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About Varel International .................................................................. 1
Varel Cutter Technology ................................................................ 2-3
Fixed Cutter Bit Nomenclature ......................................................... 4
Fixed Cutter Features .................................................................... 5-7
TOUGH-DRILL Bits Description .................................................... 8-9
Navigator Bits Description ......................................................... 10-11
VB Series Bits Description......................................................... 12-13
Hole Opening Bits Description................................................... 14-15
Specialty Bits .................................................................................. 16
Fixed Cutter Reference Tables Nozzle Series 55 .................................................................. 17 Nozzle Series 65 .................................................................. 17 Make-Up Torque ................................................................... 17 Gage Diameter Tolerances .................................................... 17 Diamond Drill Bit and PDC Bit Connection ............................... 17 Nozzle Total Flow Area .......................................................... 18
API Casing Dimensions and Bit Diameters .................................... 19
Drill Collar Weights ......................................................................... 20
API Conversion Tables ................................................................... 21
Sales Office ......................................................................Back Cover
T a b l e o f C o n T e n T s
V a r e l I n T e r n a T I o n a l
1
a b I T o f a s u C C e s s s T o r y
Performance … reliability … expertise … value … service. These are the cornerstones of Varel International, the world’s largest independent manufacturer of premium drill bits for the global oil and gas industry. Varel offers a comprehensive product line of roller cone and fixed cutter/polycrystalline diamond compact (PDC) drill bits that have evolved and improved through the technological advances and the engineering expertise of its qualified staff.
Founded in 1947, Varel remained a privately held company producing roller cone air bits for the mining industry. In 1978, Varel introduced its first range of sealed bearing products and was merged through two subsequent acquisitions. The change in ownership further advanced and improved the company to the level of success it holds today as a world leader in both the roller cone and fixed cutter drill bit industry.
The first acquisition brought a new management team that helped expand Varel and grow its capabilities and product offerings for both the global oil and gas/mining markets. During this time, Varel enhanced and expanded its engineering and manufacturing capabilities, adding fixed cutter bits and focusing on delivering value to its customers. Additionally, Varel increased its international presence by adding a significant worldwide sales and support team.
The TeChnologICal edgeIn 2005, Varel was acquired by KRG Capital Partners, a private equity firm in Denver, providing the additional capital the company needed to further expand its product offerings, proprietary technology and services worldwide. Since that time, Varel has aligned its engineering and manufacturing capabilities to provide products that consistently deliver reliability and optimum product performance, thereby lowering customers’ per foot drilling costs.
Varel is centrally located with headquarters in Carrollton, Texas, just north of Dallas, where the company manufactures carbide inserts for its tungsten carbide bits and has an impressive roller cone manufacturing facility in Matamoros, Mexico. The company’s state-of-the-art fixed cutter manufacturing facilities are in Houston and Tarbes, France.
Varel proudly serves as a major drill bit supplier to many majors, large independents and national oil companies operating in the international and domestic oil and gas drilling fronts. Innovative, yet cost-effective drilling solutions for vertical and directional wells for land and offshore projects is what customers have come to expect from Varel.
2
V a r e l f I x e d C u T T e r d r I l l b I T T e C h n o l o g y
VALUE THROUGH TECHNOLOGY
Value Through Technology The drilling industry continues to see improvements in fixed cutter bit development. These gains, are having positive effects on drilling performance and are also reducing operational costs.
There is still the need to improve rate of penetration (ROP), durability, and bit stabilization, especially in harsh drilling environments. In addition, performance efficiency in directional drilling programs also needs improvement. These challenges, if left unattended, will drive up drilling costs. As our valued customer, you have clearly stated what you want — PERFORMANCE.
At Varel, we are fully committed to bringing you VALUE through TECHNOLOGY. Our product development processes have been adapted to ensure technological innovations in the following disciplines — bit design concepts, PDC cutter development and hydraulic performance optimization — as they relate to specific applications and/or drilling challenges.
Our elaborate R&D efforts have resulted in the development of the following product design tools — GeoScienceTM (formation drillability analysis), SPOTTM (bit behavior analysis and performance prediction), and CFD (hydraulic design optimization). In addition, we continue to develop unique PDC cutters for specific applications.
VarelstandsforPERFORMANCE. Andwearecommittedtobringingyou VALUEthroughTECHNOLOGY.
3
V a r e l C u T T e r T e C h n o l o g y
Wear Flat Comparison The picture shows wear flat comparisons between standard premium cutters and specialized Varel high abrasion resistance cutters under identical conditions.
High Performance PDC Cutter Application-specific PDC cutters, which incorporate advanced carbide interface geometries (CIG™) and materials science technologies, are used in Varel bits. The carbide interface geometries are modeled using finite element analysis (FEA) to minimize damaging residual stresses (axial, hoop and radial). This process drastically improves the impact resistance of the PDC cutters.
Diamond grades are then selected, analyzed and prepared to maximize abrasion resistance (see chart below).
Wear Flat Comparison
Standard Premium Cutter
Varel High Abrasion Resistance Cutter
Carbide InterfaceGeometries (CIG)
Finite Element Analysis (FEA)
Comparision of Abrasion Resistance
Normalized Diamond Volume Removed(due to cutter wear)
VarelHigh Abrasion
Cutters
StandardPremiumCutters
Abrasion resistance comparison, at identical test conditions, between standard premium cutters and specialized Varel high abrasion resistance cutters.
(hig
her
is b
etter)
Norm
aliz
ed R
ock
Volu
me R
em
ove
d
Carbide InterfaceGeometries (CIG)
Finite Element Analysis (FEA)
f I x e d C u T T e r b I T n o m e n C l a T u r e
4
V TD 6 16 NX
Indicates that it is a VAREL product
Product Line Type
Blade CountFirst Digit
Standard PDC Bit
RT - Navigator Point the bit
RP - Navigator Push the bit
M - Navigator Steerable Motor
H - Hole Opening Bicenter
B - Lateral Jets and Oval Cutters
CB - Core Bit
TD - Tough Drill
N - Natural Diamond
P - TSP
3
4
5
6
7
8
9
10
11
12
091
13
16
19
13O2
16O
19O
23O
* 100
** 300
*** 500
S - Steel Body
B - Box connection
T - Turbine Sleeve
P - Power cutters (DR no longer exist)
G - Premium Gage
L - Lateral Jets
N - Nozzle Pattern less than One Nozzle per Blade
H - Nozzle Pattern in Excess of One Nozzle per Blade
W - Crown TSP
U - Up Drill / Back Ream
X - Shock Studs
First Digit BladeCount
Second DigitCutter Size
& ShapeSuffix FeaturesProduct Line Type
Designates Round Cutters
* Soft formation design (N and P product line)
** Medium formation design (N and P product line)
*** Hard formation design (N and P product line)
Designates Oval Cutters
Vb616 PDC bit with oval cutters, lateral jets, 6 blades, 6 nozzles and 16mm cutters
Vn300 Natural diamond bit for medium hard formation Vh813 Bi-center PDC with 8 blades and 13mm cutters VrT813o Navigator point-the-bit with 8 blades and 13mm oval cutters VTd616gnxTOUGH-DRILL Bit with 6 blades, less than 6 nozzles, premium gage, and shock studs
Cutter Size & ShapeSecond Digit
Bit Suffix Feature
5
f I x e d C u T T e r f e a T u r e s
C u T T I n g s T r u C T u r e f e a T u r e s
“u” up drIll / baCk ream When directional drilling hole wall sloughing, keyseating, or
severe dog legs can occur requiring action. The updrill feature allows hole wall cleaning as you ream the well bore eliminating
problems.
“x” shoCk sTuds
Shock Studs limit drill bit vibration and increase stability. When drilling conditions cause a vibration, Shock Studs make contact
with the formation to help restore the bit’s normal smooth cutting action. Smooth cutting action increases cutter life and
overall bit performance.
“p” powerCuTTers
Varel’s high-density “Powercutter” arrangement gives enhanced bit life through a variety of rock types without sacrificing ROP. The new Powercutter cutting structure provides extra exposure and cutter density on the critical shoulder area of the bit. Bits can now achieve maximum rates of penetration through one rock formation and then continue to penetrate harder sand or limestone beds without excessive wear or damage e.g. interbedded formations.
“w” Crown TspThermally Stable Polycrystalline diamond material is
beneficially placed behind PDC cutters to improve bit stability with a grooving effect. A unique wear pattern is created
increasing PDC cutter indentation as the cutter wears down.
g a g e f e a T u r e s
f I x e d C u T T e r f e a T u r e s
6
h y d r a u l I C s o p T I o n s
“g” premIum gage Premium gage protection is designed to insure
that correct hole diameter is maintained. A variety of gage configurations exists. The premium gage
consists of Thermally Stable Polycrystalline diamond rounds, Tungsten Carbide bricks and
PDC (Polycrystalline Diamond Compact) cutters. The number of pre-flat PDC cutters in the gage is
the only option with this feature.
“T” TurbIne sleeVe Turbine sleeves can be customized to specific lengths and diameters to match each individual requirement. Sleeves are designed so the junk slots match the bit junk slots eliminating intersections, making the design hydraulically efficient. Gage protection on the sleeve can also be matched to the customer’s need.
“l” laTeral JeT nozzles Varel bits can use highly angled lateral nozzles located near the center of the bit in combination with traditional nozzles to create cross flow hydraulics. This cross flow optimizes hydraulic energy, cooling and cleaning of the cutters, enhanced chip removal, efficiently sweeping cuttings away from the bit face into the annulus. This hydraulic configuration promotes faster ROP and reduces cutter wear for longer bit life.
7
f I x e d C u T T e r f e a T u r e s
“b” box ConneCTIon Box connections are most commonly used in conjunction with a turbine sleeve so that crossover subs are not required when connecting to turbines, RSS and other downhole tools.
o T h e r f e a T u r e s
“h” nozzle paTTern With the “H” feature, a bit will have more than one nozzle per blade. The number of nozzles will be determined by the application or bit design. Typical nozzle pattern is one nozzle per blade.
h y d r a u l I C s o p T I o n s
“n” nozzle paTTern With the “N” feature, a bit will have less than one nozzle per blade. The number
of nozzles will be determined by the application or bit design. Typical nozzle
pattern is one nozzle per blade.
“s” sTeel body
Steel body drill bit designs are typically used in applications where open-faced hydraulics and aggressive cutting structures are required. They can provide for faster penetrating bits than
conventional matrix designs.
Varel’s TOUGH-DRILL™ PDC bits are designed for hard rock applications. Due to their improved stabilization characteristics, these bits address the ROP and durability challenges experienced when drilling hard and/or abrasive formations. TOUGH-DRILL bits combine advanced cutting structure layouts, high performance PDC cutters and superior hydraulic configurations to ensure ROP and durability improvements.
Through their comprehensive engineering and development process, TOUGH-DRILL bits reduce impact damage, improve cleaning and cutter cooling efficiencies. The high abrasion resistant cutters used in TOUGH-DRILL bits drastically minimize cutter wear. Our performance continues to validate our claims.
hydraulICs
As part of the product development process, TOUGH-DRILL bits go through elaborate computational fluid dynamics (CFD) evaluations. CFD eliminates re-grinding and re-circulation of drilled cuttings, a common occurrence when drilling hard and abrasive applications. In addition, possible stagnation zones are identified and eliminated. This sophisticated process improves cleaning efficiency, cutter cooling and ROP.
8
T O U G H - D R I L L B I T s
Shown: 8 3/4” VTD616PG
9
TOUGH-DRILL AvAILABIL I Ty:3 ¼” To 18 ½” (88.9 mm To 469.9 mm) – In maTr Ix
8 ½” To 26” (215.9 mm To 660.4 mm) – In sTee l
adVanCed CuTTIng sTruCTure
TOUGH-DRILL bits are developed using Varel’s proprietary design software called SPOT™. Using extensive single cutter tests and full scale bit tests in laboratory and field conditions,
SPOT ensures cutting structure optimization for specific applications. SPOT models complete bit behavior in different rock types during a simulated drilling process. This tool also
evaluates cutter wear as a result of friction and heat transfer. Using appropriate rock geology and mechanical properties, SPOT also performs sensitivity analysis for various drilling
parameters (WOB and RPM) to evaluate their effects on ROP, cutter wear, bit vibrations and footage drilled. Using SPOT
improves the ROP and increases the footage drilled of each TOUGH-DRILL bit.
hIgh performanCe CuTTers
Application-specific PDC cutters incorporating advanced carbide interface geometries (CIG) and materials
technologies are used in TOUGH-DRILL bits. The carbide interface geometries are modeled using finite element
analysis (FEA) to minimize damaging residual stresses (axial, hoop and radial) improving impact resistance and extending cutter life, resulting in improved bit life. Diamond grades are then selected, analyzed and prepared to maximize abrasion
resistance (see chart on page 3).
powerCuTTer™ CuTTIng sTruCTure
Varel’s high-density “Powercutter” arrangement gives enhanced bit life when drilling a variety of rock types without
sacrificing ROP. The new Powercutter cutting structure provides extra exposure and cutter density on the critical
shoulder area of the bit. Bits can now achieve maximum rates of penetration through one rock formation and then continue
to penetrate harder sand or limestone beds without excessive wear or damage e.g. interbedded formations.
Varel’s Navigator bits are engineered specifically for directional wells. Each bit is custom designed to a specific directional profile for a given application. Varel believes that the bit is the most important factor affecting directional drilling success. Therefore, a bit’s ability to achieve a given well bore objective relies upon two key design factors: steerability and directional behavior. Varel’s Navigator bits possess the key design elements affecting bit steerability and directional behavior helping you achieve your drilling objectives.
The bit design process for Navigator bits utilizes GeoScience™, SPOT™ and Computational Fluid Dynamics (CFD). GeoScience is Varel’s proprietary mechanical rock properties model that utilizes well logs. Output information from GeoScience is fed into the design process through SPOT, Varel’s proprietary design software, allowing bit designers to accurately model bit dynamics. The CFD program examines the nozzle orientation for optimum bit and hole bottom cleaning. By taking all these parameters into account we fine tune the bit design for the application, making it the most effective solution for your directional application.
o-rIng sTuds
Additional matrix material in the shape of an o-ring is placed directly behind specific cutters. This additional material helps manage the torque generated by modern steerable systems while maintaining orientation for increased ROP and reduced sliding time.
updrIll feaTure When drilling a directional well, such negative outcomes like hole wall sloughing, keyseating, or severe dog legs can occur. Varel’s updrill feature allows hole wall cleaning as you ream the well bore helping eliminate such problems.
N A v I G A T O R B I T s
10
aCTIVe gage CuTTers
Push-the-bit systems require active gage designs. Navigator bits are designed to shear the formation laterally when high side forces are applied by this system.
Shown: 6 1/8” MNS65
11
NAvIGATOR AvAILABIL I Ty:6” To 17 ½” (152.4 mm To 444.5 mm) – In maTr Ix
hydraulICs
Navigator bits go through elaborate computational fluid dynamics (CFD) evaluations to identify and eliminate possible
stagnation zones. During this process, bit and bottom hole cleaning are optimized to enhance bit performance. Nozzle
orientation is also examined to insure borehole quality for steerability purposes. This sophisticated process improves
cleaning efficiency, cutter cooling and ROP.
adVanCed CuTTIng sTruCTure
Navigator bits use Varel’s proprietary software called SPOT. Using extensive single cutter tests and full scale bit tests in
laboratory and field conditions, SPOT ensures cutting structure optimization for specific applications. SPOT models complete bit behavior in different rock types during a simulated drilling
process. Additionally, this tool evaluates cutter wear as a result of friction and heat transfer. Using appropriate rock geology and mechanical properties, SPOT also performs sensitivity analysis
for various drilling parameters (WOB and RPM) to evaluate their effects on ROP, cutter wear, bit vibrations and footage
drilled. Using SPOT improves the ROP and increases the footage drilled of each Navigator bit.
hIgh performanCe CuTTers Application-specific PDC cutters incorporating advanced
carbide interface geometries (CIG) and materials technologies are used in TOUGH-DRILL bits. The carbide interface
geometries are modeled using finite element analysis (FEA) to minimize damaging residual stresses (axial, hoop and
radial) improving impact resistance and extending cutter life, resulting in improved bit life. Diamond grades are then selected,
analyzed and prepared to maximize abrasion resistance (see chart on page 3).
v B s e R I e s B I T s
12
Shown: 8 1/2” VB616laTeral JeT nozzles
VB bits use lateral jet nozzles located near the center of the bit. These nozzles are oriented in such a way that, when combined with traditional nozzles, create cross flow hydraulics. This cross
flow optimizes hydraulic energy, cooling and cleaning of the cutters, enhanced chip removal and efficiently sweeps cuttings away from the bit face into the annulus. This hydraulic configuration promotes faster
ROP and reduces cutter wear for longer bit life.
As part of the product development process,
all Varel bits utilize Computational Fluid
Dynamics evaluations.
Varel’s VB product line is a premium line of matrix bits featuring two very unique features–oval cutters and lateral hydraulic jet nozzles. The VB series is designed to provide better ROP and longer life than bits designed only with conventional round cutters and hydraulic package.
The oval cutter provides more diamond exposure than a round cutter sharing the same diamond width. The sharper tip profile of the oval cutter produces higher point loading, converting applied weight more efficiently than a round cutter, thereby increasing ROP.
The lateral jet nozzles, located near the center of the bit, provide greater efficiencies directing flow across the face of the bit for optimal cleaning and cooling of cutters. Lateral nozzles, in combination with conventional nozzles, produce higher ROP and increased bit life.
13
vB seRIes AvAILABIL I Ty:6” To 17 ½” (152.4 mm To 444.5 mm) – In maTr Ix
oVal CuTTer
The unique oval cutter design delivers 42% more diamond exposure than a round cutter of the same width. Because
of its unique shape, the increased exposure provides more footage drilled and improved bit life helping lower your cost per
foot. Additionally, the oval cutter design produces higher point loading converting applied weight on bit more efficiently and
dulling with a smaller wear flat than a round cutter of the same width.
powerCuTTer™ CuTTIng sTruCTure Varel’s high-density “Powercutter” arrangement gives
enhanced bit life when drilling a variety of rock types without sacrificing ROP. The new Powercutter cutting structure
provides extra exposure and cutter density on the critical shoulder area of the bit. Bits can now achieve maximum rates
of penetration through one rock formation and then continue to penetrate harder sand or limestone beds without excessive
wear or damage e.g. interbedded formations.
adVanCed CuTTIng sTruCTure VB bits are developed using Varel’s proprietary design
software called SPOT™. Using extensive single cutter tests and full scale bit tests in laboratory and field conditions, SPOT ensures cutting structure optimization for specific
applications. SPOT models complete bit behavior in different rock types during a simulated drilling process. In addition, it
evaluates cutter wear as a result of friction and heat transfer. Using appropriate rock geology and mechanical properties, SPOT also performs sensitivity analysis for various drilling parameters (i.e., weight on bit, WOB, and revolutions per
minute, RPM) to evaluate their effects on ROP, cutter wear, bit vibrations and footage drilled. Using SPOT improves the
ROP and increases the footage drilled of each VB bit.
Oval cutterExposure
A BRound cutterExposureCenter line
Additional drilling capacity = 42%
oVal CuTTer adVanTage
Varel’s bi-center bits are designed to enlarge the well bore, drilling 15 to 25% larger than the pass through well bore in all types of PDC drillable formations. The bi-center bits are used to increase lateral diameter, to replace under reaming, to help control trouble zones, and for expandable tubulars. The matrix material construction resists erosion and abrasion found when drilling oilfield applications. The one-piece design shortens the overall bit length for better directional control. Varel bi-center bits also have an innovative force balanced cutting structure which minimizes cutter and casing damage when drilling out. Additionally, Varel’s unique design minimizes bit vibrations often experienced with conventional hole opening tools thereby resulting in longer downhole tool life and reduced drilling costs.
one-pIeCe ConsTruCTIon Varel’s unique design, shortens the overall bit length for better directional control and eliminates the need to have a connection and weld between the pilot bit and the reamer section of the bi-center. The one piece construction also allows for optimal hydraulic configuration with pilot and reamer blade alignment, optimizing cuttings removal and improving ROP.
hydraulIC desIgn Nozzle placement, pilot bit and reamer blade alignment provide a direct flow path to the annulus. The junk slot area is maintained or increased, resulting in no decrease in fluid velocity and improved cuttings removal between the pilot and reamer.
spIraled blades Varel’s bi-center bits are designed with spiral blades to provide better contact with the casing during drill out. Spiral blades stabilize the bit ensuring less damage to the casing and resulting in better well bore quality.
The drill-out feature, designed for Varel’s bi-center bit, was recently awarded a Woelfel Best Mechanical Engineering Achievement Merit Award. The annual award, sponsored by American Society of Mechanical Engineers - International Petroleum Institute Petroleum Division (ASME-IPTI), recognizes a product or system that demonstrates a practical solution to an engineering challenge in offshore technology.
H O L e O p e N I N G B I T s
14
Shown: 7 1/2” x 8 1/2” VH813
15
HOLe OpeNeRs AvAILABILITy:3 ¾” x 4 1/8” To 14 ¾” x 17 ½” (95.25 mm x 104.8 mm To 14.34 mm x 444.5 mm) – In maTrIx
CuTTIng sTruCTure drIll ouT feaTure Varel’s Casing Saver Design cutting structure feature provides a
reliable drill out mode while protecting the cutting structure inside the casing. Because of the bi-center bits unique application, the
bit design is not symmetrical. When drilling out from casing, the bit rotates on the casing centerline and not the bit centerline. This off
center rotation of conventional bits can cause damage to cutters located near the center of the pilot bit. This cutter damage is due to backward rotation of cutters located between the bit centerline
and the casing centerline in the pilot bit. However, Varel has repositioned cutters between the two centerlines in the nose of
the pilot bit. Our design minimizes the possibility of cutter damage while inside the casing in drill out mode. As the bit transitions to formation drilling the cutters begin to rotate normally about the
bit centerline and cut the formation. This small but unique design philosophy prevents cutter damage when drilling out allowing
efficient rock–cutter interaction during formation drilling.
forCe balanCIng During the design process, the pilot and reamer cutting structure
are force balanced as a single unit. This provides increased drilling efficiencies in both vertical and deviated wells. Improved ROP,
increased durability and better directional control are all benefits of Varel’s force balancing.
CasIng saVer desIgn Pilot bit design, spiral blades, non contact gage cutters and casing
saver technology all result in minimal casing damage during drill out.
Bicenter Drillling Cement Inside the Casing Bicenter in Formation
speCIalTy bITs
Varel offers a variety of bits and core bits manufactured with natural diamond, Thermally Stable Polycrystalline (TSP) and Polycrystalline Diamond Compact (PDC) materials, available for specific drilling applications. All designs are available in matrix with size availability ranging from 4” to 17 ½” (101.6 mm to 444.5 mm). For additional details, please contact your Varel representative.
s p e c I A L T y B I T s : N A T U R A L D I A m O N D , T s p A N D c O R e B I T s
16
Shown: 6” VN300
Shown: 6” x 2 5/8” C320
Shown: 6” x 2 5/8” CK571
Shown: 6” x 2 5/8” C400
Shown: 8 1/2” VP500
Shown: 8 3/8” VN300
Shown: 8 1/2” VN300 Shown: 8 3/8” VP300
Shown: 5 1/2” x 6” VHP300
Shown: 12 1/4” x 5 1/4” CK58
r e f e r e n C e
17
nozzle ser I es 55 & 65, makeup Torque
gage dIameTer ToleranCes dIamond dr I l l b I T & pdC bIT ConneCT Ion
Diameterin.
9/32
10/32
11/32
12/32
13/32
14/32
15/32
16/32
17/32
18/32
mm
7.14
7.94
8.73
9.53
10.32
11.11
11.91
12.70
13.49
14.29
Diameterin.
9/32
10/32
11/32
12/32
13/32
14/32
15/32
16/32
17/32
18/32
19/32
20/32
21/32
22/32
mm
7.14
7.94
8.73
9.53
10.32
11.11
11.91
12.70
13.49
14.29
15.08
15.88
16.67
17.46
Diameterin.
3-3/4 to 4-1/2"
4-5/8 to 4-7/8"
5 to 7-1/4"
7-1/2 to 9-1/4"
9-7/8 to 14-1/2"
14-3/4 to 18-1/2"
API Connection in.
2-3/8" REG
2-7/8" REG
3-1/2" REG
4-1/2" REG
6-5/8" REG
7-5/8" REG
Recommended Torque ft./lbs.
3000 - 3500
6000 - 7000
7000 - 9000
12000 - 16000
28000 - 32000
34000 - 40000
Bit Size, ODin.
6 3/4 and smaller
6 25/32 to 9 inclusive
9 1/32 to 13 3/4 inclusive
13 25/32 to 17 1/2 inclusive
17 17/32 and larger
Diamond Drilling, Diamond Core, and PDC Bit Tolerances
OD Tolerances in.
+ 0 - 0.015
+ 0 - 0.020
+ 0 - 0.030
+ 0 - 0.045
+ 0 - 0.063
mm
+ 0 - 0.38
+ 0 - 0.51
+ 0 - 0.76
+ 0 - 1.14
+ 0 - 1.60
Size of Bitin.
1.75 to 2.24 inclusive
2.25 to 3.49 inclusive
3.50 to 4.5 inclusive
4 17/32 to 5 inclusive
5 1/32 to 7 3/8 inclusive
7 13/32 to 9 3/8 inclusive
9 13/32 to 14 1/2 inclusive
14 9/16 to 18 1/2 inclusive
18 9/16 and larger
Size & Style of Rotary Pin Connection
1 reg^b
1 1/2 reg^c
2 3/8 reg
2 7/8 reg
3 1/2 reg
4 1/2 reg
6 5/8 reg
6 5/8 reg or 7 5/8 reg
7 5/8 reg or 8 5/8 reg
Bit Sub Bevel Dia.^a inches +/- 1/64
1.500
1.932
3.047
3 39/64
4 7/64
5 21/64
7 23/64
7 23/64 or 8 15/32
8 15/32 or 9 35/64
millimeters +/- 0.40
38.10
49.07
77.39
91.68
104.38
135.33
186.93
186.93 or 215.11
215.11 or 242.49
Bit Bevel Dia. ^a inches +/- 1/64
1.532
1.964
3.078
3 41/64
4 9/64
5 23/64
7 25/64
7 25/64 or 8 1/2
8 1/2 or 9 37/64
millimeters +/- 0.40
38.91
49.89
78.18
93.66
105.17
136.13
187.72
187.72 or 215.90
218.90 or 243.28
r e f e r e n C e n o z z l e T o T a l f l o w a r e a
18
Nozzle Flow Area (square inches)
Nozzle Size
7/32
8/32
9/32
10/32
11/32
12/32
13/32
14/32
15/32
16/32
18/32
20/32
22/32
24/32
26/32
28/32
1
Nozzle
0.0375
0.0490
0.0621
0.0766
0.0928
0.1104
0.1296
0.1503
0.1725
0.1963
0.2485
0.3067
0.3712
0.4417
0.5184
0.6013
2
Nozzles
0.0751
0.0981
0.1242
0.1533
0.1856
0.2208
0.2592
0.3006
0.3451
0.3926
0.4970
0.6135
0.7424
0.8835
1.0369
1.2026
3
Nozzles
0.1127
0.1472
0.1863
0.2300
0.2784
0.3313
0.3888
0.4509
0.5177
0.5890
0.7455
0.9203
1.1136
1.3253
1.5554
1.8039
4
Nozzles
0.1503
0.1963
0.2485
0.3067
0.3712
0.4417
0.5184
0.6013
0.6902
0.7853
0.9940
1.2271
1.4848
1.7671
2.0739
2.4052
5
Nozzles
0.1879
0.2454
0.3106
0.3834
0.4640
0.5522
0.6481
0.7516
0.8628
0.9817
1.2425
1.5339
1.8561
2.2089
2.5924
3.0065
6
Nozzles
0.2254
0.2945
0.3727
0.4601
0.5568
0.6626
0.7777
0.9019
1.0354
1.1780
1.4910
1.8407
2.2273
2.6507
3.1109
3.6079
7
Nozzles
0.2630
0.3436
0.4348
0.5368
0.6496
0.7731
0.9073
1.0523
1.2080
1.3744
1.7395
2.1475
2.5985
3.0925
3.6293
4.2092
8
Nozzles
0.3006
0.3926
0.4970
0.6135
0.7424
0.8835
1.0369
1.2026
1.3805
1.5707
1.9880
2.4543
2.9697
3.5342
4.1478
4.8105
9
Nozzles
0.3382
0.4417
0.5591
0.6902
0.8352
0.9940
1.1665
1.3529
1.5531
1.7671
2.2365
2.7611
3.3410
3.9760
4.6663
5.4118
10
Nozzles
0.3758
0.4908
0.6212
0.7669
0.9280
1.1044
1.2962
1.5032
1.7257
1.9634
2.4850
3.0679
3.7122
4.4178
5.1848
6.0131
19
r e f e r e n C e
20
d r I l l C o l l a r w e I g h T s
1 1/4 26 770 30 900 35 1040 40 1200 45 1360 51 1530 57 1710 63 1900 70 2090 77 2300 84 2510 91 2740 99 3000 107 3200 115 3450 124 3710 133 3980 142 4250 151 4540
2
33 980 38 1130 43 1300 49 1470 55 1650 61 1830 68 2030 74 2230 82 2450 89 2670 97 2900 105 3140 113 3380 122 3650 130 3910 140 4190 149 4470 159 4540 169 5620
2 1/4
35 1060 41 1220 46 1390 52 1570 59 1760 65 1960 72 2160 79 2370 87 2600 94 2830 102 3070 110 330 119 3570 128 3840 137 4110 147 4400 156 4690 166 4990 177 5300 187 5620
2 1/2
33 980 38 1140 44 1310 50 1490 56 1680 62 1870 69 2080 76 2290 84 2510 92 2740 100 2980 108 3220 116 3490 125 3760 134 4030 144 4310 154 4610 164 4910 174 5820 185 5530 195 5860 207 6200 218 6540
2 3/4
47 1400 53 1580 59 1780 66 1980 73 2200 81 2420 88 2650 96 2890 104 3130 113 3400 122 3660 131 3940 141 4220 150 4510 160 4810 171 5120 181 5440 192 5770 204 6100 215 6450 227 6800 239 7160 251 7530
2 7/8
58 1730 65 1930 72 2150 79 2370 87 2600 95 2840 103 3080 112 3350 121 3610 130 3890 139 4170 143 4460 159 4760 169 5070 180 5390 191 5720 202 6060 213 6400 225 6750 237 7120 250 7490 262 7860 275 8250
3
56 1680 63 1880 70 2100 77 2320 85 2550 93 2790 101 3030 110 3300 119 3560 128 3840 137 4180 147 4410 157 4710 168 5020 178 5340 187 5670 200 6000 212 6350 223 6700 236 7060 248 7430 261 7810 273 8200
3 1/4
59 1770 66 1990 74 2210 81 2440 89 2680 97 2920 106 3190 115 3450 124 3730 134 4010 143 4300 153 4600 164 4910 174 5230 185 5560 197 5900 208 6240 220 6590 232 6960 244 7330 257 770 270 8090
3 1/2
70 2080 78 2330 86 2570 94 2800 102 3070 111 3340 120 3610 130 3900 140 4190 150 4490 160 4800 171 5120 181 5440 193 5780 204 6180 216 6480 228 6840 240 7210 253 7590 266 7980
3 3/4
65 1960 73 2200 81 2440 89 2680 98 2940 107 3210 116 3480 126 3770 135 4060 145 4360 156 4670 166 4990 177 5310 188 5650 200 6000 212 6350 224 6710 236 7080 249 7460 268 7850
4
77 2300 85 2540 94 2800 103 3070 112 3350 121 3630 131 3920 141 4220 151 4530 162 4850 173 5180 184 5510 195 5860 207 6210 219 6580 232 6950 244 7330 257 7710
Pounds-Per-Foot (Bold) Pounds-Per-30 Foot Collar Weights per foot rounded off to nearest pound. Weights per 30 foot collar rounded off to nearest 10 pounds
3 3/44
4 1/44 1/24 3/4
55 1/45 1/25 3/4
66 1/46 1/26 3/4
77 1/47 1/27 3/4
88 1/48 1/28 3/4
99 1/49 1/29 3/410
10 1/410 1/210 3/4
1111 1/4
1 1/2 28 830 32 960 37 1100 42 1260 47 1420 52 1570 59 1770 65 1950 72 2150 78 2330 86 2570 93 2790 101 3020 109 3260 117 3500 126 3770 134 4030 144 4310
21
r e f e r e n C e
equaTIons used In hydraulIC CalCulaTIons:
1. Annular Velocity
2. Surface Equipment Pressure Losses
3. Drill Stem Bore Pressure Losses
4. Jet Nozzle Pressure Losses
5. Annular Pressure Losses
6. Jet Velocity
7. Jet Impact Force
8. Hydraulic Horsepower
nomenClaTure:
Q = Circulation Rate (gpm)Dh = Diameter of Hole (in)Dp = Diameter of Pipe O.D. (in)V = Annular Velocity (ft/min)r = Mud Weight (lb/gal)C = Friction FactorP = Pressure (psi)L = Length (ft)Ah = Area of Nozzle (in2) ∆P = Pressure Drop (psi)Vh = Jet Velocity (ft/sec)If = Jet Impact Force (lbf)HHp = Hydraulic Horsepower (hp)d = Inside Diameter (in)
Type Equipment C1 1.02 0.363 0.224 0.15
FROM
BarrelsCubic CentimetersCubic CentimetersCubic CentimetersCubic CentimetersCubic CentimetersCubic FeetCubic FeetCubic FeetCubic FeetCubic FeetCubic InchesCubic InchesCubic InchesCubic InchesCubic InchesCubic MetersCubic MetersCubic MetersGallonsGallonsGallonsGallonsGallonsGallons
PoundsTons (metric)Tons (metric)
TO
VOLUMEGallonsCubic FeetCubic InchesCubic MetersGallonsLitersCubic CentimetersCubic InchesCubic MetersGallonsLitersCubic CentimetersCubic FeetCubic MetersGallonsLitersCubic CentimetersCubic FeetGallonsBarrelsCubic CentimetersCubic FeetCubic InchesCubic MetersLiters
MASSTons (metric)PoundsKilograms
MULTIPLY BY
423.531 x 10-5
0.0610210-6
2.642 x 10-4
0.0012831717280.028327.4828.3216.395.787 x 10-4
1.639 x 10-5
4.329 x 10-3
0.01639106
35.31264. 20.023837850.13372313.785 x 10-5
3.785
4.536 x 10-4
22041000
a p I C o n V e r s I o n T a b l e s
MKTG 12A600-09-2006
www.vare l i n t l . com
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