DRT Motor Manual 6-16-10

7/29/2019 DRT Motor Manual 6-16-10

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Volume 1

6 3/4 7/

7/8

M/L3.5

Stage

7 3/4 (8) 7/8 M/L

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73/4

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63/47/8M

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63/47/8M/L5.0Stage

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7 3/4

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63/47/8M/L5.0Stage

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4.0Stage

7 3/4 (8) 7/8 M/L

MotorManual

Oice: 405-604-2969 Toll Free: 877-350-4497

9630 Pole Road, Oklahoma City, OK 73160

www.drillrighttechnology.com


2/55

To Our Customers,

Drill Right Tools has selected the very best bear-ing assemblies and power sections in order to supply

our customers with perormance they expect and the

reliability they deserve. Our motors are given thorough

inspections to ensure every component can endure the

rugged downhole conditions while still meeting de-

mands or maximum perormance. Drill Right Tools has a

rst-class acility built around maximizing eciency and

quality control. Our goal is to help our customers achieve

accurate and ecient results without costly downtime

or ailures. Drill Right Tools provides our customers with

a select range o tool sizes to help with directional and

horizontal applications. We're pleased that you have se-

lected Drill Right Tools to help achieve maximum resultsin your application.

Sincerely,


3/55

Motor Components

Power Section

Adjustable Housing

0 to 3 or 4 Degrees

Articulated

Driveshat

Sealed Bearing

Assembly

rotor

stator

stabilizer


4/55

Motor Components

Power SectionThe drive is Moineau pump operated in reverse. Drilling uid pumped

through the assembly causes a rotor to turn and apply rotary motion and

torque to the drill bit, through the articulated driveshat and the output shat

in the sealed bearing assembly.

The power section consists o a helical shaped rotor running inside

the stator (an elastomer liner bonded to a steel tube). The stator elastomer

liner opening is dissimilar in shape to the rotor. The pitch length o the sta-

tor cavity is longer than the pitch length o the rotor. The dissimilarity in the

shapes o the rotor and stator produces wedge shaped cavities that are sealed

along their edges. The pressure that is produced as drilling uid is pumped

through the power section causes the rotor to turn and the cavities to move

orward in the direction o uid ow.

The multi-lobe conguration, employed in Drill Right Tools low

speed, high torque motors, uses a rotor with a multiple-lobed cross section

that also orms a helix. The elastomer liner in the stator has a cross section

containing one more lobe than the rotor. Its pitch length is longer than the

rotors pitch length by the ratio o the number o stator lobes divided by the

number o rotor lobes. Example: A 7 to 8 lobe conguration has 7 lobes on the

rotor, 8 lobes in the stator: and a helical pitch length o the stator equal to 8/7

times the pitch length o the rotor.

The number o stages o a Drill Right Tools PDM drive is the length o

the stator elastomer liner divided by its pitch length.

Drill Right Tools drives permit accurate determination o the bit

speed and bit torque on bottom rom the rig oor at any time by reerring to

the accompanying Motor Specications and Perormance pages. The output

torque is directly proportional to the pressure drop across it. This is a straight-line relationship and can be determined rom the standpipe pressure gauge.

The PDM drives speed is proportional to the circulation rate.

At a constant circulation rate, the speed drops o slightly as the

torque and pressure increase


5/55

The circulation rate can be read rom the pump stroke counter.

The stator is threaded on both ends with a box that uses a standarddesigned thread. It connects to the dump sub above and to the adjustable

housing below.

The rotor has a box connection that connects to the upper universal

joint o the articulated driveshat assembly.

Adjustable HousingDrill Right Tools adjustable housing connects the stator to the sealed

bearing assembly and encloses the articulated driveshat assembly. The angle

setting is eld adjustable to produce a wide range o build rates.

Fixed HousingFixed, non-adjustable housings are available (special order) in straight

or xed bend congurations

The articulated driveshat assembly converts the eccentric or pro-

cessional motion o the rotor into concentric rotation or input to the sealed

bearing assembly. It also accommodates any angle set on the adjustable bent

housing (or xed bend housing) and carries the thrust load rom the rotor

caused by the pressure drop across it.

The assembly consists o two universal joints connected by a drive-

shat. The upper joint connects to the rotor and the lower joint connects tothe sealed bearing assembly. Both universal joints are lubricated, sealed, and

pressure balanced.

Sealed Bearing AssemblyThe sealed bearing assembly transmits the rotation o the rotor,

through the articulated driveshat assembly, to the drill bit. It carries the com-

pressive thrust load created by the weight on bit, and the radial and bendingloads developed while directional or steerable drilling. It also carries the ten-

sile "o-bottom" thrust load produced by the pressure drops across the rotor

and the drill bit, as well as any load caused by back reaming.

Motor Components


6/55

Drill Right Tools radial bearings and thrust bearings are sealed in an

oil chamber balanced to the hydrostatic pressure. The thrust bearings arehigh capacity and there is no need to balance hydraulic thrust load to bit

load with the Drill Right Tools motor. The high capacity radial bearings readily

withstand side loads caused by drilling with a deection device or uneven

cutting action along the drill bit periphery.

The lower connection is an API regular bit box.

StabilizersDrill Right Tools motors are available with a thread on the outside o

the sealed bearing assembly to accept straight or spiral blade screw-on sta-

bilizers or screw-on oset pads. A protector is installed over this thread when

stabilizers or oset pads are not being used.

Speciy stabilizer / pad OD when ordering.

Stabilizers, thread protectors and oset pads should be torqued tothe values shown below.

4 3/4"or 5" 6000 8100

6 1/4" 10000 13550

6 3/4" 12000 16250

7 3/4" or 8" 20000 27000

Motor Components

t-lbs N-m


7/55

ServicingDrill Right Tools recommends that its downhole motors be serviced

ater every run and be returned to an authorized Drill Right Tool service acil-

ity.

At Drill Right Tools, the motors are visually inspected and ushed.

Motors are completely disassembled and all parts cleaned and inspected.

Threaded connections and critical components in the motors are magnetic

particle inspected by qualied operators. Threads and parts are redressed asnecessary and worn parts are replaced. Make-up and breakout o all thread-

ed connections is perormed and logged with an accurate torque machine

(Torquemaster) to ensure proper torque is applied to the threaded connec-

tion. Following reassembly, the tool is lled with oil and readied or shipping

and operation.


8/55

No matter whether the application is a correction run, directional

kick-o, sidetrack extended reach, horizontal well, or a coring run, careul

consideration o all parameters will go a long way in ensuring the successulexecution o the planned task.

Hydraulic requirements, circulating uid data, RPM requirement,

and ormation characteristics must be addressed to ensure the proper selec-

tion o the applicable Drill Right Tools motor.

Preparation or Running and Rig Site Motor TestDrill Right Tools downhole motors are shipped rom the service cen-

ter with all tool connections made up to the proper torque, and all compo-

nents inspected and tested or proper operation. High-torque low-speed mo-

tors are shipped with the rotor bore plugged unless otherwise specied. All

motors are shipped with a protector covering the screw-on stabilizer thread

unless a screw-on stabilizer is ordered. When ordered in advance, the screw-

on stabilizer is installed at the service center beore shipment.

Set the motor in the slips and install a saety clamp. Remove the litsub and make up the kelly. Remove the saety clamp and slips and lower the

motor until the dump sub is below the drilling nipple, but visible. Start the rig

pumps slowly; Fluid should ow out o the dump sub ports.

Increase the pump rate slowly until the dump sub closes. Leave the

pumps running and make note o the circulation rate and stand pipe pressure

when the dump sub closes. With the pump running and the dump sub closed,

check to ensure that there is no drill uid leakage through the ports. It is ad-visable to increase the pump speed in two or three steps, to the maximum cir-

culation rate expected downhole, and note the circulation rate and standpipe

pressure in each case. Shut down the pump. The dump sub may not open due

to a pressure lock in the short hydraulic test circuit. I this occurs, bleed o the

pressure to permit the dump sub to open.

Make up the drill bit to the proper torque with a bit breaker and

the rig tong placed on the output shat directly above the bit. Do not put rigtongs on the sealed bearing assembly housings. Inspect the output shat seal

area or any indication o an oil leak.

Operations


9/55

Operations

Running In

The drill string with a straight Drill Right Tools motor installed canbe run into the hole normally. When using a bent sub, or a non-zero angle in

the adjustable housing, be careul passing the motor through the blowout

preventors, casing shoes, liner hangers, ledges, or key seats to ensure that the

motor or drill bit does not hang up. Do not run into bottom, or bottom ll; as

it could plug the bit or damage the motor.

Starting the MotorBegin circulating o bottom with the bit turning reely. Perorm cir-

culation and pressure tests at the same circulation rates as the prior surace

test, and note the readings. The pressure will be higher due to the restrictions

o the drill string components added. The o bottom pressures noted may

be higher than calculated. This is caused by bit drag on the side o the hole

due to the bent sub, adjustable housing angle and stabilization.

DrillingAter a short hole-cleaning circulation period, slowly lower the bit

to bottom. When bottom is tagged, the standpipe pressure gauge will show

an immediate increase. Increase the bit weight slowly to achieve the desired

build up rate and/or rate o penetration. Do not exceed the recommended

maximum dierential pressure across the motor.

The o bottom pressure is the total system pressure (read on the

stand pipe gauge), rom the standpipe, through the drillstring, the annulus,and back to the drilling nipple, while circulating with the bit o bottom(i.e.

zero weight on bit).

Periodically recheck the o bottom pressure. The standpipe pres-

sure will slowly increase ater hole cleaning due to the hydraulic energy re-

quired to lit the cuttings.

The torque applied to the bit while on bottom is directly propor-tional to the dierence between the on bottom and o bottom pressures

(i.e. there are no riction losses through the rotating drill string). An increase

in the weight on bit produces an increase in torque. As the bit drills o, the

weight on bit decreases and correspondingly the pressure and torque de-

crease. The standpipe pressure gauge can thereore be used as a torque

indicator.


10/55

Operations

The range o Drill Right Tools motors permits selection o the correct

motor to provide the optimum combination o bit speed, bit torque, and cir-

culation rate or maximum rates o penetration. When the drilling conditionspermit, the rotary can be engaged.

Running into bottom can damage thrust bearings, and excessive

over pull on a stuck bit can damage o bottom bearings in the sealed bear-

ing assembly.

Drill Right Tools motors are designed or extended intervals o on

bottom drilling. The motors should be serviced ater 150 operating hours,

under ideal drilling conditions. Drilling conditions other than ideal, such as

excessive bit weight, corrosive drilling uids or rotating with high bend set-

tings will reduce this interval accordingly.

Reactive TorqueThe drill bit attached to the mud motor at the bit box turns in a right

hand, or clockwise direction, i viewed rom the drill oor. There is a reactive,

counter clockwise (or let-hand) torque produced as a result o the torque ap-plied to the bit. This anticlockwise torque must be considered when establish-

ing tool ace orientation and can be calculated by relating the:

1) dierence between o bottom ree spinning pressure; and

2) actual on bottom operating pressure.

A rough, determination o the angle o twist o the drill string canbe perormed as ollows:

1) Measure and record standpipe pressure on bottom with thedesired bit weight and circulation rate, and o bottom with thesame circulation rate.

2) From the motor perormance sheets near the end o this book,obtain the torque corresponding to the dierence between the

on bottom and o bottom pressures.

3) The torsional angle can be determined by multiplying the abovetorque, the length o drill pipe in the hole, and the angle actorsrom the table below.

3 1/2" - 13.3 lb./t. Drill Pipe Imperial: 8 1/2 (degrees) / 100 lb-tTorque /1000 t.

Metric: 19 (degrees) / 100 N.m Torque /1000 m.


11/55

Operations

Directional drillers can get an indication o the reactive torque by the

measurement while drilling (MWD) equipment, and can adjust and lock the

rotary table in order to accommodate the desired tool ace direction.

In most applications the use o measurement while drilling or steer-

ing tools to provide real time surace readout o azimuth, inclination and tool

ace is much more reliable than the single shot method o orienting.

StallingI the drill bit is overloaded, the motor will stall. An increase in stand-

pipe pressure will occur and penetration will cease.

When a stall occurs, the drilling uid deorms the stator elastomer

liner and ows through the PDM drive without turning the rotor. Bit stall

should be avoided, but when it occurs, it should be quickly remedied. Exces-sive circulation through a stalled PDM drive or repeated stalling will seriously

damage the stator elastomer liner and other components within the motor.

I the bit is picked up o-bottom when in a drilling mode, the

trapped torque within the drill string will be released uncontrollably, poten-

tially causing damage to down-hole components or causing connections to

back-o. This is especially true when a stall has occurred.

I a stall condition occurs the ollowing procedure should be ollowed

as soon as possible.

1) Shut down the rotary table immediately.

2) Release trapped torque slowly using the rotary table brake.

3) Lit the bit o bottom, and

4) Shut the pumps o, i necessary.

3 1/2" - 15.5 Ib./t. Drill Pipe

Imperial: 7 1/2 (degrees) /100 Ib-tTorque /1000 t.


41/2 - 16.6Ib./t. Drill Pipe

Imperial: 3 1/3 (degrees) /100 Ib-tTorque /1000 t

Metric: 7 1/2 (degrees) / 100 N.m. Torque /1000 m.

5 - 19.5 Ib./t. Drill Pipe

Imperial: 2 5/8 (degrees) / 100 lb-tTorque /1000 t.



12/55

Operations

Over-running the Bit

Rotating the drillstring with any positive displacement motor in astalled condition may cause the upper portion o the motor (and drill string)

to over-run the bit. This condition may damage the stator elastomer liner.

High torque, low speed multi-lobe motors are most susceptible to this type o

damage.

Rotary RPMRotating the drill string while subjected to bending loads produce

atigue loading on the motor. These bending loads can be produced even

when using adjustable bend settings that are within the recommended val-

ues (see Maximum Adjustable Bend Setting or Rotary Drilling in Section 11).

Drill string rotary speed should thereore be limited to 50 RPM to reduce the

cyclic loading on the motor.

Motor Pressure DropExceeding the recommended operating maximum dierential pres-

sure across the motor will reduce the stator lie. Circulation rates exceeding

the recommended values also reduce the rotor and stator lie.

To understand the conditions aecting the pressure drop across

positive displacement drilling motors, the ollowing should be recognized:

The pressure drops across the dump sub, benthousing, articulated

driveshat, and bearing mandrel o the sealed bearing assembly is

dependent on the circulation rate only (i.e. torque has no eect).

This pressure drop increases as the circulation rate increases.

The pressure drop across the rotor and stator increases linearly as

the torque increases, assuming a constant circulation rate.

The eect o mud weight alters the pressure drop across the motor

at no load. However, it has a negligible eect on the pressure

increase due to the torque on bottom.


13/55

Operations

Bit Pressure DropContinuous excessive pressure drops across the bit can cause early

seal ailure in the sealed bearing assembly. The bit pressure drop should belimited to 1,500 psi (10,000 kPa) or continuous drilling. However, Drill Right

Tools motors can be congured to operate with bit pressure drops in excess

o 1,500 psi. Please contact Drill Right Tools i these higher pressures are re-

quired.

Drilling Fluids

Drilling uids with a pH below 4 or above 10 can cause damage tothe stator. Circulation through the rotor and stator can minimize this damage

and should thereore be maintained when operating in drilling uids close to

the limits o this pH range. Allowing the drilling uid to stagnate will aggra-

vate the problem.

Pumping acid through a motor can seriously attack the plated com-

ponents. The motor should be ushed and serviced as soon as possible.

Drilling uids containing chlorides can reduce rotor and stator lie

due to corrosion, especially at elevated temperatures. Special attention

should be paid to the internal coatings when the chloride concentration is in

excess o 30,000 PPM. Contact Drill Right Tools i chloride concentrations are

in excess o this. The motor should be ushed and serviced as soon as pos-

sible i it has been exposed to chlorides.

Drilling mud with a density o more than 16.7 PPG (2.00 kg/I) will

cause abnormal erosion o motor internals due to suspended materials with

in these muds.

Well-mixed medium-to-ne lost circulation material can be used

without plugging or motor damage. I coarse lost circulation material is to be

used, a circulating sub should be installed above the motor assembly to

bypass the motor.

Sand content should be less than 2%. Solid content o more than 5%will shorten rotor and stator lie considerably.

Sae run times may have to be shortened to avoid down-hole motorailure i the above recommendations are not ollowed.

Never try to cement through a motor.


14/55

Operations

Oil Based Drilling FluidsDrill Right Tools motors can be successully used in oil based mud i

the operating temperature is below the aniline point o the oil. However, oil

based uids will deteriorate the elastomeric stator liner and consequently it is

recommended that the stator be relined ater it has been run in an oil based

mud.

The aniline point (i.e. temperature) o an oil is an indication o its ten-

dency to cause swelling o elastomeric parts (e.g. stator, seals), and is a mea-

sure o the oils aromatic content. The lower the aniline point, the greater theswelling tendency. The aniline point gives a measure o the solvent power o

a petroleum product or aniline, which is related to its solvent power or many

materials. This solubility increases with increasing temperature.

Operating a motor in an oil based uid at temperatures above the

oils aniline point allows the aromatic portion o the oil to permeate and swell

the stator elastomer liner and reduce its hardness and strength. The swelling

increases the intererence between the rotor and stator and results in heatbuild-up that leads to rapid destruction o the stator elastomer liner. Power

sections with larger clearances are available to minimize the eects o swell-

ing.

Elastomeric compounds seem to perorm better in mineral based

mud systems than in diesel oil based systems. Low toxicity oil base systems

are easier on elastomers because they contain ewer aromatics.

H2S (Sour) ServiceDrill Right Tools motors are manuactured rom steels with a hard-

ness in excess o that allowed by the National Association o Corrosion Engi-

neers (NACE) Specication MR0175. This hardness is required to achieve the

strength necessary or use in the drillstring, but it renders it susceptible to sul-

de stress cracking (SSC). As a consequence the drilling environment should

be controlled i these tools are to be used in sour environments.

The drilling environment may be controlled using one or more o the ollowing

1) Maintenance o the drilling uid hydrostatic head to minimize

ormation uid in-ow.

2) Use o chemical sulde scavengers.

3) Use o a drilling uid in which oil is the continuous phase.


15/55

Operations

The ollowing specications provide recommendations or drilling

sour wells and or the control o the drilling environment:

1) The American Petroleum Institute (API) Recommended Practice

RP7G Section 9.

2) The National Association o Corrosion Engineers (NACE) Specica-

tion MR0175, Sulde Stress Cracking Resistant Metallic Materials or

Oileld Equipment.

3) Alberta Recommended Practices or Drilling Critical Sour Wells.

The time that a motor is exposed to H2S in a typical drilling applica-

tion is insufcient or H2S to cause damage to the elastomers (e.g. stator liner)

within the motor.

Down-hole TemperatureAn increase in static downhole temperature reduces the strength o

the stator elastomer liner. Consequently, the maximum pressure drop acrossthe power section, i.e. the ull load pressure, must be reduced to avoid stator

elastomer premature deterioration. No reduction in ull load pressure is nec-

essary up to a temperature o 140F (60C). Beyond that temperature, the ull

load pressure obtained rom the perormance curves must be multiplied by

the dp reduction actor. For instance, i the ull load pressure obtained rom

section 11 is 600 psi and the static downhole temperature is 200F (93C), the

operating ull load pressure is calculated by multiplying 600 psi by a dp reduc-

tion actor o 0.68, yielding 408 psi.

A standard power section can operate saely in static downhole tem-

peratures up to 225F (107 degrees C). A higher static downhole tempera-

ture would require the use o a power section with larger clearances to avoid

premature deterioration. The Drill Right Tools motors have been successully

used in temperatures up to 310F (154 C) with special power sections. There-

ore, please consult Drill Right Tools should a static downhole temperature

greater than 225F (107 degrees C) be anticipated.

Plugging OThe motor may plug o with cuttings entering the drill string through

the lter plugs in the dump sub ports. To prevent this occurrence the hole

should be circulated to achieve bottoms up beore running in the hole with a

motor.


16/55

Operations

This may also occur upon breaking connections when drilling cement

or unconsolidated sands, etc. As the annulus loads up with cuttings, and the

kelly is broken o, U-Tubing occurs, (i.e. the pressure in the annulus exceedsthe pressure in the bore due to dierent uid densities). I this occurs, imme-

diately make the kelly back up and re-commence circulation and ensure that

the hole is cleaning properly. In some cases it may be necessary to blank o the

dump sub.

Hydraulic ExtensionWhen using a positive displacement motor, the drill string stretches

when bottom is tagged, increasing the weight on bit. The sequence is as ol-

lows:

1. The motor is running reely o bottom:

2. When the string is lowered and the bit tags bottom, the torque

required to drive the bit causes an increase in the pressure across

the motor.

3. This increase in internal pressure in the drill string causes the drill

pipe to stretch and correspondingly, increases the weight on bit.

Usually the bit drills o and when the string is again lowered, the

above sequence repeats. However, under certain circumstances the motor

may stall and not drill o, and drilling with a positive displacement motor

becomes virtually impossible. The hydraulic extension maximizes due to the

stall pressure, and causes the bit to become imbedded. One solution is tochange the drill bit to a less aggressive style to avoid imbedding. An alter-

nate solution is to use a motor with a higher lobe conguration because these

require less pressure drop across the rotor and stator to produce the same

torque.

Partial Rotor Bypass

Drill Right Tools low speed motors with bored rotors permit highercirculating rates than normally recommended as a portion o the circulating

uid passes through the rotor center rather than the rotor stator interace. It

should be understood that the pressure drop across the rotor bore bypass

is the same as the pressure drop across the PDM drive section. At a very low

circulation rate, below a practical rate or operation, all circulation could be

through the rotor bore bypass and the rotor and output shat will not turn

due to the static riction between the rotor and stator elastomer liner.


17/55

At high circulation rates on bottom; operating near the rated torque

o the motor, the resulting pressure drop across the PDM drive causes a sub-

stantial portion o total circulation to be directed through the rotor bore, keep-ing the ow through the rotor stator interace within recommended operating

limits.

At high circulation rates o bottom; the pressure drop across the

PDM drive is low. Consequently, the portion o the circulating uid passing

through the bypass is low, and the motor speed will exceed its recommended

limit. In order to avoid major damage, high circulating rates o bottom or

the purpose o checking pressure drop, should be kept to a short duration.

When circulating o bottom; or the purpose o hole cleaning, the

circulation rate should not exceed the maximum recommended or standard

motors without bored rotors.

Tripping Out o the Hole and Checking the ToolNo special procedures are required or tripping out o the hole with a

drill string containing a Drill Right Tools motor. The string automatically drainsthrough the dump sub. There is no requirement to perorm any special checks

on the sealed bearing assembly or bit sub, as the thrust bearings are sealed in

an oil chamber.

Note: It is normal to see a small amount o drilling uid draining rom

the vent plugs and in certain models rom the lower end o the seal bearing

assembly, just above the output shat.

Note: Lighter mud weights will typically drain while tripping out o hole.

A motor that has not drained does not suggest that the motor is damaged.

Rig Site MaintenanceWhen drilling uids containing chlorides have been used, it is im-

perative the Drill Right Tools motor is ushed, ideally with resh water. Leaving

the motor unserviced causes severe pitting o the plated suraces. The ollow-ing is the recommended minimum ushing procedure:

1) Ater the tools are removed above the dump sub, clean uidshould be poured into the top o the dump sub and the pistonactuated with a hammer handle several times until it travels reelyup and down. Fluid should be ushed through the dump sub ports,again actuating the piston until ree travel is obtained.

Operations


18/55

2) Install the ported lit sub. Lit motor and place in bit breaker. Se-

cure the motor with a chain tong on the tool body. While rotating the

table slowly clockwise, or a minimum o 6 turns, add clean uid inthe top or port provided.

Operations


19/55

adjusting ring

lock housing

oset housing

power section

power section

lock housing

adjusting ring

wear pad

oset housing

tong area

tong area

These operating instructions apply to 2 degreee,3 degree

and 4 degree adjustable housings

Adjustable Housing Operating Instructions

Figure 1- Break joint with tong on tong areas.

- Keep adjusting ring engaged with oset housing and back o lock

housing 2 turns.

NOTE: Teeth must stay engaged during the back oprocedure.

Figure 2

- Slide adjusting ring up to disengage teeth.- To adjust bend angle, rotate adjusting ring clockwise until the required

angle marked on the adjusing ring and oset housing match.

NOTE: Do not rotate counterclockwise beyond the 0degree setting.


20/55

LOCK HOUSING MAKE-UP TORQUE

2 3/8" 1,600 lb-ft 2,200 N.m2 7/8" 2,200 lb-ft 3,000 N.m3 1/8" 4,500 lb-ft 6,100 N.m3 3/8" 4,500 lb-ft 6,100 N.m3 1/2" 5,000 lb-ft 6,800 N.m3 3/4" 5,300 lb-ft 7,200 N.m4 3/4" 10,000 lb-ft 13,500 N.m

5" 15,000 lb-ft 20,300 N.m

6 1/4" 23,000 lb-ft 31,000 N.m6 3/4" / 7" 28,000 lb-ft 38,000 N.m7 3/4" / 8" 43,000 lb-ft 58,000 N.m

9 5/8" 68,000 lb-ft 92,000 N.m11 1/4" 80,000 lb-ft 108,000 N.m

Figure 3

- Engaged teeth of adjusting ring at chosen angle setting.

- Apply thread dope to mating faces of the lock housing and adjusting

ring.

- Torque lock housing to recommended value listed in the table below.

- Matched number indicates angle of bend and exact short side of motor.

apply thread dopeto this face beforeretorquing

power section

lock housing

adjusting ring

oset housing

Motor size Imperial Metric


21/55

Adjustable Housing Operations Instructions

In the event the adjusting ring disengages from the oset housing

and rotates with the lock housing, the procedure outlined below

should be followed to reset the adjusting ring to the proper posti-

tion prior to setting the bend angle:

Slide the adjusting ring up until teeth disengage from the

oset housing, if not already done.

Screw the adjusting ring (and the splined mandrel) clockwise

into the oset housing until the splined mandrel stops.

Back o 2 turns (counterclockwise rotation).

Rotate the adjusting ring clockwise until the 0 markings

align.

The adjustable housing is now reset and can be set to the desired

bend angle as indicated in the previous 2 pages.

The following table shows the available bend settings for the 2,3, and

4 degree adjustable housings.

Adjustable Housing Bend Settings

2 degree

0.00

0.260.52

0.77

1.00

1.22

1.41

1.59

1.73

1.85

1.93

1.98

2.00

3 degree

0.00

0.390.78

1.15

1.50

1.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

4 degree

0.00

0.350.69

1.04

1.37

1.69

2.00

2.29

2.57

2.83

3.06

3.28

3.46

3.63

3.76

3.86

3.94

3.98

4.00


22/55


23/55

Applications

Defection DevicesDirectional drilling or sidetracking operations traditionally used a

bent sub or kick sub placed above the dump sub. A disadvantage o the bent

sub above the motor is that it places the bend too ar o bottom and the drill

string should not be rotated.

Bent housings placed between the drive section and lower bearing

section place the bend closer to the bit, tilting the bit and bearing housing

axis in relation to the motor, minimizing bit wall drag. Motors containing bent

housings can be rotated. The disadvantage o conventional bent housings isthat their angle cannot be changed in the eld.

Drill Right Tools adjustable housing has the advantages o placing

the bend close to the bit, and it can be rotated. It is easily adjustable rom

straight to 3 degrees in 12 increments (or 2 degrees in 12 increments, or 4

degrees in 18 increments), on the rig oor. Drill Right Tools adjustable hous-

ing eliminates the need to select a bent housing angle beore a motor can be

assembled and shipped. Drill Right Tools motors contain a screw-on stabilizerthread on the lower sealed bearing assembly to enable the motor to be run

slick with the Drill Right Tools adjustable housing, or with eld installable sta-

bilization as required.

Steerable SystemsThe desired angle is set in the adjustable housing sufcient to alter

hole course with the drill string not rotating and the tool ace oriented. When

the drill string is rotated with the motor operating, the system drills straight

ahead.

The broad range o circulation rates, bit speeds, and bit torques avail-

able with Drill Right Tools steerable downhole motors make them suitable or

use with journal bearing and roller tri-cone bits, PDC bits and diamond bits.

The measurement while drilling system, sotware, bit selection, and

operation o the total system is the expertise o others. Drill Right Tools con-centrates on the ongoing development o improved motors and accessories,

to compliment the overall steerable system.


24/55

Applications

Perormance DrillingDrill Right Tools motors have been used successully with higher

output power sections or straight hole perormance drilling. These power

sections have more stages and consequently provide more uniorm torque

output since the pressure per stage required producing a given torque is less.

The result is optimum rates o penetration.

Coring

Drill Right Tools multi-lobe series motors are ideally suited to coringoperations. The high torque, low speed characteristics provide increased pen-

etration rates at lower bit weights achieving better core recovery rates. Lower

drill string and casing wear is experienced, particularly in high angle holes. As

a rule no more than 60 eet (18 m) o core barrel should be run at a time.


25/55

The Drill Right Tools multi-lobe motors may be used or drilling with

air or two-phase drilling uids as the circulating medium.

Two-phase drilling uids can be dened as ollows:

Mist: occurs when the liquid raction is less than 2.5% at downhole

conditions. In this case the liquid stays as droplets within the gas.

Foam: occurs when the liquid raction is between 2.5% and 25% at

downhole conditions. Foams are typically specied as % oam qual-

ity: Foam quality is the volume raction o the gas (i.e. 75% oamquality is 75% gas and 25% liquid, by volume).

Aerated mud: occurs when the liquid raction is greater than 25% at

downhole conditions. In this case the gas stays as bubbles within

the liquid.

Since there are large volumes o oxygen present in air drilling,

corrosion o the drillstring can be a concern. Passivating (oxidizing)inhibitors should be used to minimize this corrosion.

Selection / SetupThe critical issue with using a motor in an air or two-phase drilling application

is minimizing the temperature generated within the stator elastomer liner.

This can be accomplished as ollows:

Run stators with larger clearances i temp. dictates.

Use the lowest oam quality possible (i.e. the highest amount o liquid).

Minimize the RPM

Minimize times with no circulation.

All o the above, in addition to the downhole temperature, interactto determine the lie o the stator. Failure o the stator elastomer liner is ac-

celerated by internal heat build-up. As the liner heats up it expands, causing

an increase in the intererence t that in turn causes more riction and urther

heat build-up. Hard spots then develop in the liner and eventually chunking

occurs. The problem is urther compounded by the poor thermal conductivity

o air compared to a drilling uid.

Air or Two-Phase Drilling


26/55


There are rotors and stators available that are designed specicallyor air or two-phase drilling. These accommodate high ow rates and run at

lower pressure drops and should be selected i available. Please contact DrillRight Tools or availability and application o these power sections.

When air drilling power sections are not available, use power sec-

tions that run the slowest at the same owrate. Ideally, use high perormance

power sections (more stages) because the dierential pressure per stage re-

quired to produce a given torque is less. This lower dierential pressure will be

less damaging to the stator elastomer liner. Although the motor will produce

the same torque at a given dierential pressure when using air, the maximumobtainable dierential pressure will be less due to the extra slipage that oc-

curs with a gas. Consequently, the maximum obtainable torque (and stall) will

be lower.

A crossover sub should be used above the PDM drive rather than the

dump sub because airow will not cause the dump sub to close. Alternatively

the dump sub ports can be blanked o.

While drilling with air or two-phase uid, the uid density in the

annulus may be higher than in the bore due to the cuttings in the annulus.

When a connection is being made the pressure is reduced in the bore that can

result in cuttings entering the bore. This can damage the motor or plug the

bit. A oat valve should thereore be used when drilling with air or two-phase

uids to prevent this. A small hole is sometimes drilled in the apper to allow

pressure to equalize i the drillstring does become plugged between the oat

valve and the bit.

Fluid / Lubricant RequirementsA lubricant is required to lubricate the stator elastomer liner. Soap or gel thor-

oughly mixed with water and injected at a minimum rate (in GPM) o 5% by

volume at downhole conditions is adequate or most applications. However,

other drilling concerns may dictate higher ow (i.e. avoiding ormation o

mud rings).

Example next Page


27/55


Given:

Air ow rate required =2000 scmBit Pressure drop = 100 psi

Hydrostatic pressure = 200 psi

Pressure to turn motor (no load) =75 psi

Calculated:

Motor exit pressure = 100 + 200 =300 psi

Pressure at no load =300 + 75 =375 psi

Flow at no load conditions

=(14.7/(14.7+375))*2000* 7.48 =564 gpm

Required minimum lubricant =.05*564 =28 gpm

PressuresThe pressure at the outlet o the motor (i.e. the motor exit pressure)

has a pronounced eect on the response o the motor. The motor exit pres-

sure is the sum o the hydrostatic pressure and the bit pressure drop. This is

the pressure that determines the volume ow rate through the motor.

As the motor exit pressure increases, the motor becomes less suscep-

tible to runaway and acts more like a motor running on liquid only.

TemperatureTypically, standard t motors can be used except where the down-

hole temperature dictates that a stator with larger clearances is required.

Static bottom hole temperature up to 225F (107C) is considered standard.

The air expands as it exits the rotor stator and then the bit nozzles.

The resulting pressure drop has a cooling eect that can increase the lie o

the stator.

Volume RequirementsIn a standard air drilling application, the required air ow rate (in

SCFM) or proper motor operation is typically three to our times the maxi-

mum motor liquid ow rate (in GPM). This rule applies or motor exit pressures

up to approximately 300 psi.


28/55


As the motor exit pressure increases, the airow rate required to

achieve the same motor operating speed (rpm) also increases. This is com-

mon in some under-balanced applications. In these cases the required airow rate increases. Consult Drill Right Tools engineering in these cases.

I higher ow rates are desired, the rotor can be tted with a nozzle

to bypass a portion o the ow. However, the motor becomes even more sen-

sitive to stall i the rotor bypass is used.

OperationIn general, a motor driven by air, mist or oam should be started

while on bottom. It should not be allowed to run reely beore tagging bot-

tom because this can cause high shock loads as the bit tags bottom which

may damage the motor. Ideally, the motor should be started with uid rst.

A motor is much more torque sensitive when using air, mists, or

oams, than with liquids and consequently is more susceptible to stalling.

When drilling operations are to be stopped, let the motor drill oas the compressors and boosters are being shut down. Picking up o bot-

tom prior to equalizing the pressure can permit the air compressed in the

drill string to expand, overspeeding and possibly damaging the motor. It can

also cause the internal connections to back o.

Drilling with Nitrogen (N2)

Air itsel consists o approximately 78% nitrogen. The density o ni-trogen is approximately 3% less than that o air at standard temperature and

pressure. Functionally, the motors will run the same on nitrogen as air. How-

ever, the explosive decompression, as discussed below, is more severe with

nitrogen.

Since nitrogen is an inert gas the nitrile sealing components with-

in the motor, including the stator, are not aected chemically by nitrogen.

However, any sealing compound will absorb nitrogen (as well as other gases)to some extent while under pressure. I the pressure has been applied long

enough and the pressure is released too quickly, the gas does not have su-

cient time to be expelled rom the nitrile and explosive decompression can

occur, resulting in blistering. This is typically not a problem with continuous

pressure drops across the motor o 400 psi (3,000 kPa) and less.

Ater drilling or extended periods with nitrogen, stator damage can

be expected.


29/55


30/55

Sudden Pressure Increase

This may occur when the motor stalls. To correct, pick up o bottom,and then return to bottom with less bit weight.

The tool may be plugged internally, or the bit plugged requiring a

trip out o the hole or bit or motor replacement.

No Penetration

This may occur due to a worn bit, requiring a bit trip.

Formation changes may require changes in bit weight and circula-

tion rates.

The motor may be stalled, which can be detected by a pressure increase.

The stabilizer may be hanging up on the ormation.

The bit may be balled up requiring a dierent bit or the ormation.

The stator elastomer liner may be damaged requiring a trip out o

the hole and motor replacement.

Slow Pressure DecreaseThis may result rom a wash out in the string or the dump sub.

Lost circulation causes a decrease in pressure i there is no return

and may be conrmed by checking the pit level.

A gas kick causes a decrease in pressure and may be detected by an

increase in R.O.P. and conrmed by checking the pit level.

Trouble Shooting


31/55


32/55

Motor Performance

Imperial Units

Metric Units

4 3/4 7/8 M/L 2.0 Stage 250 80 2150 0.32 260

4 3/4 7/8 M/L 3.8 Stage 250 140 2430 0.56 490

5 -4 3/4 7/8 M/L 2.2 Stage 250 130 1660 0.56 400

6 1/4 7/8 M/L 2.9 Stage 500 85 5590 0.17 380

6 1/4 7/8 M/L 4.8 Stage 400 140 4840 0.35 620

6 3/4 7/8 M/L 3.0 Stage 600 170 3490 0.28 390

6 3/4 7/8 M/L 3.5 Stage 600 90 7830 0.15 460

6 3/4 7/8 M/L 5.0 Stage 600 170 5950 0.28 650

7 3/4 (8) 7/8 M/L 4.5 Stage 900 140 8660 0.16 520

Motor

Max

Flow

Rate

Max

Bit

Speed

Torque

at

Full Load

rev/gal

at

No Load

Pressure

at

Full Load

gpm RPM lb-ft rev/gal psi

6 3/4 7/8 M/L 3.0 Stage HR

6 3/4 7/8 M/L 3.0 Stage HR

600 6280 6800.28170

4 3/4 7/8 M/L 2.0 Stage 950 80 2913 0.085 2913

4 3/4 7/8 M/L 3.8 Stage 950 140 3290 0.148 3380

5 -4 3/4 7/8 M/L 2.2 Stage 950 130 2251 0.148 2800

6 1/4 7/8 M/L 2.9 Stage 1890 85 7570 0.045 2620

6 1/4 7/8 M/L 4.8 Stage 1510 140 6560 0.092 4270

6 3/4 7/8 M/L 3.0 Stage 2270 170 4730 0.074 26906 3/4 7/8 M/L 3.5 Stage 2270 90 10610 0.040 3170

6 3/4 7/8 M/L 5.0 Stage 2270 170 8060 0.075 4480

7 3/4 (8) 7/8 M/L 4.5 Stage 3410 140 11730 0.041 3590

Motor

Max

Flow

Rate

Max

Bit

Speed

Torque

at

Full Load

rev/gal

at

No Load

Pressure

at

Full Loadlpm RPM N.m rev/l kPa

2270 8510 0.074 4650170


33/55

Weight 950 lbs (430 kg)

Predicted Build Rates - Degrees/100ft (30m)

BendSetting

Slick SingleStabilizer

TwoStabilizers

Hole Size Hole Size Hole Size

Deg

0.39

0.78

1.15

1.50

1.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.5

4.2

7.0

9.6

12.1

14.2

16.2

17.8

19.1

20.0

20.6

20.8

1.5

3.5

6.2

8.8

11.3

13.4

15.3

17.0

18.2

19.1

19.7

20.0

1.4

2.9

4.7

7.3

9.7

11.8

13.7

15.4

16.6

17.5

18.1

18.3

2.5

5.0

7.4

9.6

12.1

14.2

16.2

17.8

19.1

20.0

20.6

20.8

2.7

5.2

7.6

9.8

11.9

13.8

15.3

17.0

18.2

19.1

19.7

20.0

3.0

5.5

7.9

10.1

12.2

14.0

15.7

17.1

18.2

18.9

19.4

19.6

1.8

4.6

7.2

9.7

12.1

14.2

16.2

17.8

19.1

20.0

20.6

20.8

1.8

4.6

7.2

9.7

11.9

13.8

15.5

17.0

18.2

19.1

19.7

20.0

1.8

4.6

7.2

9.7

12.0

14.0

15.7

17.1

18.2

18.9

19.4

19.6

6 6 1/4 6 3/4

0.0

3.0

6.0

9.012.0

15.0

18.0

21.0

24.0

27.0

30.0

33.0

36.0


TwoStabilizers


HoleCurvature

3.00

3.00

3.00

2.602.12

1.83

1.50

1.15

0.78

3.00

3.00

3.00

2.772.38

2.12

1.50

1.15

3.00

3.00

3.00

3.002.77

2.38

2.12

1.50

1.15

0.78

0.39

2.89

2.60

2.12

1.83

3.00

2.77

2.38

1.831.83

1.50

2.77

2.38

1.83

1.501.15

0.78

2.89

2.38

2.12

1.831.50

1.15

3.00

3.00

2.60

2.121.83

E

A

D

B

C

4 3/4 7/8 M/L 2.0 Stage (air)A 2 ft (0.61m)

B 5.4 ft (1.65m)

C 22.5 ft (6.86 m)

D Maximum Diameter of Motor at Upset

5.38 in (137 mm)

E set Pad: 2.65 in (67mm)

Common Top Connection: 3 1/2 IF 3 1/2 REG

Common Bottom Connection: 3 1/2 REG

Maximum Adjustable Bend Setting

For Rotary Drilling - Degrees

6 6 1/4 6 3/4 6 6 1/4 6 3/4

6 6 1/4 6 3/4 6 6 1/4 6 3/4 6 6 1/4 6 3/4

0.39

0.00

0.78

0.00

0.39

0.00 0.00

1.50

0.78

0.39

0.00

1.15

0.78

1.15

0.00

2.382.12

1.50

1.15

0.780.39

0.00

3.00

3.00

3.00

0.78

0.00

0.390.78

0.00

0.39

1.15

0.78

0.00

0.39


34/55

0 500 1000 1500 2000 2500

0 100 200 300 400

ON-BOTTOM MINUS OFF-BOTTOM PRESSURE

kPa

psi

SPEED:RPM

TORQUE:lb-ft

OUTPUTPOWER:HP

TORQ

UE:N.m

OUTPUTPOWER:kw

cations based on series 24x motor.

Maximum Pump Rate

Revolutions per Unit Volume

Pressure at Full Load

Torque at Full Load

Maximum Weight on Bit

Maximum Pull to Re-Run MotorPull to Yield Motor

gpm

rev/gal

psi

lb-ft

lbs

lbslbs

250

0.32

260

2,150

69,000

144,000331,000

lpm

rev/l

kPa

Nm

kN

kNkN

950

0.085

1790

2913

310

6501490

3/47/8M/L2.0Stage(air)

gpm (lpm)

250 (950)

200 (760)

150 (570)

100 (380)

FULL

LOAD

gpm (lpm)

250 (950)

200 (760)

150 (570)

100 (380)

3500

3000

2500

2000

1500

1000

500

90

80

70

60

50

40

30

20

10

0

30

25

20

15

10

5

0

4500

3600

2700

1800

900

0

45

40

3530

25

20

15

10

5

0


35/55



BendSetting


TwoStabilizers


Deg

0.39

0.78

1.15

1.501.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.4

4.1

6.8

9.411.8

13.9

15.8

17.5

18.7

19.6

20.2

20.4

1.4

3.4

6.1

8.611.0

13.1

15.0

16.6

17.9

18.8

19.3

19.6

1.4

2.8

4.6

7.19.5

11.6

13.5

15.1

16.3

17.1

17.7

17.9

2.5

3.9

7.3

9.411.8

13.9

15.8

17.5

18.7

19.6

20.2

20.4

2.6

5.1

7.4

9.611.7

13.6

15.0

16.6

17.9

18.8

19.3

19.6

2.9

5.4

7.7

9.912.0

13.8

15.4

16.8

17.8

18.6

19.1

19.3

1.8

4.5

7.1

9.511.8

13.9

15.8

17.5

18.7

19.6

20.2

20.4

1.8

4.5

7.1

9.511.7

13.6

15.2

16.6

17.9

18.8

19.3

19.6

1.8

4.5

7.1

9.511.8

13.8

15.4

16.8

17.8

18.6

19.1

19.3

6 6 1/4 6 3/4 6 6 1/4 6 3/4 6 6 1/4 6 3/4

0.0

3.0

6.0

9.0

12.0

15.0

18.0

21.0

24.0

27.0

30.0

33.0

36.0


TwoStabilizers


6 6 1/4 6 3/4 6 6 1/4 6 3/4 6 6 1/4 6 3/4

HoleCurvature

3.00

3.00

3.00

2.60

2.12

1.83

1.50

1.15

0.78

0.39

0.00

3.00

3.00

3.00

2.89

2.38

2.12

1.50

1.15

0.78

0.39

0.00

3.00

3.00

3.00

3.00

2.77

2.38

2.12

1.50

1.15

0.78

0.39

0.00

3.00

2.60

2.12

1.83

1.50

1.15

0.78

0.39

0.00

3.00

2.77

2.38

1.83

1.83

1.50

1.15

0.78

0.00

3.00

3.00

3.00

2.38

2.12

1.50

1.15

0.78

0.39

2.77

2.38

2.12

1.50

1.15

0.78

0.78

0.39

0.00

3.00

2.60

2.12

1.83

1.50

1.15

0.78

0.39

0.00

3.00

3.00

2.60

2.12

1.83

1.15

0.78

0.39

0.00

E

A

D

B

C

4 3/4 7/8 M/L 3.8 StageA 2ft (0.61 m)

B 5.4ft (1.65 m)

C 23.9ft (7.28 m)D Maximum Diameter of Motor at Upset

5.38 in (137 mm)


Common Top Connection: 3 1/2 IF 3 1/2 REG


Maximum Adjustable Bend SettingFor Rotary Drilling - Degrees


36/55

0 1000 2000 3000 4000

0 100 200 300 400 500 600


kPa

psi

150

125

100

75

50

25

0

250 (950)

220 (830)

190 (270)

160 (610)

gpm (lpm)SPEED:RPM

3000

2500

2000

1500

1000

500

0

4000

3500

3000

2500

2000

1500

1000

500

0

TORQ

UE:lb-ft

FULL

LOAD

OUTPUTPOWER:H

P

70

60

50

40

30

20

10

0

50

40

30

20

10

0

gpm (lpm)

250(95

0)

220(83

0)

190(27

0)

160(61

0)

TORQ

UE:N.m

OUTPUTPOWER:k

w


Maximum Pump Rate



Torque at Full Load



gpm

rev/gal

psi

lb-ft

lbs

lbslbs

250

0.56

490

2,430

69000

144000331000

lpm

rev/l

kPa

Nm

kN

kNkN

950

0.148

3380

3293

310

6501490

43/4

7/8M/

L3.8

Sta

ge


37/55



BendSetting


TwoStabilizers


Deg

0.39

0.78

1.15

1.50

1.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.6

3.6

6.5

9.3

11.9

14.3

16.3

18.1

19.5

20.4

21.0

21.3

1.9

3.1

5.8

8.6

11.2

13.5

15.6

17.4

18.7

19.7

20.3

20.5

1.5

3.0

4.5

5.8

8.2

10.4

12.4

14.1

15.5

16.4

17.0

17.2

3.1

5.6

8.0

10.3

11.9

14.3

16.3

18.1

19.5

20.4

21.0

21.3

3.3

5.8

8.2

10.4

12.6

14.4

15.6

17.4

18.7

19.7

20.3

20.5

4.2

6.6

8.9

11.1

13.2

15.0

16.7

18.0

19.1

19.9

20.4

20.5

1.9

4.7

7.5

10.0

12.4

14.3

16.3

18.1

19.5

20.4

21.0

21.3

1.9

4.8

7.5

10.0

12.4

14.4

16.1

17.5

18.7

19.7

20.3

20.5

1.9

4.8

7.5

10.0

12.4

14.5

16.4

18.0

19.1

19.9

20.4

20.5

8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8

0.0

3.5

7.0

10.514.0

17.5

21.0

24.5

28.0

31.5

35.0

38.5

42.0


TwoStabilizers


8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/4

HoleCurvature

3.00

2.60

2.38

1.831.50

1.15

0.78

0.39

0.00

3.00

2.89

2.38

2.121.83

1.15

0.78

0.39

0.00

0.00

3.00

3.00

3.00

2.892.38

2.12

1.83

1.15

0.78

0.39

0.39

0.00

2.60

2.12

1.15

0.780.39

0.00

2.77

1.83

1.50

0.780.39

0.00

2.60

2.12

1.50

1.150.39

0.00

2.12

1.83

1.15

0.390.00

2.38

1.50

1.15

0.390.00

2.12

1.50

1.15

0.390.00

E

AD

B

C

6 3/4 7/8 M/L 3.0 StageHRA 2.3ft (0.7 m)

B 6.6 ft (2.01m)

C 20 ft (6.1 m)


7.63 in (194 mm)


Common Top Connection: 4 1/2 REG 4 1/2 IF4 1/2 H-90 5 H-90

Common Bottom Connection: 4 1/2 REG 6 5/8 REG




38/55

0 1000 3000 5000 7000

0 200 400 600 800 1000


kPa

psi

150

125

100

75

50

25

0

250 (950)

200 (760)

150 (560)

gpm (lpm)SPEED:RPM

6000

5000

4000

3000

2000

0

8000

7000

6000

5000

4000

3000

2000

1000

0

TORQ

UE:lb-ft

FULL

LOAD

OUTPUTPOWER:H

P

105

90

75

60

45

30

15

0

100

80

60

40

20

0

gpm (lpm)

250(95

0)

200(75

0)

150(56

0)

TORQ

UE:N.m

OUTPUTPOWER:k

w


Maximum Pump Rate



Torque at Full Load



gpm

rev/gal

psi

lb-ft

lbs

lbslbs

250

0.56

860

4,450

69000

144000331000

lpm

rev/l

kPa

Nm

kN

kNkN

950

0.148

5900

6025

310

6501490

43/47/8

M/L

3.8S

tage

HR

1000


39/55



BendSetting


TwoStabilizers


Deg

1.15

1.50

1.83

2.122.38

2.60

2.77

2.90

3.00

8.5

13.8

19.0

23.828.1

31.8

34.7

36.9

38.6

7.6

12.7

17.8

22.426.7

30.3

33.2

35.5

37.2

6.7

11.6

16.6

21.125.4

29.0

31.8

34.0

35.6

8.3

12.2

17.8

22.426.7

30.3

33.3

35.6

37.5

8.1

12.7

16.6

21.125.4

29.0

31.8

34.0

35.6

7.8

12.9

17.9

22.926.7

30.3

33.3

35.6

37.5

7.4

12.1

16.8

21.125.4

29.0

31.8

34.0

35.6

6

0.0

3.5

7.0

10.5

14.0

17.5

21.0

24.5


TwoStabilizers


HoleCurvature

3.00

2.90

2.60

2.12

1.83

1.50

1.15

3.00

2.90

2.77

2.38

2.12

1.83

1.50

1.15

3.00

3.00

2.77

2.38

2.12

1.83

1.50

1.15

2.60

2.12

1.83

1.50

1.15

2.77

2.38

2.12

1.83

1.50

2.38

1.83

1.50

1.15

0.00

2.38

2.12

1.83

1.50

0.00

E

AD

B

C

5 - 4 3/4 7/8 M/L 2.2 StageA 1.5 ft (0.46m)

B 5.75 ft (1.75m)

C 18.9 ft (5.76 m)


8.63 in (141.2 mm)

E set Pad: 3.54 in (89.9mm)

Common Top Connection: 3 1\2 IF

Common Bottom Connection: 3 1\2 REG


6 1/8 6 1/4 6 6 1/8 6 1/4 6 6 1/8 6 1/4

8.5

13.8

19.0

23.828.1

31.8

34.9

37.1

38.9

8.5

13.7

19.0

23.828.1

31.8

34.8

37.1

38.9

6 6 1/8 6 1/4 6 6 1/8 6 1/4 6 6 1/8 6 1/4

1.15

2.77

2.38

2.12

1.83

1.50

1.15

2.38

2.12

1.83

1.50

0.00


40/55

0 60 120 180 240 300 360 420 480


kPa

psi

SPEED:RPM

TORQUE:lb-ft

OUTPUTPOWER:

HP

TORQ

UE:N

.m

OUTPUTPOWER:kw


Maximum Pump Rate



Torque at Full Load



gpm

rev/gal

psi

lb-ft

lbs

lbslbs

300

0.56

400

1660

45,000

144,000210,000

lpm

rev/l

kPa

Nm

kN

kNkN

950

0.148

2800

2251

200.2

6501472

-4

3/47/8M

/L2.2

Sta

ge

gpm (lpm)

250 (946)

175 (662)

100 (379)

FULL

LOAD

2400

2000

1600

1200

800

400

0

25

20

15

10

5

0

160

140

120

100

80

60

40

20

0 1000 2000 3000

2500

2250

2000

1750

1500

12501000

750

500

250

0

0

40

35

30

25

20

15

10

5

0

gpm (lpm)

250 (950)

200 (760)

150 (570)

100 (380)


41/55



BendSetting


TwoStabilizers


Deg

0.39

0.78

1.15

1.501.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.2

3.2

5.4

7.69.6

11.4

13.0

14.3

15.3

16.1

16.6

16.8

1.4

2.4

4.1

6.38.3

10.0

11.6

12.9

14.0

14.7

15.2

15.3

1.2

2.4

3.6

5.77.7

9.5

11.1

12.4

13.4

14.1

14.6

14.8

2.2

4.3

6.2

8.19.8

11.4

13.0

14.3

15.3

16.1

16.6

16.8

2.5

4.6

6.5

8.310.1

11.6

12.9

14.1

15.0

15.6

16.0

16.2

2.6

4.7

6.6

8.410.1

11.6

13.0

14.1

15.0

15.7

16.1

16.2

1.6

3.9

6.1

8.19.8

11.4

13.0

14.3

15.3

16.1

16.6

16.8

1.6

3.9

6.1

8.110.1

11.6

12.9

14.1

15.0

15.6

16.0

16.2

1.6

3.9

6.1

8.110.1

11.6

13.0

14.1

15.1

15.7

16.1

16.2

8 3/48 1/2

0.0

2.5

5.0

7.5

10.0

12.5

15.0

17.5

20.0

22.5

25.0

27.5

30.0


TwoStabilizers


HoleCurvature

3.00

3.00

2.60

2.12

1.83

1.50

1.15

0.78

0.39

0.00

3.00

3.00

3.00

2.60

2.12

1.83

1.50

1.15

0.78

0.39

0.00

3.00

3.00

3.00

2.77

2.38

2.12

1.50

1.15

0.78

0.39

0.39

0.00

2.60

2.12

1.83

1.50

1.50

1.15

0.39

0.00

3.00

2.89

2.38

1.83

1.50

1.15

0.39

0.00

3.00

2.89

2.38

1.83

1.50

1.15

0.78

0.00

2.38

2.12

1.83

1.15

1.15

0.78

0.39

0.00

3.00

2.60

2.12

1.50

1.15

0.78

0.39

0.00

3.00

2.60

2.12

1.50

1.15

0.78

0.39

0.00

E

AD

B

C

6 1/4 7/8 M/L 2.9 StageA 2.3ft (0.7 m)

B 6.6 ft (2.01m)

C 28 ft (8.53m)


7.12 in (181 mm)


Common Top Connection: 4 1/2 REG 4 1/2 XH4 1/2 H-90



4/388/77 8 1/2 4/388/77 8 1/27 7/8

8 3/48 1/27 7/8 8 3/48 1/27 7/8 8 3/48 1/27 7/8


42/55

kPa

psi

SPEED:RPM

TORQU

E:lb-ft

OUTPUTPOWER:HP

TORQUE:N.m

OUTPUTPOWER:k

w


Maximum Pump Rate



Torque at Full Load



gpm

rev/gal

psi

lb-ft

lbs

lbslbs

500

0.17

380

5,590

87,000

215,000

642,000

lpm

rev/l

kPa

Nm

kN

kN

kN

1890

0.045

2620

7574

390

970

2890

61/4

7/8M/

L2.9

Sta

ge

gpm (lpm)

FULL

LOAD

60

50

40

30

20

10

0

12000

10000

8000

6000

4000

2000

0


0 1000 2000 3000 4000

0 100 200 300 400 500 600

90

80

70

60

50

40

30

20

10

0

10000

9000

8000

7000

6000

50004000

3000

2000

1000

0

90

80

70

60

50

40

30

20

10

0

500 (1890)

400 (1510)

300 (1140)

200 (760)

gpm (lpm)

500 (1890)

400 (1510)

300 (1140)

200 (760)


43/55



BendSetting


TwoStabilizers


Deg

0.39

0.78

1.15

1.501.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.3

3.3

5.7

7.910.0

11.9

13.6

15.0

16.1

16.8

17.3

17.5

1.4

2.5

4.3

6.68.7

10.5

12.1

13.5

14.6

15.4

15.9

16.1

1.2

2.5

3.8

6.08.1

9.9

11.6

13.0

14.0

14.8

15.3

15.5

2.4

4.5

6.5

8.410.0

11.9

13.6

15.0

16.1

16.8

17.3

17.5

2.7

4.8

6.8

8.710.5

12.1

13.5

14.7

15.6

16.2

16.7

16.8

2.8

4.9

6.9

8.810.6

12.1

13.5

14.7

15.6

16.3

16.7

16.9

1.7

4.1

6.3

8.410.2

11.9

13.6

15.0

16.1

16.8

17.3

17.5

1.7

4.1

6.3

8.410.5

12.1

13.5

14.7

15.6

16.2

16.7

16.8

1.7

4.1

6.3

8.410.5

12.1

13.5

14.7

15.6

16.3

16.7

16.9

8 3/48 1/2

0.0

2.5

5.0

7.5

10.0

12.5

15.0

17.5

20.0

22.5

25.0

27.5

30.0


TwoStabilizers


HoleCurvature

3.00

3.00

2.60

2.12

1.83

1.50

1.15

0.78

0.39

0.00

3.00

3.00

3.00

2.60

2.12

1.83

1.50

1.15

0.78

0.39

0.00

3.00

3.00

3.00

2.77

2.38

2.12

1.50

1.15

0.78

0.39

0.39

0.00

2.60

2.12

1.83

1.50

1.15

0.78

0.39

0.00

3.00

2.77

2.38

1.83

1.50

1.15

0.39

0.00

3.00

2.77

2.38

1.83

1.50

1.15

0.78

0.00

2.38

2.12

1.50

1.15

1.15

0.78

0.39

0.00

2.89

2.38

2.12

1.50

1.15

0.78

0.39

0.00

3.00

2.38

2.12

1.501.15

0.78

0.39

0.00

E

AD

B

C

6 1/4 7/8 M/L 4.8 StageA 2.3ft (0.7 m)

B 6.6 ft (2.01m)

C 26.6 ft (8.11m)


7.12 in (181 mm)


Common Top Connection: 4 1/2 REG 4 1/2 XH4 1/2 H-90




4/388/77 8 1/2 4/388/77 8 1/27 7/8

8 3/48 1/27 7/8 8 3/48 1/27 7/8 8 3/48 1/27 7/8


44/55

0 1000 2000 3000 4000 5000 6000

0 200 400 600 800 1000


kPa

psi

SPEED:RPM

TORQUE:lb-ft

OUTPUTPOWER:HP

TORQ

UE:N.m

OUTPUTPOWER:kw


Maximum Pump Rate



Torque at Full Load



gpm

rev/gal

psi

lb-ft

lbs

lbslbs

400

0.35

620

4,840

87,000

215,000642,000

lpm

rev/l

kPa

Nm

kN

kNkN

1510

0.092

4270

6558

390

9702890

61/4

7/8M/

L4.8

Sta

ge

gpm (lpm)

400 (1510)

320 (1210)

240 (910)

160 (910)

FULL

LOAD

gpm (lpm)

8000

7000

6000

5000

40003000

2000

1000

0

140

120

100

80

60

40

20

0

150

125

100

75

50

25

0

10000

8000

6000

4000

2000

0

400 (1510)

320 (1210)

240 (910)

160 (910)

100

80

60

40

20

0


45/55



BendSetting


TwoStabilizers


Deg

0.39

0.78

1.15

1.50

1.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.6

3.6

6.5

9.3

11.9

14.3

16.3

18.1

19.5

20.4

21.0

21.3

1.9

3.1

5.8

8.6

11.2

13.5

15.6

17.4

18.7

19.7

20.3

20.5

1.5

3.0

4.5

5.8

8.2

10.4

12.4

14.1

15.5

16.4

17.0

17.2

3.1

5.6

8.0

10.3

11.9

14.3

16.3

18.1

19.5

20.4

21.0

21.3

3.3

5.8

8.2

10.4

12.6

14.4

15.6

17.4

18.7

19.7

20.3

20.5

4.2

6.6

8.9

11.1

13.2

15.0

16.7

18.0

19.1

19.9

20.4

20.5

1.9

4.7

7.5

10.0

12.4

14.3

16.3

18.1

19.5

20.4

21.0

21.3

1.9

4.8

7.5

10.0

12.4

14.4

16.1

17.5

18.7

19.7

20.3

20.5

1.9

4.8

7.5

10.0

12.4

14.5

16.4

18.0

19.1

19.9

20.4

20.5

8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8

0.0

3.5

7.0

10.514.0

17.5

21.0

24.5

28.0

31.5

35.0

38.5

42.0


TwoStabilizers


8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/4

HoleCurvature

3.00

2.60

2.38

1.831.50

1.15

0.78

0.39

0.00

3.00

2.89

2.38

2.121.83

1.15

0.78

0.39

0.00

0.00

3.00

3.00

3.00

2.892.38

2.12

1.83

1.15

0.78

0.39

0.39

0.00

2.60

2.12

1.15

0.780.39

0.00

2.77

1.83

1.50

0.780.39

0.00

2.60

2.12

1.50

1.150.39

0.00

2.12

1.83

1.15

0.390.00

2.38

1.50

1.15

0.390.00

2.12

1.50

1.15

0.390.00

E

AD

B

C

6 3/4 7/8 M/L 3.0 StageA 2.3ft (0.7 m)

B 6.6 ft (2.01m)

C 20 ft (6.1 m)


7.63 in (194 mm)







46/55

kPa

psi

SPEED:RPM

TORQU

E:lb-ft

OUTPUTPOWER:HP

TORQUE:N

.m

OUTPUTPOWER:k

w


Maximum Pump Rate



Torque at Full Load



gpm

rev/gal

psi

lb-ft

lbs

lbslbs

600

0.28

390

3,490

122,000

277,000

672,000

lpm

rev/l

kPa

Nm

kN

kN

kN

2270

0.074

2690

4792

550

1250

3020

63/4

7/8M/L3.0

Sta

ge

gpm (lpm)

600 (2270)

500 (1890)

400 (1510)

300 (1140)

FULL

LOAD

gpm (lpm)

600 (2270)

500 (1890)

400 (1510)

300 (1140)

140

120

100

80

60

40

20

0

100

90

80

70

60

50

40

30

20

10

0

8000

7000

6000

5000

4000

3000

2000

1000

0


0 1000 2000 3000 4000

0 100 200 300 400 500 600

180

160

140

120

100

80

60

40

20

0

6000

5000

4000

3000

2000

1000

0


47/55



BendSetting


TwoStabilizers


Deg

0.39

0.78

1.15

1.50

1.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.6

3.6

6.5

9.3

11.9

14.3

16.3

18.1

19.5

20.4

21.0

21.3

1.9

3.1

5.8

8.6

11.2

13.5

15.6

17.4

18.7

19.7

20.3

20.5

1.5

3.0

4.5

5.8

8.2

10.4

12.4

14.1

15.5

16.4

17.0

17.2

3.1

5.6

8.0

10.3

11.9

14.3

16.3

18.1

19.5

20.4

21.0

21.3

3.3

5.8

8.2

10.4

12.6

14.4

15.6

17.4

18.7

19.7

20.3

20.5

4.2

6.6

8.9

11.1

13.2

15.0

16.7

18.0

19.1

19.9

20.4

20.5

1.9

4.7

7.5

10.0

12.4

14.3

16.3

18.1

19.5

20.4

21.0

21.3

1.9

4.8

7.5

10.0

12.4

14.4

16.1

17.5

18.7

19.7

20.3

20.5

1.9

4.8

7.5

10.0

12.4

14.5

16.4

18.0

19.1

19.9

20.4

20.5

8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8

0.0

3.5

7.0

10.514.0

17.5

21.0

24.5

28.0

31.5

35.0

38.5

42.0


TwoStabilizers


8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/4

HoleCurvature

3.00

2.60

2.38

1.831.50

1.15

0.78

0.39

0.00

3.00

2.89

2.38

2.121.83

1.15

0.78

0.39

0.00

0.00

3.00

3.00

3.00

2.892.38

2.12

1.83

1.15

0.78

0.39

0.39

0.00

2.60

2.12

1.15

0.780.39

0.00

2.77

1.83

1.50

0.780.39

0.00

2.60

2.12

1.50

1.150.39

0.00

2.12

1.83

1.15

0.390.00

2.38

1.50

1.15

0.390.00

2.12

1.50

1.15

0.390.00

E

AD

B

C

6 3/4 7/8 M/L 3.0 StageHRA 2.3ft (0.7 m)

B 6.6 ft (2.01m)

C 20 ft (6.1 m)


7.63 in (194 mm)







48/55

kPa

psi

SPEED:RPM

TORQU

E:lb-ft

OUTPUTPOWER:HP

TORQUE:N

.m

OUTPUTPOWER:k

w


Maximum Pump Rate



Torque at Full Load



gpm

rev/gal

psi

lb-ft

lbs

lbslbs

600

0.28

680

6,280

122,000

277,000

672,000

lpm

rev/l

kPa

Nm

kN

kN

kN

2270

0.074

4650

8510

550

1250

3020

63/47/8

M/L

3.0S

tage

HR

gpm (lpm)

600 (2270)

500 (1890)

400 (1510)

300 (1140)

FULL

LOAD


0 1000 2000 3000 4000

0 100 200 300 400 500 600 700 800

180

160

140

120

100

80

60

40

20

0

0

8000

7000

6000

5000

40003000

2000

1000

80007000

60005000

4000

3000

2000

1000

9000

10000

1100012000

0

gpm (lpm)

600 (2270)

500 (1890)

400 (1510)

300 (1140)

240

200

160

120

80

40

0

160

140

120

100

80

60

40

20

0


49/55



BendSetting


TwoStabilizers


Deg

0.39

0.78

1.15

1.50

1.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.1

2.3

4.3

6.3

8.1

9.7

11.1

12.3

13.2

13.9

14.3

14.5

1.2

2.1

3.9

5.8

7.6

9.2

10.6

11.8

12.8

13.4

13.8

14.0

1.1

2.4

3.1

4.0

5.6

7.1

8.5

9.7

10.6

11.3

11.7

11.9

2.0

3.8

5.6

7.3

8.9

10.3

11.5

12.6

13.2

13.9

14.3

14.5

2.1

3.9

5.7

7.4

8.9

10.3

11.6

12.6

13.4

14.0

14.4

14.5

2.5

4.3

6.0

7.7

9.2

10.6

11.8

12.9

13.7

14.2

14.6

14.7

1.5

3.5

5.5

7.3

8.9

10.3

11.5

12.6

13.4

13.9

14.3

14.5

1.5

3.5

5.5

7.4

8.9

10.3

11.6

12.6

13.4

14.0

14.4

14.5

1.5

3.5

5.5

7.4

9.1

10.6

11.8

12.9

13.7

14.2

14.6

14.7

8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8

0.0

2.5

5.0

7.5

10.0

12.5

15.0

17.5

20.0

22.5

25.0

27.5

30.0


TwoStabilizers


8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/8 8 1/2 8 3/4 9 7/4

HoleCurvature

3.00

3.00

3.00

2.60

2.12

1.83

1.15

0.78

0.39

0.00

3.00

3.00

3.00

2.77

2.38

1.83

1.50

1.15

0.78

0.39

0.00

3.00

3.00

3.00

3.00

3.00

2.38

2.12

1.50

1.15

0.78

0.39

0.00

3.00

2.60

1.83

1.50

1.15

0.39

0.00

3.00

2.38

1.83

1.50

1.15

0.39

0.00

3.00

2.60

2.12

1.50

1.15

0.39

0.00

2.89

2.38

2.12

1.15

0.78

0.39

0.00

3.00

2.38

1.83

1.15

0.78

0.39

0.00

2.77

2.12

1.83

1.150.78

0.39

0.00

E

A

D

B

C

6 3/4 7/8 M/L 3.5 StageA 2.3ft (0.7 m)

B 6.6 ft (2.01m)

C 30.1 ft (9.54 m)


7.63 in (194 mm)







50/55

0 1000 2000 3000 4000 kPa

psi

SPEED:RPM

TORQUE:lb-ft

OUTPUTPOWER:HP

TORQ

UE:N

.m

OUTPUTPOWER:k

w


Maximum Pump Rate



Torque at Full Load



gpm

rev/gal

psi

lb-ft

lbs

lbslbs

600

0.15

460

7,830

122,000

277,000672,000

lpm

rev/l

kPa

Nm

kN

kNkN

2270

0.040

3170

10610

550

12503020

63/4

7/8M/L3.5

Sta

ge

gpm (lpm)

FULL

LOAD

gpm (lpm)

160

140

120

100

80

60

40

20

0

100

80

60

40

20

0

16000

14000

12000

10000

8000

6000

4000

2000

0


0 100 200 300 400 500 600

100

90

80

70

60

50

40

30

2010

0

12000

10000

8000

6000

4000

2000

0

600 (2270)

500 (1890)

400 (1510)

300 (1140)

600 (2270)

500 (1890)

400 (1510)

300 (1140)


51/55



BendSetting


TwoStabilizers


Deg

0.39

0.78

1.15

1.501.83

2.12

2.38

2.60

2.77

2.89

2.97

3.00

1.3

2.8

5.2

7.49.6

11.5

13.2

14.6

15.7

16.5

17.0

17.2

1.5

2.5

4.6

6.99.0

10.9

12.6

14.0

15.1

15.9

16.4

16.6

1.2

2.5

3.6

4.86.6

8.4

10.1

11.4

12.5

13.3

13.8

14

Documents

DRT Motor Manual 6-16-10