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A system capable of operating in downhole conditions at depths of several thousand meters is developed for measuring drilling engineering parameters (DEP) in real time. The aim is to monitor DEP during drilling, including the weight on the drill bit (WOB), torque on the drill bit (TOB), and lateral force on the drill bit. The design of the ...
- Ma Tian-shou, Chen Ping
- 2015
Metrol’s R&D department has developed a variety of passive sensors for measuring downhole parameters. This includes fluid ID tools and flow measuring capability. For example PRO-LOG and OCULUS. Data Centre. REAL TIME PROCESSING. Metrol’s data team has situational awareness and an immediate response to live wellsite data.
View downhole data at surface as soon as the string is in the hole to: Assess and adjust hydrostatic balance; Monitor reservoir information to adjust test time, maximise results and minimise cost; Gather valuable downhole information for troubleshooting
different wireless telemetry methods. New variants for wireless telemetry, power supplies, and measurement methods will be proposed. Preferred applications for each gauge type will be given. Downhole gauges can be improved by integrating pressure pulse, a downhole power generator, and downhole flow rate measurement into a single unit.
- Acoustic Methods
- Mud Pulse Telemetry
- TRANSMISSION SYSTEMS
- Positive Pulse System
- POWER SOURCES
- MWD SENSORS
- Downhole WOBlTorque
- Standpipe Pressure Transducer
- Electronic Filters-Amplifiers-Surface Computer
- Pre-job Requirements
- Rigging-up and Surface Checks
- (9LoTf
- Normal Surveying Procedure
- APPLICATIONS OF MWD
- Formation Evaluation
The propagation of sound or seismic waves through the drill pipe provides another possible telemetry channel. To overcome background noise due to drilling operations, a large seismic generator would be required in the BHA. Attenuation along the drill string also makes it difficult to pick up the signal at surface. Repeater stations situated at inte...
All the MWD systems commercially available are based on some form of mud pulse telemetry. Although several different companies offer an MWD MWD CABIN ElectrOniC fIlter Surface computer Printer lermlnal Planer stnng~ DOWNHOLE TOOL Power source r- ~~~~~~~iC control system - Transmitter Components of a mud pulse telemetry system. similarities among th...
The major differences between existing mud pulse telemetry systems are due to the process by which the data is transmitted. There are three different methods currently being used to encode the data downhole and to decode the data on surface.
Within the downhole tool (Fig. 8.6) there is a restrictor valve that is operated by a hydraulic actuator. When the valve is operated, it forms a temporary constriction in the flow of mud through the drill string which causes an increase in the standpipe pressure. To transmit data to surface, this valve is operated several times, creating a series o...
Since mud pulse telemetry systems have no wire line conductors running back to surface, the power source to operate the tool must be located downhole. Two forms of power source are being employed. Batteries These offer the advantage of being compact and reliable since they contain no moving parts. However, they do have a finite operational life and...
All sensors used in the downhole tool must be rugged enough to withstand the harsh environment. Only one of the systems currently available has the facility to change-out damaged components (sensor package/electronics) without tripping the whole bottom hole assembly out of the hole. The failure of one sensor may not necessarily mean that the tool h...
These measurements are made by a system of sensitive strain gauges mounted on a special sub placed close to the bit. The strain gauges will detect axial forces for WOB and torsional forces for torque. By placing pairs of gauges on opposite sides of the sub, any stresses due to bending can be eliminated. The sub must also be designed to compensate f...
On most drilling rigs the standpipe manifold has a number of pressure taps where gauges may be installed. The transducer can be installed at a convenient point by removing one of these gauges. Inside the transducer is a sensitive diaphragm that detects variation in pressure and converts these hydraulic pulses to electrical voltage pulses. The volta...
As well as detecting the MWD pulses, the transducer will also respond to pressure variations caused by the · rig pumps or downhole motors. This background noise makes it difficult to identify the MWD pulses. It is sometimes possible to alter the speed of the rig pumps to reduce this interference. Pulsation dampeners on the rig pumps should prevent ...
An operating company wishing to use an MWD system must first decide: what the basic data requirements are; which systems currently available can meet these requirements; whether the limitations and specifications of the system under consid eration are acceptable for this application (in terms of accuracy, data rate, temperature, etc.). Where severa...
All MWD systems have been designed to allow a fairly simple rig-up so that normal drilling operations are not seriously held up. The service company will supply all the necessary downhole and surface equipment. To rig-up and run an MWD system usually requires two service company engineers. The surface system requires the installation of the pressur...
MWD " Bent sub offset toolface (OTF). operating correctly. A useful test on the survey at a particular depth on every trip benchmark survey and all the results benchmark survey is usually taken depth, so that if the tool is not giving the without wasting too much rig time.
For directional MWD there are two modes of operation: Rotary drilling, in which static surveys (azimuth and inclination) are taken after each connection, or at closer intervals if required. Steering runs, in which a bent sub and downhole motor are being used. In this case it is more important to monitor the toolface as the bit is drilling. In some ...
The applications of MWD can be divided into three broad categories which are described as follows.
Logging-while-drilling with gamma-ray and resistivity sensors is becoming more popular, but it is much more difficult to justify in strict economic terms. This is because the operator will probably wish to run a complete suite of wireline logs in any case. The incremental benefits of having logging data as the well is being drilled must be investig...
- T. A. Inglis
- 1987
Rig data such as rotary torque and speed, hook load, mud temperature, mud pressure, pit volume and pump strokes, and block height are now commonly monitored in real time and are easily available to the onsite and remote crews (Rickard, 2018). Downhole measurements have also improved significantly.
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Aug 5, 2015 · A system capable of operating in downhole conditions at depths of several thousand meters is developed for measuring drilling engineering parameters (DEP) in real time. The aim is to monitor...
