Formulaire Du Foreur

A general data

Conversion factor to SI units ……………….…………..….. A1

Conversion factors…………………………………….…..… A2-A7

Decimal multiples and submultiples of a unit…………..…. A8

Decimals and metric equivalents of fraction of an inch….. A9

Temperature conversion table..…………………………….. A10

Correspondence between specifig gravity and degrees API (at 15.56 ºC in relation to water at 15.56ºC and 760 mmHg)…………………………………………..….. A11

Numerical constant and mathematical formulas………….. A12

Trigonometric formulas………………………………...……. A13

Geometry formulas for areas and volumes…………..…… A14

Inertia of plane surface………………………………………. A15

Content of horizontal cylindrical tank……………..……….. A16

Mechanics and strength of material……………..………… A17-A19

Electricity. Direct current……………………………………. A20-A21

Electricity. Alternating current………………………..…….. A22-A23

Principal chemical symbol, atomic numbers and weights………………………………………………………… A24

Specific gravity of various materials and fluids…………… A25

Physical properties of metals……………………….………. A26

Stratigraphic scale…………………………………………... A27

Buoyancy factor (Steel specific gravity = 7.85)…………... A28

B drill string standards

API steel grade and properties (API Spec 5D, 3rd edition, Aug. 1,1992)(API Spec.7, 38th edition, Apr. 1, 1994)………..………………………………………. B1

API drill pipe list and body and upset geometry (API Spec 5D, 3rd edition, August 1, 1992)…..…………… B2

Upset tubing for small-diameter work string (API Standard 5A and Spec 7)(Grade N-80)…………….. B3

Classification of used drill pipe (API RP 7G, 15th edition January 1, 1995)(All sizes, weight and grades)……………………………………………….……… B4

Inspection standards. Zones and color code identification (API RP 7G, 15th edition January 1, 1995)…………………………………………………..……. B5

Recommended practice for mill slot and groove method of drill string identification (API RP 7G, 15th edition January 1, 1995)……………………….……… B6-B7

Geometric characteristics of drill pipes (New pipe bodies and tool joints)…………………………. B8-B12

New (N), premium class (P) and class2 (2) drill pipe, torsional and tensile data (API RP 7G, 15th edition, January 1, 1995)……………………………………………. B13-B15

New (N), premium class (P) and class2 (2) drill pipe, collapse and burst pressure data (API RP 7G, 15th edition January 1, 1995)……………………………… B16-B18

Recommended minimum OD* and make-up torque of weld-on type tool joints based on the torsional strength of box and drill pipe (API RP 7G, 15th edition, January 1, 1995)…………………………………………..…. B19-B23

Thread dimensions of rotary shouldered connections (API Spec 38th edition, April 1, 1994)………….…………... B24

Shouldered connections…………………………..………… B25

Dimensions of obsolete shouldered connections (API Spec 7, Appendix I)………………………….………… B26

API threads forms and dimensions (API Spec 7, 38th edition, April 1,1994)…………………………..……….. B27

Characteristics of some non_API tool joints threads…..… B28-B29

Rotary shouldered connection interchange list………..…. B30-B31

Cylindrical drill collars. Dimensions and threads (API Spec7)…………………………………………………... B32

Ideal drill collar range………………………………………... B33

Weight of drill collar (Kg/m)…………………………………. B34

Polar modulus of drill collars (in3-mm3)…………………….. B35

Drill-collar Assembly. Rigidity R…………………………..… B36

Stress-relief features for drill collar connections (API Spec 7)………………………………………….………. B37

Large-diameter drill collars from 8¾ to 11¼ inches. Shoulder modifications for low-torque connections. Dimensions of low-torque shouldered……………….…….. B38

Spiral drill collars (Drilco)……………………………………. B39

Drill collar slip and elevator recess elevator bore dimensions (API RP 7G, 15th edition, January 1, 1995)…. B40

Recommended make-up torque for rotary shouldered drill collar connections (API RP 7G, 15th edition, January 1,1995)…………………………………………….... B41-B46

Heavy wall drill pipes (Drilco, Division of Smith International, Inc.)………………………………………..…... B47-B48

Kellys (API Spec 7, 38th edition, April 1, 1994)……………. B49

Strength of Kellys (API RP 7G, 15th edition, January 1, 1995)………………………………………………..…………. B50

Stretch of suspended drill pipe…………………………..…. B51

Drill stem design calculations (API RP 7G, 15th edition, January 1,1995)……………………………………………… B52-B55

Drill stem design calculations. Calculation examples….... B56-B59

Critical buckling force (Baker Hughes INTEQ)…….…….. B60

C casing, tubing line pipe standards

Tensile requirements. Casing and tubing (API Standard 5CT, 5th edition, April 1, 1995). Line pipe (API Standard 5L, April 1, 1995)……………………….…………………….. C1

Tensile requirements of special steels (non-API) (Vallourec & Mannesmann documentation)……..………... C2

API casing list (API Specification 5CT, 5th edition, April 1, 1995)…………………………………………..……... C3-C4

API tubing list (API Specification 5CT, 5th edition, April 1, 1995)………………………………………………..... C5

Drift diameter (API Standard 5CT, 5th edition, April 1, 1995)…………………………………………………. C6

Efficiency of a connection…………………………………... C7

Make-up torque………………………………………………. C8

Geometrical characteristics and mechanical properties of small-diameter tubing…………………………….………. C9-C15

Geometrical characteristics and mechanical properties of tubing…………………………………………….………… C16-C34

Geometrical characteristics and mechanical properties of casing…………………………………………….………… C35-C79

Geometrical characteristics and mechanical properties of coiled tubing…………………………………….…………. C80-C87

Geometrical characteristics and mechanical properties of line pipe, risers and conductor pipe………………..……. C88-C90

API and buttress casing thread forms. API round threads form. Buttress thread form…………………..…….. C91

API tubing thread form…………………………………..…... C92

Effect of tensile load on collapse resistance …………..…. C93

Ellipse of biaxial yeld stress. Effect of tensile load on collapse resistance……………………………………..…… C94

Qualitative influence of various operations on the stresses in a partially-cemented casing string………..….. C95

Quantitative influence of temperature and pressure variations on the stresses in a partially-cemented casing string………………………………………………..… C96-C97

D capacities and annular volumes

General formulas………………………………………… D1

Clearance between standard bits and casing size…… D2-D3

Capacities of cylinders…………………………………... D4-D5

Capacities of drill pipes………………………………….. D6-D7

Capacities of drill collars………………………………… D8

Capacities and displacements of casing………………. D9-D10

Capacities and displacements of tubings……………… D11

Annular volume between drill collar and open hole (liters per meter)………………………………………….. D12

Annular volume between drill pipe and open hole (liters per meter)………………………………………….. D13

Annular volume between drill pipe and casing (liters per meter)…………………………………………. D14-D15

Annular volume between casing and open hole (liters per meter)…………………………………………. D16

Annular volume between two string of casing (liters per meter)…………………………………………. D17-D19

Annular volume between casing and tubing (liters per meter)…………….…………………………… D20-D21

Capacities of coiled tubing …..………………………… D22-D23

E drilling bits and downhole motors

Common sizes and tolerance on new bits (API RP 7G, January 1, 1995)……………..……………..……………. E1

IADC roller bit classification system……………………. E2

IADC roller bit classification table (IADC/SPE 23937, February, 1992)………………………………………….. E3

How to use the roller bit table…………………………... E4

Comparison of roller bits………………………………… E5-E7

IADC fixed cutter drill bit classification system (IADC/SPE February 18-21, 1992)…………………….. E8-E9

IADC comparison of PDC bits………………………….. E10-E11

IADC comparison of TPS & natural diamonds bits ….. E12-E13

IADC dull bit grading (After IADC/SPE 23938-23939 of 1992)…………………………………………………… E14-E16

Parameters for using insert bits and friction bearings (After Baker-Hughes)……………………………………. E17

Threads and make-up torques for drill bits and coring bits (API RP 7G, January 1, 1995 - API Spec 7, April 1, 1994)…………………………………………………… E18

Turbodrill...................................................................... E19

Turbodrilling ................................................................ E20

Performance curves on turbodrill (Specific gravity d, constant flow rate Qn)……………………………………. E21

Turbodrill specifications (Specific gravity of mud 1.20) E22

Positive displacement motors………………………….. E23-E24

Performance curves of positive displacement motors for different flow rates Q………………………………… E25

Specifications of positive displacement motors (Moineau type) …………………………………………... E26-E29

F hoisting and derrick floor equipment

Hoisting mechanics. Reeving function………..…………... F1

Hoisting mechanics. Power…………………………..…….. F2

API wire rope. Factor of safety (RP 9B, May 30, 1986).. F3-F4

API wire rope………………………………………………..... F5

Typical sizes and constructions of wire rope………..…….. F6-F7

API classification of bright (uncoated) or drawn galvanized wire rope. Class 6 x 7. Fiber Core (FC) (API Spec 9A, 24th edition, June 1, 1995).……………..…. F8

API classification of bright (uncoated) or drawn galvanized wire rope. Classes 6 x 19 and 6 x 37. Fiber Core (FC) (API Spec 9A, 24th edition, June 1, 1995)………………………………………………………..… F9

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Class 6 x 19. Independent Wire Rope Core (IWRC) (API Spec 9A, 24th edition, June 1, 1995)………………………….………. F10

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Class 6 x 37. Independent Wire Rope Core (IWRC) (API Spec 9A, 24th edition, June 1, 1995)………………………….………. F11

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Configurations (API Spec 9A, 24th edition, June 1, 1995)…………….….. F12-F13

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Class 6 x 61. Independent Wire Rope Core (IWRC) (API Spec 9A, 24th edition, June 1, 1995)……………………………..……. F14

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Class 6 x 91. Independent Wire Rope Core (IWRC) (API Spec 9A, 24th edition, June 1, 1995)………………………..…………. F15

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Class 8 x 19. Independent Wire Rope Core (IWRC) (API Spec 9A, 24th edition, June 1, 1995)……………………………..……. F16

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Class 18 x 7. Fiber Core (FC). (API Spec 9A, 24th edition, June 1, 1995)………………………………………..………………… F17

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Class 19 x 7. Metal Core. (API Spec 9A, 24th edition, June 1, 1995).…. F18

API classification of bright (uncoated) or drawn galvanized wire rope (continued). Classes 6 x 25 “B”, 6 x 27 “H”, 6 x 30 “G” and 6 x 31 “V” (API Spec 9A, 24th edition, June 1, 1995)……………….……………….…. F19

API wire rope. Sheave sizes (API RP 9B, May 30, 1986)……………………………………….……………….…. F20

Sheave grooves. (API Spec 8A, 12th edition, June 1, 1992)……………………………………..……………………. F21

Work done by a drilling line………………………………..... F22

Cutoff practice for drilling lines. Cutoff length as a function of derrick or mast height and drum diameter (API RP 9B, 9th edition, may 30, 1986)…………………….. F23

Cutoff practice for drilling lines (continued). Cumulative work before first cut-off (API RP 9B, 9th edition, May 30, 1986)………………………………………………… F24

Drum and reel capacity (from IADC Drilling Manual)…….. F25

Elevator link arms. Remaining capacities of work link arms. Dimensions and nominal capacity of link arms (per set)………………………………………………….……. F26

Recommended hoisting tool contact surface radii (API Spec 8A, 12th edition, June 1, 1992)…………….…… F27-F29

Drill pipe elevators bores (API Spec 8A, 12th edition, June 1, 1992)……………………………………………..….. F30

Brake blocks………………………………………………...... F31

Vibrator and drilling hose (API Spec 7K, 2nd edition, February, 1996)……………….. F32-F33

Chains (API Standard 7F, 5th edition, October 1, 1993)…. F34

Chains (continued). Standard chain dimensions (ANSI Standard, B29.1)…………………………………..…………. F35

Chains (continued)………………………………………..…. F36

Rotary table opening and square drive master bushing (API Spec 8C, 2nd edition, June 1, 1992)………………….. F37

Four-pin drive Kelly bushing and master bushing (API Spec 8C, 2nd edition, June 1, 1992)…………….……. F38

Tension in slings. Two-wire slings……………………..….. F39

G pumping and pressure losses

Mud pumps……………..…………………………………….. G1

Pumping power……………..………………………………... G2

Output in liters per stroke double acting duplex pumps based on liner size and piston rod diameter……..……….. G3-G4

Triplex pumps. Maximum pressure based on liner (kPa)…………………………………………………………... G5

Output in liters per stroke of single acting triplex pumps (Volumetric efficiency 100%)………………..…….. G6

Mud cycle time……………………………………………..… G7

Circulation flow rate (l/min) as a function of mud rising velocity opposite drill pipes (Vr in meters per minute) and hole / pipe annulus (Va in liters per meter)……….….. G8-G9

Amount of drilled cuttings in mud………………..…………. G10

Annular mud specific gravity dann…………………….....….. G11

Hydraulics…………………………………………………….. G12

Rheology…………………………………………………....… G13

Critical velocity based on rheological parameters (Practical units)…………………………………………...….. G14

Pressure losses (General)…………………….…………….. G15

Pressure loss equations…………………………………...... G16-G18

Pressure drop in orifices…………………….………….…… G19

Calculation of the bit nozzle velocity……………..……….. G20

Pressure loss calculation………………..…...…….…..….. G21-G22

Table of coefficients B……………………….…..……….... G23-G29

Table of coefficients N1. Calculation of pressure losses in surface equipment………………………..….…… G30

Table of coefficients N2. Calculation of pressure losses in drill pipes………………………………..…….…... G31-G44

Table of coefficients N3. Calculation of pressure losses in drill collars…………………..…………….………. G45-G46

Calculations of pressure drop in nozzles. Combination of three nozzles…………………………………….………… G47-G52

Calculations of pressure drop in nozzles. Combination of two nozzles…………………………………..….………… G53-G55

Table of nozzle areas. Combinations of three nozzles….. G56

Table of nozzle areas. Combinations of two nozzles……. G57

Table of nozzle areas………………………….……………. G58

Table of coefficients N4. Calculations of pressure loss in hole/drill collar annulus…………………………………… G59-G63

Table of coefficients N5. Calculation of pressure loss in hole/pipe annulus……………………….………………… G64-G67

Equivalent lengths for special line connections (in meter)…………………………………………………….. G68

H drilling mud

Relationship between mud weight and pressure head of mud………………….………………….……….. H1

Increase of mud specific gravity with barite (d = 4.2) Weight (in kg) of barite to add to 1 m3 of mud (M)….... H2

Increase of mud specific gravity with calcium carbonate (d = 2.65). Weight (in kg) of calcium carbonate to add to 1 m3 of mud (M)………..………….. H3

Mud specific gravity reduction with water (d = 1) Water volume in liters to add to 1 m3 of mud (M).……. H4

Mud specific gravity reduction with oil (d = 0.85) Oil volume in liters to add to 1 m3 of mud (M)………… H5

Final volume VF (in liters) after adding weighting material of specific gravity da to 1 m3 of mud. Ma weight of weighting material added (kg/m3)…...….. H6

Mud volume (in liters) required to prepare 1 m3 of mud weighted with barite (d = 4.2)…………………….. H7

Ternary diagram for determining solid content of mud (water base muds)………………………………..……… H8

Ternary diagram m for determining solid content of mud (saturated salt water mud)…………………..……. H9

Properties of sodium chloride solutions……………….. H10

Properties of calcium chloride solutions………….……. H11

Properties of potassium chloride solutions………...….. H12

Properties of sodium carbonate (Na2CO3) solutions…. H13

Properties of potassium carbonate (K2CO3) solutions.. H14

Properties of sodium bromide (NaBr) solutions…..….. H15

Effect of temperature on densities of calcium chloride and sodium chloride solutions (Field Data Handbook, Dowel Schlumberger)……………………………………. H16

Grain size classification of solids (1µ = 0.000001 m) H17

Shale shaker screens…………………………….……… H18

Screen standards…………………………….………….. H19

Air/gas flow rate required for drilling. Data for calculating approximate circulation rates required to produce a minimum annular velocity which is equivalent in lifting power to a standard air velocity of 914 m/min (3000 ft/h)…………………………..…….. H20

I cementing

General data units commonly used in cementing…...…. I1

Correlation between sacks and tons of cement……..……. I2

API cement classes and types (API Spec 10, 5th edition, July 1, 1990)……………………………….…... I3

API Specifications for cements (API Spec 10, 5th edition, July 1, 1990)…………………………..…..…….. I4

Preparation of freshwater slurry………………..…………... I5

Cement slurry (freshwater)………………………………..… I6

Preparation of one cubic meter of freshwater cement slurry……………………………………………………..……. I7

Preparation of salt water slurry (Brine 315 g/l, d = 1.20)…………………………..……………………….….. I8

Cement slurry (saturated salt-water), (Brine 315 g/l, d = 1.20)………………………………………………...…….. I9

Preparation of one cubic meter of saturated salt-water slurry………………………………………………..……...….. I10

Preparation of bentonite cements………..………………… I11-I12

Bentonite cement slurry. Class G (per 100 kg of cement)………………………………………………..………. I13

Preparation of one cubic meter of bentonite cement slurry - Class G cement……………………..…………………….... I14

Preparation of weighted cements…………………..………. I15

Cementing additives……………………………..…………... I16-I18

Effects of some additives on cement properties…..……… I19

Slurry displacement………………………………..………… I20-I21

Bottomhole cementing temperature by depth (API RP 10B, 22nd edition, December, 1997)…………….. I22

J directional drilling

Reference coordinates………………………………..…….. J1-J2

Radius of curvature and project in the vertical plane…..… J3

Calculation of characteristic points of the theoretical vertical profile. J hole : D < R…………..………………….. J4-J5

Calculation of characteristic points of the theoretical vertical profile. J hole : D > R……………..……………….. J6-J7

Calculation of characteristic points of the theoretical vertical profile. S hole : R1 + R2 < D…………..……….….. J8-J9

Calculation of characteristic points of the theoretical vertical profile. S hole : R1 + R2 > D……………..…..……. J10-J11

Theoretical vertical profile. Rate of buildup: 0.50 deg/10 m………………………………………….…….. J12

Theoretical vertical profile (continued). Rate of buildup: 1.00 deg/10 m………………………………………………… J13

Theoretical vertical profile (continued). Rate of buildup: 1.50 deg/10 m…………………………….………………….. J14

Theoretical vertical profile (continued). Rate of buildup: 2.00 deg/10 m………………………………………….…….. J15

Theoretical vertical profile (continued). Rate of buildup: 2.50 deg/10 m………………………………….…..………… J16

Ragland diagram…………………………………...………… J17-J18

Control of actual hole shape. Calculation of projections……………………………………………..……… J19

Control of actual hole shape. Different calculation formulas…………………………………………………….…. J20-J21

Course correction………………………….…………….…… J22-J23

Radius of borehole curvature limitation on downhole tools………………………………………………....….……... J24-J25

K kick control fishing

Main symbols used…………..……………………..……….. K1-K2

Preliminary calculations…………..…………..…………….. K3

Driller’s procedures…………………..……………..……….. K4-K5

Calculation after well shut-in……………...…………..…….. K6

Driller’s method on land or on fixed support…...………….. K7

Wait and weight method on land or on fixed support…..… K8

Wait and weight method on floating support (Example without kick assembly)…………………….…….. K9

Control on a floating rig……………………………………... K10

Well strength…………………………………….……..…….. K11-K12

Charts giving coefficient K and gas specific gravity…..…. K13

Example of kick control………………………..……………. K14-K17

Determination of the length of free pipe in a stuck string………………………………………………. K18-K19

Maximum allowable number of turns which can be given to 1000 m of new drill pipe under a given axial tension (Grade E drill pipe)………..………... K20

Maximum allowable number of turns which can be given to 1000 m of new drill pipe under a given axial tension (Grade X95 drill pipe)………………………………...……… K21

Maximum allowable number of turns which can be given to 1000 m of new drill pipe under a given axial tension (Grade G105 drill pipe)……..……… K22

Maximum allowable number of turns which can be given to 1000 m of new drill pipe under a given axial tension (Grade S135 drill pipe)……….…….. K23

Back-off……………………………………………………..… K24

Tool joint matting surface area (API Spec 7, April 1, 1994)………………………………….. K25

L wellheads

API flanges. Working pressure as a function of nominal size (API Spec 6A, 17th edition, February 1 , 1996)……..……………………………………………………. L1

Physical properties of steel for wellheads (PSL 1 to 4) API Spec 6A, 17th edition, February 1, 1996)……..………. L2

Minium vertical full-opening body bores and maximum casing sizes (API Spec 6A, 17th edition, February 1, 1996)……………………………….…………… L3

API type 6B flanges. Working pressure 2000 psi (13.8 Mpa) (API Spec 6A, 17th edition, February 1, 1996) ………………………………………………………..… L4

API type 6B flanges. Working pressure 3000 psi (20.7 MPa) (API Spec 6A, 17th edition, February 1, 1996)………………………………………………..…………. L5

API type 6B flanges. Working pressure 5000 psi (34.5 MPa) (API Spec 6A, 17th edition, February 1, 1996)……………………………………………….………….. L6

API type 6BX flanges. Working pressures: 2000 psi (13.8 MPa), 3000 psi (20.7 MPa), 5000 psi (34.5 MPa) and 10 000 psi (69 MPa) (API Spec 6A, 17th edition, February 1, 1996)………………………..………………….. L7

API type 6BX flanges. Working pressures: 2000 psi (13.8 MPa), 3000 psi (20.7 MPa), 5000 psi (34.5 MPa) and 10 000 psi (69 MPa) (API Spec 6A, 17th edition, February 1, 1996)……………………..……………………... L8

API type 6BX flanges. Working pressure: 15 000 psi (103.5 MPa), (API Spec 6A, 17th edition, February 1, 1996)…………………………………………..………………. L9

API type 6BX flanges. Working pressures: 20 000 psi (138 MPa), (API Spec 6A, 17th edition, February 1, 1996)…………………………………………………………... L10

API Type R ring-joint gaskets. (API Spec 6A, 17th edition, February 1, 1996)…………………………….... L11

API Type RX ring-joint gaskets (API Spec 6A, 17th edition, February 1, 1996)……………………….……... L12

API Type BX ring-joint gaskets. (API Spec 6A, 17th edition, February 1, 1996)…………………...…………. L13

Recommended flange bolt torque…………………….……. L14

API Type 16B integral hub connections (API Spec 6A, 1st edition, November 1, 1986)………………………...……….. L15-L17

Clamp for flanges. Clamp dimensions (Cameron)…...….. L18

CIW clamp for flanges. Make-up torque on bolts of CIW clamps……………………………………………..…. L19

Cameron Ram-Type blow-out preventers Operating data……………………………..………..……….. L20

Hydril Ram-Type blow-out preventers Operating data……………………………………………….. L21-L22

NL Shaffer blow-out preventers. Operating data………… L23

Koomey Ram-Type blow-out preventers. Operating data…………………………………….…………. L24

Cameron ram-type blow-out preventers. Dimensions and weights…………………………………….. L25

Hydril ram-type blow-out preventers. Dimensions and weights………………………….…………. L26

NL Shaffer ram-type blow-out preventers. Dimensions and weights…………………………………….. L27-L29

Koomey ram-type blow-out preventers. Dimensions and weights…………………………………….. L30-L31

Cameron type D annular blow-out preventers . Dimensions and operating data……………..…………..…. L32

Hydril annular blow-out preventers. Dimensions and operating data………………...………….. L33-L34

Hydril annular blow-out preventers. Average closing pressure (psi) required to establish initial seal-off in a surface installation……………………………………… L35-L37

NL Shaffer annular blow-out preventers. Dimensions and operating data. Closing pressure on casing (psi)…... L38

BOP control system. Example of calculations for fluid capacity (IADC Drilling Manual, 11th edition, 1992)………. L39-L41

Schematic symbols for fluid power diagrams (Bases on ANSI Y.32.10) (API Spec 16D, 1st edition, March 1, 1993)……………………………………………….. L42-L46

M geology

Tertiary and quaternary cenozoic eras……..……………… M1

Secondary Mesozoic era.................................................... M2

Primary paleozoic era………………………………...…..…. M3

Table of grain size classes……………………..………..….. M4

Representation of sediments…………………..…………… M5-M6

Exploration symbols in drilling……………………..…..…… M7

Gases present in drilling muds and detected by chromatography………………………………………...……. M8

Physical properties of H2S………………………………..… M9

Pore pressure………………………………………………... M10

Fracturing gradient and leak off test………………………. M11

Abbreviations used in wireline logging – Halliburton……. M12-M13

Abbreviations used in wireline logging – Schlumberger………………………………………………… M14-M15

Abbreviations used in wireline logging - Western Atlas…. M16-M17