Implementation of Wired Drill Pipe Saved Multiple Days Per Well, by Addressing Performance Limiters, Increasing Drilling Efficiency

Teelken, Reina; Jaring, Colin; Craig, A. D.; Allan, Roy; Roberts, Huw; Hatch, A.J.; Shepherd, Nicol

doi:10.2118/178798-ms

Day 1 Tue, March 01, 2016 2016

DOI: 10.2118/178798-ms

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Implementation of Wired Drill Pipe Saved Multiple Days Per Well, by Addressing Performance Limiters, Increasing Drilling Efficiency

Reina Teelken¹,

Colin Jaring²,

A. D. Craig³

et al.

Abstract: This paper will discuss the implementation of the Wired Drill Pipe telemetry on two wells of the Babbage development project in the Central North Sea and will present the quantified efficiency gains achieved across various drilling operations. Wired Drill Pipe (WDP) telemetry enables bi-directional, high speed data transmission to and from downhole tools at speeds up to 57,600 bps (Olberg et al. 2008). This enables real-time "recorded" quality MWD and LWD data to be transmitted instantaneously t… Show more

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Cited by 4 publications

References 13 publications

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Smart Wired Pipe: Drilling Field Trials

Macpherson

Roders

Schoenborn

et al. 2019

Day 1 Tue, March 05, 2019

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Drilling systems automation requires a downhole digital backbone for closed-loop control, as do many other real-time drilling, completion and production operations. The absence of a reliable, high data bandwidth, bi-directional communication method between surface and downhole is a barrier to digitalization and automation of the oil field. This paper describes the development and successful drilling field trial of a micro-repeater wired pipe – effectively "smart pipe" – that removes this barrier. The developed system uses battery-powered micro-repeaters (a fail-safe signal booster) placed within the box of each tubular and fully encapsulated dual RF-resonant antennas to transmit data between tubulars. The current system delivers 1-Mbps backbone data rate with a maximum payload of 720 kbps, and with a very low latency of 15 μsec/km, making it ideal for control-loop applications. The system design focusses on reliability: failure of multiple components will not affect telemetry. The prototype system has been rigorously field tested during drilling in Oklahoma. Testing occurred on a drilling rig in Beggs, Oklahoma. The first trial (2016) covered drilling operations, the second (2017) covered controlling downhole technology; both were successful. The drilling trial demonstrated fitting the system to pipe with conventional API connections, standard rig-floor pipe handling, reliable wireless transmission between surface receivers and wired pipe network, the use of multiple along-string measurements of temperature and vibration, and simulated component failure. Of particular note was the surface system: it is wireless and no modification to the drilling rig was required. Conventional tubulars can be refit with the system, which removes a barrier to the use of wired pipe for automation and LWD/MWD measurements in lower cost onshore operations. There is a benefit for drilling operations: all pipe joints contain a micro-repeater and are addressable for "smart pipe" applications such as an electronic pipe tally, and pipe condition monitoring. Drilling operations are the first users of the system, but it serves other operations, for example tubing conveyed wireline operations. The smart wired pipe concept is truly innovative. It enables drilling systems automation and logging-while-drilling applications, such as seismic-while-drilling with along-string sensors, by providing a fully open acquisition and control platform to the industry.

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Smart Wired Pipe: Drilling Field Trials

Macpherson

Roders

Schoenborn

et al. 2019

Day 1 Tue, March 05, 2019

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Quantifying PDC Bit Wear in Real-Time and Establishing an Effective Bit Pull Criterion Using Surface Sensors

Witt-Doerring

Pastusek

Ashok

et al. 2021

Day 3 Thu, September 23, 2021

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It is useful during drilling operations to know when bit failure has occurred because this knowledge can be used to improve drilling performance and provides guidance on when to pull out of hole. This paper presents a simple polycrystalline diamond compact (PDC) bit wear indicator and an associated methodology to help quantify wear and failure using real-time surface sensor data and PDC dull images. The wear indicator is used to identify the point of failure, after which corresponding surface data and dull images can be used to infer the cause of failure. It links rotary speed (RPM) with rate of penetration (ROP) and weight-on-bit (WOB). The term incorporating RPM and ROP represents a "sliding distance", i.e. the number of revolutions required to drill a unit distance of formation, while the WOB represents the formation hardness or contact pressure applied by the formation. This PDC bit wear metric was applied and validated on a data set comprised of 51 lateral production hole bit runs on 9 wells. Surface electric drilling recorder (EDR) data alongside bit dull photos were used to interpret the relationship between the wear metric and observed PDC wear. All runs were in the same extremely hard (estimated 35 – 50 kpsi unconfined compressive strength) and abrasive shale formation. Sliding drilling time and off-bottom time were filtered from the data, and the median wear metric value for each stand was calculated versus measured hole depth while in rotary mode. The initial point in time when the bit fails was found to be most often a singular event, after which ROP never recovered. Once damaged, subsequent catastrophic bit failure generally occurred within drilling 1-2 stands. The rapid bit failure observed was attributed to the increased thermal loads seen at the wear flat of the PDC cutter, which accelerate diamond degradation. The wear metric more accurately identifies the point in time (stand being drilled) of failure than the ROP value by itself. Review of post-run PDC photos show that the final recorded wear metric value can be related to the observed severity of the PDC damage. This information was used to determine a pull criterion to reduce pulling bits that are damaged beyond repair (DBR) and reduce time spent beyond the effective end of life. Pulling bits before DBR status is reached and replacing them increases overall drilling performance. The presented wear metric is simple and cost-effective to implement, which is important to lower-cost land wells, and requires only real-time surface sensor data. It enables a targeted approach to analyzing PDC bit wear, optimizing drilling performance and establishing effective bit pull criteria.

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Novel Use of Wired Drill Pipe for Real Time Remotely Operating Controls System During Well Completions

Teelken¹,

Wilenski²,

Mulholland

et al. 2022

Day 1 Wed, April 27, 2022

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The recent industry downturn has forced operators and contractors to re-think and look at different ways to reduce costs while improving the complete well delivery process. Compounding challenges are longer reservoir sections with more complex well trajectories and tighter geological constraints. These complex drilling challenges have been successfully completed in the past, thru use of high-speed Wired Drill Pipe (WDP) telemetry (Schils et al. 2016; Teelken et al. 2016), where the WDP telemetry enabled bi-directional high-speed data transmission to and from downhole tools at speeds up to 57,600 bps (Olberg et al.2008). Whilst the use of WDP telemetry within the ‘drilling phase’ of the well delivery process has become more accepted and implemented globally, providing improved performance and wellbore placement, the use of WDP during the ‘completions phase’ has never been attempted. That is, till today. This paper focuses on the use of WDP during the ‘completion phase’, discussing the first ever application of the battery operated Remotely Operated Completion System (ROCS) on WDP, used offshore North Sea, for umbilical-less Tubing Hanger installation. The ROCS consists of redundant controls architecture and pumps to operate the electrical and hydraulic functions and read gauges. Thru use of the highspeed WDP telemetry, the ROCS is controlled in real-time from topside to operate the Tubing Hanger Running Tool (THRT), Tubing Hanger (TH), downhole functions and downhole gauges, eliminating the need for the traditional umbilical deployed within the Marine Riser. The WDP operated ROCS allows for a simplified system mobilization and operation, reducing total number of rig days and costs significantly. The main advantages that will be discussed and shown include: Eliminating the Electro-Hydraulic umbilical and handling equipment (costly associated equipment) Reduces personnel in red zone (umbilical-less: no clamping) Reduces/Eliminates rig interfaces, (such as Workover Control System (WOCS) container reducing the deck space demand, increasing rig flexibility) Ready to Run (ROCS including THOJ/THRT (Tubing Hanger Orientation Joint/Tubing Hanger Running Tool) tested and mobilized already connected to the TH Significantly reduces risk of Waiting on Weather Real-time readings local to tool, (accurate volumes and pressures, no umbilical influence) The system has been used for horizontal and vertical completions and can operate different running tools, offering field proven benefits for the industry.

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Implementation of Wired Drill Pipe Saved Multiple Days Per Well, by Addressing Performance Limiters, Increasing Drilling Efficiency

Cited by 4 publications

References 13 publications

Smart Wired Pipe: Drilling Field Trials

Smart Wired Pipe: Drilling Field Trials

Quantifying PDC Bit Wear in Real-Time and Establishing an Effective Bit Pull Criterion Using Surface Sensors

Novel Use of Wired Drill Pipe for Real Time Remotely Operating Controls System During Well Completions

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