The recent industry downturn has driven a demand for predictable, repeatable drilling performance and precise well placement, enabling increasing confidence in forecasting the commercial viability of geological assets. This has, in turn, led to a need for real-time downhole data of a quality and quantity sufficient to have a substantial impact on our ability to visualize downhole conditions.

Today, we can stream real-time data through high-speed wired drill pipe (WDP) telemetry that allows operators to make more data-driven decisions with clarity and confidence. The IntelliServ WDP includes a revolutionary data connection by incorporating a coaxial cable along the length of the drill string from the rig to sensors near the drill bit. This high-speed data network, using inductive coils located in the drill string connections, enables bidirectional data transmission between downhole tools and the surface at speeds up to 57,000 bits per second.

The data transmitted includes high-frequency direction and inclination, temperature, pressure and three axes vibration sensors. These sensors are not restricted to the near-bit location, there are also along-string measurement (ASM) sensors at regular intervals along the drill string allowing visibility of, for example, annular pressure, which provides indications of hole-cleaning efficiency and allows the mitigation of problems such as pack-offs.

When combined with NOV’s programmable automation platform, NOVOS, this near instantaneous transmission of downhole data allows for the fine-tuning of several critical operations. For example, constant vibration measurements near the bit enable a refinement of the tagging-bottom procedure, which we know in the past has been a source of the challenging dynamic conditions that can lead to drill bit damage and downhole tool failure.

Significant time is saved by high-speed communication with MWD/LWD tools and rotary steerable systems, eliminating much of the lost time it has traditionally taken to communicate with these tools.

In addition to the benefits of the stand-alone WDP network, it also plays a crucial role in being able to drill automatically. For many years, NOV has been the leading supplier of structures, designs, and the topside drilling equipment essential to drilling rigs, both offshore and onshore, while also providing the controls for the equipment. These control systems provide the driller with joystick control of the rig and the drilling process. It has been clear that during the drilling process the human-in-the loop (i.e. the driller) has multiple responsibilities, including the safety of the crew, which do not allow for undivided attention on the efficiency of the drilling process. This challenge has been addressed with the introduction of the NOVOS automation platform.

Bringing together downhole sensors, the rig control system with the IntelliServ downhole network connecting them, has enabled an advanced closed-loop automated drilling system. An open architecture philosophy and a software development kit allow third-parties to write algorithms to control the system which can, for example, enhance drilling through down-hole automated ‘drill-off’ tests that constantly analyze the efficacy of different combinations of drilling parameters. One NOVOS application being used is the Equivalent Fluid Density (EFD) viewer, which was designed to manage wellbore stability by utilizing the ASM’s for measuring annular pressure. This provides the operator with the ability to view the cuttings transportation along the wellbore and identifying any zones that are accumulating cuttings or creating potential cutting beds.

The network can also be used for communication with third-party downhole tools and sensors. Controlling the drilling process using downhole data allows for a borehole quality that is very difficult to achieve using the inferred measurements at surface we have used traditionally.

Typically within our industry, when drilling out of the production sweet spot it is technically possible to directionally drill back into the production zone within one single (30 ft); however, this would create a high dog leg in the wellbore and increase wellbore tortuosity. It is more practical to complete this within one stand (90 ft). When looking at the average potential loss of production over 90 ft., it could be well over $200,000 over the life of the well.

Maximizing potential production demands precise well-placement, requiring geosteering, which in turn demands interpretation of geological data during the drilling process. The use of WDP allows data from logging sensors to be streamed to surface providing, in real-time, an image quality only previously seen in memory mode, which allows for much greater clarity for those with well-placement responsibility. Geosteering without WDP is almost like driving in the dark with no headlights. Geosteering with WDP is like driving with headlights on and ensures the operator can stay within the target zone by being able to steer real time.

When using mud pulse telemetry, it is typically 2-12 bits per second and has a time delay in downlinking data to the surface, with WDP there is real-time communication at internet speeds of 57,000 bits per second. This enables customers to proactively mitigate risks by providing accurate geosteering, which helps avoid potential production loss.

This type of accuracy is even more important as we see horizontal lateral lengths in the U.S. unconventional market continuing to get longer. From 2016 to now, there has been a 40% increase in horizontal lateral length from 5,800 ft to 8,000 ft, and at this current pace it could average 15,000 ft by the year 2020. NOV is enabling and powering the industry to ensure that they have the advanced technology needed to achieve these longer laterals.

Our industry is once again proving that the adoption of advanced technology can enable us to improve the efficiencies required to drill our way out of a downturn.

Stop by booth #2839 at the Offshore Technology Conference (OTC) to learn more about drilling precisely and intelligently.