19963-MS Design and Development of High-Strength, Sour Serv

7/24/2019 19963-MS Design and Development of High-Strength, Sour Serv

1/9

IADCYSPE

lADC/SPE 19963

Design and Development of High-Strength, Sour Service Drillpipe

R.M. Shivers ill, Texaco U.S..; J.B. Greer, Greer Engineering Co.; and J.E. Smith, Hughes Tool Co.

SPEMembers

copyright 1SS0, lADC/SPE Drlllng Conference.

This paper wee prepared for preeenta ion at the l= IAIXXSFE Orill lngConference held in Houston,Texas, February 27-March 2, 19S0.

This paper wae eeleeted for preeentatlonby an IADCLSPEProgram Commlttea followingreview of informatkrncontained in an abstract submittedby the author(a). Ccni6 lt of the

papar, as presented, have notbeenreviewedby the Society ofPetrolaum

EnQlnOSrar

the InternationalAaeociatlonof DrillingContrectoraand are sub)ectto correctionEyIhe author(a).

Tka material, se presented, does notneceeaarilyreflect any positionofthe IAN or SPE, itsofficers,or mombefe. Papers presentedat IALWSPE meetings are aubjeotto publketkm

reviewby EditorialCommltteea of the IADO and SPE. Permissionto copy Is restricted to an abstract of notmore

than300

words. Illustralionemay notbe capbd. The abstract should

mtein correpkuouaaCkrWb8dQMSntofW@reandby*m * PSPWiaPfeeented.WritepufJf~t~ MWVSQSJIE. p-o.

SOX. R~~~I ~ ~ C T I~ ~

Abntraat

The Norphlet is generally sour across

the entire Mississippi -Alabama-Florida

Drillpipe for deep, sour, highly

region.

Well tests in Alabama State

deviated,

abnormally pressured Norphlet

Waters, show ii2Sconcentrations up to 8.8

wells in the Mobile Bay Area requires

z401epercent.

Concentrations in wells

tensile and torsional strength in excess of

drilled in Federal waters are much

conventionalAPI Grade X-95 drillpipe with

lower--

generally less than 1.0 Mole

NC50 tool joints.

It was decided to

percent.

construct a drillstring from 105,000 psi

[724 MPa] minimum yield strength steels

The first two prospects to be drilled

with optimum chemical composition for

required directional wells under shipping

welding, toughness, and resistance to H2S

fairways in OCS waters in Mobile Blooks 872

exposure.

Design load requirements led to

and 869.

The initial exploratorywells for

the selection of a tool joint with a

these leases would require horizontal

secondary torque shoulder. Quality displacementsof 2,800

ft

and 6,000 ft [850

assurance testing indicated that an SSC

m and 1830 m], respectively.

Torque and

resistant, Grade CG-105 grade drillpipe is

feasible to manufacture.

drag analysis indicated that conventional

API Grade X-95 drill pipe would not have

adequate strength to drill either of these

two wells with an acceptabledesign factor.

Introduction

Some operators have overcome the

Commercial gas reserves have been

discovered

in Mobile

torque and drag problems introduced by

Bay

and

the

ultra deep

~irectional drilling by using

surrounding

offshore

areas

in the API Spec 5D , S-135 drillpipe; however,

ultradeep, sour,

abnormally pressured

this violates generally accepte

-$ i:~stry

Norphlet Sandstone.

Production intervals

practice for H S drilling.

+

was

in the Mobile Bay Area range from 20,000

decided to cons ruct a drillstring from

feet to 25,000 feet [6100 m to 7600 m] in

105,000 psi [724 MPaJ minimum yield

depth necessitating a high strength

drillstring suitable for directional

strength steels with optimum chemical

composition for welding, toughness and

drr::ing with possible exposure to sour

resistanceto

H2S exposure~ termed

CG-105.

All of Texacols leasehold in the Lower

Drill String Design

Mobile Bay area lies in the federal waters,

rig. 1.

The Norphlet lies between 21,000

ZZ9U 2iUUR?XK~

and 23,000 ft [6400 and 7000 m] on the

Texaco leases.

Several of these leases are

Drillstrixt:torque and drag analYsis

crossed by shipping fairways necessitating

was conducte~ &sing a computer program

directionaldrilling to exploit reserves.

developed by &he Joint Industry Drilling

Engineering Association Extended Reach

----------------------------

Drilling Program.

The program calculates

Referencesand illustrationsat end of paper

torque aiuidrag as the product of the

..

4s1


2/9

2

DESIGN AND DEVEIA2PMENT

OF

HIGH STRENGTH, SOEA SERVICE DRILL PIPE

IADC/SPE1

Laterdl force of the drill string against

Fig. 3. This tool joint has the same thre

the borehole, drill string diameter, and a

form as the 5-1/2 in. [14 cm] Full Hol

friction factor.

Actual torque and drag

It features a secondary torque shoulder

data from two offset directionalwells were

the pin nose to increase torsiona

history matched to determine friction

capacity.

When the joint is Whandtightw

factor vulues.

Torque and drag versus

gap of 0.009w+/-0.003w[0.23am +/-0.08 m

horizontaldisplacementwere calculated for

both steel and aluminum drillstring in

exists between the secondary shoulder

the pin and the mating sesondary should

both oil and water base muds.

in the box.

The gap closes when the

joint

Apparent friction factors derived from

is made-up power tight, and rotationa

friction between the secondary shoulde

offset

directionalwells drilled with water

boosts the torsional yield

of

th

base mud were unexpectedlyhigh.

Friction

connection.

The connection performance

factors for drag ranged up to 0.80 and

for

torque up to 0.62.

sensitive to the handtight gap clearanc

These friction facto:us

but Eor all cases, it satis2ies th

include escalation to account for miilor

drillstringdesign criteria.

wellbore undulations.

Both oil base mud and aluminum

Nickel electroplatingwas selected a

drillpipe substantially lower predicted

the primary anti-gallingprotectionfor t

connection based on experience.

torque and drag.

Only t

The use of these two

box member was nickel platel because nick

options would have eliminatedthe need for

special steel drillpipe.

on nickel will gall unless one member

Howover, this

hardened.

option was rejected because of concern

regarding the ability of aluminum drillpipe

to retain its strength in the 400F [204C]

The largest high torque connecto

BHST drilling environment. The practical

previously used was an HT-50 (4-1/2

equivalent);

limit for steel drillpipe in water base mud

therefore,a test program w

conducted to confirm performanceproperti

appeared to be 6,000 ft [1830 m] horizontal

displacementand this was adequate to drill

of the HT-55 before beginning productio

the two initial exploratorywells.

lwo prototypeconnectionswere manufactu

representing the maximum and IniniIRumg

range 0.006- 0.012 in. [0.15- 0.30

mm

rig.

2 Giiows

that the practical

tensile limit (80% yield) on new 5~0,25.6

The connections were strain gaged

[12.7 cm 38.1 kg/ra],X-95 drillpipe is

critical stress areas on the ID and O

Makeup tests were conducted to determine

exceeded with only 2000 ft [600 m]

displacement.

Torque and drag for the

optimum maJceup torqus of 40,000 ft-lbs (

200 N-m).

6,000 ft [1800 m] displacement were

The made up

connections we

loaded in a test frame to monitor t

estimated at 40,000 ft-lb [54 200 N-m]

drilling torque and 800,000 pounds [3 559

effects of combined tension, torsion~a

000 N] pickup load.

bending loads at ambient temperature

a

The design criteria

300F [149C]. A summary of the te

called for drill pipe capable

of

handling

these loads with minimum tensile SF = 1.25

results are shown in Tsble 1.

and torsional SF = 1.5 under combined

loadingconditions.

Strain gage testing showed tha

yielding is not a limitin~ ~~ctor f

JZUIR$UU fZ@D

expected service loads.

Notationa

displacementtransducerswere used to che

5 for tool joint

tandard API equations

for relative movement between the box a

tensile and torsional strength do not

pins.

These showed that the limitin

factor on tool joint performance w

account for combined tension and torsion

load effects.

Special equations were used

additional makeup at 300F (149C) und

combined tensile and torsion loading.

ri

in the tool joint design to account for

combined load effects.6

4 shows the threshold torque for additio

makeup as a function of tension.

Fishing considerations limited the

maximum tool joint O.D. to 7.5 in. [19 cm]

in the 9.5 in. [24

cm]

drift drilling

Drillpipe Metallurgy

liner.

The largest API tool joints that

fit within this dimension were the 5-1/2

The Texaco CG-105 drillpipe

in. [14 cm]_Full Hole and 6-5/8 in. [17 cm]

specification was formulated alo

Regular.

Neither of these connections

traditional high quality OCTG pi

satisfied criteria for combined load design

manufacturing principles to meet t

followingobjectives:

and manufacturingease.

1.

U221- ~evelo~ment

Achieve good SSC resistance in t

105,000 psi [724 Mpa] minimum yie

Because the API 5-1/2 in. [14 cm] Full

strength 5-1/5~$[14 cm] internal-exte

upset pipe.

Hole and 6-5/8 in. [17 cm] connections did

not meet the design criterial

a high

2.

torsio al strength tool joint, named the

Achieve tool joint toughness and S

HT-55,

Y

resistance comparable to the pip

was considered as an alternative,

considering the additional thickness

---

432


3/9

IADWSPE 19963

ROBERT M. SHIVERS, III, J. 8RXSON GREER AND JACKIE

E.

SMITH

the tool joint.

While both the tubes and the tool

joints have a minimum yield strength

of

3.

Achieve good weldability, hardness

105,000 psi [724 MPa], the weldnent i

COntrOl, improved toughness and SSC designed for a minimum yield of R0,000 ps

resistance in the pipe to tool joint

[552 HPa]. This was to insure that maximu

weldment. hardness in the weld

area did

not

xcee

Rockwell C 30

in

spite of the fact that

~~

minimum and maximum hardness and yield

strengthranges in welds are much

wider

an

The nominal dimensions, Table 2, for

more difficult to control than in the tube

the tubes, tube-upsets and tool joints are and tool joints. The enlarged cross

important factors in selecting chemical

sectional area of the weld upset more tha

compositions suitable for subsequent heat

compensates for the reduced yield strength

treatment processes. The cross-sectionfor

the tool joint is mere than four times as

~~~ U@Ul

large, and the ID area available for

quenching is decreased compared to the

Tensile specimens were removed from

tube. The quench and tempered tube and its

the t~bes, tool joints, HAZ, and wald line

upset must be spin-friction or inertia

of production pipe and tested for sulfid

welded to the tool joint.

This composite-

stress cracking


4/9

4

.

DESIGN AND DEVELOPMENTOF HIGH STRENGTH, SO~ SERVICE DRILL PIPE

XADC/SPE 199

A eidp benefit of &he 5--1/2in. [14

cm] drill pipe waE.its ability to run the

long, heavy (8,500 ft, 500,000 lb) [2590m,

2 224 000 N] drilling liners required in

the casing program.

summary

Metallurgical

specifications,

manufacturing procedures and quality

control resulted in a drillstring with

relativelylow hardness, high toughness and

Ssc resistance .for

its

strength.

Experience has shown that G-105 drillpfpe

typically lies in the 25-35 Rockwell C

hardness range as compared to an HRC 22-30

range obtained with this string. This

improvementis due to the restrictedyield

etrength range of the CG-105 drillpipe,

105,000-120,000psi [724-827MPa] in tubes

and 110,000-130,000 psi [758-896 MPa] in

tool joints, and also to the higher yield

to tensile strength ratio associated with

fully transforming and high tempering

temperature,chromium-molybdenumsteels.

Weldability of the upset tubes to the

tool joints was excellent with no problems

being experienced during manufacture.

Transverse Charpy V impact tests of the

wel< line were above 50 ft-lbs [68 N-m].

Typ.tally, impact energies are below 25

ft-lbs [34 N-m] for drillstring pipe to

tool joint weldments.

The measured impact

energies of the tubes, tool joints and

weldments were all well in excess of the

critical toughness needed to prevent

brittle fracture according the criteria of

API Spec 5CT12 Grade Q-125.

Sulfide stress cracking tests taken as

a quality

assurance

measure showed that the

heavy wall composite drillpipe structure

had SSC resistancewhich approachedthat of

sour environment production tubulars,

despite the 105,000 psi minimum yield

strength of the tubes and tool joints.

Analysis of threshold stresses

on a cross

sectional area basis indicated that the

design of the CG-105 drillpipe was balanced

frora an SSC as well as a mechanical

perspective.

Reported13 SSC thresholdstress values

for G-105 drillpipe and tool joints lie in

the 30-45 percent of yield stress range,

while threshold SSC values for x-135

drillpipeare in the 10-20 percent

of

yield

strength stress range. Threshold SSC

stresses for the CG-105 drillpipe were

above 80 percent of the minimum yield

strength for the pipe body and above 50

percent for the tool joint and weld areas.

Impact-tension prototype tests

also

confirmed

the viability of

the

manufacturing process and toughness of the

drillpipe assembly. The pipe suffered

significant damage after being used on the

first well, but damage was greatly reduced

on the second well through better pipe

handling practices.

.- .

Conolusioas

A special 5-1/2ti[14 cm] O.D. x 0.550H

and 0.750 [0.?7

cm x 1 9 cm] wall

thickness drillstring was designed and

manufacturedthat:

1.

Provides sulfide stress cracking

resistance superior to X-95 drillpipe

despite increased wall thickness and

minimum yield strength,

2. Can handle torque and drag up to

40,000 ft-lbs [54 200 N-m] rotation and

;~O&,000 pounds [3 559 000 N] pick up

3*

Performs well under simulateddropped

impact :.oading,and

4.

Provides a means to safely run long

heavy, drilling and production liners.

1.

API Specification 5D, Specificatio

for Drillpipe, First Edition, March 15,

1988,N American Petroleum Institute,211 N.

Ervay, suite 1700, Dallas, Texas 75201.

2.

H. M. Rollins, Drill-StemFailures Du

to

H S,w

The Oil and Gas Journal, 1966,

82-8

z.

3*

L. P. Grizzaffi and B. M. Thompson,

HDrilling and Testing of Deep Wells With

High H2S

concentration in southern

Missisaippi,npresented at the API Divisio

of Production Spring Meeting of the

Southern District, 1970.

4. W. L. Kirk,

C:DeepMississippi Drillin

Practices, 1$

Journal of

Petroleum

Technology,June, 1972, 633-642.

5*

API Recommended Practice RP 7G,

llReco~endedpractice for Drill Stem

DeSigII

and Operating Limits, American Petroleu

Institute,

211 N. Ervay, Suite 1700,

Dallas, Texas 75201.

6.

l fannesmann-Roehenwerke,

llLoa

Diagrams--DrillPipe and Tool Joints, Jul

1985 Edition, 11-14.

7. HT-55 is a proprietary tool joint

product designation of Hughes Tool Company

5425 Polk Street, Houston,Texas 77252.

8.

P. J. Grc::ner,D. L. Sponseller and W

w. Cias, wDevelopment of Higher-Strengt

HzS-ResistantSteels

for Oil Field Applica

tlons,llclimax Molybdenum Co.~ November

1973.

9.

A

lkeda, S. Nagata, T. Tsumura, Y

Nara and M Kowaka, Development of Hig

Strength Oil Country Tubular Goods Highl

Resistant to Sulfide Stress Corrosion

Cracking,~ Sumitomo Metal Industries,

4a4


5/9

IADC/SPE 19963

ROBERT M. SHIVERS, III,

J. BRISON GREER

AND JACKIE E. SMITH

5

presented to the APX ProductionDepartment

13

M. Watkins and G.

A.

Vaughn, Effects

Symposiumon Tubular Goods, June, 1977.

of

H2S Partial Pressure on the Sulfide

Stress Cracking Resistance of Steel,

10.

J. Brison Greer and W. E. Holland, Materials Performance,January 1986, 44-48.

@Iiigh-StxengthHeavy-Wall Casing for Deep,

Sour Gas Wells,w JPT, December 1981, 2389-

S1 Metric

Conversion

Faotors

2397.

nile x 1.609*3

E+OO = m

1

X

3.048

11. NACE Standard TM-01-77,

Testing

of

ft

X

2.831 685 ;-ii ~ ;3

Metals

for Resistance to Sulfide Stress F (F-32~/l.8 =Oc

Cracking at Ambient Temperatures, NACE,

in. x 2.54

E+OO = OM

Houston, Texas 1977.

lbm x 4.535 924 E-01 = kg

lbf

X

4.448 222 E+OO = N

12* API Specification 5CT, ISpecification

ft-lbf x 1.355 818 E+OO = N-m

for Casing

and

Tubing, First Edition,March

psi x 6.894 757 E+OO = kPa

15, 1988,U American Petroleum Institute,

PPG

X

1.198 264 E-01 =

g/cm3

211 N. Ervayt SUite 1700, Dallas, Texas

75201.

*Conversion i.~toris exact.

Table 19

Suxmary of Test Results

for the HT-55 Tool Joint.

Torsional Yield

at O lbs. Tension:

80,000-100,000ft-lbs.

Tensile Yield at

O ft-lbs. Torque: 2,200,000 lbs.

40,000 ft-lbs. Torque:

1,800,000 lbs.

Bending Yield at

600,000 lbs. Tension:

2,200,000 ft-lbs.

Table 2.

Nominal DrillpipeDimensions.

Inside Outside Wall

Diameter Diameter Thickness

Description

inches

inches

inches

*************************************************************

5.5 x 0.550$Tube

4.400

5.500

0.550

5.51 x 0.750$1Tube

4.000 5.500

0.750

Tube Upset-As Forged

3.188 5.938

1.375

Tube Upset-MachinedAfter Welding 3.250 5.750 1.250

Tool Joint-As Forged

2.850

7.628

2.416

Tool Joint-MachinedAfter Welding 3.250

7*500

2.125

~able 3.

Chemical Compositionsfor

Table 4.

Specificationand Average Au-

Tubes and Tool Joints

Quenched Hardness of Drillpipeand Tool Joints.

Percent by Weight

Rockwell C Hardness

*******************

**********************

Element Tube

Tool Joint Description

I.D. M.W. O.D. Var.

----------- -----

----------

-----------------------------------------

Carbon

0.29

O*3O

Specification

---44 minimum--- N.A.

Manganese

0.92 1*O3

-----------------------------------------

Chromium 0.97 1.44 0.550W Drill Pipe 49.3 47.7 47*3 1.9

Molybdenum

0.68

0.82

0.750t~Drill Pipe 49.3 47.6 47.4 L.9

columbium

0.023 0.03

Tc>l Joint 49.4 50.3 49.3 1.0

Sulfur

0.001

0.003

Phosphorous 0.007

0.010

Calcium 0.003

0.003

Hydrogen

0.0001

Degassed

Silicon

0.30

0.34

Aluminum

0.023

0.027

Soron --

0.0001

Nickel

O*O2

0.06

Copper O*O2

0.05

.*.


6/9

Sf 9963

m h s

specificationand Average Q&T

Hardness of Drillpipe and Tool Joints.

Rockwell C Hardness

***********************

Description

I.D. M.W.

O.D. Var.

------------------------------------------

Specification

---28 maxim~---

4 max

-------------------------------------------

0.550 Drill Pipe

26.8 27.0 26.8 0.3

0.750$Drill Pipe

26.0 26.1 25.0 1.3

------------------------------------------

specification

---30 maximum--- 5 max

------------------------------------------

Tool Joint

29.5 29.7 29.2 1.0

Table 6.

Qualificationand Production

Tool Joint to Pipe Weldment Hardness.

Maximum hardness HRC 29.

Rockwell C Hardness, HRC

************************************

Tool TJ

Weld Weld Pipe Pipe

Description

Joint HAZ Line Line HAZ

Upset

------------.---~-----------------------------------

Qualification

28.2 24.5 25.4 23.6 19.6 23.0

0.550 Weldment 30.2 27.3 28.4 26.6 18.7

22.4

0.75081Weldment 27.4 24.2 25.3 23.0

16.4 21.2

Tablo 7.

Specification

and TransverseCharpy V

and Measured Tensile

Impact Properties.

Yield Tensile

Impact

Strength Strength Energy

Upsat mlbo8

psi

psi

ft-lbs

-----------------------------------------------

Spec. Min.

105,000

115,000

25

Spec. Max.

120,000

------------------------------------------------

0.55011Drillpipe

110,900

124,900

136

0.7501Drillpipe

110,600

122,800

136

T@Ol J0int8

-------------------------------------------------

Spec. Min. 110,000

120,000

30

Spec. Max.

130,000

------------------------------------------------

Tool Joint

118,300

135,000

61.3

------------------------------------------------

Wmld Area

------------------------- ------------------------

Spec. Min.

80,000

90,000

16

Spec. Max.

120.000

-----------------------------------------------

Qualification

95,150 110,000

69

o.550H Weldment

91,100 108,150

56

0.750$ Weldment

84,500 102,600

53

436


7/9

.

TExAg

AREA

LEASE

TE)CAC() FULL

INTEREST

g TExACo PARTIAL

INTEREST

SAFETY FAIRWAY

. . . .,,.

.,

FIGURE f

1000

Maw

PICK UP LOAD VS

- Soo

100

ktORIZONTAL DNPLA~MENT

~

700 -

M872

@ 22 )00 WD

* 600

2

~ 000 +

@

g 400 -

/: o:

d

I

/

10%7sNsloN

TORQIJE w

5,

5.W,

X95

mPLAOEt4ENT

10ol- 4s ~ A*C6

o

,

1 ,

,

a

1

1

. .

-MAKE-UP SHOULDER

-BOX COUNTERBORE SEC

PIN BASE

hAST ENGAGED THREAD

TION

THREADS

.PtN HOSE

bii60ibARY SHOULDER

.1

FIGURE ?

m


8/9

SW 19963

79112, 1142110

Ids=

WJGHE MT 55 TOOL JOINT

OPERATIONAL LOAD ENVELOPE

1000.0 )

1

TttnssHOLO TORQUE

~edltlonat mske-up (300 F o.o12 WP)

000.0

THRESHOLDTORQUE

G

~

8ddltlonal make-up (300 F 0.006 g-p)

I

S 600.0

2

0

~ 400.0

z

Lu

b

00 0

I

I

0.0

.0

TORQUE,

(ft =kips)

FIGURE 4

100

90

10

0

17

v

18

1 ~,

1

Pi@

P14u

WL

WL

TJ W

NACETEslum

PIPE AND TOOL JOW

w

. -- .-.:

.

. .

. - .. *


9/9

100

90

NACE lEslMm w

WELD

AREA

.

u

- .. 09-

. m

. . 4mw

lEMcowEmz

.

l-+-t-

t

1~

I I

I

I I

10

0

TEST

u

PIPE

HAZ

WELDLINE

&&&

TOOLJOINTHAZ g m

1

I

1 1

I 1

i II

.

10

100

1000

I

.-

LOG

TIME (HOURS)

FIGURE7

19963-MS Design and Development of High-Strength, Sour Serv

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Transcript of 19963-MS Design and Development of High-Strength, Sour Serv