DRILL STRING DESIGN
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Drill String Design Common grades of drill pipe with yield strength Grade
E X G S
2
Minimum Yield psi
Maximum Yield psi
Tensile Strength psi
75,000 (517 MPa)
105,000 (724 MPa)
85,000 (586 MPa)
95,000 (655 MPa) 105,000 (724 MPa) 135,000 (931 MPa)
125,000 (862 MPa) 135,000 (931 MPa) 165,000 (1138 MPa)
105,000 (724 MPa) 115,000 (793 MPa) 145,000 (1000 MPa)
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Drill String Design
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Drill String Design The API recognizes four classes of drill pipe New Premium Class Class 2 Class 3
Pipe is rarely considered new If it has been run in the hole, it is considered premium class 4
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Drill String Design The DS-1 standard has an additional class of drill pipe It is premium class, reduced TSR The tool joints do not meet the standards for API tool joints and have a reduce torsional strength Pressure and tensile ratings are the same, but torsional strength is lower 5
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Drill String Design Premium class assumes that there is 80% wall thickness remaining on the tube and that the reduction in wall thickness comes from the outside diameter of the tube
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Drill String Design A reduction in outside diameter removes the most steel and results in the lowest strength 5” by 4.276”
5”, 19.5# As = 5.2746 in2 20% outer wall As = 4.1538 in2
20% inner wall As = 4.2855 in2 4.8552” by 4.276” 7
5” by 4.4208” © 2005 PetroSkills LLC, All Rights Reserved
Drill String Design The worn OD can be determined from the following formula
Dpw Dp Di t h Di The worn OD can be used to calculate tensile strength and combined torsion and tension limits 8
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Drill String Design Class 2 has at least 70% of the wall thickness remaining with the loss on the OD Class 2 is seldom used for drilling except small rigs with limited hook load capability Class 3 is less than 70% wall thickness remaining and is considered junk 9
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Drill String Design Drill string design starts at the bottom of the hole with the BHA The drill collars must provide enough weight for the bit with the top of the drill collars remaining in tension (not buckled, the top of the drill collars are actually not in axial tension) 10
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Drill String Design A design factor (DF) is used to make sure sufficient drill collars are available for estimated weight on bit Typical design factors are 10% to 15% or 1.10 to 1.15 in equation 10-43 W DF Lc
11
Wf B
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Drill String Design Example shows how to determine the number of drill collars Maximum anticipated weight on 8 3/4 inch (222.3 mm) bit is 50,000 lbs (22,400 daN) Drill collar size is 6 1/2 inch (165.1 mm) by 2 13/16 inch (71.4 mm) Mud weight is 11.5 ppg (1380 kg/m3) Excess collars should be 10% (DF = 1.10) to insure the drill pipe remains in tension
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Drill String Design The number of 30 foot (9.14 m) collars to be run First determine the weight per foot of the drill collars in air
Wf 2.67 Dp 2 Di 2
Wf 2.67 6.52 2.81252 92 lbs per foot Wf 665 k g / m
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Drill String Design Determine the buoyancy factor B 1 0.015m B 1 0.01511.5 0.83
Calculate the length of the drill collars W DF Lc Wf B
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500001.10 Lc 720 feet 219.5 m 920.83
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Drill String Design Determine the number of collars and weight of collars in drilling fluid 720/30 = 24 drill collars Wtc 24 30 92 0.83 54,979 lbs Wtc 24,643 daN
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Drill String Design
Neutral Point Drill collars
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Drill String Design With BHA components, most of the bending will occur in the connections BHA connections are subjected to bending and fatigue from buckling
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Drill String Design The BSR is a ratio of the relative stiffness of the box and pin for a given connection A typical target BSR is 2.5, +/0.25 Graphs showing the BSR can be found in the API RP 7G
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Drill String Design 11.5
8.75
11
8.25
7.75
8 5/8 REG
Outside Diameter, inches
Outside Diameter, inches
10.5
8 5/8 H90
10
NC 77
9.5
7 5/8 H90
9
6 5/8 H90 7.25
6 5/8 REG 5 1/2 FH NC56
6.75 5 1/2 H90 5 1/2 REG NC50
6.25
5 H90
NC70
8.5 NC 61 7 H90 3
NC46
6 5/8 FH
2.5
2
5.25 1.5
1
3.5
3
2.5
2
Bending Strength Ratio
Bending Strength Ratio 19
4 1/2 FH NC44 4 H90
NC40
5 1/2 IF
8 3.5
4 1/2 H90
5.75
7 5/8 REG
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1.5
1
Drill String Design The BSR for a given connection is a function of the ID of the pin and OD of the box In theory, high BSR’s will cause accelerated pin failures and low BSR’s will cause accelerated box failures
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Drill String Design The DS-1 standard gives the following recommended BSR’s Drill Collar OD
Traditional API BSR Range
DS-1 Recommended BSR Range
< 6 inches (152 mm)
2.25 to 2.75
1.80 to 2.50
6 to 7 7/8 inches
2.25 to 2.75
2.25 to 2.75
2.25 to 2.75
2.50 to 3.20
(152 - 200 mm) > or = to 8 inches (203 mm) 21
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Drill String Design Many operators will place approximately 6 joints of HWDP on top of the drill collars as a transition to the drill pipe It may help reduce drill pipe failures at the top of the drill collars
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Drill String Design Other operators will rotate the drill pipe from Neutral Point the top of the drill collars on trips 23
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HWDP
Drill collars
Drill String Design If jars are placed in a vertical well, they are at the top of the collars and then additional collars (3 to 4) are run above the jars In a vertical well, the jars should not be run in compression
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Drill String Design Jars are often run in compression in directional wells
HWDP
Drill collars Jars
Neutral Point Drill collars
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Drill String Design Drill pipe is usually designed with a design factor plus overpull A normal design factor is 1.10 or 10% Overpull can range from 50,000 to 100,000 lbs (22,411 – 44,822 daN) 26
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Drill String Design The overpull is the amount that can be pulled on the pipe over and above the drill string weight If the drill pipe consists of more than one weight or grade of pipe, the overpull is balanced between the two strings
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Drill String Design Example 6 shows how to design the drill string Well depth is 12,000 feet (3658 m) Drill pipe: 5”, 19.50#/ft (127.0 mm, 29.02 kg/m), Grade E, Premium Class and 5”, 19.50#/ft (127.0 mm, 29.02 kg/m), Grade G, Premium Class Design factor is 1.10 Over pull is 100,000 pounds (44,822 daN) 28
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Drill String Design Calculate the worn OD of the drill string Dpw Dp Di t h Di Dpw 5 4.276 0.80 4.276 4.855 " (123.32 mm)
Calculate the cross sectional area of the drill pipe As As 29
D 4
pw
2
Di
4.855 4
2
2
4.2762 4.152 in2 (2679 mm2 ) © 2005 PetroSkills LLC, All Rights Reserved
Drill String Design Calculate the tensile strength of the grade E pipe Tst Yp As
Tst 75,000 4.152 311,000 pounds 141,067 kg
Calculate the tensile strength of the grade G pipe Tst 105,000 4.152 436,000 pounds 197,767 kg
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Drill String Design
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Drill String Design The maximum pull on the grade E with the 1.10 design factor would be:
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Pmax
Tst DF
Pmax
311000 283,000 pounds (128,367 kg) 1.10
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Drill String Design The maximum weight of grade E that can be used with 100,000 pounds over pull is: Wmax 283000 54979 100000 128,021lbs 58,069 kg
The maximum length of grade E drill pipe that can be used is: Lmax
33
128021 6565 feet (2001m) 19.50
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Drill String Design The maximum pull on the grade G with the 1.10 design factor would be: Pmax
34
436000 396,000 pounds 179,623 kg 1.10
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Drill String Design The maximum weight of grade G that can be used with 100,000 pounds over pull is: Wmax 396000 54979 100000 128021 113,021 pounds Wmax 51,266 kg
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Drill String Design The maximum length of grade G drill pipe that can be used is: Lmax
36
113000 5795 feet 1766 m 19.50
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Drill String Design The drill string would consist of the following: 720 feet of drill collars (219.5 m) 6565 feet (2001 m) of 5”, 19.50#/ft, (127.0 mm, 29.02 kg/m) grade E drill pipe and 4715 feet (1437 m) of 5”, 19.50#/ft, (127.0 mm, 29.02 kg/m) grade G drill pipe 37
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Drill String Design
Top of Grade E Drill Pipe
HWDP
Neutral Point Drill collars
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Drill String Design Class Problem – Design the drill string Drill 12 ¼” (311.2 mm) hole to 10,000’ (3048 m) Maximum bit weight is 65,000 lbs (29,000 daN) Collars 8” OD (203.2 mm) by 2 13/16” ID (71.4 mm) 4 ½”, 16.60 (114.3 mm, 24.7 kg/m) Grade E, Premium 4 ½”, 16.60 (114.3 mm, 24.7 kg/m) Grade S135, Premium Use 1.10 design factor for collars Design factor of 1.10 with overpull of 75,000 lbs (34,000 daN) for drill pipe Mud weight is 9.5 ppg (1140 kg/m3) 39
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Drill String Design The drill string would consist of the following: 570 feet (173.7 m) of drill collars (19) 5300 feet (1615 m) of 4 1/2”, 16.60#/ft (114.3 mm, 24.7 kg/m), grade E drill pipe and 4130 feet (1259 m) of 4 1/2”, 16.60#/ft (114.3 mm, 24.7 kg/m), grade S drill pipe 40
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Drill String Design First determine the weight per foot of the drill collars in air
Wf 2.67 Dp 2 Di 2
Wf 2.67 8 2 2.8125 2 150 lbs/ft (223 kg/m)
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Drill String Design Determine the buoyancy factor B 1 0.015m
B 1 0.0159.5 0.86
Calculate the length of the drill collars W DF Lc Wf B
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650001.10 Lc 554 feet (168.9 m) 1500.86
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Drill String Design Determine the number of collars and weight of collars in drilling fluid 554/30 = 18.5 drill collars Use 19 drill collars Wtc 19 30 150 0.86 73,530 lbs 33,353 kg
Get the tensile strength of pipe from the API spec 43
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Drill String Design
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Drill String Design The maximum pull on the grade E with the 1.10 design factor would be: Pmax
Tst DF
Pmax
45
260,165 236,513 pounds (107,281kg) 1.10
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Drill String Design The maximum weight of grade E that can be used with 75,000 pounds over pull is: Wmax 236,513 73,530 75,000 87,983 pounds Wmax 39,908 kg
The maximum length of grade E drill pipe that can be used is: Lmax 46
87,983 5300 feet 1515 m 16.60 © 2005 PetroSkills LLC, All Rights Reserved
Drill String Design The maximum pull on the grade S with the 1.10 design factor would be: 468,297 425,725 pounds 1.10 193,106 kg
Pmax Pmax
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Drill String Design The maximum weight of grade S that can be used with 75,000 pounds (34,019 kg) over pull is: Wmax 425,725 73,530 75,000 87,983 189,212 pounds Wmax 85,825 kg
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Drill String Design The maximum length of grade S drill pipe that can be used is: Lmax
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189,212 11,398 feet 3474 m 16.50
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Drill String Design The drill string would consist of the following: 570 feet (173.7 m) of drill collars (19) 5300 feet (1615 m) of 4 1/2”, 16.60#/ft (114.3 mm, 24.7 kg/m), grade E drill pipe and 4130 feet (1259 m) of 4 1/2”, 16.60#/ft (114.3 mm, 24.7 kg/m), grade S drill pipe 50
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Drill String Design In directional wells, the pipe weight available for bit weight is a function of the inclination Bit Weight = W cos I
Inclination, I W
Normal Force = W sin I 51
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Drill String Design Most of the drill collars are often replaced by heviwate drill pipe (HWDP). Helps reduce torque and drag by reducing string weight Fewer drill collar connection failures 52
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Drill String Design The body of a drill collar is stiffer than the connection and bending occurs in the connection In HWDP, bending occurs in the body and not at the connection, so fewer connection failures are experienced
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Drill String Design Frequently, the drill pipe is also run in compression for bit weight In a vertical well, drill pipe will buckle with little or no compressive load Buckling will create bending stresses in the drill pipe which can lead to fatigue if the bending stresses are high enough In a directional well, the compressive load must exceed the critical buckling load in order to buckle the drill pipe 54
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Drill String Design Therefore, drill pipe can be run in compression in a directional well without causing buckling provided the compressive load is less than the critical buckling load Fcrit Fcrit
EIAg sin I 2 r
Basic Units
9.82 105 (OD 4 ID 4 )(Wt / ft) B sin I ( Dh OD)
English Units 55
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Drill String Design The critical buckling load is a function of the pipe size, inclination and radial clearance
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Drill String Design 40,000
Critical Buckling Load, lbf
35,000 30,000 25,000 20,000 15,000 10,000
4 1/2" in 8 1/2" Hole 4 1/2" in 12 1/4" Hole 5" in 8 1/2" Hole
5,000
5" in 12 1/4" Hole
0
10
20
30
40
50
Inclination 57
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60
70
80
90
Drill String Design Buckling is actually a little more complicated It also depends upon the curvature of the wellbore, internal pressure and external pressure The DS-1 Standard has more detailed buckling calculations
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Drill String Design The pipe weight and grade can be identified by the pin end, tool joint
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Drill String Design Pipe weight codes can be found in Table 17 Grade Grade Code E-75 E X-95 G-105 S-135 60
X G S © 2005 PetroSkills LLC, All Rights Reserved
Drill String Design Pipe Weight Code
Pipe Grade Code
Standard Weight Grade E Drill Pipe
Heavy Weight Grade E Drill Pipe
Pipe Weight Code
Pipe Weight Code
Pipe Grade Code
Pipe Grade Code
Standard Weight High Strength Drill Pipe
Heavy Weight High Strength Drill Pipe
Old API markings for tool joints 61
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Drill String Design
Standard Weight Grade E-75 Drill Pipe
Standard Weight Grade G-105 Drill Pipe
Standard Weight Grade X-95 Drill Pipe
Standard Weight Grade S-135 Drill Pipe
Mill slot and groove method of drill string identification 62
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Drill String Design Drill pipe identification is not strictly followed and you have to look Pipe Weight Code
Pipe Grade Code
Heavy Weight Grade E-75 Drill Pipe
Heavy Weight Grade X-95 Drill Pipe
Heavy Weight Grade G-105 Drill Pipe
Heavy Weight Grade S-135 Drill Pipe
Mill slot and groove method of drill string identification 63
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Drill String Design Combined torque and tension When torque is added to the drill pipe, the tensile strength is reduced At low values of torque, the tensile strength does not change substantially As torque increases, the tensile strength decreases
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Drill String Design The equation for calculating the maximum allowable torque based on tension is as follows: 0.096167 J 2 T Yp QT 2 D pw As 2
0.5
English
1.1536 10 J 2 (9800T ) Y p QT 2 D As pw 6
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2
0.5
SI
Drill String Design 60,000
Torque, ft-lbs
50,000
40,000
30,000
19,242 ft-lbs (26,119 N-m) 20,000
250,000 lbs (112,000 daN) 10,000
0 0
100,000
200,000
300,000
400,000
500,000
Tension, pounds Grade E
66
Grade X
Grade G
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Grade S
600,000
Drill String Design Drill string inspection Periodically the drill string must be inspected to make sure that the pipe and BHA components are still fit for purpose There are no API standards for drill string inspection; however, some of the industry uses the inspection standards in the DS-1 67
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Drill String Design Service Category 1 Very shallow, very routine wells in well-developed areas When drill stem failures occur, failure costs are so minimal that the cost of extensive inspection would not have been justified
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Drill String Design Service Category 2 Routine drilling conditions where the established practice is to perform minimal inspection and failure experience is low
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Drill String Design Service Category 3 Mid-range drilling conditions where a standard inspection program is justified If a failure occurs, the risk of significant fishing cost or losing part of the hole is minimal
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Drill String Design Service Category 4 Drilling conditions more difficult than Category 3 Significant fishing cost or losing part of the hole is likely in the event of a drill stem failure
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Drill String Design Service Category 5 Severe drilling conditions Several factors combine to make the cost of a possible failure very high
The service category is selected by the operator depending upon their risk analysis
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Drill String Design Directional wells will have a higher service category than vertical wells Very deep, very high pressure and sour wells are beyond the scope of the DS-1 Standard
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Drill String Design
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Drill String Design The BHA components should be inspected before they are picked up After the components have been picked up, additional inspections should be carried out at regular intervals
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Drill String Design
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