Llqud Regulator Fus,hle

Manual IF

Emergency ShuGOown Valve a, Boat Landmo

(ESD) - I Lx- I, I

\ Control Panel ./

Pressure Sensors

t Surface Controlled Subsurface Safety Valve

Fig. 3.6-Production platform safety shut-in system.


TABLE3.20-API TYPE 68 FLANGES FOR 5,000~psi MAXIMUM WORKING PRESSURE

Basic Flange Dimensions Boltmg Dimensions

Nominal

Size and Old

Nominal Outside Total Basic Diameter Olameter Length

Bore of Diameter Thvzkness Thickness Diameter of Bolt of Bolt of Stud

Hydraulic Surface c1 Safety Valve

Surface Controlled

Subsurface Safety

Valve

Fig. 3.7-Safety shut-in system with hydraulic valves and pneumatic valves Flange Size of

of Flange of Flange of Flange of Hub Circle Diameter Rtng

Flange ~ Number of Bolts Holes Bolts Number

(in.) [mm] (in.) (in.) [mm] (m) [mm] (In.) [mm] (in.) [mm] (in.) [mm] of Bolts On.1 (in.) [mm] (In.) [mm] R or RX

-46.0

--~

t I% 1% 7 178 1% 38.1 1 /4 31 8 2% 69.9 4% 123.8 1.12 29 5% 140 20 1.00 26 6 152 24

.._ WE 52.4 2 8% 216 13,s 46.0 1 % 38 1 4% 104.3 6% 165.1 2% 6 65.1 2% 9% 244 l5/,16 49.2 1% 41.3 4% 123.8 7% 190.5 3/s 79.4 3 10% 267 2% 55.6 1% 47.6 5% 133.4 8 203.2

4% 103.2 4 12% 311 256 61 .9 2% 54.0 6% 161.9 91/z 241.3 t 5% 130.2 5 14% 375 33/jG 81 0 27/e 73 0 7% 196.9 11% 292.1

7% 179 4 6 15% 394 3% 92.1 31% 82.6 9 228.6 12% 317.5

9 228.6 8 19 483 4%~ 103.2 35/a 92.1 11% 292.1 15% 393.7

&h 279.4 346.1 ,35/8 10 23 - 584 - 41%~ - 119 - 1 4% - 108.0 - 14% - 368.3 - 19 - 482.6 _

$163/q 425.5 ,lj3/4 - - - - - - - - - -

4 1

8 V8

8 1

8 1 /B

: 1 1 /r /2

12 1 3/a

12 1% 12 1 /s - -

- -

1.12 29 6% 165 27

1 25 32 7% 184 35

1 38 35 8 203 39

1.62 42 10 254 44

1 50 39 10% 273 46

1.75 45 12 305 50 200 51 13% 349 54

345 bar. *See Table 3 18 sketch +These sues ,nactwe, wallable on spectal order only *See Table 3 22 for dtmenslon details an these sizes.

Fusible

Plug

Pneumatic Surface

- Safety Valve

Control Panel

S

7346

osnginrs(te

at the entrance to the sales pipeline or the pipeline leav-ing a platform.

lve-bodysure andl pressure

ecause theressure.

e simplered gas are

the usual control fluids. Control pressures are generally250 psi or less.

the SSVntrols theon the general-the well.Most SSVs are reverse-acting production-gate valvesLow-ratio hydraulic actuators are used where with piston-type actuators (Fig. 3.8). Valve-bodyis to be controlled by the same system that copressure against the lower stem area moves the gate toSSSV, or where limited space is available the up/closed position. Control pressure applied to theChristmas tree (Fig. 3.9). Control pressures arepiston pushes the gate to the down/open position. Usual-ly slightly greater than the shut-in pressure of REQUIREMENT

,,3,4,and5 SeeTable2 R1n9.groove radius r,g shall Ye jhz m (0 79 mm] for 9roove widths & and s/S2 m [86 Except for bore of welding-neck flanges, dtmenslons for suxs 11%6 III to 23/,5 !n [7 and 8 See Table 3 19

Surface Safety Valves (SSVs)An SSV on the Christmas tree is usually the secin the flow stream. Hence it is the second maif it is in the vertical run, otherwise it is a wiSSVs can be located downstream of the well cess train at such places as (1) flowline headetion, discharge, and bypass on a compressor safety valve safe mode is open instead of closFig. 3.8Pneumatic-powered ratio-piston surface safety vaFOR TABLE 3.20

and 11 91 mm]. 1/,6 1. (1 59 mm] for wdths Xz and 2& [13 49 and 16 67 mm]0 to 65 1 mm]. mclus~ve, are ldentlcal with 3,000.PSI [207-bar] flanges I Table 3 19

nd valveter valve, valve.

the pro-, (2) suc-

he bypassd), or (3)

ly a spring is used to close the valve if vapressure is not present. Valve-body prespiston/stem area ratio determine the controrequired.

Large-ratio pneumatic actuators are used blarger ratio permits use of lower control pLower-pressure control-system valves can band more reliable. Compressed air or producWELLHEAD EQUIPMENT AND FLOW CONTROL DEVICES 3-21

TABLE 3.20API TYPE 6B FLANGES FOR 5,000-psi* MAXIMUM WORKING PRESSURE (continued)

Ring-Joint Groove and Flange Facing Dimensions

PitchDiameter

Nominal of Type DiameterSize and R Ring ofBore of and Width of Depth of Raised

HubLength

ThreadedLine-Pipe

Hub and Bore Dimensions**

Hub NeckHub Length Diameter Maximum

Length Hub Welding Welding Bore ofThreaded Length Neck Neck Welding

Casing Tubing Line-Pipe Line-Pipe NeckFlange Groove Groove Groove Face Flange Flange

(in.) [mm] (in.) [mm] (in.) [mm] (m) [mm] (in.) [mm] (in.) [mm] (In.) [mm]~--__- __~

t 1%6 46.0 211/,, 68 26 /zz 8.73 /4 6 35 3 % 92 2 51 - -2/,, 52 4 3% 9525 % 11.91 % f 7 94 4 % 124 2%~ 65 - -24, 65 1 4% 107.95 Sk* _ 11.91 %6 - 7 94 5 a/a 137 213/16 71 - -3 % 79.4 5% 136.53 1% 11 91 %6 7.94 6% 168 33/16 81 - -

4116 1032 6 % 161.93 1%~ 11.91 % 6 7 94 7s/, 194 3 % 98 3 % 98t 518 1302 7 % 193.68 1Yz2 11.91 %6 7.94 9 229 4%6 113 4x6 113

7%6 179.4 85/j6 211.14 /zz 1349 3/s 9.53 9 % 248 5x6 129 5x6 1299 228.6 10% 269.88 *l/x2 16.67 /I 6 11 11 12% 318 WI, 154 wl6 154

11 279 4 12% 323.85 2/~2 16.67 %6 11 11 14% 371 6%6 170 6/,6 170

Flange Flange Flange Flange

On.) Imml bn) lmml 0n) lmml t(n) ~[mm1-~2 51 3 /2 8 8 9 1.90483133733 9629~~ 65 45/j6 109 523/16 71 47/,6 112733/16 81 415/]6 125 4

3 % 98 53/,6 131 8- - 6/,6 163 5- - 7% 181 0- - 83/>~ 223 8- - lOY,e 265 1

2.38 605 1 689 42 902 88 73 .2 2 .125 53 983 50 889 2624 66 65

4 5 0 1 1 4 3 3 4 3 8 87 335 5 6 1 4 1 2 4 3 1 3 1 0 9 5 56 6 3 1 6 8 4 5 1 8 9 1 3 1 8 08 6 3 2 1 9 2 6 . 8 1 3 1 7 3 0 5

1 0 7 5 2 7 3 1 8 5 0 0 2 1 5 9 0$135/E 346.1 - - - - - _ - - - _ _ _ _ _ _ - _ - _ -$163/q 4255 - - - _ - - - - - _ - _ _ - _ - - - - -

345 barSee Table 3 16 skerchlve.Fig. 3.9Pneumatic and hydraulic surface safety valves


TABLE 3.21-API TYPE 6BX INTEGRAL FLANGES FOR 5,000-AND lO,OOO-psi MAXIMUM WORKING PRESSURE

2.000 PSI (138 bar)

Bmc Flange Dlmerwons

Nommal Large Small Sue and OutsIde Total Diameter Diameter Length Radus Bore Diameter Thickness of Hub of Hub of Hub at Hub

(in 1 lmml On ) [mm1 bn) bml W ) Imml (in) bml (ln) lmml (ln 1 lmml -__ 26% 6795 41 1041 4='/2> 126 2 322%~ 835.8 29% 743 0 73/,6 166 vu 159

3.000 PSI (207 bar) 26%

5,000 PSI (345 bar) 13% 716% 18% 2 1%

10,000 ps, (690 bar) '*I"&

I'%16 2%6

6795 43% 1102 6"/>, 161 1 34% 870.0 30%, 7763 75& 186 518 15 9

346.1 26% 673 4x6 1127 la'%, 481 0 16"/,6 423 9 4% 114 ve 159 425.5 30% 772 5% 1302 21% 5556 20% 527 1 3 76 74 19 1 476.3 35% 905 6'7/,2 1659 26%~ 674 7 23%, 598 5 6 152 % 159 539.8 39 991 7% 181.0 29% 7588 26% 679.5 6% 165 "AS 175

429 7%6 183 1% 42.1 3% a4 1 2'3/>2 61.1 12y32 47 ve 9.5 46.0 7% 187 12%~ 42 1 3% 08 9 2% 65.1 1% 48 % 9 5 52.4 7% 200 14%4 44.1 3'%. 1000 2'5& 746 2% 52 K 9 5

65.1 9 'h 232 2%. 51.2 4% 120 7 3% 92.1 2M 57 V8 9.5 77 8 10% 270 2'Ysq 563 5'9,& 142.1 4"/32 110.3 2% 64 3% 9 5 1032 12',$6 316 2-/s, 702 73/,e 1826 5% 1461 2% 73 W 95 1302 14'/IS 357 31/s 79.4 813/,, 2238 7'& 182.6 3% 81 3/s 9 5

1794 18% 479 4%. 1032 11% 3016 IO 254.0 3% 95 5% 159 2286 21% 552 4% 1238 14% 374.7 12% 327.0 3'Xs 94 s/s 15.9 2794 25% 654 5%6 141 3 17% 450 9 15% 400.1 4vj6 103 5/s 15.9

346 1 30% 768 6% 1683 21% 5525 lS'/z 4953 4% 114 =/s 15.9 425 5 345ie 872 6% 1683 25'%a 6556 23'1/,6 601.7 3 76 % 19.1 476 3 40'5/,, 1040 Sz5/,z 223 0 29% 752.5 21?/~ 674 7 6% 156 % 15.9 5398 45 1143 9% 2413 33% 8477 30 762 0 6% 165 13/,rj 206

Nominal

Boltmg Dlmensms Facing andGroove Dimensions

Diameter Diameter Lenath Raised

2.000 MI (138 bar) 3.000 psr (207 bar)

Sam and of Bolt Diameter of Bolt of Siud Face Gr0CW? Width of Depth of Bore Circle Number 01 Bolls H&S Bolts Diameter OD GKPSe GrCO!e t3ng

w 1 [mm] (m) [mm] of Bolts (117 ) (m ) [mm] (in.) [mm] (ln ) [mm] (1n.1 /mm] (in) [mm] (in.) [mm] Number

26% 679.5 37% 9525 20 ~ 1 % 1.88 48 13% 349 31"',,, 804 9 30.249 768.32 0902 22.91 2',32 21.43 BX-167

26% 6795 39% 10001 24 2 2.12 54

1 78 1.75 45 1 % 2.00 51 2 2.12 54 2 2.12 54

u 088 23 3'4 088 23 % 0.88 23

'/s 100 26 1 112 29 1 '/a 125 32

1 '/a 125 32 1 'h 162 42 1 'h 1 62 42 1% 1 88 48

1 w 200 51 1% 200 51 2% 238 61 2% 262 67

17 432 32% 831.9 30.481 774.22 1.018 25.86 25'32 21.43

I8 4572 16063 408.00 0786 1996 V,s 1429 21%~ 535 0 16.832 478.33 0.705 1791 *'kn 6.33 24"& 627.1 22.185 563.50 1.006 25 55 '3& 18.26 27% 701.7 24.904 63256 1.071 27 20 % 19 05

4 101 6 2.893 73.48 0.450 11 43 '& 5 56 4% 104 8 3062 77.77 0.466 11 84 ?& 5 56 4% 111.1 3395 8628 0.498 12 65 '%a 5 95

5% 131 8 4.046 10277 0.554 14 07 '%a 6 75 6 152.4 4685 11900 0.606 1539 's,64 7 54 7% 184 9 5.930 150.62 0.698 17 73 ?%a 8 33

6'%s 220.7 6.955 17666 0666 1692 3/s 9 53 11% 301.6 9.521 241 83 0.921 23 39 %6 11 11 14% 358.8 11 774 29906 1039 26 39 'h 1270 16% 428.6 14064 35723 1.149 2918 %h 1429

20% 517.5 17.033 43264 1279 3249 5/s 15 88 22"/,, 576.3 18.832 478 33 0 705 17.91 z'& 8 33 27'A6 696.9 22752 57790 1290 32 77 23& 18 26 30% 781.1 25.507 64788 1373 3487 % 19 05

8X-168

5,000 ps; 13% 346.1 23% 590.6 16 (345 bar1 t16% 425.5 26% 676.3 16

18% 476.3 31% 603.3 20 2 1% 539.8 34% 885.8 24

10,000 ps, * * 1 1% 6 429 5% 6 141.3 8 (690bar) 1'%6 46 0 5% 146 1 8

2h 524 6% 1586 8 2% 65 1 7% 184 2 I3 3%6 77 6 8% 2159 6 4',& 1032 1O3/,6 2588 8

5% 1302 ll'Y,s 3000 12 71:s 1794 15% 4032 12 9 2286 18% 4763 16 11 2794 22% 5652 16

13% 346 1 26% 6731 20 16% 4255 30% 7763 24 18% 4763 36% 9255 24 21% 5396 40% 10224 24

'345 and 690 bar '.ThlS flange 14 InaCtIve avaIlable on s&x?clal Older only

12% 318 14% 368 17% 445 18% 476

5 5 5%

127 127 133

6 6% 8

8% 1 1% 13 15

17% 17% 22% 24'h

152 171 203

222 286 330 381

438 445 572 622

+Thts tlangewasadopledJ"ne 1969 and shall be marked wth both theworking ,xessure (50OOWP)and the test ~ressure,10,000TPI ,n add,l,on ,aalher mark,nS requwemenfs

BX-160 8X-162 8X.163 BX-165

EX-150 8X-151 8X-152

8X-153 8X-154 BX-155

8X-169 8X-156 BX-157 BX-158

6X-159 6X-162 EX-164 BX~l66

WELLHEAD EQUIPMENT AND FLOW CONTROL DEVICES 3-23

TABLE 3.22-API TYPE 68X WELDING-NECK FLANGES FOR lO,OOO- AND 15,000-psi MAXIMUM WORKING PRESSURE

Nominal Size and Bore

Basic Flange Dlmenslons

Large S"Mll OutsIde Total Dlametet Diameter Length R&us Diameter Thickness of Hub of Hub of Hub at Hub

10.000 psi

(690 bar)

15,000 PSI (1035 bar)

bml On.)

429 7%6 460 7% 524 7%

651 9% 778 lO~/n 1032 12%6

1302 14%6 1794 18v.. 2286 21%

2794 25% 346 1 30'14 425 5 34%,

lmml (ln) Imml (in ) [mm] (in.) [mm] (tn.) [mm] (m ) [mm] 183 lvx 42 1 3%6 84 1 2'Y32 61.1 12x2 47 I 9 5 187 1v3* 42 1 3'/2 88.9 29/~6 65 1 129/,1 48 % 95 200 I'%4 44 1 3'Yje 1000 2'7,6 74.6 2%2 52 ?/8 9 5

232 2'/64 51 2 4% 120 7 35/e 92.1 2'14 57 3/s 95 270 2's& 58.3 5f=/32 142 1 4"/s2 110 3 2'/2 64 =/a 9 5 316 PS& 70 2 73/,6 182.6 5% 1461 2'ls 73 318 9 5

357 31% 794 6"/,vj 2236 7x6 1826 3Y,e 81 3h 9.5 479 4'/16 1032 11R 301.6 10 254.0 3% 95 5/a 159 552 47/s 1238 14% 374.7 127/n 327.0 3('/(6 94 78 159

654 5Y6 141 3 17% 4509 15% 400.1 4'& 108 s/s 159 768 65/s 1683 21% 5525 19'h 495.3 4'h 114 s/a 159 872 65/s 1683 2513/,5 6556 23'%6 601 7 3 76 % 19.1

**1/j6 42 9 75/e 194 1% 44 5 3"/18 937 21Y,6 68 3 178 48 ?/s 9 5 1'3/.. 46 0 8%. 208 12% 45 2 32'/w 97.6 2'3h. 71 4 1% 48 3/a 9 5 , . .- , 2% 6 524 6% 222 2 50 8 4%- 111.1 3'/4 82 6 2Vs 54 k 9 5 244 6 651 IO 254 2% 57 2 51/15 128.6 31%6 100 0 2'14 57 % 9 5 3% 6 778 ll%e 287 2'/;, 64.3 6%, 1540 4'3/16 122 2 2'12 64 Vs 95 4x5 103 2 143/,, 360 33/32 786 7"/js 195.3 6'/4 158 8 27/e 73 Ye 95 7'/< 6 1794 19vn 505 4"& 119 1 12'3h6 3254 10% 2762 35/s 92 VI3 159

Bolting Dlmensons Facmg and Groove Dlmenslons

Nominal Diameter Dlametet Length Ralsed SIX and of Bolt Diameter of Bolt of Stud Face G"JOVt? Width of Depth of B0te Circle Number of Bolts

Holes Bolts Dwneter 00 Groove GVXNe mng

(1" 1 [mm] (in) [mm] of Bolts (1" 1 (1") [mm] (in) [mm] (in.) [mm] (in.) [mm] (1) [mm] (tn.) [mm] Number

10.000 DSI . f 1 ',< c 42 9 5%. 141 8 % 068 23 5 127 4 101 6 2.893 73.48 0.450 11 43 '/w 556 (690 ba;) 1 ' % 6 46.0 5%- 146 1 8 %

2%6 524 6 % 1588 a % 291,s 65 1 7'/s 184 2 8 7/s 3'& 778 a','* 215 9 8 1 4'& 1032 lOz& 2588 8 1 '/s

5'18 1302 11'v,/,6 3000 12 1 'ia 7'h. 1794 15'/s 4032 12 1 '/2 .I 9 2286 18% 4763 16 1 'h

11 2794 221/n 5652 16 1% 135/a 346 1 26% 6731 20 1 '/a 16% 425 5 30%~ 7763 24 1 '/a

15,000 PSI * * 1 'j/,6 429 6 1524 a % (1035 bar) I?/,6 46 0 65/16 1603 8 %

2%6 52 4 6% 174.6 8 xl 2%6 65 1 7'/s 2000 8 1 3% I 77 8 9% 2302 8 1'18

088 23 088 23

100 26 112 29 125 32

125 32 1.62 42 162 42

1.88 48 200 51 200 51

0.88 23 100 26 1.00 26 1.12 29 125 32 1.50 39 1.62 42

127 133

152 171 203

4?e 104.8 3.062 77.77 0.466 11 84 :i; 5 56 43/a 111 1 3395 8623 0498 1265 's/h4 5 95

5%~ 131 8 4.046 102.77 0554 1407 '!/64 6 75 6 1524 4685 11900 0606 1539 %4 754 7%, 184 9 5.930 150.62 0.698 1773 2'ka 8 33

222 286 330

381 438 445

8"h 220 7 6.955 176.66 0.666 16 92 3/s 9 53 IlVe 301 6 9.521 241.83 0.921 2339 '/,e 11 11 14'/s 358 8 11.774 299.06 1.039 2639 '/2 12 70

1678 428 6 14.064 357.23 1.149 29 18 91. 14 29 203/s 517 5 17.033 432.64 1.279 32 49 5/E 15 66 22'%8 576.3 18.832 476.33 0.705 17.91 =h4 8.33

133 3'3A, 96.8 2.893 73.48 0.450 11 43 ',& 5.56 140 43/,6 106.4' 3.062 77.77 0.466 11 84 "32 5.56 152 4% 114.3 3.395 66.23 0 498 12 65 '%4 5 95 171 5'/4 133.4 4.046 102.77 0.554 14.07 '%A 675 191 6'/,, 154.0 4.685 119.00 0.606 15 39 '?& 7.54 235 7Vs 193.7 5.930 150.62 0 698 1773 VM 8 33 324 12 304.8 9.521 241.83 0.921 23.39 '/I/(6 11 11

BX-151 BX-152

BX-153 BX-154 BX-155

BX-169 BX-156 BX-157

8X-158 8X-159 6X-162

BX-150 BX-151 6X-152 BX-153 BX-154 BX-155 BX-156

REQUlREMENTSFORTABLES3.22ANO3.24

1 Dueto the d~ff~cuity offteld welding API Types 2 and 3 material from which theseilangesare made,atransjt~on p~ecemay beshopwelded tothe base flange and the weld properly heat treated This frans~t~on piece shall be made from the same or smlar matenal as the pipe to which II IS Lo bewelded by the cusfomer Trans~t~on prxe ID and OD al the held weid~ng end. and 11s maternal. shall be speclfled on the purchase order 2 The length of the lransit~on pwe shall be great enough thal the near from fleid weldmg will not affect the metallurgIcal properws of the shop weld 3 The API monogram shall be apphed lo the weldmg-neck flange (solld outl~nej The API monogram does "at apply to the shop weld or the trans,tion p,ece 4 D~mensianh,, may be omltted onstudded connections


77 8 103 2

9x6 230.2 8 1 l/a 125 32 7'/2 191 11x6 290.5 6 1 3/s 1 50 39 9% 235

154.0 4.665 119 00 0.606 15.39 'g& 7 54 193.7 5 930 150 62 0.696 17.73 2/k4 a 33

6X-154 BX-155

Documents

67992588 Wellhead Equipment and Flow Control Devices