OTC-28735-MS

High Speed Telemetry on Wired Drill Pipe, History, and Impact on Drilling
Process

Robert Foster and Robin Macmillan, NOV

Copyright 2018, Offshore Technology Conference

This paper was prepared for presentation at the Offshore Technology Conference held in Houston, Texas, USA, 30 April–3 May 2018.

This paper was selected for presentation by an OTC program committee following review of information contained in an abstract submitted by the author(s). Contents of
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Abstract
This paper discusses the history and impact of using high-speed telemetry and wired drill pipe on the drilling
process. Efficiency gains, well placement advantages, campaign cost reductions, automation improvements,
as well as what other operational efficiencies high-speed telemetry can enable.

History of Wired Drill Pipe

Wired drill pipe (WDP) has been in commercial use since 2006. Following around 150 wells of experience,
an engineering team took the lessons learned to change and upgrade some of the features.
It was through those lessons and updates that a second version of wired drill pipe was later released in
2015. With a focus on lowered total cost of ownership and increased reliability, version two has been a
significant improvement.
Key changes made to version 2 wired drill pipe are:

• Reusable, field-replaceable inductive coils.

• Recessed inductive coils in the pin end of drill pipe.

• Proud box-end inductive coils maintain coil contact to provide superior signal transfer.

• Improved corrosion resistance of armored coaxial cable by switching to Inconel 825.

• Integrated battery controller that permits more efficient use of battery packs.

Impact on the Drilling Process

High-speed telemetry on wired drill pipe runs at speeds exceeding 57,600 bits per second, significantly
eclipsing the speed and reliability of other telemetry systems. Improved reliability now typical provides
uptimes of 98%.
Since the introduction of high-speed telemetry to the market, operators are recognizing the benefits and
impact on their drilling processes in a variety of ways, for example:
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• Improved safety

• Time savings

• Improved well-bore quality

• Extended reservoir sections

Initial investment savings

Engineering changes not only made wired drill pipe more robust, they also reduced the total cost of
ownership by enabling and leveraging in-place, in-region facilities to perform rework and maintenance
(R&M).
Wired drill pipe has been used commercially in varied applications in several locations, for example;
Myanmar, the North Slope of Alaska, the Gulf of Mexico, Latin America, the North Sea, Saudi Arabia,
Canada and US land. More than 250 wells have drilled using the WDP high-speed telemetry.
When using logging while drilling (LWD), measurement while drilling (MWD), and along-string
measurement (ASM) tools in real time, decisions are made during the drilling process rather than during a
post-well investigation. The speed of telemetry allows for these data sources to stream to surface without
any compromise in rate of penetration.
Many papers have been written, some of which are highlighted below.
SPE-178798-MS -This paper describes two wells in the Babbage development project in the Southern
North Sea that showed the viability of transmitting MWD and LWD data to the surface and sending almost
instantaneous downlink commands to MWD, LWD and rotary steerable systems (RSS) tools while drilling.
They show how WDP telemetry enabled better understanding of the downhole drilling environment and
formation characteristics in real time, which dramatically improved well bore placement and saved more
than one day per well on telemetry time alone. They also saw more rig time savings through fewer bit and
BHA trips through reduced downhole tool failures.
Overall, multiple days per well were saved both in trip time and drilling time.
SPE-178863-MS - This paper describes the use of WDP in a complex drilling environment to increase
overall drilling efficiency and reduce well times. The paper covers the main advantages and opportunities
that resulted from the implementation of WDP telemetry on the Martin Linge development in the North
Sea, which were:

• Rig time savings that added up to about one day per well.

• Rate of penetration (ROP) steadily improved over time. As experience was gained, drilling
parameters were optimized and subsequent sections drilled more efficiently.
• 93% Uptimes were realized on the WDP telemetry system.

New technology was successfully developed and implemented during the project, which saved rig time
and optimized GeoSteering with real-time memory-quality formation evaluation and drilling dynamics data
that resulted in improved well placement, increased reservoir section length, and optimized sand exposure
(expected 67%, attained 81%).
Along string measurement readings were valuable for understanding and managing equivalent circulating
density (ECD) when drilling horizontally and the optimized sand exposure is attributed to the real-time use
of LWD tools. Data and adjustments were improved by getting high quality gamma ray, resistivity, density,
and neutron data.
The new technologies developed and implemented during the project were integrated reamers and
seismic-while-drilling tools.
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SPE-166428-MS – This paper discusses the results of an automated drilling system that was field
tested where direct closed loop control of machines performed drilling optimization tasks using high speed
downhole data. The downhole data was then measured by a drilling dynamics sub and transmitted via wired
drill pipe to the surface and then visualized and analyzed by a surface application. The application then
provided set points thorough a control interface to the rig's pre-existing system.
There are two key areas that the paper focuses on:
1. The rate of penetration improvements that occurred while rotating, sliding, and sliding using an
automated rocking application.
2. The positive behavioral change that occurs when the downhole environment is fully understood.
The results from the field test demonstrated that these technologies have a significant improvement
on the sliding performance and that high speed downhole drilling dynamics allowed the driller and
customer representatives to maximize the performance of the rig without compromising safety or equipment
reliability.
SPE-173159-MS – This paper highlights a test program that was implemented across a 6-well project
drilling in the Eagle Ford unconventional shale formation in South Texas. To analyze the performance
benefits a road map was put together where the automated drilling applications were tested against
drive system, formation type, and wellbore geometry. The objectives were to find out which applications
combined with which drive system delivered the largest, consistent performance gains and the greatest cost
savings. The paper goes through the various automated applications that were tested and it was concluded
that the high-speed downhole-driven control of the rig equipment allowed the driller and the customer
representatives to maximize the performance of the rig. It was also seen that drilling with automated motor
BHAs and automated non-motorized rotary steerable BHAs allowed for repeatable improvements in drilling
performance of 37%.
SPE-184694-MS – This paper discusses the implementation and performance impact of drilling with a
fully integrated automation system that combines high-speed surface downhole data, a process controller,
and a modern 1500-HP AC land rig. At the time of the paper, it was the first time in the world that the
above combination was utilized in drilling. The paper highlights the equipment used in the fully integrated
drilling automation system and various impacts on performance of components of the system and benefits
of a fully integrated system. It was seen that throughout the drilling process, the drilling applications and
software interfaced with the control system to provide real-time downhole dynamics data such as WOB,
toolface control, wellbore stability, cuttings monitoring, and performance steering. By utilizing integrated
automation, the rig drilled close to its technical limit, applying proven drilling processes for consistent,
repeatable performance. It was seen that the integrated system significantly reduced the spread of spud-
to-total-depth times and learnings were able to be implemented efficiently and consistently to deliver
continuous improvement.

Results
We have drilled for many years without the benefit of downhole real-time data. Now this has been enabled
by wired drill pipe, our drilling operations can be more efficient, wellbore quality improved, and wellbore
placement more precise.

Conclusion
Over numerous commercial applications, the benefits of downhole high-speed telemetry have been
demonstrated and further benefits of precise geo-steering can be expected.
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Acknowledgements
Reina Teelken (NOV Wellbore Technologies) | Colin Jaring (NOV Wellbore Technologies) | Andrew Craig
(NOV Wellbore Technologies) | Roy Allan (E.ON E & P) | Huw Roberts (E.ON E & P) | Andy Hatch
(E.ON E & P) | Nicol Shepherd (E.ON E & P) Saskia Schils, Total E&P Norge AS | Reina Teelken,
NOV Wellbore Technologies | Brian van Burkleo, NOV Wellbore Technologies | Ove Johnny Rossa, Baker
Hughes Drilling Services | Nils Edwards, Baker Hughes Drilling Services Sehsah, O., Saudi Aramco |
Ghazzawi, A., Schlumberger | Vie, G. J., Schlumberger | Al-Tajar, T., Schlumberger | Ali, A., Schlumberger
| Al-Mohammed, A. H., Schlumberger | Itani, M., Schlumberger | Ullah, S., Schlumberger | Escalera, H.,
Schlumberger | Balka, M., Schlumberger

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