IADC Drilling Manual Part 2 ppsx

A-88 International Association of Drilling ContractorsIADC Drilling Manual - Eleventh Edition Tracking can sometimes be alleviated by using a softer bit to drill the formation and/or by

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A-84 International Association of Drilling Contractors

IADC Drilling Manual - Eleventh Edition

PN (Plugged Nozzle) - (Fig A4-20)

Figure A4-20 Plugged Nozzle, PN

This dulling characteristic does not describe the cutting structure but can be useful in providing information about abit run

A plugged nozzle can lead to reduced hydraulics or force a trip out of the hole due to excessive pump pressure.Plugged nozzles can be caused by:

Jamming the bit into fill with the pump off

Solid material going up the drill string through the bit on a connection and becoming lodged in a nozzle whencirculation is resumed

Solid material pumped down the drill string and becoming lodged in a nozzle

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International Association of Drilling Contractors

Chapter A: Bit Classification and Grading

RG (Rounded Gage) - (Fig A4-21)

Figure A4-21 Rounded Gauge, RG

This dulling characteristic describes a bit that has experienced gauge wear in a rounded manner, but will still drill afull size hole

The gauge inserts may be less than nominal bit diameter but the cone backfaces are still at nominal diameter.Rounded Gage can be caused by:

Drilling an abrasive formation with excessive RPM

Reaming an under gauge hole

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SD (Shirttail Damage) - (Fig A4-22)

Figure A4-22 Shirttail Damage, SD

Shirttail damage may be different than junk damage and is not a cutting structure dulling characteristic.Shirttail wear can lead to seal failures

Some causes of shirttail damage are:

Junk in the hole

Reaming under gauge hole in faulted or broken formations

A pinched bit causing the shirttails to be the outer most part of the bit

Poor hydraulics

High angle well bore

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SS (Self Sharpening Wear) - (Fig A4-23)

Figure A4-23 Self Sharpening Wear, SS

This is a dulling characteristic which occurs when cutters wear in a manner such that they retain a sharp crestshape

TR (Tracking) - (Fig A4-24)

Figure A4-24 Tracking Wear, TR

This dulling characteristic occurs when the teeth mesh like a gear into the bottomhole pattern

The cutter wear on a bit that has been tracking will be on the leading and trailing flanks

The cone shell wear will be between the cutters in a row

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Tracking can sometimes be alleviated by using a softer bit to drill the formation and/or by reducing the hydrostaticpressure if possible

Tracking can be caused by:

Formation changes from brittle to plastic

Hydrostatic pressure that significantly exceeds the formation pressure

WO (Washed Out Bit) - (Fig A4-25)

Figure A4-25 Bit Washout, WO

Bit washouts are not cutting structure dulling characteristics but can provide important information when used as

an "Other" dulling characteristic This can occur at anytime during the bit run

If the bit weld is porous or not closed, then the bit will start to washout as soon as circulation starts

Often the welds are closed but crack during the bit run due to impact with bottom or ledges on connections.When a crack occurs and circulation starts through the crack, the washout is established very quickly

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WT (Worn Teeth) (Fig A4-26)

Figure A4-26 Worn Teeth, WT

This is a normal dulling characteristic of the tungsten carbide insert bits as well as for the stoft tooth bits

When WT is noted for steel tooth bits, it is also often appropriate to note self sharpening (SS) or flat crested (FC)wear

NO (No Dull Characteristics)

This code is used to indicate that the dull shows no sign of the other dulling characteristics described

This is often used when a bit is pulled after a short run for a reason not related to the bit, such as a drill stringwashout

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Chapter B: Drill String

Chapter B

Drill String

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B-2 International Association of Drilling Contractors

Table of Contents - Chapter B

Drill String

Preface B-5 B1 Drill String B-6 Introduction B-6

I Weld-on Tool Joints B-6 B2 Steel Drill Pipe B-45 B3 Tool Joints Care And Handling B-54

I Cleaning and Inspection B-54

II Picking Up the Drill String B-55 III Thread Compounds B-58

IV Breaking In New Tool Joints B-58

V Tripping B-59

VI Laying Down Drill String B-67 VII Damage and Failures Cause Prevention B-69 VIII Repair of Tool Joints B-87

IX Emergency Procedures B-93

X Transportation B-94

XI Storage B-95 XII Floor Handling Procedures B-96 B4 Drill String Operating Limits B-104

I Fatigue and Lateral Forces caused by Dog Legs and Floating Vessels B-104

II Fatigue Caused by Other Factors B-115 III Critical Rotary Speed B-120

IV Collapsed Pipe From Drill Stem Test and BOP Test B-120

V Transition from Drill String to Drill Collars B-121

VI Maximum Allowable Pull and Rotary Torque B-121 VII Make up Torque versus Drilling Torque B-123

IX Dynamic Loading of Drill Pipe during Tripping B-125

X Biaxial Loading of Drill Pipe B-125

XI Drill String Design B-126 XII References B-126 B5 Drill String Corrosion B-127

I Introduction B-127

Il Corrosion B-127 III Sulfide Stress Cracking B-132

IV Drilling Fluids Containing Oil B-135 B6 Drill String Inspection And Classification B-136

I Purpose B-136

II Drill String Marking and Identification B-136 III Drill Pipe And Tubing Work Strings B-136

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IV Tool Joints B-144 B7 Aluminum Drill String B-148 Introduction B-148

II Installation and Removal of Tool Joints B-148 III Aluminum Drill Pipe B-148

IV Drill String Care and Handling B-150

V Drill String Maintenance B-151

VI Drill String Operating Limits B-151 B-8 Glossary Of Drill String Terms B-154

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This Page Left Intentionally Blank

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Figure B1-1 Weld-on Tool Joint

Both inertia and continuous drive friction welders utilize frictional heat for achieving welding temperatures, ever, the inertia welder uses a flywheel and momentum principle whereas the continuous drive friction weldermaintains a constant rpm motor and brake system

how-A Tool Joint Selection

Tool joint selection for all weights and grades of drill pipe should be discussed with the manufacturer if unusualoperating conditions are anticipated Tool joints for standard weights and grades have been established by API.However, many other tool joints are being manufactured and are in use and most are included in API RP7G Thesetables were utilized in the preparation of Tables B1-1 through B1-4, titled Selection Chart

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B-8

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B-9

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Notes on Table B1-2

1 Tool Joint Plus 29.4' of Drill Pipe

2 Tensile Yield Strength of Drill Pipe Based on 75,000 psi

3 Tensile Yield Strength of the Tool Joint Pin is based on 120,000 psi Yield and the Cross Sectional Area at theRoot of the Thread 5/8 inch from the Shoulder

4 Torsional Yield Strength of the Drill Pipe is Based on a Shear Strength of 57.7% of the Minimum Yield Strength

5 Torsional Yield Strength of the Tool Joint Based on Tensile Yield Strength of the Pin and Compressive YieldStrength of the Box - Lower Value Prevailing

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B-11

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Notes on Table B1-3

2 Tensile Yield Strength of Drill Pipe Based on 75,000 psi

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B-13

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B-14

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Notes on Table B1-4

2 Tensile Yield Strength of Drill Pipe Based on Minimum Yield Strength for that Grade

NOTE: The tool joint OD and ID dimensions have been selected so that the torsional ratio between too[ joint andtube is 80% or more

Other OD and ID tool joints may be satisfactory when design is based on tensile rather than torsional strengthrequirements

Additional detailed dimensional data for joints is shown in Table B1-5 and Table B1-6

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For Full Size Image of this Table Click HereNotes on Table B1-5

*The bevel diameters on drill stem members may vary

The length of perfect threads in box shall not be less than maximum pin length (LpC), plus 1/8"

Note: See Figure B1-5 for nomenclature

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Notes on Table B1-6

H - Thread Height, Not Truncated

hn-h, - Thread Height, Truncated

sm-srs, fm-frn - Root Truncation

fon - fcb - Crest Truncation

Fcn - Fcb - Width of Flat, Crest

Fm - Frs - Width of Flat, Root

rm - rrs - Root Radius

r - Radius at Thread Corners

This is primarily for the use of crews in inspecting pipe and field shops repairing joints For design purposes,reference is also made to Table B 1-7, showing comparative allowable torque and dimensional data for drill pipeand tool joints

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B-20

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B-21

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B-22

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B-23

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Figure B1-2 Tool Joint Interchangeability Chart <From API RP 7G, 14th ed Table 2.14>

Notes on Table B1-7

1) The use of outside diameters (OD) smaller than those listed in the table may be acceptable on slim hole (SH) tooljoints due to special service requirements

2) Tool joint with dimensions shown has a lower torsional yield ratio than the 0.80 which is generally used

3) Recommended make-up torque is based on 72,000 psi stress

4) In calculation of torsional strengths of tool joints, both new and worn, the bevels of the tool joint shoulders aredisregarded This thickness measurement should be made in the plane of the face from the I.D of the counter bore

to outside diameter of the box, disregarding the bevels

* Tool joint diameters specified are required to retain torsional strength in the tool joint comparable to the torsionalstrength of the attached drill pipe These should be adequate for all service Tool joints with torsional strengthsconsiderably below that of the drill pipe may be adequate for much drilling service

Figure B1-2 and Figure B1-5 depict the interchangeability of the older API rotary shouldered connection style andthe current series referred to as the number style or numbered connection, NC

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Figure B1-5 Tool Joint Interchangeability Chart

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The NC connection is designated by a two-digit number indicating the pitch diameter of the pin member at the gagepoint The NC connections employ a "V" thread form having a 065 inch flat crest and 038 inch rounded root This

is designated as the V-0.038R form and mates with the V-0.065 thread form

B Torsional Strength of Tool Joints

The torsional strength of a tool joint is a function of several variables These include the strength of the steel,connection size, thread form, lead, taper, and coefficient of friction on the mating surfaces of threads and shoulders.The torque required to yield a rotary shouldered connection may be obtained from the equation in Appendix A, APIRP7G

The pin or box area, whichever controls, is the largest factor and is subject to the widest variation The tool jointoutside diameter (OD) and inside diameter (ID) largely determine the strength of the joint in torsion The ODaffects the box area and the ID affects the pin area Choice of OD and ID determines the areas of the pin and boxand establishes the theoretical torsional strength, assuming all other factors are constant

The greatest reduction in theoretical torsional strength of a tool joint during its service life occurs with OD wear Atwhatever point the tool joint box area becomes the smaller or controlling area, any further reduction in OD causes adirect reduction in torsional strength If the box area controls when the tool joint is new, initial OD wear reducestorsional strength If the pin controls when new, some OD wear may occur before the torsional strength is affected.Conversely, it is possible to increase torsional strength by making joint with oversize OD and reduced ID

The curves in Figures B1-6 through B1-30 depict the theoretical torsional yield strength of a number of commonlyused tool joint connections over a wide range of inside and outside tool joint diameters

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Figure B1-6

Figure B1-7

Figure B1-8

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Figure B1-9

Figure B1-10

Figure B1-11

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Figure B1-12

Figure B1-13

Figure B1-14

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Figure B1-15

Figure B1-16

Figure B1-17

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Figure B1-18

Figure B1-19

Figure B1-20

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Figure B1-21

Figure B1-22

Figure B1-23

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Figure B1-24

Figure B1-25

Figure B1-26

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Figure B1-27

Figure B1-28

Figure B1-29

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Figure B1-30

The theoretical torsional yield strength for the purpose of these curves is the theoretical torque which will causeadditional make-up of a tool joint each time the torque is used to make up pin and box The coefficient of frictionbetween mating surfaces, threads, or shoulders, is assumed to be 0.08, and minimum tensile yield is 120,000 psi.The curves may be used by taking the following steps:

a Select the curve for the size and type tool joint connection being studied

b Extend a horizontal line from the OD under consideration to the curve and read the torsional strength ing the box

represent-c Extend a vertical line from the ID to the curve and read the torsional strength representing the pin

d The smaller of the two torsional strengths thus obtained, is the theoretical torsional strength of the tool joint

e It is emphasized that the values obtained from the curves are theoretical values of torsional strength Tool joints

in the field, subject to many factors not included in determination of points for the curves, may vary considerablyfrom these values

f The curves are most useful to show the relative torsional strengths of joints for variations in OD and ID, bothnew and after wear In each case, the smaller values should be used

The recommended make-up torque for a used tool joint is determined by taking the following steps:

a Select the appropriately titled curve for the size and type of tool joint connection being studied

b Extend a horizontal line from the OD under consideration to the curve and read the recommended make-uptorque representing the box

c Extend a vertical line from the ID under consideration to the curve and read the recommended make-up torquerepresenting the pin

d The smaller of the two recommended make-up torques thus obtained is the recommended make-up torque for thetool joint

e A make-up torque higher than recommended may be required under extreme conditions

Tiêu đề	IADC Drilling Manual Part 2 ppsx
Tác giả	International Association of Drilling Contractors
Trường học	University of Houston
Chuyên ngành	Drilling Engineering
Thể loại	Manual
Năm xuất bản	Eleventh Edition
Thành phố	Houston

Định dạng
Số trang	73
Dung lượng	1,72 MB