PayzoneTracker Delivers Near-Bit Insight Behind RSS
MWD Downhole Drilling Tools has successfully completed its fourth run of the 6.75" PayzoneTracker positioned directly above a D-Tech Rotary Steerable System (RSS) — continuing to demonstrate the value of Near-Bit measurements in RSS drilling applications.
In this configuration, PayzoneTracker is positioned approximately 16 feet behind the bit, placing critical directional, formation, and drilling dynamics measurements much closer to the steering system than conventional MWD/LWD measurements farther up the BHA.
But the real value isn't simply being closer to the bit.
It's seeing the response sooner.
Near-Bit Visibility for the Directional Driller
One of the most valuable lessons from these four runs has been the additional insight PayzoneTracker provides the Directional Driller during RSS operations.
When a steering command is downlinked to an RSS, the Directional Driller ultimately needs to know one thing:
Did the BHA respond the way we expected?
With conventional measurements positioned farther behind the bit, additional footage may need to be drilled before the resulting directional response becomes clearly visible.
Positioning PayzoneTracker directly above the RSS changes that equation.
Its Near-Bit measurements provide an earlier view of the BHA's directional response following a steering command, giving the Directional Driller greater confidence that the intended change is taking effect — without unnecessarily drilling ahead while waiting for measurements farther up the BHA to confirm the response.
Approximately 16 Feet Behind the Bit
Measurement distance matters.
In the current RSS configuration, PayzoneTracker sits approximately 16 feet behind the bit and immediately above the RSS.
That proximity creates a valuable measurement point between the steering system and the traditional MWD/LWD tool string.
Instead of waiting for the response to propagate to sensors positioned significantly farther behind the bit, the drilling team gains access to Near-Bit information much earlier.
This can be particularly valuable during:
Steering changes
Toolface or directional corrections
Critical trajectory adjustments
Landing operations
Maintaining position within narrow drilling targets
Evaluating RSS response after a downlink
The objective isn't simply more data.
It's earlier information at the point where a directional decision needs to be made.
Formation and Drilling Dynamics Insight
The same Near-Bit platform also provides additional information about the environment immediately above the RSS.
PayzoneTracker provides Azimuthal Gamma Ray along with Near-Bit directional measurements and drilling dynamics data, including axial and radial shock and vibration.
This gives the drilling team another perspective on formation response and the mechanical environment experienced by the lower BHA.
Across each run, the data also contributes to a growing post-run dataset that can be used to evaluate relationships between steering activity, drilling parameters, trajectory response, shock and vibration, and overall BHA performance.
Four Runs — From Concept to Repeatability
The first successful deployment proves a concept.
The second gets your attention.
By the fourth successful run, you're beginning to establish something much more important:
Repeatability.
The completion of four PayzoneTracker runs behind the D-Tech RSS continues to build confidence in both the mechanical configuration and the value of placing intelligent measurements immediately above the steering system.
More importantly, these runs are helping demonstrate a practical application for Near-Bit measurements that goes beyond traditional formation evaluation.
Near-Bit data can become part of the steering decision itself.
Closing the Gap Between Command and Confirmation
RSS technology gives Directional Drillers extraordinary control over wellbore placement.
PayzoneTracker adds another layer of visibility by moving key measurements closer to where that steering action is actually occurring.
Approximately 16 feet behind the bit.
Directly above the RSS.
Providing earlier insight into how the BHA is responding after a steering command.
The result is greater situational awareness and increased confidence in steering decisions — while reducing the amount of formation that may need to be drilled before the directional response becomes evident in measurements farther up the BHA.
After four successful runs, we're continuing to expand that dataset and explore how Near-Bit intelligence can improve directional drilling, wellbore placement, drilling dynamics analysis, and RSS performance.
The closer you measure to the steering system, the sooner you know what's happening.
DRILL HARD. MEASURE EVERYTHING.
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