Oil & Gas Measurement While Drilling systems allow the driller to gather and transmit information from the bottom of the hole back to the surface without interrupting normal drilling operations. This information can include directional deviation data, data related to the petrophysical properties of the formations, and drilling data, such as WOB and torque (check also: torque & drag).
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The information is gathered and transmitted to the surface by the relevant sensors and transmission equipment which is housed in a non-magnetic drill collar in the bottom hole assembly (check also: types of Bottom hole assembly). This tool is known as a Measurement While Drilling Tool. The data is transmitted through the mud column in the drill string, to the surface. At the surface, the signal is decoded and presented to the driller in an appropriate format. The transmission system is known as mud pulse telemetry and does not involve any wireline operations.
To take a directional survey using conventional wireline methods may take 1-2 hours. Using an MWD system a survey takes less than 4 minutes. Although MWD operations are more expensive than wireline surveying an operating company can save valuable rig time, which is usually more significant in terms of cost.
More recently MWD companies have developed more complicated tools which will provide not only directional information and drilling parameters (e.g. torque, WOB) but also geological data (e.g. gamma-ray, resistivity logs). The latter tools are generally referred to as Logging While Drilling – LWD Tools.
As more sensors are added the transmission system must be improved and so MWD tools are becoming more sophisticated. Great improvements have been made over the past few years and MWD tools are now becoming a standard tool for drilling operations.
Depending on the level and complexity of the MWD service used, applications include:
- Directional Drilling control
- Relief well drilling
- Bottom hole location
- Casing seat selection
- Gas influx identification
- Lithological identification
- Offset well correlation
- Coring point selection
- Invasion profiling
- Pore pressure analysis
- Precision geosteering in high angle wells
- Hydrocarbon identification
- Shallow gas control
- Reconnaissance and insurance logging in high risk wells
- Cost effective wireline replacement
Where drilling mechanics MWD is used, it may be possible to provide information to aid in the following:
- Drilling optimization & measurement
- Drilling Hydraulics optimization
- Bottom hole assembly damage avoidance
- Drilling Bit whirl analysis
- Influx monitoring (well kick)
- Swab and surge measurements while tripping pipe (avoiding well kicks or conversely formation damage)
Measurement While Drilling System Components
All MWD systems have certain basic similarities which are as follows:
- A downhole system which consists of a power source, sensors, transmitter and control system.
- A telemetry channel (mud column) through which pulses are sent to surface.
- A surface system which detects pulses, decodes the signal and presents results (numerical display, geological log, etc.).
Check the full article of MWD Tool Components:
Measurement While Drilling Sensors
All MWD systems use basically the same directional sensors for calculating inclination, azimuth, and tool face. The sensor package consists of 3 orthogonal accelerometers and 3 orthogonal magnetometers.
An accelerometer performs measurement of the component of the earth’s gravitational field along the axis in which it is oriented while drilling. It works on the “force-balance” principle. Atest mass is suspended from a quartz hinge which restricts any movement to along one axis only. As the mass tends to move due to gravity acting along that axis, its central position is maintained by an opposing electromagnetic force.
The larger the gravitational force, the larger the pick-up current required to oppose it. The voltage drop over a resistor in the pickup circuit is measured, and this is directly related to the gravitational component. Depending on the orientation of the BHA the reading on each accelerometer will be different. From these 3 components, the angle of inclination and tool face can be calculated.
A magnetometer will measure the component of the earth’s magnetic field along 1 axis. If a wire is wrapped around a soft iron core and then placed in a magnetic field, the current induced in the pick-up circuit will vary depending on the angle at which the toroid is placed. Therefore the size of the current is related to the direction of the coil with respect to the direction of the magnetic field. As with the drilling accelerometer the voltage measurement is done across a resistor in the pick-up circuit of the magnetometer. The voltages read at each magnetometer can then be used to calculate azimuth.
Sensors Surveying & Calculations
In the following equations a, b, c, x, y, z refer to the accelerometer and magnetometer readings with axes as shown.
Inclination – the angle between C accelerometer and vertical. Looking at a verticalion cross-section
Toolface – the angle between the high side and B accelerometer. Looking down the tool along the C axis:
Azimuth – the angle between the Z-axis and magnetic North, when projected onto the horizontal plane. Looking in the horizontal plane we define 2 vectors V1 and V2 where V1 lies along the tool axis.
Notice that accelerometer readings are also used in the calculation of azimuth. If there is any mistake in the accelerometer readings, therefore, inclination, tool face, and azimuth will all be wrong. Since we are relying on the magnetometers responding only to the earth’s magnetic field any local magnetic effects from the drill string must be isolated. There must be enough non-magnetic drill collars above and below the sensors to stop any such interference. As a result of this, the sensors will be operating 40′ – 80′ behind the bit (the exact distance must be known before the tool is run).
Check the full article of MWD sensors:
Measurement While Drilling Normal Surveying Routine
The usual practice in taking a survey is to drill to the end of the string and make the connection. Run in the hole and tag bottom. Pick up 5′-10′ and keep pipe steady for 2 minutes (this allows survey data to be stored). Re-start drilling and survey data is transmitted to the surface. In some tools the transmission is initiated by rotation, in others, it senses pump pressure. During steering (Check also Rotary steerable drilling system) run, where a drilling mud motor is being used an update of tool face, is usually transmitted every minute. This is of great value to the directional driller as he monitors the progress of the well.
Accuracy of Measurement While Drilling
MWD companies quote slightly different figures for accuracy but generally within the following limits:
These figures compare favorably with Magnetic single shot Survey accuracies and MWD offers the advantage of being able to repeat surveys at the same depth with little loss in rig time