Lyons W.C. (ed.). Standard handbook of petroleum and natural gas engineering.2001- Volume 1

037

ft

-

2675

fi

9861

fi

1'"

4

t

Casing and Casing String Design

1165

SECTION

No.4

7"

-

321bIft

,

N-80

Casing

SECTlON

No.

3

7"

-

29

Ib/ft

,

N

-80

Casing

SECTION

No.

2

7"

-

261bIft. N-80

Casing

SECTION

No.

I

7"

-

29

Ib/ft,

N-80

Casing

Figure

4-378.

Schematic diagram

of

combination casing string.

1.6

Care must be exercised, particularly when running long casing strings,

to ensure that slip bushing or bowl is in good condition. Tongs should

be examined for wear on hinge pins and hinge surfaces. The backup

line attachment to the backup post should be corrected if necessary to

be level with the tong in the backup position,

so

as

to

avoid uneven

load distribution on the gripping surfaces of the casing. The length

of

backup line should be such as

to

cause minimum bending stresses on

the casing and to allow full stroke movement of the makeup tong.

1.7

The following precautions should be taken in the preparation of casing

threads for makeup in the casing strings:

a.

Immediately before running, remove thread protectors from both field

and coupling ends and clean the threads thoroughly, repeating as

additional rows become uncovered.

1166

Drilling and Well Completions

b. Carefully inspect the threads. Those found damaged, even slightly,

should be laid aside unless satisfactory means are available for

correcting thread damage.

c. The length

of

each piece of casing shall be measured prior to

running.

A

steel tape, calibrated in decimal feet to the nearest

0.01

ft,

should be used. The measurements should be made from the outer-

most face of the coupling or box to the position on the externally

threaded end where the coupling or the box stops when

the

joint is

made up powertight. On round-thread joints this position is the place

of the vanish point on the pipe; on buttress-thread casing, this

position is to the base of the triangle stamp on the pipe; on extreme

line casing to the shoulder on the externally threaded end. The total

of the individual length

so

measured will represent the unloaded

length of the casing string.

Note:

The actual length under tension in the hole can be obtained

from pertinent graphs or approximately calculated from

(4-323)

where

AL

=

casing elongation in in.

L

=

original length of casing in in.

E

=

casing modulus of elasticity (for steel

E

=

(30)(106)

lb/in.*)

y,

=

casing specific weight, lb/ix~.~ (for steel

ys

=

0.283

Ib/h5)

yf

=

fluid specific weight in lb/in.3

p

=

Poisson’s ratio (for steel

p

=

0.28)

Formula

4-323

is valid for any consistent system of units and is

applicable to vertical holes.

d. Check each coupling for makeup. If the stand-off is abnormally great,

check the coupling for tightness. Tighten any loose couplings after

thoroughly cleaning the threads and applying fresh compound over

the entire thread surfaces, and before pulling the pipe into the

derrick.

e. Before stubbing, liberally apply thread compound to the entire

internally and externally threaded areas. It

is

recommended that high-

pressure modified thread compound

as

specified in

API

Bulletin

5A2:

“Bulletin on Thread Compounds” be used except in special cases

where severe conditions are encountered; it

is

recommended that high

pressure silicone thread compound as specified in Bulletin

5A2

be used.

f.

Place a clean thread protector on the field end of the pipe

so

that

the thread will not be damaged while rolling pipe on the rack and

pulling into the derrick. Several thread protectors

may

be cleaned

and

used repeatedly for this operation.

g. If a mixed string is to be run, check to determine that appropriate

casing will be accessible on the pipe rack when required according

to program.

h.

Connectors used as tensile and lifting members should have their

thread capacity carefully checked to assure that the connector can

safely support the load.

i. Care should be taken when making

up

pup joints and connectors to

assure that the mating threads are of the same size and type.

Casing and Casing String Design

1167

1.8

Drifting of casing. It is recommended that each length of casing be

drifted for its entire length just before running with mandrels con-

forming to the requirements

of

Standard

5A

“Specification for Casing,

Tubing and Drill Pipe.” Casing that will not pass the drift test should

be laid aside.

1.9

Lower

or

roll each piece of casing carefully to the walk without dropping.

Use rope snubber if necessary. Avoid hitting casing against any part of

derrick

or

other equipment. Provide a hold back rope at window. For

mixed and unmarked strings, a drift

or

“jack rabbit” should be run

through each length of casing when it

is

picked up from the catwalk

and pulled onto the derrick floor, to avoid running a heavier length or

one with a lesser inside diameter than called for in the casing string.

Stubbing, Making

Up,

and Lowering

1.10

Do not remove thread protector from field end

of

casing until ready

to stub.

1.11

If

necessary, apply thread compound over entire surface of threads just

before stubbing.

1.12

In stubbing, lower casing carefully to avoid injuring threads. Stub

vertically, preferably with assistance

of

someone

on

the stubbing board.

If the casing stub tilts to one side after stubbing, lift up, clean and correct

any damaged thread

with

threecornered file, then carefully remove any

filings to ensure that threads

are

engaging properly and not cross-threading.

If spinning line is used, it should pull close to the coupling.

Note:

Recommendations in paragraphs

1.13

and

1.14

for casing makeup

apply to the use

of

power tongs.

For

recommendations of makeup of

casing with spinning lines and conventional tongs, see paragraph

1.15.

1.13

The use

of

power tongs for making up casing made desirable the

establishment of recommended torque values

for

each size, weight and

grade of casing. Early studies and tests indicated that torque values are

affected by a large number

of

variables, such as variations in taper, lead,

thread height and thread form; surface finish; type

of

thread compound;

length of thread; weight and grade of pipe; etc. In view of the number

of variables and the extent that those variables, alone or in combination,

could affect the relationship of torque versus madeup positions, it was

evident that both applied torque and madeup position must be con-

sidered. Since the API joint pullout strength form& in API Bulletin

5C2

contains several of the variables believed to affect torque, the use of

a

modification

of

this formula to obtain torque values was investigated.

Torque values obtained by taking

1%

of the calculated pull-out value

were found to be generally comparable to values obtained by field

makeup tests using API-modified thread compound in accordance with

API Bulletin 5A2. This procedure was, therefore, used to establish the

optimum makeup torque values listed in Table

4-153.

Maximum torque

values listed are 75% of optimum values and maximum values listed are

125% of optimum values. These values must necessarily be considered

a guide only, due to the very wide variations in torque requirements

that can exist

for

a specific connection. Because

of

this, it is essential

that torque be related to makeup position as outlined in paragraph

1.14.

(text

continued

an

page

11

74)

1168

Drilling

and

Well

Completions

Table

4-153

Recommended Casing Make-up Torque

1

2

3

4

5

6

7

8

9

Nominal

Weight Toque, ft-lb

Size:

Threads,

Grade

r

Outside and

Short

Thread

Long

Thread

Diameter

Coupling

r

-.

in.

Ibnerft

Ontimum

Mium

bhximum

Oetimum

Minimum

&ximum

4K 9.50

H-40

9.50 5-55

10.50 5-55

11.60 5-55

9.50 K-55

10.50 K-55

11.60 K-55

11.60 G75

13.50 G75

11.60

L80

13.50

La0

11.60

N-80

13.50

N-80

11.60 G95

13.50 G95

11.60 P-110

13.50 P-110

15.10 P-110

770

1010

1320

1540

1120

1460

1700

580

760

990

1160

840

1100

1280

960

1260

1650

1930

1400

1830

2130

-

1620

-

1800

2150

2600

2230

2710

2280

2760

2580

3130

3020

3660

4400

-

1220

-

1350

1610

1950

1670

2030

1710

2070

1940

2350

2270

2750

3300

-

2030

-

2250

2690

3250

2790

3390

2850

3450

3230

3910

3780

4580

5500

5

11.50 5-55 1330 1000 1660

-

- -

13.00 5-55

1690 1270

2110 1820

1370 2280

15.00 5-55 2070 1550

2590 2230

1670 2790

11.50 K-55 1470

1100

1840

-

13.00 K-55 1860

1400 2330

2010

1510 2510

15.00 K-55 2280

1710

2850 2460 1850 3080

15.00

GI5

- -

-

2960

2220

3700

18.00

G75

- -

-

3770 2830

4710

21.40

GI5

-

4660 3500

5830

24.10

GI5

-

5390 4040

6740

-

3080 2310 3850

15.00

L80

-

3950 2950 4910

18.00

L-80

-

21.40

L80

-

- -

4860 3650 6080

- -

5610 4210 7010

24.10

L-80

-

15.00

N-80

-

3140 2360

3930

18.00

N-80

- -

-

4000

3000 5000

21.40

N-80

-

4950 3710

6190

24.10

N-80

-

5720 4290

7150

-

3560 2670 4450

15.00 G95

-

18.00 G95

-

4550 3410 5690

21.40 C95

-

5620 4220 7030

24.10 G95

-

6500 4880 8130

-

4170 3130 5210

15.00 P-110

-

18.00 P-110

- -

-

5310 3980 6640

21.40 P-110

-

- -

6580 4940 8230

24.10 P-110

-

7600 5700 9500

Casing and Casing String Design

1169

Table

4-153

(continued)

1

2 3

4

5

6

7

8

B

"in81

=ht.

Tomu*.

It-lb

-

5% 14.00

H-40

1300

980

1690

2150

- -

-

1520 2170 1630 2710

2470 1850 3090

12W

2530

14.00 5-55 10

15.50 5-55 2020

17.00 J-55 2290 1720 2860

14.00 K-55 1890 1420 2360

-

15.50 K-56

2220

1670 2780

2390 1790 2990

17.00 K-55 2520

1890 3150

2720 2010

3400

-

3270

2450 4090

-

4030

3020 5040

-

4730

3550 5910

17.00 C-75

20.00 C75

23.00

c-75

-

3410 2560 4260

-

4200 3150 5250

17.00 680

23.00

L-80

-

- -

4930 3iOO 6160

20.00

LBO

-

3480 2610 4350

-

4280 3210 5350

17.00

N-80

23.00 N.80

-

5020 3770 6280

20.00

N-80

-

3960

2970 4950

-

4870 3653 6090

17.00 C95

23.00 C-95

-

5720 4290 7150

20.00 c-95

3470 5780

5690 7110

8350

4620 4270

17.00 P-110

29.00 P-110

- -

-

6680 5010

20.00 P-110

-

20.00

24.00

20.00

24.00

28.00

32.00

24.00

28.00

32.00

24.00

28.00

32.00

24.00

28.00

32.00

24.00

28.00

92.00

H40

J-55

5-55

K-55

G76

c-75

C-76

LBO

680

L-80

N-80

C-95

c-95

c.95

P-110

FllO

P-110

1840

2460

8140

2670

3420

1380

1840

2360

2000

2570

2300

3060

3930

3340

4280

2660

3400

2900

3720

4530

5520

5380

4730

5760

6660

4810

5860

6770

5490

6690

7740

6410

7810

9040

2000

2650

2180

2790

3400

4140

4790

3550

4320

5000

3610

4400

5080

4120

5020

6810

4810

5860

6780

3330

4250

3630

4650

5660

69M)

7980

5910

7200

8330

6010

7330

8460

6860

8360

9680

8010

9760

11300

1170

Drilling and

Well

Completions

Table 4-153

(continued)

1

2 3

4

5

6 7

5

9

Torque.

It-lb

Short

Tbnad

ton.

Thread

Omhum

Nislmum

Mnximum

Optimum Minimum luimm

Nomind

and

Gmplinr

Ib.

wr

fL

cnde

c

s1.c:

pl&t;

OuWdc

Diumem

In.

I

17.00

20.00

23.00

26.00

20.00

25.00

26.00

23.00

26.00

29.00

32.00

36.00

88.00

29.00

26.00

29.00

32.00

35.00

38.00

25.00

26.00

29.00

32.00

35.00

38.00

26.00

29.00

32.00

35.00

38.00

H-40

3-55

J-65

K-55

G75

(2-75

c-75

C-75

c-75

GI6

L-80

L-50

L-80

N-80

E95

G95

E95

c-95

P-110

-

- -

3130 2350

3670 2750

3410 2560

4010 3010

-

4160 3120

4890 3670

5620 4220

6330 4750

7030 5270

7670 5750

4350 3260

5110 3830

5870 4400

6610 4960

7340 6510

5010 6010

6930 5200

7970 5980

8970 6730

9960 7470

10570 8150

-

3910

4590

4260

5010

5200

6110

7030

7910

8790

9590

5440

6390

7340

8260

9180

10010

5530

6490

7460

8400

9330

10180

6310

7410

8540

9600

10660

11640

8660

9960

11210

12450

13590

-

7% 24.00 €I-40 2120 1590 2650

-

- -

26.40

5-56

3150

2360 3940

3460

2600 4330

26.40 K-65 3420

2570

4280 3'770

2830 4710

C-75

(3-75

c-75

C-76

4610

5420

6350

7510

8520

9530

3460

4070

4760

5630

6390

7150

5760

6780

7940

9390

10650

11910

Casing

and

Casing

String

Design

1171

Table

4-153

(continued)

-

4820

3020 6030

-

5670 4250 7090

26.40 L-80

-

6640 0980

8300

29.70 L-80

-

7860 5900

9630

33.70

LBO

-

8910 6680

11140

39.00 L-80

47.10 L-80

-

9970 7480

12460

42.80

LBO

-

26.40

29.70

33.70

39.00

42.80

47.10

N-80

4900

Si50

6740

7980

9060

10130

3680

4310

5060

5980

6800

7600

6130

7190

S430

9980

11330

12660

26.40

29.70

33.70

39.00

42.80

47.10

C-95

c-95

G95

c-95

42-95

5600 4100

6590 4940

7720

3790

9140

6860

10370 7780

11590 8690

7690

57iO

9010

6760

12100 9080

13530 10150

10660

Boon

7000

8240

9650

11430

12960

14490

29.70

33.70

39.00

42.80

47.10

P-110

9610

11260

13330

15130

16910

1750

2090

1830

2790

3260

2910

3490

3050

4650

6430

H-40

5-55

2330

2790

2440

3720

4340

2630

4020

4680

28.00

85

92.00

24.00

32.00

36.00

3130

3650

3390

3950

-

5210

6080

5650

6580

-

4170

4860

K-55

K-56

1970

3020

3510

3290

5030

5850

24.00

32.00

36.00

-

4520

5260

6480

7420

8340

9390

4860

5570

6260

7040

8100

9280

10430

11740

36.00

40.00

44.00

49.00

c-75

C75

36.00

40.00

44.00

49.00

LBO

L-80

LBO

N-80

6780

7760

8740

9830

5090

5890

6560

'i3iO

8080

9700

10930

12290

6880

7880

8870

9970

7890

9040

10170

11440

5160

6910

6660

7480

5920

6780

SC30

8580

8600

9850

11090

12460

9860

11300

12710

14300

36.00

40.00

44.00

49.00

36.00

40.00

44.00

49.00

40.00

44.00

49.00

C95

c-95

C95

P-110

10550

11860

13360

7810

8900

10010

13190

14830

16690

1172

Drilling and

Well

Completions

Table

4-153

(continued)

1

2

S

4 5 6

7

8

9

32.30

"

36.00

40.00

36.00

40.00

43.50

47.00

53.50

40.00

43.50

47.00

53.50

40.00

43.50

47.00

53.50

40.00

43.50

47.00

63.50

43.50

47.00

53.50

H-40

J-55

K-55

IC-55

C-75

c-75

G75

G80

L-80

N-80

c-95

P-110

-

4530

5200

4830

5610

God0

5760

8520

9990

7270

8130

8030

10470

1310

8950

9050

10620

8470

9480

10400

13200

11060

12130

14230

I-

-

3400

3900

3670

4210

5210

5820

6390

'7490

5450

6100

6700

7850

5539

6190

6730

7970

6350

7110

7800

9150

8300

9100

10670

-

5660

6500

GllO

7010

8680

9700

10650

12490

9090

10160

11160

13090

9210

11310

13280

10590

11950

13000

15250

13830

15160

17780

10310

-

32.75

E40

2060

1540

2580

40.50

H-40

3140

2360

3930

40.50 3-66

1200

3150

5250

-

45.50 J-55

4930

3700

6160

-

51.00

J-55 5650

4240

7080

-

3380

6630

-

5280

6600

-

61.00

K-55

6060

4550

7580

-

4500

3960

40.50 K-55

45.50 K-55

51.00 G75 7560 5670 9450

-

55.50 C-75 8430 6520 10540

-

51.00

L-80

7940 5960 0930

-

55.50 L-80 8840

6630

11050

-

61.00

N-80 8040 6030

10050

-

55.50 N-80 8950

6710

11190

-

51.00 '2-95 9270

-

6950 11500

55.50 G95 10320 7740

12900

-

51.00

P-110

10800

8100

13500

55.60 P-110

12030

9020

15n10

60.70

P-110

13380

10040 16iRO

-

65.70

P-110

14720

11040

18

100

-

Casing and Casing String Design

1173

Table

4-153

(continued)

1

2 3 4

5

6

7

a

9

Temuc.

rut.

Short

Thd

lane

Ihmd

Xominill

sir:

Wcinht.

=nd

C0"Pll.l

Ib

wr

ft

Outsid.

Thmds

Grade

,

'

Optimum

Midmum

Yuimrm

Ortinwu Minimum

Mmxinum

Diameter

in.

3840

-

11% 42.00 H-40

3070

2300

47.00 J-55 4770 3580 5960

1100 54.00 J-55 5630 4260

60.00

J-55 6490 4870 8110

6360

- -

-

47.00 K-55 5090 3820

1580

54.00 K-55 6060 4550

60.00

K-55 6930 5200 8660

8690 6520

10860

-

60.00

C-75

60.00

680 9130 6850 11410

-

60.00

N-80 9240 6930 11550

-

10660

8000 13330

-

60.00

C-95

60.00

P-110 12420

9320

16530

-

- -

-

18% 48.00

54.50

61.00

68.00

54.50

61.00

68.00

72.00

68.00

72.00

68.00

12.00

68.00

12.00

68.00

72.00

H-40

5-55

K-55

C-75

GI5

680

N-80

c-95

G95

P-110

3220

5140

5950

6750

2420

3860

4460

5060

5470

6330

1180

9060

9780

9620

10290

9630

10400

11140

12040

12970

14020

4100

4750

5390

6800

7340

7140

7720

7220

7800

8360

9030

9130

10520

4030

-

6430

7440

8440

-

6840

7910

8980

-

11330

-

12230

-

11900

12860

12040

13000

13930

15050

16210

-

17530

-

*16 65.00 H-40

-

4390

75.00 J-55

-

7100

84.00 5-55

-

8170

-

7520

75.00

K-65

84.00 K-55

-

8650

*18K

87.50

H-40

-

5590

87.50 5-55

-

7540

87.50 K-55

-

7940

-

- -

-

~~ ~~

-

a20

94.00

H-40

-

5810

-

1840

94.00 J-55

-

9130

106.50 J-55

133.00

5-56

-

11920

94.00

K-55

-

8240

106.50

K-55

-

9600

133.M)

K-55

-

12530

-

9070

-

10570

-

13800

-

9550

-

11130

-

14530

-

-I"

pa-.

1.14h

for

nr.~.-me

imtnmwna

Source: Taken

from

API

RP

5C1,

12th

Edition,

March

1981.

1174

Drilling and Well Completions

(text

continued

from

puge

1167)

The torque values listed in Table

4153

apply to casing with zinc-plated

couplings. When making up connections with tin-plated couplings,

80%

of the listed value can be used as a guide.

Fieid Makeup

1.14

The following practice is recommended for field makeup casing.

Round Thread,

44

through 133 in.

OD

a. It is advisable when starting to run casing from each particular mill

shipment to make up sufficient joints to determine the torque

necessary to provide proper makeup. See paragraph

1.15

for proper

number of turns beyond hand-tight position. These values may

indicate that a departure from the recommended optimum values

listed in Table

4-153

is advisable. If other optimum torque values are

chosen, the minimum torque should not be less than

75%

of the

optimum selected. The maximum torque should be not more than

125%

of the optimum torque.

b. The power tong should be provided with a reliable torque gage of known

accuracy. To prevent galling when making up connections in the field,

the connections should be made up at a speed not to exceed

25

rpm.

c. Continue the makeup, observing both the torque gage and the approxi-

mate position of the coupling face with respect to the last scratch position.

d. The optimum torque values as shown in Table

4153

have been selected

to give optimum makeup under normal conditions and should be

considered as satisfactory providing the face of the coupling is flush with

the last scratch

or

within two thread turns plus or minus the last scratch.

e. If the makeup is such that the last scratch is buried, two thread turns

and the minimum torque shown in Table

4-153

is not reached, the

joint should be treated as a questionable joint as provided under

paragraph

1.16.

f. If several threads remain exposed when the optimum torque is

reached, apply additional torque up to the maximum shown in Table

4-153.

If the stand-off (distance from face of coupling to last scratch)

is greater than three thread turns when the maximum torque is

reached, the joint should be treated as a questionable joint as pro-

vided under paragraph

1.16.

Buttress Thread,

4

3

through 13 +-in.

OD

g. Makeup torque for buttress thread casing connection in sizes

4+

through

139

in.

OD

should be determined by carefully noting the

torque to make up each of several connections to the base of the

triangle; then, using the torque value thus established, make up the bal-

ance of the pipe of that particular weight and grade in the string.

Round Thread and Buttress Thread,

16,

18#- and 20-in.

OD

h. Makeup of

16,

18%

and 20-in.

OD

shall be to a position on each

connection represented by last scratch on 8-round thread and the

Lyons W.C. (ed.). Standard handbook of petroleum and natural gas engineering.2001- Volume 1

Подождите немного. Документ загружается.