SMITH Tubulars & Tubular Services.pdf

Rotary Kelly

TABLE OF CONTENTS Rotary Kelly



Mudsaver Valve Drill Pipe



1



2



3-5

TSDS High Torque Connection

6

Engineered for Strength: TSDS Tool Joint Connection Data

7-11

Hevi-Wate™ Drill Pipe - Standard and Spiral

12-13

Drill Collars-Standard and Spiral

14-15

Rotary, Bit Sub and Lift Sub

16

Top Drive Sub and Thread Protectors

17

Ezy-Torque™ Hydraulic Cathead

18

Tru-Torque Automatic Torque Control System

19

Machine Shop Services

20-23

Inspection Services

24

Portable Hardbanding Service

25

®

Most of the world’s drilling rigs rely on this important piece of equipment to transmit the torsional energy from the rotary table to the drillstring and ultimately to the bottom of the hole. The kelly’s ability to perform this function over a prolonged period of time is a result of the mechanical properties of the steel and the specifications to which it is manufactured.

The Rotary Kelly is manufactured with one of two basic configurations – square or hexagonal, and is available in three standard lengths: • 40 feet (12.2m) overall length with a 37 foot (11.3m) working space • 46 feet (14.0m) overall length with a 43 foot (13.1m) working space • 54 feet (16.5m) overall length with a 51 foot (15.5m) working space

Each Smith Services kelly is heat treated along its entire length for uniform toughness and durability. A hardness range of 285 to 341 BHN, and a Charpy V-notch impact value of 40 ftlb are guaranteed one inch below the surface at room temperature. Each kelly meets the mechanical properties listed in API Spec 7 and when applicable, can be stamped with the API monogram.

Other sizes are available through special order.

Features and Benefits • Machined flats and upsets ensure tight tolerances and a high-quality drive section. This will retard wear on the kelly itself in addition to prolong the service life of the kelly drive bushing rollers

Specifications - Hexagonal Kelly Nom. Size

Available Lengths (A)

(in.)

(ft.)

3 ¹⁄₂

40, 46

4 ¹⁄₄ 5 ¹⁄₄

Top Upset API Box Left-hand Conn.

(in.)

6 ⁵⁄₈ REG.

7 ³⁄₄

4 ¹⁄₂ REG.

5 ³⁄₄

40, 46

6 ⁵⁄₈ REG.

7 ³⁄₄

40, 46, 54

6 ⁵⁄₈ REG.

7 ³⁄₄

Drive Section

Available Lengths (A)

(in.)

(ft.)

3

40, 46

3 ¹⁄₂

40, 46

4 ¹⁄₄

40, 46, 54

1

Top Upset

Across Corners (F)

Across Flats (G)

(in.)

(in.)

(in.)

(in.)

NC 31 (2 ⁷⁄₈ IF)

4 ¹⁄₈

2*

3.937

3 ¹⁄₂

NC 38 (3 ¹⁄₂ IF)

4 ³⁄₄

2 ¹⁄₄

4.781

4 ¹⁄₄

1,740

NC 46 (4 IF)

6 - 6 ³⁄₈

2 ¹³⁄₁₆

NC 50 (4 ¹⁄₂ IF)

6 ¹⁄₈ - 6 ³⁄₈

3

5.900

5 ¹⁄₄

2,550

Right-hand Conn.

API Box Left-hand Conn.

Bottom Upset OD (C)

Right-hand Conn.

(in.)

6 ⁵⁄₈ REG.

7 ³⁄₄

4 ¹⁄₂ REG.

5 ³⁄₄

6 ⁵⁄₈ REG.

7 ³⁄₄

4 ¹⁄₂ REG.

5 ³⁄₄

6 ⁵⁄₈ REG.

7 ³⁄₄

16" Top upset with lefthanded connection

A less 3 ft.

G

F

G

F

A

E E

Wt. of 40 ft. Length

Bore (E)

OD (D)

A less 3 ft.

NC 31 (2 ⁷⁄₈ IF)

Drive Section Bore (E)

Across Corners (F)

Across Flats (G)

(in.)

(in.)

(in.)

(in.)

4 ¹⁄₈

2*

3.875

3

OD (D)

NC 38 (3 ¹⁄₂ IF)

4 ³⁄₄

NC 46 (4 IF)

6 - 6 ³⁄₈

NC 50 (4 ¹⁄₂ IF)

6 ¹⁄₈ - 6 ³⁄₈

Bottom upset with righthanded connection

(lb.) 1,300 1,200

Specifications - Square Kelly Nom. Size

16"

A

Bottom Upset

OD (C)

C

C

20"

20"

D

D

Square Kelly

Hexagonal Kelly

Wt. of 40 ft. Length (lb.) 1,080 980

2 ¹⁄₄

4.437

3 ¹⁄₂

1,320

2 ¹³⁄₁₆

5.500

4 ¹⁄₄

1,820

* Not an API standard Ordering instructions, please specify: • Hexagonal or square kelly • Nominal size • Length (A) • Bore ID (E) • Size and type of top connection • Size and type of bottom connection • Top upset OD (C) • Bottom upset OD (D) • Type of shipping scabbard. (Rathole drilling scabbards are available upon request)

Mud Saver Valve The Mud Saver Valve is designed to reduce or eliminate the undesirable loss of fluid when making a connection. Placed on the end of the kelly, it opens from pressure when the rig pumps are engaged, enabling circulation down the drillstring. The valve closes when circulation is stopped, trapping the drilling fluid inside the kelly, thus making drillstring trips drier, faster and safer.

Rugged design extends tool life to eliminate the need to make and break connections to pick up a backup mud saver valve during a job. Low crack pressure and pressure drop • Valve cracks open at 150 psi to allow holding at least 100 ft of 18 ppg mud. • Maximum pressure drop through the valve is 100 psi. Increased safety for higher productivity • Eliminates mud loss during connections. • Eliminates rig time lost waiting for the kelly to drain. • Dry rig oor reduces the risk of a serious accident. • Improves crew efficiency when racking back tubulars. Compact easy to use design • 36 inches shoulder-to-shoulder • Doubles as a kelly saver sub Completely automatic operation • Closes immediately when the mud pumps are shut down • Opens when mud ow is resumed • No manual intervention required

Drill Pipe

•

Features and Benefits Designed to withstand extreme drilling conditions • 850 gpm mud flow rate • 4,500 psi drillstring pressure • 18 ppg mud density • 30% solids content Wireline operation eliminates risk • No need to use an overshot and deal with the complexities of shearing pins and retrieving a spear assembly • Easy to use sinker bar breaks a plastic cap for wireline operations Designed for superior durability & reliability • The geometry is optimized using fluid flow analysis to reduce erosion in critical areas. • Solid tungsten carbide seat reduces wear and improves reliability. • Backow feature permits pressure equalization in the kelly, allowing normal drill pipe readings at the standpipe.

Smith Services drill pipe follows a strict quality control regimen from initial material selection to final inspection to ensure each joint meets the customer’s needs for durability and performance. Drill pipe is manufactured from a proprietary alloy that allows for exceptionally tight dimensional tolerances. The result is a product that provides a 95 percent minimum wall in every tube, meaning as much as 100 percent more wall wear for API premium class drill pipe.

Open

All tool joints exceed API requirements, and threading is performed in accordance with API Spec 7. Hardbanding is applied to the customer’s specification; tungsten carbide and casing-friendly hardbanding types are available upon request. Grade identification grooves are applied to API RP7G specification, or to specific requirements. Smith Services\Texas Steel Conversion SRT series drill pipe is an optional product designed for applica-

Applications • Rotary rigs utilizing a kelly drive can benefit from the use of a Mud Saver Valve • Top drive rotary rigs can benefit from the use of a Mud Saver Valve • Hazardous drilling fluids can be effectively contained, reducing environmental impact and subsequent clean up costs

Minimum flow area in open position

3.98 in2 36”

Length (shoulder to shoulder), w protector

40”

Connections (API)

NC-50/ 4 ½” IF & NC-46/ 4” IF

Tool Sub OD

6 ½”

Tool Sub ID

2.812”

Tool Sub weight (No Rubber Protect Groove)

212 lbs

Tool Sub weight (With Rubber Protect Groove)

233 lbs

Connection break-in prior to placing new drill pipe in service is a recommended practice for all rotary shouldered connections. New connection

Drill pipe size

Nominal weight Lb/Ft

API nominal wall new

TSC minimum wall new 95%

API minimum wall new 87 1⁄2%

API minimum wall premium class

API drill pipe

TSC drill pipe

2 7⁄8

10.40

.362

.344

.317

.290

.027

.054

13.30

.368

.350

.322

.294

.028

.056

15.50

.449

.427

.393

.359

.034

.068

14.00

.330

.314

.289

.264

.025

.050

15.70

.380

.361

.332

.304

.028

.057

16.60

.337

.320

.295

.270

.025

.050

20.00

.430

.408

.376

.344

.032

.064

22.82

.500

.475

.437

.400

.037

.075

19.50

.362

.344

.317

.290

.027

.054

25.60

.500

.475

.437

.400

.037

.075

21.90

.361

.343

.316

.289

.027

.054

24.70

.415

.394

.363

.332

.031

.062

25.20

.330

.314

.289

.264

.025

.050

27.70

.362

.344

.317

.290

.027

.054

Closed

Minimum wall wear premium class

3 1⁄2

4

4 ⁄2 1

Valve weight (No Body or Sub)

36 lbs

Valve crack pressure

150 psi

Maximum pressure drop (after valve opens)

100 psi

Maximum operating limits

• • • •

Sinker bar for wireline

1 ¾” OD sinker bar

Impact strength of knock out cap

(144 ft-lbs) equivalent to 3 foot sinker bar dropped 8 feet in 18 ppg drilling mud/ 6 foot sinker bar dropped 4 feet in 18 ppg drilling mud.

Clear opening with knock out cap ruptured by sinker bar

2”

Notes: • The 3 inch valve is used in a 3 ¹⁄₂ IF connection • The 4 inch valve is used in a 4 ¹⁄₂ IF - 4 ¹⁄₂ XH connection • The 6 inch valve is used in a NC-50 4 1⁄2” IF & NC-46 4” IF

Restricted yield strength X-95CY and G-105CY drill pipe are optional products offered by Smith Services\ Texas Steel Conversion. Our restricted yield strength drill pipe meets all applicable API specifications, in addition to our internal requirement that restricts maximum allowable tensile yield strength to 110,000 psi for X95CY and 120,000 psi for G-105CY.

95% Minimum wall means longer drill pipe life

Specifications Length (shoulder to shoulder), no protector

tions that require low temperature enhanced impact toughness. SRT series drill pipe is engineered to meet a minimum average Charpy Vnotch impact energy of 59 ft-lbs at -4°F on a 10mm x 7.5mm specimen size. Proprietary material and heat treat processes are used to insure each joint of SRT drill pipe meets the specified toughness. SRT drill pipe is available in strengths up to and including API grade S-135.

5

850 gpm mud flow rate 4500 psi drill string pressure 18 ppg mud density 30% solids content

5 1⁄2

6 5⁄8

Mudsaver Valve

All dimensions in inches unless otherwise noted.

2

3

Superior Quality Drill Pipe

break-in is an optional service available for all drill pipe orders that is performed at the factory under controlled conditions by Texas Steel Conversion personnel. Factory break-in can result in substantial cost savings compared to new connection breakin performed on the rig. Features and Benefits • 95 percent minimum wall provides as much as 100 percent more wall wear for API premium class drill pipe • All tool joints exceed API requirements • Threading performed to API Spec 7 • Grade identification grooves applied to API RP7G specification

Drill Pipe Only the best tubes are selected to make the best drill pipe. Quality begins with the selection of the best materials. Tubes are procured from mills with a recognized track record for manufacturing the highest quality pipe. Our proprietary tube specification requires a richly alloyed chemistry and tightens the pipe’s dimensional tolerances. The result is a product that provides a 95% minimum wall in every tube. This can mean up to 100% more wall wear for API premium class drill pipe. (See chart). Drill pipe is available in standard sizes from 2 7/8" to 6 5⁄8" and grades E, X, G and S. Tool joints are made to your requirements. Tool joints are heat-treated and manufactured from materials selected to exceed API requirements. Threading is done in accordance with API Specification 7. Application of hardband is done to the customer’s specification.

Drill Pipe

Both tungsten carbide and casing friendly types of hardband are available upon request. Grade identification grooves are applied to API RP7G specification or to the customer’s specific requirements.

Inertia Welder

results in drill pipe with superior fatigue resistance.

When we say up to 100% minimum wall, we guarantee it.

Tightly controlled manufacturing processes ensure quality in each joint. The first step in drill pipe manufacture is the upsetting process. Texas Steel Conversion, Inc. has developed proprietary upsetting practices that produce an extra long internal runout. Increasing the runout length

Our high product standards are “raising the bar.”

After removal of the weld flash, the weld zone is heated to a temperature within the austenitizing range. The weld area is austenitized, quenched, and then tempered to achieve the required mechanical properties. The actual heat-treat cycles are recorded and compared against the specified parameters. Ultrasonic and wet magnetic particle inspections are used to verify the integrity of each weld zone. This is one

Once the tube has been upset it goes to heat treat. This is a strictly controlled process where each tube is quenched and tempered to bring it into compliance with API specifications. Careful attention is given to the laboratory testing of the heat-treated tubes to assure the correct mechanical properties are achieved.

of seven QA/QC processes that each joint of drill pipe goes through before it is ready for shipment.

Smith Services and Texas Steel Conversion, Inc. are proud to offer this new standard of excellence in drill pipe manufacture. Superior quality components, excellent processes, drill pipe built to customer specifications, and on time delivery are just some of the ways Smith Services is “raising the bar”. To discuss your drill pipe requirements please contact your Smith Services representative.

Both the internal and external weld areas are polished to assure the removal of all steps and machining marks. From here the drill pipe goes on for internal plastic coating, thread protectors are installed and the drill pipe surfaces are painted or otherwise protected for shipment to the customer.

The tool joints are joined to the heattreated tubes using an inertia welding process. The complete welding cycle is electronically controlled. The actual weld conditions are recorded and compared against proprietary parameters.

Premium Tool Joint

Premium Tool Joint exploded view

4

5

TSDS High Torque Connection The Texas Steel Conversion Double Shouldered High Torque Connection (TSDS) substantially increases drilling safety and performance by providing torque capacity that is 30% to 40% greater than standard API connections for comparable size drill pipe. This superior torsional strength makes the TSDS ideal for use in aggressive drilling programs.

Engineered for Strength: TSDS Tool Joint Connection Data

TSDS Tool Joint Connection Data

TSDS High Torque Connection

Connection Size & Style

Box OD (in)

4¾

The double shoulder design allows the primary external shoulder to serve as the sealing surface, while the secondary shoulder serves as the mechanical stop for the connection. The TSDS pin and box sections are engineered to distribute the make-up forces between the two shoulders, providing additional torsional strength for high-torque applications.

TSDS 38

Improved flow rates can be obtained by using a larger than standard bore in the tool joint while maintaining higher torsional strengths than the standard API connection. The ability to improve hydraulics and maintain tool joint torsional strength without decreasing connection life makes the TSDS connection an excellent choice for tough downhole applications.

4⅞

5

The TSDS is interchangeable with standard API connections, giving the customer additional operational flexibility for use with existing conventional drillstrings. The TSDS running procedure is similar to API connections , no special handling tools are required and no additional trip time to make and break the connection. TSDS connection rework material loss is similar to a standard API connection.

Connection Size & Style

Box OD (in)

5 1⁄8

Repairs to the TSDS connection must be performed by licensed machine shops with NC machine capabilities. These repair facilities are located in a number of oilfield service centers around the world.

TSDS 40

5¼

5½

6

7

Pin ID (in)

Make-Up Torque (ft-lbs)

Torsional Yield (ft-lbs)

Pin Tensile Yield (lbs)

2 1⁄8

17,870

29,798

842,400

2 7⁄16

15,910

26,525

708,000

2 9⁄16

15,020

25,041

649,100

2 1⁄8

20,120

33,538

842,400

2 7⁄16

17,630

29,389

708,000

2 9⁄16

15,570

25,963

649,100

2 1⁄8

22,280

37,136

842,400

2 7⁄16

17,630

29,389

708,000

2 9⁄16

15,570

25,963

649,100

Pin ID (in)

Make-Up Torque (ft-lbs)

Torsional Yield (ft-lbs)

Pin Tensile Yield (lbs)

2 7⁄16

21,340

35,578

897,100

2 9⁄16

20,420

34,048

838,200

2 11⁄16

19,440

32,413

776,400

2 7⁄16

23,910

39,862

897,100

2 9⁄16

22,000

36,666

838,200

2 11⁄16

19,720

32,866

776,400

2 7⁄16

24,160

40,269

897,100

2 9⁄16

22,000

36,666

838,200

2 11⁄16

19,720

32,866

776,400

TSDS Tool Joint Connection Data (continued) Connection Size & Style

Box OD (in)

6

TSDS Tool Joint Connection Data (continued)

Pin ID (in)

Make-Up Torque (ft-lbs)

Torsional Yield (ft-lbs)

Pin Tensile Yield (lbs)

2¾

37,560

62,611

1,183,900

3

31,960

53,275

1,048,400

Connection Size & Style

Box OD (in)

Pin ID (in)

Make-Up Torque (ft-lbs)

Torsional Yield (ft-lbs)

Pin Tensile Yield (lbs)

2¾

48,160

80,267

1,551,700

3

45,670

76,115

1,416,200

3¼

42,870

71,452

1,268,900

3½

36,130

60,229

1,109,900

2¾

52,060

86,774

1,551,700

3

49,570

82,622

1,416,200

3¼

43,310

72,186

1,268,900

3½

36,130

60,229

1,109,900

2¾

55,910

93,188

1,551,700

3

49,900

83,172

1,416,200

3¼

43,310

72,186

1,268,900

3½

36,130

60,229

1,109,900

6 3⁄8 3¼

TSDS 46

6 1⁄8

25,820

43,045

901,100

2¾

37,560

62,611

1,183,900

3

31,960

53,275

1,048,400

3¼

25,820

43,045

901,100 TSDS 50

6¼

2¾

37,560

62,611

1,183,900

3

31,960

53,275

1,048,400

3¼

25,820

43,045

901,100

6½

6⅝

8

9

TSDS Tool Joint Connection Data (continued) Connection Size & Style

Box OD (in)

TSDS Tool Joint Connection Data (continued) Pin ID (in)

Make-Up Torque (ft-lbs)

Torsional Yield (ft-lbs)

Pin Tensile Yield (lbs)

1,778,200

4¼

82,450

137,423

2,102,200

1,619,200

4½

77,330

128,889

1,896,100

Pin ID (in)

Make-Up Torque (ft-lbs)

Torsional Yield (ft-lbs)

Pin Tensile Yield (lbs)

3¼

59,200

98,673

3½

55,920

93,207

Connection Size & Style

8

7

TSDS 55

Box OD (in)

3¾

52,300

87,168

1,448,400

4¾

70,360

117,272

1,678,100

4

43,990

73,319

1,265,800

5

57,050

95,088

1,448,400

3¼

63,890

106,485

1,778,200

4¼

88,590

147,654

2,102,200

3½

60,610

101,019

1,619,200

4½

82,930

138,222

1,896,100

TSDS 65

7 1⁄8

8 1⁄8

3¾

53,070

88,455

1,448,400

4¾

70,360

117,272

1,678,100

4

43,990

73,319

1,265,800

5

57,050

95,088

1,448,400

3¼

68,700

114,500

1,778,200

4¼

94,760

157,935

2,102,200

3½

61,510

102,525

1,619,200

4½

82,930

138,222

1,896,100

8¼

7¼ 3¾

53,070

88,455

1,448,400

4¾

70,360

117,272

1,678,100

4

43,990

73,319

1,265,800

5

57,050

95,088

1,448,400

TSDS connection data for common tool joint sizes is shown in these tables. Contact Smith Services for data on sizes not listed. Torsional yield values shown in yellow type indicate the connection is box weak in torsion. Torsional values are based on using a thread compound with a 1.0 API friction factor. Pin tensile yield values are based on tensile loading conditions only, and do not take into consideration the effect of combined torsional and tensile loading.

10

11

Hevi-Wate™ Drill Pipe - Standard and Spiral Hevi-Wate Drill Pipe is the industry standard for an intermediate-weight drill stem member, and is available in standard, spiraled and non-magnetic designs, making it useful in a number of applications. It has drill pipe dimensions for easier handling. Hevi-Wate Drill Pipe utilizes a unique center upset or wear pad to increase tube life while reducing hole drag and differential sticking problems. Features and Benefits • Long tool joints provide ample space to recut the connections, reduce the wear rate on the OD and extend the service life • The center upset protects the tube from OD wear by keeping the tube away from the hole wall, while at the same time reducing the risk of differential sticking • The API Bore Back Box feature is standard for the box connection on 4 inch Hevi-Wate Drill Pipe and larger, helping to extend the service life of the connection • Cold rolling the thread roots on all Hevi-Wate Drill Pipe connections increases the connection’s ability to resist fatigue cracking • Hevi-Wate Drill Pipe can be picked up with the drill pipe elevators for fast, efficient handling on the rig floor

Hevi-Wate™ Drill Pipe - Standard and Spiral

Optional Features • Hardbanding placed on the tool joints and center wear pad will increase abrasion resistance and extend service life • The API Stress-relief Groove feature on the pin connection for sizes 4 inches and larger Applications Directional Drilling: • An effective weight-on-bit member in extended reach, horizontal and conventional directional well designs • Improves directional control by reducing torque and drag • The center upset helps reduce the risk of differential sticking Vertical Drilling: • Use as an active weight-on-bit member in place of a portion of the drill collar string to reduce torque and shorten trip time • Hevi-Wate Drill Pipe can be used to provide a portion of the anticipated drilling weight when using soft formation PDC rock bits

Bending Strength Ratios

Spiral Hevi-Wate Drill Pipe

Hevi-Wate Drill Pipe vs. Maximum Hole Size (when used as bit weight in vertical hole)

3 1⁄2

4

4 1⁄2

5

5 1⁄2

6 5⁄8

Max. hole size

(in.)

7

8 1⁄8

9 1⁄16

10 1⁄16

11

13 1⁄2

Wt. (Approx.) Incl. Tube & Joints (lbs.)

Nom. Size (in.)

Transition Zone: • 18 to 21 joints of Hevi-Wate Drill Pipe run above the drill collars will reduce the risk of drill pipe fatigue failure

(in.)

Hevi-Wate Max. Drill Collar Drill Pipe Bending Strength Size* Size Ratio

Hevi-Wate Drill Pipe Weight and Center Upset Dimensions

Note: Hevi-Wate Drill Pipe should not be used as bit weight in vertical holes larger than those listed in the table below.

Hevi-Wate size

See Machine Shop section for Hevi-Wate Drill Pipe hardband details.

Hydraulic Improvements • Hevi-Wate Drill Pipe can be used to reduce drillstring pressure losses when used to replace part of the drill collar string. This can be effective in the 6 inch to 8 ¾ inch hole size range where drill collar bore size is relatively small

Remedial Operations • Hevi-Wate Drill Pipe is used to provide the weight required in milling, underreaming or hole opening operations

Center upset

Standard Hardband • A variety of abrasion resistant materials are available for application. Contact a Smith Services representative for more information • Pin – 5 inches of hardmetal applied flush with the OD • Box – 4 inches of hardmetal applied flush with the OD and 1 inch on the taper • Center upset – two 3-inch bands applied to the OD

Jar Placement • Hevi-Wate Drill Pipe is well suited for jar placement. Utilize a sufficient number of joints below the jar to ensure that the jar is not in the transition zone, and 20 percent of the recommended jar overpull as hammer weight above the jar in areas where differential sticking is a problem. See a Smith Services representative for additional information and placement recommendations

Tapered Drillstrings • Hevi-Wate Drill Pipe should be used in the crossover area of the drill stem when the bending strength ratio (ratio of I/C or section modulus) between the drill collars and the drill pipe exceeds 5.5. Hevi-Wate Drill Pipe will provide a gradual transition in stiffness between the drill collars and drill pipe, reducing fatigue damage to the drill pipe. Refer to table “Bending Strength Ratios” for maximum drill collar size to be run directly below Hevi-Wate Drill Pipe. Also refer to the “Drilling Assembly Handbook” for additional information

Standard Hevi-Wate Drill Pipe

lb/ft

lb/Jt 31 ft

Center Upset Length (ft.)

3 1⁄2

27.5

849

4

34.3

4 1⁄2 5

Wt. (Approx.) Incl. Tube & Joints (lbs.)

(in.)

(in.)

3 1⁄2

5 3⁄4 x 2 1⁄4

18.2 / 3.5 = 5.2:1 26.5 / 5.2 = 5.1:1

lb/ft

lb/Jt 31 ft

Center Upset Length (in.)

4

6 ⁄2 x 2 ⁄4

18.5

23.4

721

24

4 1⁄2

7 1⁄2 x 2 13⁄16

36.5 / 7.7 = 4.7:1

1,057

18.5

29.9

920

24

5

8 1⁄4 x 2 13⁄16

54.3 / 10.7 = 5.1:1

46.5

1,431

18.5

41.1

1,265

24

5 1⁄2

9 x 2 13⁄16

70.8 / 14 = 5.1:1

55.4

1,706

18.5

50.1

1,543

24

6 5⁄8

10 1⁄2 x 3

113 / 22.4 = 5.0:1

5 1⁄2

63.8

1,962

18.5

57.6

1,770

24

6 5⁄8

77.7

2,389

18.5

71.3

2,193

24

1

1

*Indicates the largest size drill collar to be run directly below the Hevi-Wate Drill Pipe. If drill collars larger than the maximum size shown are to be used, run at least three collars of the maximum size shown between the large drill collar and the Hevi-Wate Drill Pipe.

Hevi-Wate Drill Pipe Dimensions - Standard and Spiral Mechanical Properties Tube Section

Tube Nom. Tube Dimensions

Nom. Size

(in.)

Standard Hevi-Wate Drill Pipe

Spiraled Hevi-Wate Drill Pipe

Wall Thickness

Area

(in.)

(in.)

(sq. in.)

1

3 ⁄2

2 ¹⁄₄

0.625

4

2 ⁹⁄₁₆

0.719

1

4 ⁄2

2 ³⁄₄

0.875

5

3

1.000

1

5 ⁄2

3 ³⁄₈

1.063

6 ⁄8

4 ¹⁄₂

1.063

5

12

ID

13

Center Elevator Tensile Upset Upset Yield OD OD (lb.)

Torsional Yield

Tool Joint

Conn. Size and Type

(ft-lb)

Approx. Approx. Overall Tensile Torsional Make-up Overall Length Yield Yield Torque Length Pin/Box

OD

ID

(in.)

(in.)

(lb.)

(ft-lb)

(ft-lb)

(in.)

(ft.)

(in.)

(in.)

5.645

4

3 ⁵⁄₈

310,475

18,460

NC 38 (3 ¹⁄₂ IF)

4 ³⁄₄

2 ³⁄₈

675,045

17,575

10,000

30 / 27

31

7.410

4 ¹⁄₂

4 ¹⁄₈

407,550

27,635

NC 40 (4 FH)

5 ¹⁄₄

2 ¹¹⁄₁₆

711,475

23,525

13,300

30 / 27

31

9.965

5

4 ⁵⁄₈

548,075

40,715

NC 46 (4 IF)

6 ¹⁄₄

2 ⁷⁄₈

1,024,500 38,800

21,800

30 / 27

31

12.566

5 ¹⁄₂

5 ¹⁄₈

691,185

56,495

NC 50 (4 ¹⁄₂ IF)

6 ⁵⁄₈

3 1⁄16

1,266,000 51,375

29,200

30 / 27

31

14.812

6

5 ⁵⁄₈

814,660

74,140

5 ¹⁄₂ FH

7

3 ¹⁄₂

1,349,365 53,080

32,800

30 / 27

31

18.567

7 ¹⁄₈

6 ³⁄₄

1,021,185

118,845

6 ⁵⁄₈ FH

8

4 ⁵⁄₈

1,490,495 73,215

45,800

30 / 27

31

Drill Collars - Standard and Spiral The drill collar is not only the most common member in the BHA, it is also the most critical to its overall performance. The care taken in materials specification, heat treat, machining and inspection are only a few of the reasons Smith Services drill collars outperform the competition. By helping our customers select the optimum connections and the right optional features, Smith Services combines the right product with the best advice for trouble-free BHA performance. Standard Features and Benefits • Rolled, milled or machined surface finishes available • The critical threaded section has a hardness range of 285 to 341 BHN and a Charpy impact value of 40 ft-lbs at room temperature guaranteed one inch below the surface

• •

•

• •

Drill Collars - Standard and Spiral

New drill collar connections are manufactured to the specifications contained in the API Spec 7 Connections are kemplated (phosphate coated) to protect them from the elements after machining and to help prevent galling upon initial make-up Thread roots are cold rolled on API and H-90 connections; excluding the 2 3⁄8, 2 7 ⁄8 inch REG. and Slim-Line H-90. Cold rolling compresses the fibers in the thread root making this area of the connection more resistant to fatigue Pressed steel thread protectors are supplied for all drill collars that are equipped with standard connections All drill collars are subjected to rigorous quality assurance procedures during manufacture, including ultrasonic testing of drill collar bars after heat treating

Optional Features and Benefits • Slip and elevator recesses are designed to cut drill collar handling time by eliminating lift subs and safety clamps. Extreme care is taken to machine smooth radii free of tool marks. Cold rolling the radii at the upper shoulder of each recess is done to extend the fatigue life of the drill collar. Slip and elevator recesses may be used together or separately • An API Stress-relief Groove on the pin and an API Bore Back Box are available on request and are recommended for drill collars and all downhole tools where fatigue can occur as a result of bending. These features remove the unengaged threads in the highly stressed areas of the drill collar connection. This provides a connection that is less likely to crack due to fatigue because bending in the connection occurs in areas with smooth surfaces free of stress concentrations • Spiral drill collars offer the benefit of reducing the area of contact between the drill collar and the hole wall. This feature should be applied in drilling conditions where differential sticking is a problem

Standard Sizes, Bores and Connections Drill Collar Conn. Size & Type

Min. OD

Bore

Length

(in.)

(in.)

(ft.)

Bending Strength Ratio***

Drill Collar Wt.

NC 26 (2 ³⁄₈ IF)

3 ¹⁄₂

1 ¹⁄₂

30

2.42:1

801

NC 31 (2 ⁷⁄₈ IF)

4 ¹⁄₈

2

30

2.43:1

1,041

NC 38 (3 ¹⁄₂ IF)

4 ³⁄₄

2 ¹⁄₄

31

1.85:1

1,451

NC 38 (3 ¹⁄₂ IF)

5

2 ¹⁄₄

31

2.38:1

1,652

NC 44

6

2 ¹⁄₄

31

2.49:1

2,561

(lb.)

NC 44

6

2 ¹³⁄₁₆

31

2.84:1

2,353

NC 44

6 ¹⁄₄

2 ¹⁄₄

31

2.91:1

2,806

NC 46 (4 IF)

6 ¹⁄₄

2 ¹³⁄₁₆

31

2.63:1

2,598

NC 46 (4 IF)

6 ¹⁄₂

2 ¹⁄₄

31

2.76:1

3,085

NC 46 (4 IF)

6 ¹⁄₂

2 ¹³⁄₁₆

31

3.05:1

2,877

NC 46 (4 IF)

6 ³⁄₄

2 ¹⁄₄

31

3.18:1

3,364

NC 50 (4 ¹⁄₂ IF)

7

2 ¹⁄₄

31

2.54:1

3,643

NC 50 (4 ¹⁄₂ IF)

7

2 ¹³⁄₁₆

31

2.73:1

3,434

NC 50 (4 ¹⁄₂ IF)

7 ¹⁄₄

2 ¹³⁄₁₆

31

3.12:1

3,714

NC 56

8

2 ¹³⁄₁₆

31

3.02:1

4,675

6 ⁵⁄₈ REG.

8

2 ¹³⁄₁₆

31

2.60:1

4,675

6 ⁵⁄₈ REG.

8 ¹⁄₄

2 ¹³⁄₁₆

31

2.93:1

5,016

7 ⁵⁄₈ REG.

9 ¹⁄₂

3

31

2.81:1

6,727

7 ⁵⁄₈ REG.**

9 ³⁄₄

3

31

3.09:1

7,130

8 ⁵⁄₈ REG.**

11

3

30

2.78:1

8,970

** Low torque face *** Ratio of box-to-pin section modulus. See API RP7G for explanation.

Note: The weight of a round drill collar will be reduced by approximately four percent by spiral conversion.

Drill collar hardbanding is the most effective way to retard the OD wear that occurs on a drill collar under normal open hole drilling conditions. Standard hardbanding material consists of granular tungsten carbide that is fed into the molten weld puddle to obtain uniform distribution of the tungsten carbide particles. The resulting deposit is flush to 1⁄32 inch above the OD of the collar. Hardbanding should not be applied to the box end unless the drill collar has been equipped with a slip recess because hardbanding will cover the normal slip area Applications • Drilling weight is the most universal application of drill collars. A typical drill collar string is designed so that its buoyed weight is approximately 15 percent more than the maximum bit weight required for optimum bit performance. This will ensure that enough drill collars are run in compression so that the neutral point is maintained in the drill collar string • Hole  size integrity results from proper drill collar sizing (while maintaining conventional fishability) enabling the desired casing size to be run to bottom. The drill collar accomplishes this by limiting the lateral movement of the drill bit in the absence of larger diameter drilling tools

•

Drill collar stiffness is important to drill and maintain a straight wellbore. The first 90 feet of BHA above the bit has the greatest impact on hole straightness and is where drill collar stiffness should be optimized. Refer to the “Drilling Assembly Handbook” for more information

Slip and Elevator Recess Option

20"

Radius cold worked

16"

3"

Radius cold worked

18"

Note: Slip and elevator recesses may be used together or separately.

Stress-relief Option Spiral drill collar

Smooth surface free of tool marks increases flexibility and permits bending without cracking

Standard drill collar

API Stress-relief Groove Pin

Last scratch of box thread covered by pin

Notes: • Other sizes and connections are available • Optional features available upon request

14

15

API Bore Back Box

Large radii reduce stress concentrations

Note: The 4 ¾" OD drill collar is the smallest diameter that can be hardbanded. Ordering instructions, please specify: • Drill collar OD • Drill collar bore ID • Length of drill collar • Size, type and location of connections. Example: NC 50 box up x NC 50 pin down • Cast or pressed steel thread protectors Refer to page 21 for drill collar hardbanding options.

Rotary, Bit Sub and Lift Sub Rotary and Crossover Rotary Subs have two primary applications. They can be used to cross over from one connection size to another, or as the disposable component, used to extend the connection life of a more expensive drill stem member. Rotary Subs are available with box x pin, box x box or pin x pin connections. The connections are protected by a phosphate surface coating that minimizes galling on initial makeup. When subs are ordered to conform to API specifications, Smith Services is authorized to apply the API monogram. The following Rotary Subs are available: • Straight OD Sub is used to connect drill stem members that have a similar outside diameter. The drill bit, downhole tools, Hevi-Wate™ Drill Pipe and drill pipe can be crossed over using a Straight OD Sub.

•

•

When Bit Subs are ordered to conform to API standards, Smith International is authorized to apply the API monogram. Size availability ranges from 3 ⅛ inch - 11 inch OD and 36 inches - 48 inches in length.

Reduced Section Sub is used to connect drill stem members that have different diameters that warrant the cross-sectional change necessary to accommodate different connections. This sub would be used to cross over large OD drilling tools or a tapered drill collar string. Saver Sub is used to extend the life of the kelly by taking the connection wear each time it is made up to a drill stem component. The Saver Sub connection is sacrificed because it can be easily repaired or inexpensively replaced. The Saver Sub can be equipped with a rubber protector to reduce BOP equipment and casing wear resulting from contact damage with the lower kelly connection.

Lift Sub A Lift Sub enables the safe, efficient handling of straight OD tubulars such as drill collars, shock tools, jars, directional equipment and other tools by using the drill pipe elevators. Note: For a box-up Lift Sub, add 6" to the overall length.

18"

Bit Sub Smith Services manufactures a complete line of Bit Subs made from materials that are heat treated to drill collar specifications. Connections are protected by a phosphate surface coating to minimize galling on initial make-up.

Features and Benefits • Heat treated to meet or exceed API specifications for drill pipe tool joint mechanical properties • Precision machined API connections standard, with proprietary connections available machined by licensed vendors • Serialized for complete material traceability

Box x pin Fig. 2

Reduced Section Subs

36"

48"

Pin x pin Fig. 3

Certified Cast Steel Thread Protector Certified Cast Steel Thread Protectors (CCSTP) with lifting bails offer the ultimate in thread protection, including certified lifting capacities to ensure safe handling of tubular products during manufacture, shipping or at the rig site. The CCSTP is manufactured from steel castings with heavy-duty bails suitable for picking up and laying down a drill collar with the catline. Each lifting bail is proof tested to 300 percent of the maximum anticipated load and is capable of picking up one drill collar within the recommended diameter for the type and size of connection on the CCSTP. Threads and shoulders are precision machined.

Saver Subs

Box x box Fig. 4

Pin x box Fig. 5

Ordering instructions, please specify: • Identify sub use. Example: Kelly Sub, crossover drill pipe to drill collar, drill collar to drill collar, bit sub, etc. • Overall length • Largest diameter • Bore ID • Size and type of upper and lower connections, indicating pin or box

• • • • • •

Box x box Box x pin Fig. 6 Fig. 7

Pin x pin Fig. 8

Box x pin Fig. 9

Features and Benefits • Unique serial number is permanently affixed to each protector for complete traceability • Traceable for test date, applied load vs. time, and inspection results • Each protector is load tested and certified • NDT inspected for cracks after pull testing Each CCSTP has been load tested and inspected prior to sale. Due to the rough nature in which drill collars are handled, Smith Services recommends frequent inspection to ensure the bail is not cracked and that proper makeup to the connection is possible. Note: Cast Steel Thread Protectors should only be used to pick up or lay down one drill collar at a time.

Certified CSTP

S/N

S/N

Pin

Box

Specifications - Top Drive Sub

36"

48"

12"

Box x box Fig. 1

Thread protectors are available in three types: • Cast Steel, with lifting bail, are made from steel castings that meet ASTM specification A27 Grade 60-30 (60,000 psi tensile - 30,000 psi yield) and are equipped with heavy-duty bails suitable for picking up and laying down a drill collar with the catline. Threads and shoulders are precision machined. • Pressed Steel light-duty protectors are suitable for shipping and storing threaded drill stem components only. • Plastic light-duty protectors are suitable for shipping and storing threaded drill stem components only.

Lift Sub

Straight OD Subs

36"

Top Drive Sub Top Drive Subs serve as the sacrificial element between the drillstring and the top drive, reducing repair and maintenance costs. The Top Drive Sub can easily be repaired or replaced in the event the lower pin threads become galled or damaged. These tools are manufactured from selected bars of alloy steel, heat treated to provide the strength and toughness required to carry the entire weight of the drillstring.

Thread Protector Thread protectors should always be used to protect both the pin and box connection when drill stem components are being shipped or stored at the warehouse or on location.

36"

Rotary and Crossover Subs

36"

Top Drive Sub and Thread Protectors

Box x pin Fig. 10

Cast or pressed-steel thread protectors For Reduced Section Subs, add: diameter of reduced section Length of reduced section: 8", 12", 18" or 24" For Bit Subs, add: float bore size and type if desired For Kelly Saver Subs with protectors, add: casing OD and weight to properly size the casing protector For Lift Subs, specify tapered or square shoulder and drill pipe OD

• •

16

OD

ID

(in.)

(in.)

Lower Pin Conn. Upper Pin Conn. Size

Lower Pin Conn. Size

Tensile Yield

Torsional Yield

(lbs.)

(ft-lbs)

8 ⁵⁄₈

4

7 ⁵⁄₈ REG.

6 ⁵⁄₈ FH

2,296,000

118,000

8 ⁵⁄₈

3 ¹⁄₂

7 ⁵⁄₈ REG.

5 ¹⁄₂ FH

1,619,000

72,000

8 ⁵⁄₈

3

7 ⁵⁄₈ REG.

NC-50

1,416,000

57,000

8 ⁵⁄₈

2 ¹⁄₂

7 ⁵⁄₈ REG.

NC-46

1,307,000

49,000

8 ⁵⁄₈

2 ¹⁄₄

7 ⁵⁄₈ REG.

NC-38

790,000

24,000

 tandard sizes shown above. Additional sizes available upon request, S including box up design Mechanical properties based on 120,000 psi material yield strength

17

Top Drive Sub

Cast Steel Thread Protector

Box

Pressed Steel Thread Protector

Box

Ezy-Torque™ Hydraulic Cathead The Ezy-Torque Hydraulic Cathead provides smooth, constantly increasing make-up loads ranging from 40,000 to 150,000 ft-lbs of torque, utilizing either an independent power source or a rig source. This smooth application of line pull force to the rig tongs ensures proper make-up of large, rotary shouldered connections. When the EzyTorque Hydraulic Cathead is to be used on connections that require less than 40,000 ft-lbs of torque, the unit should be used in conjunction with a calibrated load cell. The Ezy-Torque Hydraulic Cathead is available in two systems: The Ezy-Torque Model E Type I consists of a cylinder assembly and a self-contained hydraulic power supply that can be temporarily or permanently installed on the drilling rig, preferably on the rig floor. Features and Benefits • Remote control module enables pressure regulation and cylinder operation from a convenient location on the rig • Hydraulic operation of the remote control module eliminates electrical hazards • Provides a simple hydraulic circuit for trouble-free performance • A positive displacement tandem pump provides efficient, steady hydraulic energy

•

The cylinder assembly produces the high line pulls necessary to develop make-up torques to 150,000 ft-lbs (203, 400 N•m). It is a key component to both the Model D and Model E Systems. The cylinder assembly includes wireline for connection to the rig tongs.

Tru-Torque® Automatic Torque Control System

r we Po oke s tr " 45

Snub line

Pressure port (power stroke)

Caution: Do not exceed the torque rating of the rig tongs.

The Tru-Torque ATCS includes an intrinsically safe load cell, explosion-proof air controllers and an airpurged control panel to permit operation in Class 1, Group D, Divisions 1 and 2 hazardous environments. The optional power time delay unit is available for all Division 1 situations. The Tru-Torque ATCS can be used on any rig with manual tongs and airactivated cathead clutches.

Pressure port (return stroke)

The Ezy-Torque Model D Type II consists of a cylinder assembly, auxiliary hydraulic control unit, remote control module (and hoses) for the control unit and remote control module. The auxiliary control unit plumbs (conversion fittings are not supplied) into an existing rig hydraulic supply such as the accumulator portion of the blow out preventer system.

Model E Type I power unit

Features and Benefits • Utilizes existing rig hydraulic equipment, minimizing unit space requirements • Remote control module enables hydraulic pressure regulation from a convenient location • Hydraulic fluid pressure is regulated through the remote control module • Air and hydraulic operation of the remote control module eliminates electrical hazards

The heart of the Tru-Torque Automatic Torque Control (ATCS) System is the Model 2000 digital electronic controller. It ensures that the recommended API torque is applied for proper make-up of drillstring components. This extremely accurate control unit will automatically terminate the make-up of your drillstring connections when a pre-specified torque limit is achieved.

Note: The hydraulic auxiliary control unit is designed with a closed center valve for connection to a hydraulic system utilizing accumulators. A conversion kit may be required depending on the rig’s hydraulic power source, such as when powered by a positive displacement pump.

Min. Flow Rate

Max. Flow Rate

Max. Test Pressure

Max. Working Pressure

Stroke Length

Line Pull

Torque Range

4 gpm

35 gpm

3,000 psi

2,500 psi

22.5 in.

32,900 lbs.

40,000 - 150,000 ft-lbs

18.9 lpm

132.5 lpm

20.68 MPa

17.2 MPa

571.5 mm

146,000 N

54,240 - 203,400 N•m

Line pull: Torque: Accuracy: Settings: Indicator: Tong arm settings: Electrical power in: Connecting voltage: Air controllers: Calibration: Construction: Safety factor:

Power Data Frequency (Hz)

10 hp - 1,750 rpm 7 ¹⁄₂ hp - 1,450 rpm

Amps (Approx.)

Applications • Drilling or service rig operations where drill pipe and tubing are being handled • Reduction of pin and box damage by preventing improper torque, a primary cause of swelled boxes, stretched pins and galled threads and shoulders

Cathead Clutch Air Controllers: • Direct pneumatic connections except when electrical pulse vents clutch line • Internal pneumatic safety latchoperating pressure range of 5 to 150 psi • Automatic reset ensures clutch release and regulated torque application on driller’s command only • Fiberglass reinforced plastic caseadaptable for use with air over hydraulic catheads Optional Power Time Delay Unit: • For Class 1, Group D, Division 1 applications • Explosion-proof enclosure and electrical connections • Interrupts power and delays reactivation if system controller door is opened or purge pressure is lost

Cylinder Assembly

Cylinder Assembly

Motor, Three-phase

Features and Benefits • Easy to use interface enables drillers and rig crews to be promptly trained • Controls are within easy reach of the driller • User friendly menu-driven controls and settings • Retrievable make-up history file • Sunlight-viewable LCD read out • Minimize the fishing risk due to washouts and twistoffs • Reduce trip time by improving pipe handling efficiency • Improving rig safety by allowing the driller to focus attention on rig floor activities

Cylinder Time (Seconds) Power Return Stroke Stroke

230V

460V

220V

380V

60

25.4

12.7

n/a

n/a

10

5

50

n/a

n/a

23.4

11.7

11

6

Ordering instructions, please specify: • Ezy-Torque Model E Type I • Cycles of power source: 50 Hz or 60 Hz • Voltage the motor should be wired for. The following are available: 60 Hz – 230V or 460V and 50 Hz – 220V or 380V. Other voltages are available upon special order

System Controller Stainless steel housing, air purged for Class 1, Group D, Division 2 operation

Ordering instructions, please specify: • Ezy-Torque Model D Type II • With or without conversion kit

18

0 to 30,000 lbs. load cell range 0 to 150,000 ft-lbs w/ 60" tong arm 1,000 to 30,000 lbs.: ± 1% or better Torque is in ft-lbs and line pull in lbs. w/ 10 lb. increments 6 digits 24" to 99" w/ 1" increments 115 VAC 50 / 60 Hz nominal; 2.0 amp maximum Load cell: +15V DC through an intrinsic safety barrier 12-19V DC via cable w/ locking plug Load Cell 1% or better at 30,000 lbs. with ±1.0% NIST traceable line pull Manufactured from stainless steel and sealed for rugged use 4 times at 30,000 lbs.

19

Machine Shop Services Smith Services personnel are experts in the machining and repair of rotary shouldered connections. Highly trained and experienced machinists ensure that each job is done to API and Smith Services standards. The quality process starts before the component ever sees the machine shop floor. A qualified Smith Services representative meets with the customer to discuss the scope of work, review inspection reports, dimensional data and confirm that the connection to be machined best suits the OD and ID of the tubular. Once in the lathe, the machinist will size, monitor and measure the five critical elements of the rotary shouldered connection: thread form, lead, taper, size and bevel diameter. Lead and taper are measured with calibrated gauges while gauge point standoff (size) will be measured using calibrated hardened and ground ring or plug gauges. The rotary shouldered connection is a structural member and requires adequate make-up torque to achieve 100 percent of its strength. The most common cause of connection failure or damage is insufficient torque applied during make-up. Refer to the recommended make-up torque tables found in the Smith Services “Drilling Assembly Handbook”, or call a Smith Services representative for more information.

Tool joint build-up is an industry-accepted procedure to extend the service life of drill pipe and Hevi-Wate™ Drill Pipe. Tool joints that meet minimum recommended length and diameter criteria can be professionally restored to their original OD at selected Smith Services facilities. A properly rebuilt tool joint will yield a connection with the same OD, seal face area and bevel diameter as a new tool joint.

The API Stress-relief Groove removes the unengaged threads near the pin shoulder and provides large radii for smooth distribution of stresses around the corners. To mitigate the notch effect, all threads of the pin must be engaged with threads from the box. Considering the length of the box counterbore and the starting thread chamfer, API specifies the relief groove to be one inch in length. Note: This feature is not recommended for some small connections.

Trepanning

Kemplating is the application of a phosphate coating that provides a barrier between the metallic surfaces of the pin and box to prevent galling until connections become work-hardened. This porous finish also helps retain the thread compound, ensuring proper lubrication of the mating surfaces. A phosphate coating can be applied either by vat-dipping or spray-on solution and can be done at a Smith Services facility. Machine connection

The API Bore Back Box feature is a long cylindrical bore machined into the box to provide relief from bending stress. The unengaged threads in the back of the box are machined out, removing the notches and subsequent stress risers that are otherwise created. The length of the cylinder section provides increased flexibility for this high-stress area. Note: This feature is not recommended for some small connections.

Drill collar spiraling

Machine Shop Services

Cold rolling on drill collars and downhole drilling tools increases the fatigue life of the connection by placing thread root fibers into compression. In this compressed state, the thread roots better resist fatigue. Industry tests have confirmed that the fatigue life of a thread will increase with cold working, which is accomplished either with the cold rolling process or by peening.

Tubular Repair Services Connection recuts are the most common type of tubular repair. This process is similar for drill collars, drilling tools, rotary kellys and other tubular products. The procedure requires that four to six inches of material be removed depending on the connection type and its features. Enough material must be removed to ensure that the damaged area (near the base of the box or pin) is not part of the recut connection. Most rotary shoulder connections can be recut and repaired at any Smith Services facility. Repairs to drill collars and downhole drilling tools are completed and inspected using calibrated lead and taper gauges and ring and plug gauges. It is recommended that a recut connection be cold rolled, phosphate coated and equipped with a thread protector before leaving the shop.

Smith Services adheres to the following processes and parameters to ensure trouble-free life for a rebuilt tool joint: • The depth of the heat affected zone must be prevented from entering the threaded area • A proprietary blend of wire and flux provides a build-up material with an optimum combination of yield strength, wear resistance and ductility • Existing hard metal is removed • Maximum build-up limits will not be exceeded • Preheat and postheat cycles are carefully monitored to ensure mechanical properties of the tool joint are maintained and adequate postweld stress relief is accomplished • The tool joint is machined to its finished diameter, the hardbanding reapplied and the connection re-machined to specific dimensions

Stubbing

A variety of hardband materials can be applied following the rebuild process to add additional life to the tool joint. A Smith Services representative can evaluate your downgraded tubulars to help determine which joints are repairable and at what cost. Stub Welding Ends on Drill Collars and Specialty Tools (Stubbing) When drill stem members become too short, box-weak from OD wear or pin-weak from ID wear, they can be put back into service using a process referred to as stubbing. Smith Services is the industry specialist at stub welding new material to the ends of worn tools and cost-effectively restoring the physical dimensions back to acceptable requirements. Stubbing should be considered when: • Repeated reworking of connections has left the tool too short for use • Outside wear on the tool has reduced the bending strength and torsional strength of the box • Enlargement of the bore by erosion has affected the bending and torsional / tensile strength of the pin

Note: The recut connection should be handled and broken-in using the same procedures as any newly manufactured connection.

Tool joint build-up

20

Hevi-Wate Drill Pipe build-up should be considered to extend the usable life of the tubular. The center upset and long tool joints should be rebuilt to new dimensions and hardbanding reapplied before total wear gets below these limits: • The center upset section might not wear concentrically. At least ⅛ inch material must remain at all points on the circumference for build-up • The pin and box tool joint sections may be built-up if minimum diameter and length requirements are met

21

Tools to Consider for Stubbing: The following is a partial list of drilling tools that can be considered for the stub welding repair. Drill collars, heavy wall drill pipe, stabilizers, roller ream-

ers, hole openers and rotary kellys. Smith Services uses a carefully selected weld material and flux to produce a weld deposit with adequate strength, while maintaining optimum hardness and ductility. Strict attention is given to the preheating of parts, welding processes and post-heat cycles. Automated stubbing units ensure high quality stub welds and conformance to requirements on every stub weld. Consider stub welding as a method to prolong the life of your drilling tools. Non-magnetic Materials Stubbing Shortened non-magnetic specialty tools can be repaired and placed back into service using proprietary stubbing processes and materials developed by Smith Services. Most nonmag drill collars, MWD collars and other high-priced components can cost-effectively have their useful life extended. Call a Smith Services representative to ensure that a procedure has been qualified to stub the non-magnetic tools in your fleet.

Machine Shop Services Rotary Kelly Repair The Rotary Kelly is the drive link between the surface power of the rig and the drill bit. When kelly wear becomes appreciable, it can usually be repaired at selected Smith Services facilities. The following conditions can be repaired at most service centers. • Connection Damage: The upsets on each end of the kelly are manufactured with sufficient length to allow the connections to be recut a number of times • Crooked: In most cases a bent kelly can be straightened using a hydraulic straightener. The kelly should be closely inspected for indications of fatigue damage prior to straightening and subsequent return to service • Rounded Drive Corners: This condition can be repaired in one of two ways. The first and easiest method to accomplish this is to reverse the ends. This process enables the unworn side of the corners to be placed into service. The second method is to re-machine the drive flats to a smaller non-API size. This process may require special milling equipment not available in most field service centers. It should be noted that when this procedure is selected, special rollers must be purchased for use with the modified kelly. The re-machined kelly has a reduced load capacity. Kelly life can be extended significantly by implementing the following recommendations: • Always use a saver sub to reduce thread wear and damage on the lower connection • Always use a scabbard when transporting a kelly • Lubricate the drive surfaces of the kelly to permit it to slide freely through the drive bushing • Inspect frequently for indications of fatigue damage and stay alert to changing wear patterns on the kelly flats

Hardbanding Smith Services is known around the world for the quality application of hardband for OD wear protection on drill collars, drill pipe, heavy wall drill pipe and other tools used in drilling applications. An automatic, metalarc, inert gas shielded, consumable electrode process is used with closely controlled preheat and postheat. When hardband is replaced, it is necessary to remove the existing material prior to the application of the new hardfacing. Conventional hardband material consists of granular tungsten carbide fed automatically into the molten puddle to obtain uniform distribution of the tungsten carbide particles. A selection of casing friendly, non-tungsten carbide hardband from industryapproved suppliers is also available through Smith Services. The standard application is flush to 1 ⁄32 inch (unless otherwise specified) above the OD of the drill collar or tool joint. Hevi-Wate™ Drill Pipe: Hardbanding is recommended for the pin and box tool joints, as well as the center upset wear pad section. The standard application consists of: 5 inches of hardfacing placed flush with the OD on the pin tool joint, 5 inches of hardfacing placed flush with the box tool joint OD (4 inches on the tool joint OD and 1 inch on the taper) plus fingers applied to the tapered section of the box tool joint to prevent fluid undercutting.

Machine Shop Services

Hevi-Wate Drill Pipe Hardbanding

4" 1"

1"

Straightening Services Smith Services understands the importance of straight drill stem components. Bent tubular products and drilling tools can cause premature wear and subsequent failure of BOP equipment, drillstring and BHA members.

Drill pipe, drill collars, Hevi-Wate™ Drill Pipe and rotary kellys can be straightened at most Smith Services facilities. Make-up and Breakout Services Make-up and Breakout Services help improve rig economics by allowing drill pipe to be shipped in preassembled double lengths, reducing rig time spent on making up or breaking connections. In addition to makeup and breakout of drill pipe, Smith Services qualified operators use calibrated equipment to break in rotary shouldered connections. Breakingin these connections in a controlled environment ensures reliable on-site performance.

A certified Smith Services inspector will automatically check for straightness during the standard inspection process. The most common causes of bent drill pipe are improper make-up and breakout procedures, dropping the drillstring and mishandling during transportation.

3" 3"

• • •

Manufacture and repair of crossover subs, pup joints and saver subs Downhole tool repair Stabilizer redress and repair Custom repairs

Smith Services has offices and service centers located in most of the major oilfields in the world offering consistent, high quality drill stem service and repair. These facilities perform work to API specifications, when applicable, and Smith Services standards.

Other Machine Shop Services There are a number of other valuable services offered by Smith Services that include the following: • Spiraling of drill collars • Turning drill collar OD

5"

Standard

•

Spiraled Make-up and Breakout Unit Port Fourchon Facility

Automated Hardbanding Unit

The center upset wear pad section is provided with two 3-inch long bands applied to the OD to prevent wear to the center of the tube. Spiral HeviWate drill pipe will require tool joint hardbanding only.

Drill Collar Hardbanding Options Type A Pin End

Type B Type C Box End with Zip Lift (Slip Recess Only) (Elevator and Slip Recess)

Drill Collars: There are three standard options for applying hardband to drill collars; Type A, Type B and Type C as indicated in the Drill Collar Hardbanding Options reference on page 27. Variations of these options are available upon request. Please consult with a Smith Services representative for more information.

4" 1"

10"

Note: Drill collars smaller than 4 3⁄4" OD cannot be hardbanded due to thin walls.

1"

1" 30" min.

10"

Hardbanding Tool illustration is not to scale.

22

23

1" 10"

Inspection Services Service centers are equipped with the latest nondestructive testing (NDT) equipment and offer a full range of inspection that includes a variety of third party standards. Smith Services inspectors are ASNT Level II certified in both the principles and techniques of oilfield inspection. Extensive training combined with good old fashioned experience means that when a tool is inspected and marked with the “OK DRILCO” stencil, it is certified ready for service.

ing inspections can be conducted depending on customer specifications: • Complete thread inspection • Dimensional inspection • Visual inspection (VT) • Magnetic particle (MT) • Liquid dye penetrant (PT) • Ultrasonic inspection of rotary shouldered connections (UT) • Ultrasonic inspection of high stress areas and tube upsets • Electromagnetic dual function tubular inspections (ET)

Inspection capabilities include: • API - RP7G, Spec 7, RP 5A5, 5CT • Third party standards • DS-1 • NS-2 • Customer defined standards

Field repair of minor cracks, thread and shoulder blemishes can be completed by the Smith Services inspector while on location. These problems, if not repaired, will cause damage to other connections in the drillstring, and necessitate the expense of trucking equipment to a machine shop for repair.

Field Inspection Periodic inspection of drill pipe, drill collars, subs and drilling tools conducted at the drilling rig by a certified Smith Services inspector is the first important step in preventing downhole failures. The mobile inspection units are completely self-contained, housing all the equipment, consumable products and accessories necessary to provide complete service. Equipment can also be packaged for air transportation to remote or offshore locations. The inspector uses several NDT methods to check the high stress areas such as connections, slip areas, upset areas, weld areas, radius changes and tubes to detect cracks and indications. Once the areas to be inspected are thoroughly cleaned, any of the follow-

Thread lead measurement

Electromagnetic Inspection This system consists of a laptop computer, electronics package, data acquisition board and proprietary signal processing software. Features and Benefits • Dual function with 16 channels of information • Data can be viewed on most computers • Data can be delivered to the customer electronically • Fast and accurate calibration • Fast inspection and reliable results • Easy to interpret display • Indications can be easily located and investigated • Completely computer controlled • Highly transportable

Portable Hardbanding Service

Electromagnetic inspection station

Overall, the new state-of-the-art drill pipe inspection system and its ease of use allows for increased inspection production, greater operator efficiency and reduced overall operating costs.

Smith Services portable hardbanding units offer our customers the ultimate in cost effective maintenance for their drillstring. With today’s high cost of tubulars, having the ability to keep them in top shape without incurring the additional cost of shipping back and forth to a service center means a more efficient utilization of your tubular inventory and a higher return on your drillstring investment. The Smith Services portable hardbanding service provides: • Onsite application • State-of –the-art portable equipment

• • •

Fully trained & qualified personnel Drill pipe, drill collar & HeviWate™ applications Superior abrasion & wear protection Standard tungsten carbide & premium hardbanding materials

Smith Services Portable Hardbanding extends the useful life of drilling tubulars and is available from our 24 hour Service Centers worldwide.

Harbanding Application

In-shop Inspection Services When your drill stem products arrive at a Smith Services facility, they will receive thorough inspection by certified personnel. The following in-shop inspection services are available: • Complete thread inspection • Dimensional inspection • Visual inspection (VT) • Magnetic particle (MT) • Liquid dye penetrant (PT) • Ultrasonic inspection of rotary shouldered connections (UT) • Ultrasonic inspection of highstress areas and tube upsets • Full length ultrasonic inspection* • Full length dual function electromagnetic inspection (EMI)

Portable Harbanding Unit

Once inspected, tubular products and downhole tools can be fully repaired at a Smith Services machine shop. From simple straightening, connection repair or machining new connections, your drill stem components will be returned to drilling-ready condition. *Only available at the Port Fourchon Super Service Center.

24

•

25