03 - System Specifications Rev B

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
What changes during the drilling of a well that may affect the selection of an MWD system?

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Hole Size (Collar Size)
Mud Flow Rate
Mud Density
Formation Temperature
Bottom Hole Pressure

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Hole Size
Usually decreases with hole depth
Why?

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Hole Size
Usually decreases with hole depth
Why?
Casing or liner is run to isolate shallower hole sections.
A smaller diameter drill bit is then required to pass through the casing.
Smaller diameter drill collars are used.

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
12 1/4 Inch
Hole
9 5/8 Inch
Casing
8 1/2 Inch
Hole

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Hole Size
12 1/4 inch hole
8 inch collars
Select
650 or 1200 System
8 1/2 inch hole
6-3/4 inch collars
Select
650 system

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Mud Flow Rate
Usually decreases with hole depth
Why?

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Mud Flow Rate
Usually decreases with hole depth
Why?
As hole diameter decreases less flow is required to clean the hole.
As hole depth increases circulating pressure also increases
Flow is reduced to keep the circulating pressure within limits.

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Flow Rate
12 1/4 inch hole
8 inch collars
850 gpm
Select
1200 System
8 1/2 inch hole
6-3/4 inch collars
620 gpm
Select
650 system

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Mud Density
Changes with hole conditions
Why?

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Mud Density
Changes with hole conditions
Why?
Mud density is adjusted to balance the formation pressure.
It usually increases with depth, but may decrease again after casing is set.

© 2001, Halliburton Energy Services, Inc.
March 7, 2001

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Mud Density
12 1/4 inch hole
8 inch collars
850 gpm
12 ppg
Select
1200 System
8 1/2 inch hole
6-3/4 inch collars
620 gpm
13 ppg
Select
650 system

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Temperature
Increases with true vertical depth
Why?

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Temperature
Increases with true vertical depth
Why?
Due to conductance of heat from earth’s core to surface.
Temperature increases between 0.5°-5°C per 100 m, average 2.5°C per 100 m
Temperature increases between 0.25°-2.5°F per 100 ft, average 1.5°F per 100 ft

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Temperature
Affects the selection of: Pulser

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Pulser Temperature Ratings

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Temperature
12 1/4 inch hole
8 inch collars
850 gpm
12 ppg
100° C at 10,000 ft
Select
1200 System
Any pulser
8 1/2 inch hole
6-3/4 inch collars
620 gpm
13 ppg
145° C at 14,000 ft
Select
650 system
Any pulser

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Temperature
Affects the selection of:
Pulser
Directional sensor

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Directional Sensor Temperature Ratings

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Temperature
12 1/4 inch hole
8 inch collars
850 gpm
12 ppg
100° C at 10,000 ft
Select
1200 System
Any pulser
Any directional probe
8 1/2 inch hole
6-3/4 inch collars
620 gpm
13 ppg
145° C at 14,000 ft
Select
650 System
Any pulser
Do not use DEP/DEPII

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Temperature
Affects the selection of:
Pulser
Directional sensor
Gamma sensor

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Gamma Sensor Temperature Ratings

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Temperature
12 1/4 inch hole
8 inch collars
850 gpm
12 ppg
100° C at 10,000 ft
Select
1200 System
Any pulser
Any directional probe
Any gamma sensor
8 1/2 inch hole
6-3/4 inch collars
620 gpm
13 ppg
145° C at 14,000 ft
Select
650 System
Any pulser
Do not use DEP/DEPII
Any gamma sensor

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Pressure
Two components
Hydrostatic Pressure
Circulating Pressure

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Hydrostatic Pressure
Increases with true vertical depth
Increases with increases in mud density
Why?

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Hydrostatic Pressure
Increases with true vertical depth
Increases with increases in mud density
Why?
Pressure = 0.052 x TVD (ft) x Mud Density (ppg)

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Circulating Pressure
Increases with hole depth.
Increases with increases in flow rate.
Increases with increases in Mud Density, PV, YP.
Increases with decreases in flow area of drillstring, jets, and annulus.

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Pressure
What pressure is the tool exposed to?

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Pressure
What pressure is the tool exposed to?
Hydrostatic Pressure plus the following circulating pressure losses:
Pressure loss in the BHA below the tool
Pressure loss at the jets
Pressure loss in the annulus

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Sensor Pressure Ratings
Sondes are limited by pressure case.
Superslim pressure cases have molded on centralizers, hence thinner walls, lower pressure rating.

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Sensor Pressure Ratings
* Unofficial pressure rating
System Specifications

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Pressure
12 1/4 inch hole
8 inch collars
850 gpm
12 ppg
100° C at 10,000 ft
6,240 hyd + 1,500 circ
Select
1200 System
Any pulser
Any directional probe
Any gamma sensor
8 1/2 inch hole
6-3/4 inch collars
620 gpm
13 ppg
130 ° C at 14,000 ft
9,464 hyd + 1,200 circ
Select
650 System
Any pulser
Do not use DEP/DEPII
Any gamma sensor

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
What other specifications are important?
Dogleg Severity
Sand Content
Plastic Viscocity
Lost Circulation Material
Tool Joint Torque

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Dogleg Severity
Rotating is the worst situation

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Sand Content
Less than 2%, recommended less than 1%.
Above 1100 gpm limited to 1% or less.
Plastic Viscosity
Maximum 50 centipoise

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Lost Circulation Material (LCM)
40 lb/bbl medium non-fibrous (nut plug) and some fine fibrous (kwik seal)
Superslim is less tolerant to LCM
Straight flow sub less than 7.5 lb/bbl
Undercut flow sub greater than 7.5 lb/bbl

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Tool Joint Torque
Pin ID on positive pulse 1500, 1200, 650 System HOS/HOC’s are bored-out.
Use torque specifications for standard sizes
For Pin ID 2.88 inch, use 2-13/16 inch
For Pin ID 3.31 inch, use 3-1/4 inch
For Pin ID 4.04 inch, use 4 inch

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Sensor Measure Point
Used to calculate sensor to bit distance
Surveys referenced to where measurements made, not to bit
Gamma referenced to where measurements made, not to bit

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Sensor to bit distance - DEP

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Sensor Measure Point – DEP2

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Sensor Measure Point - PCD

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Sensor Measure Point - PCG

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Sensor Measure Point – PCD
Metric Units

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
Sensor Measure Point – PCG
Metric Units

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
Tool Joint Torque
How do we apply it correctly?
For example:
8 inch collar
6-5/8 API Regular Connection
3-1/4 inch pin bore
47,000 ft-lb Torque
4 foot tongs

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
47,000 ft-lb Torque
Single line
Pull angle 90°
Pull of 11,750 lbs
Torque = 47,000 ft-lb
4 feet
11,750 lb
Tongs
Collar

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
47,000 ft-lb Torque
Double line
Pull angle 90°
Pull of 5,875 lbs
Torque = 47,000 ft-lb
4 feet
5,875 lb
Tongs
Collar

© 2001, Halliburton Energy Services, Inc.
March 7, 2001
System Specifications
47,000 ft-lb Torque
Double line
Pull angle 42°
Pull of 5,875 lbs
Torque = 35,250 ft-lb
3 feet
5,875 lb
Tongs
Collar