NOTE: Since Rate of Penetration (Item 1.13) and Weight-On-Bit values (Item 1.16 & 1.17) are only meaningful during activities where the bit is actively "on bottom", a value should only be present under certain rig activity codes, those being:
2. Drilling 4. Reaming 5. Hole Opening 6. Coring 20. Drilling Cement
At other times, a NULL value should be placed in these fields.
1.1 Well Identifier
Number/name assigned to the well by the operator for identification purposes. This item is common to all
records. This includes a four-character code identifying the SENDER.
1.2 Sidetrack/Hole Section Number
Number of the sidetrack being drilled at the time the computer generated the record. Prior to having a
sidetrack, this number is always 0. The sidetrack number indexes at the time drilling new formation
commences (not while drilling the cement plug). This item is common to all records.
1.3 Record Identifier
Logical data record type identifier. This item is common to all records and, for current Pre-Defined
Records,
contains a value between 1 and 25, according to the record type. Types 26 through 49 inclusive are
reserved for future expansion of the Pre-Defined records. Types 50 through 80 inclusive are open for
Custom user definition. NOTE that the Logical Record Type for a record is this number plus 150, thus
WITS Record 1 is Logical Record Type 151, WITS Record 2 is Logical Record Type 152, etc.
1.4 Sequence Identifier
Indicates the number of times this record has been generated (it is not reset to zero for a sidetrack). The
computer should automatically increase the number by one each time it creates a new record. This item
is common to all records. The sequence identifier in each individual record type keeps track of the count
for that particular record only. Thus there is a sequence identifier for each record type used.
1.5 Date
Indicates the date the computer generated this record. The date is reported as a 6 digit integer in a
YYMMDD type format. e.g. 910404 would represent April 4, 1991. It is common to all records. Note that,
like Time below, Universal Coordinated Time (Greenwich Mean Time) is used as the common reference.
Note also that though this number should never decrease, there is no guarantee of this fact.
1.6 Time
Indicates the time of day (24 hour clock), when the computer generated the record, eg. 225015 would
represent 10:50:15 pm. This item is common to all records. Note that, like Date above, Universal
Coordinated Time (Greenwich Mean Time) is used as the common reference.
1.7 Activity Code
Code indicating what activity is currently being performed on the rig. IT IS ESSENTIAL that this information
be as accurate and current as possible. Acceptible codes are shownhere
1.8 Depth Bit - Meas
Measured depth of the bit at the time the record is generated. This is the measured depth of the shoe
when running casing or liner.
1.9 Depth Bit - Vert
Vertical depth of the bit at the time the record is generated. This is the vertical depth of the shoe when
running casing or liner.
1.10 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
1.11 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
1.12 Block Position
Measured distance of the traveling block above the rotary table.
1.13 Rate of Penetration - Avg
Calculated rate of penetration, averaged over the interval, while on bottom, drilling new hole or reaming.
1.14 Hookload - Avg
Measured hookload, averaged over the specified interval or connection.
1.15 Hookload - Max
Maximum hookload, measured over the specified interval or connection.
1.16 Weight on Bit - Surface, Avg
Measured surface weight on the bit, averaged over the interval.
1.17 Weight on Bit - Surface, Max
Maximum surface weight on the bit, measured over the interval.
1.18 Rotary Torque - Surface, Avg
Measured rotary torque, averaged over the interval.
1.19 Rotary Torque - Surface, Max
Maximum rotary torque, measured over the interval.
1.20 Rotary Speed - Avg
Measured surface rotations per minute, averaged over the interval.
1.21 Stand Pipe Pressure - Avg
Measured stand pipe pressure, averaged over the interval.
1.22 Casing (Choke) Pressure - Avg
Measured casing (choke) pressure, averaged over the interval.
1.23 Pump Stroke Rate #1 - Avg
Stroke rate for Pump 1, averaged over the interval.
1.24 Pump Stroke Rate #2 - Avg
Stroke rate for Pump 2, averaged over the interval.
1.25 Pump Stroke Rate #3 - Avg
Stroke rate for Pump 3, averaged over the interval.
1.26 Tank Volume (active) - Avg
Cumulative volume of mud, indicated by sensors, in all of the active compartments, averaged over the
interval.
1.27 Tank Volume Change (active)
Net gain/loss of mud in all the active compartments since the Tank Volume Reset Time (Item 14 of Record
11).
1.28 Mud Flow Out % - Avg
Flow measured by a paddle or target type sensor and averaged over the interval, where 0 % = no flow,
100 % = full deflection of the sensor.
1.29 Mud Flow Out - Avg
Measured flow rate of the mud leaving the hole, averaged over the interval.
1.30 Mud Flow In - Avg
Measured/calculated flow rate of the mud entering the hole, averaged over the interval.
1.31 Mud Density Out - Avg
Density of the mud leaving the hole, averaged over the interval.
1.32 Mud Density In - Avg
Density of the mud entering the hole, averaged over the interval.
1.33 Mud Temperature Out - Avg
Temperature of the mud leaving the hole, averaged over the interval.
1.34 Mud Temperature In - Avg
Temperature of the mud entering the hole, averaged over the interval.
1.35 Mud Conductivity Out - Avg
Conductivity of the mud leaving the hole, averaged over the interval.
1.36 Mud Conductivity In - Avg
Conductivity of the mud entering the hole, averaged over the interval.
1.37 Pump Stroke Count - Cumulative
Cumulative strokes for all pumps since reset. Normally reset at a major change in rig activity, e.g. from
drilling to tripping, or as specified by the Operator.
1.38 Lag Strokes
Total strokes (based on the pump(s) currently operating) being used for lagging cuttings, using either the
calculation or tracer method.
1.39 Depth Returns - Meas
The measured hole depth (lagged depth) that corresponds to the depth of returning mud/cuttings sample.
1.40 Gas - Avg
Total combustible gas content in the returning mud sample, averaged over the interval.
1.41-1.45 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
2.1- 2.7 See item descriptions in Record 1
2.8 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
2.9 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
2.10 Rate of Penetration - Avg
Calculated rate of penetration, averaged over the interval.
2.11 Weight on Bit - Surface, Avg
Measured surface weight on the bit, averaged over the interval.
2.12 Hookload - Avg
Measured hookload, averaged over the specified interval or connection.
2.13 Stand Pipe Pressure - Avg
Measured stand pipe pressure, averaged over the interval.
2.14 Rotary Torque - Surface, Avg
Measured rotary torque, averaged over the interval.
2.15 Rotary Speed - Surface, Avg
Measured surface rotations per minute, averaged over the interval.
2.16 Bit Revolutions - Cumulative
Measured/calculated running total of the bit revolutions while on bottom. This does not include reaming
time. For a re-run bit, it is the total revolutions since the last trip.
2.17 Mud Density In - Avg
Density of the mud entering the hole, averaged over the interval.
2.18 ECD at Total Depth - Avg
Effective circulating density, at the current measured hole depth, of the fluids currently in the hole.
2.19 Mud Flow In - Avg
Measured/calculated flow rate of the mud entering the hole, averaged over the interval.
2.20 Mud Flow Out - Avg
Measured flow rate of the mud leaving the hole, averaged over the interval.
2.21 Mud Flow Out % - Avg
Flow measured by a paddle or target type sensor and averaged over the interval, where 0 % = no flow,
100 % = full deflection of the sensor.
2.22 Tank Volume (active) - Avg
Cumulative volume of mud, indicated by sensors, in all of the active compartments, averaged over the
interval.
2.23 Cost/Distance - Instantaneous
Average per distance cost to drill the interval since the last record was generated.
2.24 Cost/Distance - Cumulative
Cumulative per distance cost to drill from a specified point (i.e. normally the start of the current bit run) to
the current depth.
2.25 Bit Drilled Time
Total number of drilling hours on the current bit. This does not include reaming time. For a re-run bit, this
is only the time since the last full trip.
2.26 Bit Drilled Distance
Total distance drilled for the current bit run. For a re-run bit, this is only the distance drilled since the last
full trip.
2.27 Corr. Drilling Exponent
Calculated drilling exponent (Jordan & Shirley, with Rehm & McClendon correction) for the interval just
drilled.
2.28-2.36 Spares 1-9
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
3.1- 3.7 See item descriptions in Record 1
3.8 Depth Connection - Meas
Measured depth of the bit at the time the connection is made. This may or may not be the same as hole
measured depth.
3.9 Depth Connection - Vert
Vertical depth of the bit at the time the connection is made. This may or may not be the same as hole
vertical depth.
3.10 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
3.11 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
3.12 Elapsed Time - Bottom to Slips
Time interval between coming off bottom and setting the slips, for the current connection.
3.13 Elapsed Time - In Slips
Time interval between setting the slips and then releasing them, for the current connection.
3.14 Elapsed Time - Slips to Bottom
Time interval between releasing the slips and returning to bottom (setting weight on the bit), for the current
connection.
3.15 Elapsed Time - Pumps Off
Time interval between stopping the pumps and starting them again after the connection is made.
3.16 Running Speed Up - Max
Maximum upward velocity of the drillstring while picking up. This value is reset following transmission of
the record. It should always be a positive number. An appropriate sampling interval should be used to
eliminate spikes ( eg. 1 second).
3.17 Running Speed Down - Max
Maximum downward velocity of the drillstring while running into the hole. This value is reset following
transmission of the record. It should always be a positive number. An appropriate sampling interval should
be used to eliminate spikes ( eg. 1 second).
3.18 Hookload - Max
Maximum hookload, measured over the specified interval or connection.
3.19 String Weight - Rotating, Avg
Off bottom rotating string weight. This value should be updated at specified intervals while drilling. The
average should be based on the time interval of Record 1 and reset when Record 1 is generated.
This value should be obtained while in an off bottom mode and represents the free-hanging total buoyed
weight of the string plus blocks, compensator, etc., while the drilling fluid is circulating and the bit is rotating (if appropriate). It is included here as a reference against which the actual measured maximum hookload during the connection can be compared.
3.20 Torque - Makeup, Max
Maximum torque applied while making up the connection.
3.21 Torque - Breakout, Max
Maximum torque required to break out the connection.
3.22-3.26 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
4.1- 4.7 See item descriptions in Record 1
4.8 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
4.9 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
4.10 Depth Bit - Meas
Measured depth of the bit at the time the record is generated. This is the measured depth of the shoe
when running casing or liner.
4.11 Depth Bit - Vert
Vertical depth of the bit at the time the record is generated. This is the vertical depth of the shoe when
running casing or liner.
4.12 Mud Density In - Avg
Density of the mud entering the hole, averaged over the interval.
4.13 Mud Flow In - Avg
Measured/calculated flow rate of the mud entering the hole, averaged over the interval.
4.14 Stand Pipe Pressure - Avg
Measured standpipe pressure, averaged over the interval.
4.15 Plastic Viscosity
Measured plastic viscosity of the mud. Where this is manually entered, it's value should remain, rather than
being replaced by a NULL, until the next entry is made. The SENDER should enter NULL if the value is
no longer valid.
4.16 Yield Point
Measured yield point of the mud. Where this is manually entered, it's value should remain, rather than
being replaced by a NULL, until the next entry is made. The SENDER should enter NULL if the value is
no longer valid.
4.17 Pressure Loss - Bit
Calculated pressure differential across the bit.
4.18 Pressure Loss - String
Sum of the calculated frictional pressure losses inside the drillstring.
4.19 Pressure Loss - Annulus
Sum of the calculated frictional pressure losses in the annulus.
4.20 Pressure Loss - Surface
Sum of the calculated frictional pressure losses in the surface equipment.
4.21 Pressure Loss - Mud Motor
Calculated/measured pressure differential across the mud motor or turbine.
4.22 Pressure Loss - MWD Tool
Calculated/measured pressure differential across the MWD tool.
4.23 Pressure Loss - % at the Bit
Proportion of the total system pressure loss which occurs across the bit.
4.24 Bit Hydraulic Power
Calculated hydraulic horsepower generated by the flow of fluid through the bit nozzles.
4.25 Bit Hydraulic Power per Unit Area
Total hydraulic horsepower, as in 4.24, divided by the cross-sectional area of the bit.
4.26 Jet Impact Force
Force exerted on the bottom of the hole by the flow of fluid through the bit.
4.27 Jet Velocity
Calculated velocity of the drilling fluid as it exits the bit nozzles.
4.28 Annular Velocity - Min
Calculated minimum velocity of the drilling fluid in the annulus.
4.29 Annular Velocity - Max
Calculated maximum velocity of the drilling fluid in the annulus.
4.30 ECD at Total Depth
Effective circulating density, at the current hole measured depth, of the fluids currently in the hole.
4.31 ECD at Bit
Effective circulating density, at the current bit measured depth, of the fluids currently in the hole.
4.32 ECD at Casing Shoe
Effective circulating density, at the casing shoe measured depth, of the fluids currently in the hole.
4.33 Pump Hydraulic Power
Hydraulic power output of the pumps.
4.34 Calc/Observed Pressure Loss Ratio
Ratio of the sum of all the calculated pressure losses in the circulating system to the actual standpipe
pressure, expressed as a percentage.
4.35-4.39 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
5.1- 5.7 See item descriptions in Record 1
5.8 Depth Bit - Meas
Measured depth of the bit at the time the record is generated. This is the measured depth of the shoe
when running casing or liner.
5.9 Depth Bit - Meas
Vertical depth of the bit at the time the record is generated. This is the vertical depth of the shoe when
running casing or liner.
5.10 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
5.11 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
5.12 Trip Number
Sequential number assigned to all trips, as specified by the Operator.
5.13 In-Slips Status
In- or Out-of slips condition. "I" indicates that the slips are set, "O" indicates that the slips are out, at the
time that the record is generated.
5.14 Hookload - Avg
Measured hookload, averaged over the specified interval or connection.
5.15 Block Position
Measured distance above the rotary table of the traveling block.
5.16 Running Speed Up - Max
Maximum upward velocity of the drillstring while picking up. This value is reset following transmission of
the record. It should always be a positive number. An appropriate sampling interval should be used to
eliminate spikes ( eg. 1 second).
5.17 Running Speed Down - Max
Maximum downward velocity of the drillstring while running into the hole. This value is reset following
transmission of the record. It should always be a positive number. An appropriate sampling interval should
be used to eliminate spikes ( eg. 1 second).
5.18 Fill/Gain Volume - Observed, Cumulative
Cumulative volume of mud gained or lost from the trip tank on the current trip.
5.19-5.23 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
6.1- 6.7 See item descriptions in Record 1
6.8 Depth Bit - Meas
Measured depth of the bit at the time the record is generated. This is the measured depth of the shoe
when running casing or liner.
6.9 Depth Bit - Vert
Vertical depth of the bit at the time the record is generated. This is the vertical depth of the shoe when
running casing or liner.
6.10 Depth Hole - Meas
Measured depth of the hole at the time of the record is generated.
6.11 Depth Hole - Vert
Vertical depth of the hole at the time of the record is generated.
6.12 Trip Number
Sequential number assigned to all trips, as specified by the Operator.
6.13 Connections Done
Number of connections made on the current trip.
6.14 Connections Remaining
Number of connections remaining on the current trip.
6.15 Elapsed Time - In Slips
Elapsed in-slips time for the current connection.
6.16 Elapsed Time - Out of Slips
Elapsed out-of-slips time for the current connection.
6.17 Running Speed Up - Max
Maximum upward velocity of the drillstring while picking up. This value is reset following transmission of
the record. It should always be a positive number. An appropriate sampling interval should be used to
eliminate spikes ( eg. 1 second).
6.18 Running Speed Up - Avg
Average upward velocity of the drillstring while picking up. This value is reset following transmission of the record. It should always be a positive number. An appropriate sampling interval should be used to
eliminate spikes ( eg. 1 second).
6.19 Running Speed Down - Max
Maximum downward velocity of the drillstring while running into the hole. This value is reset following
transmission of the record. It should always be a positive number. An appropriate sampling interval should
be used to eliminate spikes ( eg. 1 second).
6.20 Running Speed Down - Avg
Average downward velocity of the drillstring while running into the hole. This value is reset following
transmission of the record. It should always be a positive number. An appropriate sampling interval should
be used to eliminate spikes ( eg. 1 second).
6.21 Hookload - Max
Maximum hookload, measured over the specified interval or connection.
6.22 Hookload - Min
Minimum hookload, measured over the specified interval or connection, while not in slips.
6.23 Hookload - Avg
Average hookload measured during the connection.
6.24 Torque - Makeup, Max
Maximum torque applied to makeup the connection.
6.25 Torque - Breakout, Max
Maximum torque required to break out the connection.
6.26 Fill/Gain Volume - Observed
Measured volume of mud gained in, or lost from, the trip tank due to the movement of the current stand
or joint.
6.27 Fill/Gain Volume - Expected
Calculated volume per stand or joint which should be gained or lost from the trip tank due to the movement
of the pipe.
6.28 Fill/Gain Volume - Observed, Cumulative
Cumulative volume of mud gained or lost from the trip tank on the current trip.
6.29 Fill/Gain Volume - Expected, Cumulative
Calculated cumulative volume of mud which should have been gained or lost from the trip tank on the
current trip.
6.30- 6.34 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
7.8 Depth Survey/Reading - Meas
Measured depth of the directional sensor at the time the measurement was taken.
7.9 Depth Survey/Reading - Vert
Vertical depth of the directional sensor at the time the measurement was taken.
7.10 Pass Number
Sequential number assigned to repeated survey runs over the same hole interval. Survey runs may be
a mix of MWD-derived surveys, multishot, etc. The original hole should have a pass number of 0. Any
new hole drilled should have a pass number of 0. Repeat survey sections in a hole should have the pass
number incremented by 1. Except for returning to 0 for new sections, the pass number will always
increment for each repeat section.
As an example:
A hole is drilled from 2000m to 4000m, using MWD-derived survey measurements, with pass number 0. It is decided to run a multishot survey over the section. The pass number is 1 for these surveys. New hole is again drilled from 4000m, once again using an MWD tool for survey measurements. The pass number returns to 0. After drilling to 5000m, it is decided to run another multishot survey from 2000m to 5000m. The pass number for this section is 2. Thus, for the interval 2000m to 5000m, the following passes exist: From 2000 - 4000m, pass 0, 1, 2 4000 - 5000m, pass 0, 2
7.11 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
7.12 Svy Type
Type of instrument used to take the measurement. Suggested types are:
MWD (1) (Measurement While Drilling) Mag-SS (2) (Magnetic Single Shot) Mag-MS (3) (Magnetic Multi Shot) Gyr-Free (4) (Gyro-Free) Gyr-Rate (5) (Gyro-Rate Integrating ) Inertial (6) (Inertial Navigation System)
Other types should be agreed upon between the two parties.
7.13 Svy Inclination
Borehole inclination measured by the directional sensor.
7.14 Svy Azimuth - Uncorrected
Borehole azimuth measured by the directional sensor relative to local magnetic north.
7.15 Svy Azimuth - Corrected
Borehole azimuth measured by the directional sensor relative to true north, i.e. corrected for declination.
7.16 Svy Magnetic Tool Face
Magnetic tool face measured by the directional sensor.
7.17 Svy Gravity Tool Face
Gravity tool face measured by the directional sensor.
7.18 Svy North-South Position
Distance, at the survey depth, that the axis of the hole lies north or south of the axis of the pre-defined
surface reference point. A positive number denotes north, a negative number south.
7.19 Svy East-West Position
Distance, at the survey depth, that the axis of the hole lies east or west of the axis of the pre-defined
surface reference point. A positive number denotes east, a negative number west.
7.20 Svy Dog Leg Severity
Rate of change of hole angle and/or direction evaluated between the current survey point and the next
shallowest survey point (for the current pass number).
7.21 Svy Rate of Walk
Measurement of the tendency of the drillstring to be displaced to the right or left of the intended well path.
7.22- 7.26 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
8.1- 8.7 See item descriptions in Record 1
8.8 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
8.9 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
8.10 Depth Bit - Meas
Measured depth of the bit at the time the record is generated.
8.11 Depth Bit - Vert
Vertical depth of the bit at the time the record is generated.
8.12 Pass Number
Sequential number assigned to repeated MWD logging runs over the same hole interval.
The original hole should have a pass number of 0. Any new hole drilled should have a pass number of
0. Repeat logging sections in a hole should have the pass number incremented by 1. Except for returning
to 0 for new sections, the pass number will always increment for each repeat section. As an example:
A hole is drilled from 2000m to 4000m with pass number 0. It is decided to repeat log the section from 3500m to 4000m. The pass number is 1 for this section. New hole is again drilled from 4000m. The pass number returns to 0. After drilling to 5000m, it is decided to relog the section from 3500m to 5000m. The pass number for this section is 2. Following this, another repeat log is taken from 4800m to 5000m. This pass is number 3.
Thus, for the interval 2000m to 5000m, the following passes exist:
From 2000 - 3500m, pass 0 3500 - 4000m, pass 0, 1, 2 4000 - 4800m, pass 0, 2 4800 - 5000m, pass 0, 2, 3
8.13 Depth Resistivity 1 Sensor - Meas
Measured depth of Resistivity sensor #1.
8.14 Depth Resistivity 1 Sensor - Vert
Vertical depth of Resistivity sensor #1.
8.15 Resistivity 1 Reading
Value of Resistivity sensor #1.
8.16 Resistivity 1 - Borehole Corr
Value of Resistivity sensor #1 corrected for borehole effects.
8.17 Depth Resistivity 2 Sensor - Meas
Measured depth of Resistivity sensor #2.
8.18 Depth Resistivity 2 Sensor - Vert
Vertical depth of Resistivity sensor #2.
8.19 Resistivity 2 Reading
Value of Resistivity sensor #2.
8.20 Resistivity 2 - Borehole Corr
Value of Resistivity sensor #2 corrected for borehole effects.
8.21 Depth Gamma Ray 1 Sensor - Meas
Measured depth of Gamma Ray sensor #1.
8.22 Depth Gamma Ray 1 Sensor - Vert
Vertical depth of Gamma Ray sensor #1.
8.23 Gamma Ray 1 Reading
Value of Gamma Ray sensor #1.
8.24 Gamma Ray 1 - Borehole Corr
Value of Gamma Ray sensor #1 corrected for borehole effects (normalized).
8.25 Depth Gamma Ray 2 Sensor - Meas
Measured depth of Gamma Ray sensor #2.
8.26 Depth Gamma Ray 2 Sensor - Vert
Vertical depth of Gamma Ray sensor #2.
8.27 Gamma Ray 2 Reading
Value of Gamma Ray sensor #2.
8.28 Gamma Ray 2 - Borehole Corr
Value of Gamma Ray sensor #2 corrected for borehole effects (normalized).
8.29 Depth Por 1 Sensor - Meas
Measured depth of Porosity sensor #1.
8.30 Depth Por 1 Sensor - Vert
Vertical depth of Porosity sensor #1.
8.31 Porosity Tool 1 Reading
Value of Porosity sensor #1.
8.32 Depth Por 2 Sensor - Meas
Measured depth of Porosity sensor #2.
8.33 Depth Por 2 Sensor - Vert
Vertical depth of Porosity sensor #2.
8.34 Porosity Tool 2 Reading
Value of Porosity sensor #2.
8.35 Downhole Fluid Temperature - Ann
Average fluid temperature measured outside the MWD collar.
8.36 Downhole Fluid Temperature - Pipe
Average fluid temperature measured inside the MWD collar.
8.37 Downhole Fluid Resistivity - Ann
Average fluid resistivity measured outside the MWD collar.
8.38 Downhole Fluid Resistivity - Pipe
Average fluid resistivity measured inside the MWD collar.
8.39 Depth Form Density Sensor - Meas
Measured depth of the Formation Density sensor.
8.40 Depth Form Density Sensor - Vert
Vertical depth of the Formation Density sensor.
8.41 Formation Density
Value of Formation Density measured by the MWD tool.
8.42 Depth Caliper Sensor - Meas
Measured depth of the Caliper sensor.
8.43 Depth Caliper Sensor - Vert
Vertical depth of the Caliper sensor.
8.44 Caliper
Value of the Caliper sensor.
8.45 Pore Pressure Grad - MWD
Computed formation pore pressure gradient, based exclusively on MWD readings, for the current depth.
8.46 Frac Pressure Grad - MWD
Computed formation fracture pressure gradient, based exclusively on MWD readings, for the current depth.
8.47- 8.55 Spares 1-9
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
9.1- 9.7 See item descriptions in Record 1
9.8 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
9.9 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
9.10 Depth Bit - Meas
Measured depth of the bit at the time the record is generated.
9.11 Depth Bit - Vert
Vertical depth of the bit at the time the record is generated.
9.12 Pass Number
Sequential number assigned to repeated MWD logging runs over the same hole interval.
The original hole should have a pass number of 0. Any new hole drilled should have a pass number of
0. Repeat logging sections in a hole should have the pass number incremented by 1. Except for returning
to 0 for new sections, the pass number will always increment for each repeat section. As an example:
A hole is drilled from 2000m to 4000m with pass number 0. It is decided to repeat log the section from 3500m to 4000m. The pass number is 1 for this section. New hole is again drilled from 4000m. The pass number returns to 0. After drilling to 5000m, it is decided to relog the section from 3500m to 5000m. The pass number for this section is 2. Following this, another repeat log is taken from 4800m to 5000m. This pass is number 3.
Thus, for the interval 2000m to 5000m, the following passes exist:
From 2000 - 3500m, pass 0 3500 - 4000m, pass 0, 1, 2 4000 - 4800m, pass 0, 2 4800 - 5000m, pass 0, 2, 3
9.13 Bottom-Hole Annulus Press
Pressure measured in the annulus, averaged over the interval.
9.14 Bottom-Hole Internal Press
Pressure measured inside the drillstring, averaged over the interval.
9.15 Downhole Weight on Bit - Avg
Measured downhole weight on bit, averaged over the interval.
9.16 Downhole Weight on Bit - Max
Maximum measured downhole weight on bit over the interval.
9.17 Downhole Torque - Avg
Measured downhole (bit) torque, averaged over the interval.
9.18 Downhole Torque - Max
Maximum measured downhole (bit) torque recorded over the interval.
9.19 Downhole Motor RPM
Average rotary speed of a downhole motor as measured by a MWD tool
over the interval.
9.20 Alternator Voltage
Alternator voltage of the MWD tool averaged over the interval.
9.21- 9.29 Spares 1-9
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
10.8 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
10.9 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
10.10 Depth Sample - Meas
Measured depth corresponding to the origin of the lagged cuttings.
10.11 Depth Sample - Vert
Vertical depth corresponding to the origin of the lagged cuttings.
10.12 Est. Form. Pore Press Grad.
Estimated formation pore pressure gradient at this depth, expressed as equivalent mud density.
10.13 Est. Form. Frac Press Grad.
Estimated formation fracture pressure gradient at this depth, expressed as equivalent mud density.
10.14 Est. Form. Overburden Pressure Grad.
Estimated overburden pressure gradient at this depth, expressed as equivalent mud density.
10.15 Est. Kick Tolerance
Estimated kick tolerance at this depth, based on zero influx and no trip margin (unless specified by the
Operator).
10.16 Max. Permitted SICP - Init
Initial maximum allowable Shut-In Casing Pressure at this depth, with the present mud density (assuming
no fluid influx into the borehole).
10.17 Connection Gas - Avg
Average value of connection gas since the last record was generated.
10.18 Connection Gas - Max
Maximum value of connection gas since the last record was generated.
10.19 Connection Gas - Last connection
Value of the last connection gas recorded.
10.20 Last Trip Gas
Trip gas recorded after the last trip.
10.21 Shale Density
The density of a representative shale sample taken from the cuttings, measured using a shale density kit.
10.22 Cuttings CEC
The shale factor or cation exchange capacity of a shale or clay sample, measured using the methylene
blue titration method.
10.23 Cavings %
That proportion of the cuttings which are interpreted to be cavings.
10.24 Corrected Drilling Exponent
The calculated drilling exponent (corrected) at the time the record is generated. (Jordan & Shirley drilling
exponent, with Rehm & McClendon correction for mud density/ECD)
10.25- 10.33 Spares 1-9
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
11.1- 11.7 See item descriptions in Record 1
11.8 Depth Hole - Meas
Measured depth of the hole at the time the record is generated.
11.9 Depth Hole - Vert
Vertical depth of the hole at the time the record is generated.
11.10 Tank Volume - Total, Avg
Total volume of mud, indicated by sensors in all the compartments, averaged over the interval.
11.11 Tank Volume - Active, Avg
Total volume of mud, indicated by sensors in all the ACTIVE compartments, averaged over the interval.
11.12 Tank Volume Change - Total
Net gain/loss of mud in all the compartments since the Tank Volume Reset Time indicated in 11.14.
11.13 Tank Volume Change - Active
Net gain/loss of mud in all the active compartments since the Tank Volume Reset Time indicated in 11.14.
11.14 Tank Volume Reset Time
Time that the tank volume change variables (11.12 & 11.13) were last zeroed. The time displayed is based
on a 24 hour clock. e.g. 225015 represents 10:50:15 pm. Dates and times are in Universal Coordinated
Time (Greenwich Mean Time).
11.15-
11.28 Tanks 1-14 Volumes
Volume of mud, indicated by sensors, in each of the designated compartments, averaged over the interval.
11.29 Trip Tank 1 Volume
Current volume of mud, indicated by a sensor, in trip tank 1 when the record is generated.
11.30 Trip Tank 2 Volume
Current volume of mud, indicated by a sensor, in trip tank 2 when the record is generated.
11.31- 11.35 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
12.8 Depth Chrom Sample - Meas
Measured hole depth corresponding to origin of the lagged sample.
12.9 Depth Chrom Sample - Vert
Vertical hole depth corresponding to origin of the lagged sample.
12.10 Date Chrom Sample
Date that the sample was processed by the chromatograph, e.g. 910404 represents April 4, 1991. Dates
and times are in Universal Coordinated Time (Greenwich Mean Time). This date is normally part of an
integrator report generated at the end of processing chromatograph signals.
12.11 Time Chrom Sample
Time based on a 24 clock, that the sample was processed by the chromatograph. e.g. 225015 represents
10:50:15 pm. Dates and times are in Universal Coordinated Time (Greenwich Mean Time). This time is
normally part of an integrator report generated at the end of processing chromatograph signals.
12.12 Methane - C1
Methane content of the sample.
12.13 Ethane - C2
Ethane content of the sample.
12.14 Propane - C3
Propane content of the sample.
12.15 Iso-Butane - IC4
Iso-Butane content of the sample.
12.16 Nor-Butane - NC4
Nor-Butane content of the sample.
12.17 Iso-Pentane - IC5
Iso-Pentane content of the sample.
12.18 Nor-Pentane - NC5
Nor-Pentane content of the sample.
12.19 Neo-Pentane - EC5
Neo-Pentane content of the sample.
12.20 Iso-Hexane - IC6
Iso-Hexane content of the sample.
12.21 Nor-Hexane - NC6
Nor-Hexane content of the sample.
12.22 Carbon Dioxide Content
Carbon dioxide content of the sample.
12.23 Acetylene
Acetylene content of the sample.
12.24- 12.28 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
13.1- 13.7 See item descriptions in Record 1
13.8 Depth Returns - Meas
Measured hole depth (lagged depth) corresponding to the depth of the returning mud/cuttings sample.
13.9 Depth Returns - Vert
Vertical hole depth (lagged depth) corresponding to the depth of the returning mud/cuttings sample.
13.10 Methane-C1 - Avg
Average methane content of the returning mud sample, over the interval.
13.11 Methane-C1 - Min
Minimum methane content of the returning mud sample, over the interval.
13.12 Methane-C1 - Max
Maximum methane content of the returning mud sample, over the interval.
13.13 Ethane-C2 - Avg
Average ethane content of the returning mud sample, over the interval.
13.14 Ethane-C2 - Min
Minimum ethane content of the returning mud sample, over the interval.
13.15 Ethane-C2 - Max
Maximum ethane content of the returning mud sample, over the interval.
13.16 Propane-C3 - Avg
Average propane content of the returning mud sample, over the interval.
13.17 Propane-C3 - Min
Minimum propane content of the returning mud sample, over the interval.
13.18 Propane-C3 - Max
Maximum propane content of the returning mud sample, over the interval.
13.19 Iso-Butane-IC4 - Avg
Average iso-butane content of the returning mud sample, over the interval.
13.20 Iso-Butane-IC4 - Min
Minimum iso-butane content of the returning mud sample, over the interval.
13.21 Iso-Butane-IC4 - Max
Maximum iso-butane content of the returning mud sample, over the interval.
13.22 Nor-Butane-NC4 - Avg
Average normal butane content of the returning mud sample, over the interval.
13.23 Nor-Butane-NC4 - Min
Minimum normal butane content of the returning mud sample, over the interval.
13.24 Nor-Butane-NC4 - Max
Maximum normal butane content of the returning mud sample, over the interval.
13.25 Iso-Pentane-IC5 - Avg
Average iso-pentane content of the returning mud sample, over the interval.
13.26 Iso-Pentane-IC5 - Min
Minimum iso-pentane content of the returning mud sample, over the interval.
13.27 Iso-Pentane-IC5 - Max
Maximum iso-pentane content of the returning mud sample, over the interval.
13.28 Nor-Pentane-nC5 - Avg
Average normal pentane content of the returning mud sample, over the interval.
13.29 Nor-Pentane-nC5 - Min
Minimum normal pentane content of the returning mud sample, over the interval.
13.30 Nor-Pentane-NC5 - Max
Maximum normal pentane content of the returning mud sample, over the interval.
13.31 Neo-Pentane - Avg
Average neo-pentane content of the returning mud sample, over the interval.
13.32 Neo-Pentane - Min
Minimum neo-pentane content of the returning mud sample, over the interval.
13.33 Neo-Pentane - Max
Maximum neo-pentane content of the returning mud sample, over the interval.
13.34 Iso-Hexane-IC6 - Avg
Average iso-hexane content of the returning mud sample, over the interval.
13.35 Iso-Hexane-IC6 - Min
Minimum iso-hexane content of the returning mud sample, over the interval.
13.36 Iso-Hexane-IC6 - Max
Maximum iso-hexane content of the returning mud sample, over the interval.
13.37 Nor-Hexane-NC6 - Avg
Average normal hexane content of the returning mud sample, over the interval.
13.38 Nor-Hexane-NC6 - Min
Minimum normal hexane content of the returning mud sample, over the interval.
13.39 Nor-Hexane-NC6 - Max
Maximum normal hexane content of the returning mud sample, over the interval.
13.40 Carbon Dioxide - Avg
Average carbon dioxide content of the returning mud sample, over the interval.
13.41 Carbon Dioxide - Min
Minimum carbon dioxide content of the returning mud sample, over the interval.
13.42 Carbon Dioxide - Max
Maximum carbon dioxide content of the returning mud sample, over the interval.
13.43 Acetylene - Avg
Average acetylene content of the returning mud sample, over the interval.
13.44- 13.48 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.
If the record is time-triggered only:
Average, minimum and maximum values for items in this record are based on the current time triggering
interval for this record and are reset following the transmission of this record.
14.1- 14.7 See item descriptions in Record 1
14.8 Depth Returns - Meas
Measured hole depth (lagged depth) corresponding to the origin of the returning mud/cuttings sample.
14.9 Depth Returns - Vert
Vertical hole depth (lagged depth) corresponding to the origin of the returning mud/cuttings sample.
14.10 Mud Density In - Lagd
For the returning mud sample, the density when it entered the hole. For use in differential comparisons.
14.11 Mud Density Out - Avg
Average density of the returning mud sample.
14.12 Mud Temperature In - Lagd
For the returning mud sample, the temperature when it entered the hole. For use in differential
comparisons.
14.13 Mud Temperature Out - Avg
Average temperature of the returning mud sample.
14.14 Mud Conductivity In - Lagd
For the returning mud sample, the conductivity when it entered the hole. For use in differential
comparisons.
14.15 Mud Conductivity Out - Avg
Average conductivity of the returning mud sample.
14.16 Hyd.Sulfide Hazard Potential - Avg
Total amount (in ppm) of H2S that could exist in the air above the mud, based on the measured pH and
pHS (14.17 & 14.18) concentrations.
14.17 Hyd.Sulfide pH - Avg
pH (percent concentration of H+ in the mud - ie. acidity/alkalinity) of the mud, as measured by a continuous
monitoring sensor. Range is 0 - 19.9.
14.18 Hyd.Sulfide pHS - Avg
14.19 Gas In - Lagd
14.20 Gas - Avg
14.21 Gas - Maximum
14.22 Carbon Dioxide - Avg
14.23 Hyd. Sulfide - Avg
14.24 Hyd. Sulfide - Max
14.25- 14.29 Spares 1-5
15.8 Depth Sample - Meas
15.9 Depth Sample - Vert
15.10 Description Type
15.12 Lith 1 %
15.13 Lith 1 Classification
15.14 Lith 1 Color
15.15 Lith 1 Texture
15.16 Lith 1 Hardness
15.17 Lith 1 Grain Size
15.18 Lith 1 Roundness
15.19 Lith 1 Sorting
15.20 Lith 1 Matrix/Cement
15.21 Lith 1 Accessories
15.22 Lith 1 Porosity
15.23 Lith 1 Permeability
15.24 Lith 2 Type
15.25 Lith 2 %
15.26 Lith 2 Classification
15.27 Lith 2 Color
15.28 Lith 2 Texture
15.29 Lith 2 Hardness
15.30 Lith 2 Grain Size
15.31 Lith 2 Roundness
15.32 Lith 2 Sorting
15.33 Lith 2 Matrix/Cement
15.34 Lith 2 Accessories
15.35 Lith 2 Porosity
15.36 Lith 2 Permeability
15.37 Lith 3 Type
15.38 Lith 3 %
15.39 Lith 3 Classification
15.40 Lith 4 Type
15.41 Lith 4 %
15.42 Lith 4 Classification
15.43 Lith 5 Type
15.44 Lith 5 %
15.45 Lith 5 Classification
15.46 Fossils
15.47 Composite Show
15.48 Bulk Density
15.49 Cuttings Gas
15.50 Calcimetry Calcite %
15.51 Calcimetry Dolomite %
15.52 Cuttings CEC
15.53 Cavings %
15.54 Shale Density
15.55- 15.59 Spares 1-5
16.8 Show Number
16.9 Show Interval - Top Depth, Meas
16.10 Show Interval - Top Depth, Vert
16.11 Show Interval - Bottom Depth, Meas
16.12 Show Interval - Bottom Depth, Vert
16.13 Show Lith Type
16.14 Show Lith Classification
16.15 Show Lith Color
16.16 Show Lith Texture
16.17 Show Lith Hardness
16.18 Show Lith Grain Size
16.19 Show Lith Roundness
16.20 Show Lith Sorting
16.21 Show Lith Matrix/Cement
16.22 Show Lith Accessories
16.23 Show Lith Porosity - Visible
16.24 Show Lith Porosity - Meas
16.25 Show Lith Permeability
16.26 Show Lith Stain Description
16.27 Show Lith Fluor Description
16.28 Show Lith Cut Description
16.29 Show Lith Cuttings Gas
16.30 Show Titrated Salinity
16.31 Show Mud Sample Methane
16.32 Show Mud Sample Ethane
16.33 Show Mud Sample Propane
16.34 Show Mud Sample Iso-Butane
16.35 Show Mud Sample Nor-Butane
16.36 Show Mud Sample Iso-Pentane
16.37 Show Mud Sample Nor-Pentane
16.38 Show Mud Sample Neo-Pentane
16.39 Show Mud Sample Iso-Hexane
16.40 Show Mud Sample Nor-Hexane
16.41 Show Comments
16.42- 16.46 Spares 1-5
17.1-
17.7 See item descriptions in Record 1
17.8 Depth Hole - Meas
17.9 Depth Hole - Vert
17.10 Depth of Casing Shoe - Meas
17.11 Depth of Casing Shoe - Vert
17.12 Pump Pressure
17.13 Hookload - Avg
17.14 Block Position
17.15 Cem Flow Rate In - Calc
17.16 Cem Flow Rate In - Meas
17.17 Cem Flow Rate Out - Meas
17.18 Cem Flow Out - %
17.19 Cem Fluid Density In - Avg
17.20 Cem Fluid Density Out - Avg
17.21 ECD at Casing Shoe
17.22 Cem Fluid Temperature In - Avg
17.23 Cem Fluid Temperature Out - Avg
17.24 Cem Stage Number
17.25 Depth Of DV Tool
17.26 Cem Fluid Type/Batch
17.28 Cem Individual Volume Pumped
17.29 Cem Cement Volume Pumped
17.30 Cem Total Volume Pumped
17.31 Cem Volume to Bump Plug
17.32 Cem No./Status of Plug(s)
17.33 Cem Job Type
18.1-
18.7 See item descriptions in Record 1
18.8 DST Identification
18.9 DST Interval Top Depth - Meas
18.10 DST Interval Top Depth - Vert
18.11 DST Interval Bottom Depth - Meas
18.12 DST Interval Bottom Depth - Vert
18.13 DST Tool Time
18.14 DST State of Well
18.15 DST Surface Pressure - Tubing
18.16 DST Surface Pressure - Casing
18.17 DST Surface Temperature - Tubing
18.18 DST Bottom Hole Pressure
18.19 DST Bottom Hole Temperature
18.20 DST Liquid Flow Rate
18.21 DST Gas Flow Rate
18.22 DST Total Flow Rate
18.23 DST Cum Liquid Production
18.24 DST Cum Gas Production
18.25 DST Cum Total Production
18.26 Hydrogen Sulfide
18.27- 18.31 Spares 1-5
19.8 Depth Hole - Meas
19.9 Depth Hole - Vert
19.10 No. Drill String Sections
NOTE: If there is only one section, DS Section 1 Length becomes -9999.0, and the remaining DS elements
(2-6) contain -9999.0. If there are two drillstring sections, DS Section 2 Length becomes -9999.0 and the
remaining DS elements (3-6) contain -9999.0, etc. The null value indicates that the section length will be
increasing during drilling (with the addition of new joints of pipe) and should be calculated by subtracting
actual section lengths from total depth.
19.11 DS Section 1 OD
19.12 DS Section 1 ID
19.13 DS Section 1 Tool Joint ID
19.14 DS Section 1 Tool Joint OD
19.15 DS Section 1 Mass/Length
19.16 DS Section 1 Length
19.17 DS Section 2 OD
19.18 DS Section 2 ID
19.19 DS Section 2 Tool Joint ID
19.20 DS Section 2 Tool Joint OD
19.21 DS Section 2 Mass/Length
19.22 DS Section 2 Length
19.23 DS Section 3 OD
19.24 DS Section 3 ID
19.25 DS Section 3 Tool Joint ID
19.26 DS Section 3 Tool Joint OD
19.27 DS Section 3 Mass/Length
19.28 DS Section 3 Length
19.29 DS Section 4 OD
19.30 DS Section 4 ID
19.31 DS Section 4 Tool Joint ID
19.32 DS Section 4 Tool Joint OD
19.33 DS Section 4 Mass/Length
19.34 DS Section 4 Length
19.35 DS Section 5 OD
19.36 DS Section 5 ID
19.37 DS Section 5 Tool Joint ID
19.38 DS Section 5 Tool Joint OD
19.39 DS Section 5 Mass/Length
19.40 DS Section 5 Length
19.41 DS Section 6 OD
19.42 DS Section 6 ID
19.43 DS Section 6 Tool Joint ID
19.44 DS Section 6 Tool Joint OD
19.45 DS Section 6 Mass/Length
19.46 Kelly ID
19.47 Kelly Length
19.48 Drill Pipe Stand Length
19.49 No. Joints/Stand
19.50 No. Hole Sections
NOTE: If there is only one section, Hole Section 1 Length becomes -9999.0, and the remaining Hole
Section elements (2-5) contain -9999.0. If there are two hole sections, Hole Section 2 Length becomes
-9999.0 and the remaining Hole Section elements (3-5) contain -9999.0, etc. The null value indicates that
the section length will be increasing during drilling (with the drilling of new hole) and should be calculated
by subtracting actual section lengths from total depth.
19.51 Hole Section 1 Diameter
19.52 Hole Section 1 Length
19.53 Hole Section 2 Diam
19.54 Hole Section 2 Length
19.55 Hole Section 3 Diam
19.56 Hole Section 3 Length
19.57 Hole Section 4 Diam
19.58 Hole Section 4 Length
19.59 Hole Section 5 Diam
19.60 Pump 1 Capacity
19.61 Pump 1 Efficiency
19.62 Pump 2 Capacity
19.63 Pump 2 Efficiency
19.64 Pump 3 Capacity
19.65 Pump 3 Efficiency
19.66 Rig Operating Cost/Hour
19.67 Trip Rate (Dist/Time)
19.68 Kill Line ID
19.69 Kill Line Joint ID
19.70 Kill Line Joint Fraction
19.71 Kill Line Length
19.72 Choke Line ID
19.73 Choke Line Joint ID
19.74 Choke Line Joint Fraction
19.75 Choke Line Length
19.76 Depth Casing Shoe - Meas
19.77 Depth Casing Shoe - Vert
19.78 Depth PIT - Meas
19.79 Depth PIT - Vert
19.80 Fracture Pressure Gradient at PIT
19.81 Drilling Contractor
19.82 Rig Name
19.83 Rig Type
19.84-
19.89 Vendor 1-6 Name/Service
19.90- 19.94 Spares 1-5
20.8 Mud Report Depth - Meas
20.9 Mud Report Depth - Vert
20.10 Mud Report Number
20.11 Mud Report Mud Type
20.12 Mud Report Sample Location
20.13 Mud Report Sample Date
20.14 Mud Report Sample Time
20.15 Mud Report Mud Density
20.16 Mud Report Funnel Viscosity
20.17 Mud Report Funnel Viscosity Temperature
20.18 Mud Report Plastic Viscosity
20.19 Mud Report Yield Point
20.20 Mud Report Gel - 10 sec
20.21 Mud Report Gel - 10 min
20.22 Mud Report Gel - 30 min
20.23 Mud Report Filtrate
20.24 Mud Report Filter Cake
20.25 Mud Report HTHP Temperature
20.26 Mud Report HTHP Pressure
20.27 Mud Report HTHP Filtrate
20.28 Mud Report HTHP Filter Cake
20.29 Mud Report Solids % - Retort
20.30 Mud Report Water % - Retort
20.31 Mud Report Oil % - Retort
20.32 Mud Report Sand %
20.33 Mud Report Low Gravity Solids %
20.34 Mud Report Solids % Calc
20.35 Mud Report Barite Content
20.36 Mud Report LCM Content
20.37 Mud Report MBT Capacity
20.38 Mud Report pH
20.39 Mud Report pH Sample Temp
20.40 Mud Report Pm
20.41 Mud Report Pf
20.42 Mud Report Mf
20.43 Mud Report P1
20.44 Mud Report P2
20.45 Mud Report Chloride Content
20.46 Mud Report Calcium Content
20.47 Mud Report Magnesium Content
20.48 Mud Report Potassium Content
20.49 Mud Report Rheometer Temperature
20.50 Mud Report Viscometer 3 RPM
20.51 Mud Report Viscometer 6 RPM
20.52 Mud Report Viscometer 100 RPM
20.53 Mud Report Viscometer 200 RPM
20.54 Mud Report Viscometer 300 RPM
20.55 Mud Report Viscometer 600 RPM
20.56 Mud Report Brine %
20.57 Mud Report Alkalinity
20.58 Mud Report Lime Content
20.59 Mud Report Electrical Stability
20.60 Mud Report CaCl - Wt %
20.61- 20.65 Spares 1-5
21.8 Bit Number
21.9 Bit Diameter
21.10 Bit Manufacturer
21.11 Bit Name
21.12 Bit IADC Code
21.13 Bit Serial Number
21.14 Bit Cost
21.15 Bit Jet 1 Diameter
21.16 Bit Jet 2 Diameter
21.17 Bit Jet 3 Diameter
21.18 Bit Jet 4 Diameter
21.19 Bit Center Jet Diameter
21.20 Bit Total Flow Area
21.21 Bit Starting Depth (Depth In)
21.22 Bit Ending Depth (Depth Out)
21.23 Bit Run Drilled Distance
21.24 Bit Run Drilled Time
21.25 Bit Reamed Time
21.26 Bit Run Penetration Rate Avg
21.27 Bit Run Weight On Bit Avg
21.28 Bit Run Weight On Bit Max
21.29 Bit Run Rotary Speed Avg
21.30 Bit Run Rotary Speed Max
21.31 Bit Run Mud Flow Rate Avg
21.32 Bit Run Mud Density Avg
21.33 Bit Run Stand Pipe Pressure Avg
21.34 Bit Reason Run
21.35 Bit Reason Pulled
21.36 Bit Grade In
21.37 Bit Grade Out
21.38 Bit Shock Sub Used ?
21.39 Bit Mud Motor Used ?
21.40 Bit Comments
21.41- 21.49 Spares 1-9
22.8 Depth Hole - Meas
22.9 Depth Hole - Vert
22.10 Comments
23.8 Well Name
23.9 Well Identification Number
23.10 Operator
23.11 Well Classification - Lahee
23.13 Well UTM Position
23.14 Well Surface Latitude
23.15 Well Surface Longitude
23.16 Field Name
23.17 Elevation : Datum Point-MSL
23.18 Elevation : Kelly Bushing-MSL
23.19 Elevation : Ground Level-MSL
23.20 Water Depth
23.21 Spud Date
23.22-
23.31 Custom Field Identifiers (01-10)
23.33 Time Zone Offset
23.34- 23.37 Spares 1-4
24.1-
24.7 See item descriptions in Record 1.
24.8 Water Depth - Mean
24.9 Tide
24.10 Vessel Heading
24.11 Rig VCG
24.12 Riser Tension
24.13 Rig Offset - Avg
24.14 Rig Offset - Max
24.15 Rig Offset Direction
24.16 LMRP Angle - Avg
24.17 LMRP Angle - Max
24.18 LMRP Direction
24.19 Fluid Density in Riser
24.20- (even numbers)
24.21- (odd numbers)
24.44- (even numbers)
24.45- (odd numbers)
24.60- 24.64 Spares 1-5
25.1-
25.7 See item descriptions in Record 1.
25.8 Water Depth - Mean
25.9 Air Temperature
25.10 Barometric Pressure
25.11 Waves - Significant Height
25.12 Waves - Maximum Height
25.13 Waves - Mean Period
25.14 Waves - Direction
25.15 Swell - Significant Height
25.16 Swell - Maximum Height
25.17 Swell - Mean Period
25.18 Swell - Direction
25.19 Wind Speed - 1 min.
25.20 Wind Gusts - 5 sec.
25.21 Wind Direction
25.22 Anemometer Height
25.23 Current Speed
25.24 Current Direction
25.25 Depth Current Measured
25.26 Vessel - Mean Draft
25.27 Heave - Peak to Peak - Significant
25.28 Heave - Peak to Peak - Max
25.29 Heave - Mean Period
25.30 Roll - Peak to Peak - Significant
25.31 Roll - Peak to Peak - Max
25.32 Roll - Mean Period
25.33 Pitch - Peak to Peak - Significant
25.34 Pitch - Peak to Peak - Max
25.35 Pitch - Mean Period
25.36 Yaw - Peak to Peak - Significant
25.37 Yaw - Peak to Peak - Max
25.38 Yaw - Mean Period
25.39 Surge - Peak to Peak - Significant
25.40 Surge - Peak to Peak - Max
25.41 Surge - Mean Period
25.42 Sway - Peak to Peak - Significant
25.43 Sway - Peak to Peak - Max
25.44 Sway - Mean Period
25.45 Trim
25.46 Heel
25.47 Weather / Sea State Comments
25.48- 25.52 Spares 1-5
pHS (percent concentration of HS-
For the returning mud sample, the flammable gas content when it entered the hole. For use in differential
comparisons.
Total combustible gas content in the returning mud sample, averaged over the interval.
Maximum combustible gas content in the returning mud sample, measured over the interval.
Carbon dioxide content of the returning mud sample, averaged over the interval.
Hydrogen sulfide content of the returning mud sample, averaged over the interval.
Maximum hydrogen sulfide content of the returning mud sample, measured over the interval.
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #15 : Cuttings/Lithology Record
15.1-
15.7 See item descriptions in Record 1
Measured depth of the hole corresponding to the origin of the lagged cuttings.
Vertical depth of the hole corresponding to the origin of the lagged cuttings.
Indicates whether the description is for cuttings, core or sidewall core samples:
Cuttings (1)
Core (2)
Sidewall (3)
15.11 Lith 1 Type
Type of the primary lithology present in the sample.
NOTE : If English abbreviations are to be used, it is recommended that those published by the AAPG be
followed (Reference 4)
Percentage of the sample which is composed of lithology 1.
Classification of lithology 1.
Color of lithology 1 present in the sample.
Texture of lithology 1 present in the sample.
Hardness or induration observed in lithology 1.
Average grain size observed lithology 1.
Degree of grain rounding observed in lithology 1.
Degree of sorting observed in lithology 1.
Type of matrix or cementing materials observed in lithology 1.
Chief accessory associated with lithology 1 in the sample.
Measured porosity of lithology 1.
Measured permeability of lithology 1.
Type of the secondary lithology present in the sample.
Percentage of the sample which is composed of lithology 2.
Classification of lithology 2.
Color of lithology 2 present in the sample.
Texture of lithology 2 present in the sample.
Hardness or induration observed in lithology 2.
Average grain size observed in lithology 2.
Degree of grain rounding observed in lithology 2.
Degree of sorting observed in lithology 2.
Type of matrix or cementing materials observed in lithology 2.
Chief accessory associated with lithology 2 in the sample.
Measured porosity of lithology 2.
Measured permeability of lithology 2 .
Type of lithology 3 present in the sample.
Percentage of the sample which is composed of lithology 3.
Classification of lithology 3.
Type of lithology 4 present in the sample.
Percentage of the sample which is composed of lithology 4.
Classification of lithology 4.
Type of lithology 5 present in the sample.
Percentage of the sample which is composed of lithology 5.
Classification of lithology 5.
Amount and/or type of fossils observed in the sample, especially if markers.
Overall hydrocarbon show quality, if any. e.g. GOOD, FAIR, TRACE, NONE, etc.
Density of a representative sample taken from the cuttings, using the bulk density method.
Amount of flammable gas released from a fixed volume of cuttings following pulverization in a blender.
Measured percentage of calcite present in the sample.
Measured percentage of dolomite present in the sample.
Shale factor, or cation exchange capacity, of a shale or clay sample, using the methylene blue titration
method.
Proportion of the cuttings which are interpreted to be cavings.
Density of a representative shale sample taken from the cuttings, measured using a shale density kit
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #16 : Hydrocarbon Show Record
16.1-
16.7 See item descriptions in Record 1
Sequential number assigned to consecutive show reports.
Measured depth of the top of the interval.
Vertical depth of the top of the interval.
Measured depth of the bottom of the interval.
Vertical depth of the bottom of the interval.
Type of the show lithology.
Classification of the show lithology.
Color of the show lithology.
Texture of the show lithology.
Hardness or induration observed for the show lithology.
Average grain size observed in the show lithology.
Degree of grain rounding observed in the show lithology.
Degree of sorting observed in the show lithology.
Type of matrix or cementing materials observed in the show lithology.
Chief accessory associated with the show lithology.
Observed (descriptive) porosity of the cuttings sample.
Measured porosity of the cuttings sample.
Measured permeability of the cuttings sample.
Amount, degree and color of staining observed in the sample, e.g. spotty, streaky, patchy, uniform, with
relevant color and intensity.
Type and amount of fluorescence observed in the sample.
Effects, under natural and Ultra-Violet light, of the addition of a solvent (e.g. Chlorothene), to the sample.
Measured cuttings gas concentration during the show.
Measured salinity of the mud filtrate from a sample taken during the show.
Amount of methane present in the gas extracted from the mud sample and injected into the chromatograph.
Alternatively, where a steam still is not used, this is the value of methane measured from the gas stream
at the peak of the show.
Amount of ethane present in the gas extracted from the mud sample and injected into the chromatograph.
Alternatively, where a steam still is not used, this is the value of ethane measured from the gas stream at
the peak of the show.
Amount of propane present in the gas extracted from the mud sample and injected into the chromatograph.
Alternatively, where a steam still is not used, this is the value of propane measured from the gas stream
at the peak of the show.
Amount of iso-butane present in the gas extracted from the mud sample and injected into the
chromatograph. Alternatively, where a steam still is not used, this is the value of iso-butane measured from
the gas stream at the peak of the show.
Amount of nor-butane present in the gas extracted from the mud sample and injected into the
chromatograph. Alternatively, where a steam still is not used, this is the value of nor-butane measured
from the gas stream at the peak of the show.
Amount of iso-pentane present in the gas extracted from the mud sample and injected into the
chromatograph. Alternatively, where a steam still is not used, this is the value of iso-pentane measured
from the gas stream at the peak of the show.
Amount of nor-pentane present in the gas extracted from the mud sample and injected into the
chromatograph. Alternatively, where a steam still is not used, this is the value of nor-pentane measured
from the gas stream at the peak of the show.
Amount of neo-pentane present in the gas extracted from the mud sample and injected into the
chromatograph. Alternatively, where a steam still is not used, this is the value of neo-pentane measured
from the gas stream at the peak of the show.
Amount of iso-hexane present in the gas extracted from the mud sample and injected into the
chromatograph. Alternatively, where a steam still is not used, this is the value of iso-hexane measured
from the gas stream at the peak of the show.
Amount of nor-hexane present in the gas extracted from the mud sample and injected into the
chromatograph. Alternatively, where a steam still is not used, this is the value of nor-hexane measured
from the gas stream at the peak of the show.
Comments pertaining to the hydrocarbon show
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #17 : Cementing Record
Average, minimum and maximum values for items in this record are based on the current triggering interval
for this record and are reset following the transmission of this record.
Measured depth of the hole at the time the record is generated.
Vertical depth of the hole at the time the record is generated.
Measured depth of the casing shoe being cemented.
Vertical depth of the casing shoe being cemented.
Measured pump pressure, averaged over the interval. This is the pressure required to displace fluid down
the hole during the entire cementing operation (ie. rig pump pressure, cement truck pump pressure, etc.).
Measured hookload, averaged over the specified interval or connection.
Measured distance of the traveling block above the rotary table.
Flow rate of the fluid entering the hole, based on strokes per minute, averaged over the interval.
Flow rate of the fluid entering the hole, measured with a flow sensor, averaged over the interval.
Flow rate of the fluid leaving the hole, measured with a flow sensor, averaged over the interval.
Percent of flow out as measured by a paddle or target sensor in the flow line, where 0% = no flow, 100%
= full deflection of the sensor.
Measured density of the fluid entering the well, averaged over the interval.
Measured density of the fluid leaving the well, averaged over the interval.
Effective circulating density, at the casing shoe measured depth, of the fluids currently in the hole.
Measured temperature of the fluid entering the well, averaged over the interval.
Measured temperature of the fluid leaving the well, averaged over the interval.
Current stage number of the cementing operation (i.e. 1 , 2, 3, etc.).
Measured depth of the DV tool at the time the record is generated.
Type/batch of fluid currently being pumped. An integer number indicates the fluid type and a letter (ie.
A,B,C etc.) indicates the batch. Type codes are:
Drilling fluid (1)
Spacer (2)
Cement (3)
DisplacemenT (4)
The coding sequence for a cement job could look like this:
1A, 2A, 2B, 3A, 3B, 4A, etc.
17.27 Cem Cumulative Returns
Cumulative calculated/measured returns since the start of the cement job. This does not include mud
circulation prior to pumping cement or spacer.
Cumulative volume of fluid pumped, for the current individual type/batch, at the time the record is
generated. This number should be reset to zero whenever the fluid type or batch changes.
Cumulative volume of cement pumped (all batches in the current stage) at the time the record is generated.
Cumulative volume of spacer, cement and displacement fluid pumped (current stage) at the time the record
is generated.
Calculated volume required for the plug to bump.
Number/status of all plugs for the current stage. Number the plugs in sequential order starting with the first
plug that will be released (i.e. bottom plug (1), middle plug (2), top plug (3)). The status is either loaded
(L) or dropped (D) (ie. 1D2L3L).
Type of cementing job being performed. Valid types are:
Casing (1)
Liner (2)
Plug (3)
Squeeze (4)
17.34- 17.38 Spares 1-5
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #18 : Drill Stem Testing Record
Average, minimum and maximum values for items in this record are based on the current triggering interval
for this record and are reset following the transmission of this record.
Identifier assigned to current DST.
Measured depth of top perforations, or depth of top packer in an open hole DST.
Vertical depth of top perforations, or depth of top packer in an open hole DST.
Measured depth of bottom perforations, or depth of bottom packer in an open hole DST.
Vertical depth of bottom perforations, or depth of bottom packer in an open hole DST.
Time elapsed since the tool began running.
Current state of the well : 1=flowing, 0= shut in
Pressure recorded inside the tubing at the surface.
Pressure recorded inside the casing at the surface.
Temperature recorded inside the tubing at the surface.
Pressure recorded at the bottom of the hole.
Temperature recorded at the bottom of the hole.
Measured liquid flow rate at the time the record is generated.
Measured gas flow rate at the time the record is generated.
Measured total flow rate at the time the record is generated.
Total liquid production up to the time the record is generated.
Total gas production up to the time the record is generated.
Total production up to the time the record is generated.
Measured concentration of hydrogen sulfide at the time the record is generated.
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #19 : Configuration Record
19.1-
19.7 See item descriptions in Record 1
Measured depth of the hole at the time the record is generated.
Vertical depth of the hole at the time the record is generated.
Number of different sections in the drill string (1-6), starting at the first section above the bit. The limitation
of six sections means that parts of the BHA may have to be treated as a combined unit.
Outside diameter of the pipe constituting drillstring section 1.
Inside diameter of the pipe constituting drillstring section 1.
Inside diameter of the tool joint of drillstring section 1.
Outside diameter of the tool joint of drillstring section 1.
Mass per unit length of drillstring section 1.
Length of drillstring section 1.
Outside diameter of the pipe constituting drillstring section 2.
Inside diameter of the pipe constituting drillstring section 2.
Inside diameter of the tool joint of drillstring section 2.
Outside diameter of the tool joint of drillstring section 2.
Mass per unit length of drillstring section 2.
Length of drillstring section 2.
Outside diameter of the pipe constituting drillstring section 3.
Inside diameter of the pipe constituting drillstring section 3.
Inside diameter of the tool joint of drillstring section 3.
Outside diameter of the tool joint of drillstring section 3.
Mass per unit length of drillstring section 3.
Length of drillstring section 3.
Outside diameter of the pipe constituting drillstring section 4.
Inside diameter of the pipe constituting drillstring section 4.
Inside diameter of the tool joint of drillstring section 4.
Outside diameter of the tool joint of drillstring section 4.
Mass per unit length of drillstring section 4.
Length of drillstring section 4.
Outside diameter of the pipe constituting drillstring section 5.
Inside diameter of the pipe constituting drillstring section 5.
Inside diameter of the tool joint of drillstring section 5.
Outside diameter of the tool joint of drillstring section 5.
Mass per unit length of drillstring section 5.
Length of drillstring section 5.
Outside diameter of the pipe constituting drillstring section 6.
Inside diameter of the pipe constituting drillstring section 6.
Inside diameter of the tool joint of drillstring section 6.
Outside diameter of the tool joint of drillstring section 6.
Mass per unit length of drillstring section 6.
Internal diameter of the kelly.
Length of the kelly
Average length of a stand of drill pipe.
Number of tool joints per stand of drill pipe (typically 2 or 3).
Number of different hole size sections in the well (1-5), starting from below the flowline. The first section
is usually the conductor or riser.
Internal diameter of the first hole section (from the top), usually the internal diameter of the riser (floating
rig) or the last string of casing.
Length of the first hole section.
Internal diameter of the second hole section.
Length of the second hole section.
Internal diameter of the third hole section.
Length of the third hole section.
Internal diameter of the fourth hole section.
Length of the fourth hole section.
Internal diameter of the fifth hole section.
Rated output of Pump 1 at 100% efficiency
Measured operating efficiency of Pump 1.
Rated output of Pump 2 at 100% efficiency
Measured operating efficiency of Pump 2.
Rated output of Pump 3 at 100% efficiency
Measured operating efficiency of Pump 3.
Hourly operating cost of the drilling operation, as specified by the operator.
Estimated average rate of tripping pipe.
Internal diameter of the kill line.
Internal diameter of the joints in the kill line.
Proportion of the total kill line which is made up of joints, expressed as a percentage.
Total length of the kill line.
Internal diameter of the choke line.
Internal diameter of the joints in the choke line.
Proportion of the total choke line which is made up of joints, expressed as a percentage.
Total length of the choke line.
Measured depth of the last casing shoe.
Vertical depth of the last casing shoe.
Measured depth at which the last Pressure Integrity Test on formation was performed.
Vertical depth at which the last Pressure Integrity Test on formation was performed.
Total pressure (hydrostatic + pump) required to inject fluid into the formation, expressed in equivalent mud
density for the last Pressure Integrity Test on formation.
Name of the drilling contractor.
Name of the drilling rig, including number where appropriate.
Type of rig installation. (e.g. LAND / BARGE / SUBMERSIBLE / PLATFORM / JACKUP / DRILLSHIP /
SEMISUB / ARTIFICIAL ISL., etc.)
Names of up to six service companies used on the well, reported in the form "company name/service
rendered", e.g. Smith Co./Wireline
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #20 : Mud Report Record
20.1-
20.7 See item descriptions in Record 1.
Measured hole depth at the time that the mud sample was taken.
Vertical hole depth at the time that the mud sample was taken.
Sequential count corresponding to actual mud reports filled out at the rig. This number may or may not
correspond to the sequence identifier.
Type of mud system in use at the time of the report. e.g. lignosulfonate, KCl, etc.
Source of the mud sample. e.g. flowline, suction, etc.
Date of the report, in form YYMMDD. Dates and times are in Universal Coordinated Time (Greenwich Mean
Time).
Time of the report, in form HHMMSS. Dates and times are in Universal Coordinated Time (Greenwich Mean
Time).
Density of the mud sample.
Viscosity of the mud in terms of the time taken for a given volume to pass through a funnel.
Temperature of the mud sample at the time of the measurement of funnel viscosity.
Plastic viscosity of the mud, derived from viscometer readings.
Yield point of the mud, derived from viscometer readings.
Gel strength of the mud 10 seconds after stirring.
Gel strength of the mud 10 minutes after stirring.
Gel strength of the mud 30 minutes after stirring.
API filtrate (fluid loss) using a filter press at 100 psi pressure and surface temperature.
Thickness of the residual solid film deposited on the filter paper by the loss of fluid from the filter press.
Operating temperature of the high temperature-high pressure filter press. API specification is
300 deg F.
Operating pressure of the high temperature-high pressure filter press. API specification is 500 psi.
API HTHP fluid loss from the high temperature-high pressure filter press.
Thickness of residual solid film deposited on the filter paper by the loss of fluid from the HTHP filter press.
Proportion of suspended and dissolved solids measured after passing the mud sample through a retort
(mud still).
Proportion of water measured after passing the mud sample through a retort.
Proportion of oil measured after passing the mud sample through a retort.
Proportion of sand-size particles in the mud sample, measured with a sand screen set.
Proportion of low gravity solids in the sample.
Calculated solids content of the sample.
Amount of barite present in the sample.
Estimated amount of lost circulation material present in the sample.
Cation exchange capacity (CEC) of the mud sample as measured by methylene blue titration.
Measured hydrogen ion concentration in the sample.
Temperature of the mud sample at the time of pH measurement.
Phenolphthalein alkalinity of the mud, measured by titration with a standardized acid solution.
Phenolphthalein alkalinity of the filtrate, measured by titration with a standardized acid solution.
Bromocresol green-methyl orange alkalinity of the filtrate measured by titration following the Pf reading.
Phenolphthalein alkalinity of the filtrate to which sodium hydroxide and barium chloride have been added.
Phenolphthalein alkalinity of the water and reagents used to determine P1, the filtrate being omitted.
Measured chloride ion concentration (salinity) in the mud filtrate.
Measured calcium ion concentration in the mud filtrate.
Measured magnesium ion concentration in the mud filtrate.
Measured potassium ion concentration in the mud filtrate, measured by the STPB, sodium perchlorate or
potassium select electrode method.
Temperature of the mud when the viscometer readings were made.
Observed viscometer dial deflection at 3 rpm.
Observed viscometer dial deflection at 6 rpm.
Observed viscometer dial deflection at 100 rpm.
Observed viscometer dial deflection at 200 rpm.
Observed viscometer dial deflection at 300 rpm.
Observed viscometer dial deflection at 600 rpm.
Proportion of the liquid fraction of an oil based mud which is composed of brine, calculated from the
corrected oil/water ratio.
Phenolphthalein alkalinity (Pm) of an oil based mud, measured by titration with sulphuric acid.
Calculated lime content of the oil based mud sample.
Measured electrical stability of the sample, used to estimate emulsion strength of the oil based mud.
Percent by weight of calcium chloride in the water phase of an oil based mud.
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #21 : Bit Report Record
21.1-
21.7 See item descriptions in Record 1.
Bit number, as specified by the operator.
Outside diameter of the bit.
Name of the manufacturer of the bit.
Name for the bit as designated by the manufacturer.
International Association of Drilling Contractors (IADC) identifying code for the bit type.
Serial number for the bit assigned by the manufacturer.
Cost of the bit, as specified by the operator.
Diameter of jet (nozzle) 1. If bit has more than 5 jets, enter null here and enter Total Flow Area in 21.20.
Diameter of jet (nozzle) 2. If bit has more than 5 jets, enter null here and enter Total Flow Area in 21.20.
Diameter of jet (nozzle) 3. If bit has more than 5 jets, enter null here and enter Total Flow Area in 21.20.
Diameter of jet (nozzle) 4. If bit has more than 5 jets, enter null here and enter Total Flow Area in 21.20.
Diameter of the center jet (nozzle). If bit has more than 5 jets, enter null here and enter Total Flow Area
in 21.20.
Total Flow Area for fluid calculated for a given bit. This variable is entered for any bit which has a throat
rather than jets or has more than five jets. Otherwise, it should be null. Do not enter jet sizes when
reporting TFA.
Measured depth at the start of the bit run.
Measured depth at the end of the bit run (null if bit run not over).
Total distance drilled in a given bit run. For a re-run bit, this pertains only to this run and does not include
the distance drilled during previous runs of the same bit.
Total number of hours in a given bit run. This does not include wash and ream, connection time, survey
time or reaming time (null if bit run not over).
Total number of hours spent reaming during this bit run (null if bit run not over).
Drill rate averaged over this bit run. In the case of a re-run bit, calculate ROP based on this run only (null
if bit run not over). Calculated from 21.23/21.24.
Average weight on bit over the bit run (null if bit run not over).
Maximum weight on bit over the bit run (null if bit run not over).
Average rotary speed over the bit run (null if bit run not over).
Maximum rotary speed over the bit run (null if bit run not over).
Average mud flow rate over the bit run (null if bit run not over).
Average mud density in over the bit run (null if bit run not over).
Average stand pipe (pump) pressure over the bit run (null if bit run not over).
Primary reason for running the bit.
Primary reason for pulling the bit (blank if bit run not over).
IADC dull grade condition of the bit as it went into the hole.
IADC dull grade condition of the bit as it came out of the hole (blank if bit run not over).
Indicate whether a shock sub was used with the bit (Y or N).
Indicate whether a mud motor was used with the bit (Y or N).
Any comments concerning bit grade or unusual operating conditions.
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #22 : Remarks Record
22.1-
22.7 See item descriptions in Record 1.
Measured depth of the hole at the time the record is generated.
Vertical depth of the hole at the time the record is generated.
General comments concerning the drilling environment. Include any comments which may help clarify data
received in the other records, such as unusual activities or equipment failures.Record #23 : Well Identification Record
23.1-
23.7 See item descriptions in Record 1.
Wellname assigned by the Operator.
Well number assigned by the Operator.
Name of the company designated as Operator.
Classification for the type of well being drilled, based on Lahee :
NEW FIELD W'CAT (1)
NEW POOL W'CAT (2)
DEEPER TEST (3)
SHALLOWER TEST (4)
EXTENSION TEST (5)
DEVELOPMENT WELL (6)
23.12 Well Location
Name of the jurisdictional area, county, state or offshore area (+ block number) where the well is being
drilled.
Universal Transverse Mercator location of the wellbore relative to the standard reference point.
Latitude of the wellbore surface location.
Longitude of the wellbore surface location.
Name of the field in which the well is being drilled. Enter prospect names for wildcats.
Elevation of the designated datum point for the well above mean sea level.
Elevation of the rotary kelly bushing above mean sea level.
Elevation of the ground level above mean sea level (null if offshore).
Distance from the seabed to mean sea level (null if onshore). If dredging has occurred, enter the
pre-dredge seabed depth.
Date on which the drilling commenced. Specified by the Operator. In the form YYMMDD.
Custom field identifiers indicate the use of Spare fields in other records. This permits at- a-glance
identification of customized records and variables. Identification information should be reported in the form:
RRIIMMMMMMMMUUUUDDDDDDDDDDDDDDDD
RR = record number in which the spare field is used
II = item number of spare field in that record
MMMMMMMM = long mnemonic for variable (or MMMM and four spaces
for short mnemonic)
UUUU = units mnemonic for variable
DDDDDDDDDDDDDDDD = variable description
23.32 Units type used
Indicates the type of units used. Acceptable standard types are "FPS" and "METRIC". Non-standard types
must be agreed upon between the operator and the vendor. Only the standard types are used at WITS
levels 0, 1 and 2.
Time difference of the rig location from Universal Coordinated Time (Greenwich Mean Time). This is
expressed in the form (-)HHMMSS such that a six hour difference west of UCT would be -60000, while a
three hour difference east of UCT would be 30000. In locations where daylight savings time (summer time)
is used, it is necessary to update this field and transmit the record following the resetting of clocks at the
wellsite (if applicable).
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #24 : Vessel Motion/Mooring Status Record
Average, minimum and maximum values for items in this record are based on the current triggering interval
for this record and are reset following the transmission of this record.
Mean distance between sea level and the sea bed.
Variance (+/-) in mean water depth.
Heading of the vessel, relative to true north, at the time the record is generated.
Most recently calculated vertical center of gravity of rig, measured from the bottom of the keel.
Tension on the riser at the time the record is generated.
Average horizontal displacement of the rig from the wellbore since the last record was generated.
Maximum horizontal displacement of the rig from the wellbore since the last record was generated.
Direction, relative to true north, the rig is displaced from the wellbore.
Average angle of the Lower Marine Riser Package from vertical, since the last record was generated.
Maximum angle of the Lower Marine Riser Package from vertical, since the last record was generated.
Direction, relative to true north, the LMRP is displaced from vertical.
Density of the fluid in the riser at the time the record is generated.
24.42 Mooring Line Tension - Avg
Average tension in each of the designated mooring lines since the last record was generated.
24.43 Mooring Line Tension - Max
Maximum tension in each of the designated mooring lines since the last record was generated.
24.58 Thruster Force
Force being generated by each of the designated thrusters at the time the record is generated.
24.59 Thruster Direction
Direction, relative to true north, of each of the designated thrusters at the time the record is generated.
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.Record #25 : Weather/Sea State Record
Average, minimum and maximum values for items in this record are based on the current triggering interval
for this record and are reset following the transmission of this record.
Mean distance between sea level and the sea bed.
Temperature of the air at the time the record is generated.
Barometric pressure at the time the record is generated.
Average of the highest one third observations of local waves measured over the interval.
Average of the highest one tenth observations of local waves measured over the interval.
Average elapsed time between occurrences of successive zero-up crossings of local waves.
Direction, relative to true north, from which the waves are coming at the time the record is generated.
Average of the highest one third observations of the swell measured over the interval.
Average of the highest one tenth observations of the swell measured over the interval.
Average elapsed time between occurrences of successive zero-up crossings of the swell.
Direction, relative to true north, from which the swell is coming at the time the record is generated.
Maximum one minute wind speed measured over the interval.
Maximum 5 second wind speed measured over the interval.
Direction, relative to true north, from which the wind is coming at the time the record is generated.
Distance of the anemometer above mean sea level.
Average speed of the current measured over the interval.
Direction, relative to true north, from which the current is coming at the time the record is generated.
Depth at which the current is measured, below mean sea level.
Mean draft of the vessel at the time the record is generated.
Average of the highest one third observations of heave of the vessel measured over the interval.
Average of the highest one tenth observations of the heave of the vessel measured over the interval.
Average time elapsing between successive occurrences of heave, measured over the interval.
Average of the highest one third observations of roll of the vessel measured over the interval.
Average of the highest one tenth observations of the roll of the vessel measured over the interval.
Average time elapsing between successive occurrences of roll, measured over the interval.
Average of the highest one third observations of pitch of the vessel measured over the interval.
Average of the highest one tenth observations of the pitch of the vessel measured over the interval.
Average time elapsing between successive occurrences of pitch, measured over the interval.
Average of the highest one third observations of yaw of the vessel measured over the interval.
Average of the highest one tenth observations of the yaw of the vessel measured over the interval.
Average time elapsing between successive occurrences of yaw, measured over the interval.
Average of the highest one third observations of surge of the vessel measured over the interval.
Average of the highest one tenth observations of the surge of the vessel measured over the interval.
Average time elapsing between successive occurrences of surge, measured over the interval.
Average of the highest one third observations of sway of the vessel measured over the interval.
Average of the highest one tenth observations of the sway of the vessel measured over the interval.
Average time elapsing between successive occurrences of sway, measured over the interval.
Mean trim angle of the vessel at the time the record is generated; bow down is positive, stern down is
negative.
Mean heel angle of the vessel at the time the record is generated; starboard side down is positive, port side
down is negative.
Any comments of relevance to this record, such as weather forecasts, hurricane tracking, etc.
Spares may be used to customize the record. Since there is no formal definition of spare content
the sender and receiver must agree in advance about such customization.