This paper will address the improvements in well placement and drilling efficiency seen during a start-up project where wired drillpipe was introduced as an enabling technology during the project. By using multiple strands of new technology, in a controlled, managed fashion, Eon Ruhrgas delivered rate of penetration (ROP) increases of 200% and, at the same time, increased net-to-gross by nearly 100%. The delivery of these new technologies will be reviewed along with the culture of learning and constant improvement fostered by the Eon Ruhrgas. The collaborative atmosphere led to an open environment where all the potential issues, risks, and hazards had been discussed and contingencies made to ensure that delivery would not be compromised. A case study on the drilling of the first three wells on the Babbage field, where significant new technology advances were introduced on the second and third development wells, will outline, in detail, the improvements in performance observed. In summary, the introduction of wired telemetry drillpipe and the use of a downhole-powered rotary steerable system (RSS) ensured optimum trajectory control, ensuring "sweet" spots were identified and delivered, while maintaining an optimum ROP. By using the increased data-carrying capability of the wired drillpipe, it was possible to provide high quality image data, allowing a better understanding of the downhole environment and ensuring that the stratigraphic control was optimized. The optimization was enhanced by 24-hour operations geological support, continuous dip-picking, and geosteering modelling support onshore but live-linked to the wellsite. By using this knowledge in conjunction with a mud motor power section attached to an RSS, it was possible to deliver a step change in drilling performance through the reservoir.

The positive experience and results obtained by using a new class of high temperature / high pressure (HT/HP) logging while drilling (LWD) tool in a slimhole (5–3/4-in.) exploration well in Italy's Po Valley opens new possibilities for trajectory and stratigraphic control while drilling in deep, HT/HP wells. Using the LWD suite, the operator was able to acquire real time, continuous temperature, gamma ray and resistivity data for analysis and correlations at 180°C (356°F) and 16,780 psi - conditions previously unachievable. As a result, the operator pinpointed the stratigraphic position of a main direct fault that raised the upper reservoir above the prognosis estimation and was able to:achieve critical placement of the casing shoe to avoid a well control hazard posed by drilling into a partially depleted reservoir;drill continuously without having to pull the bottomhole assembly out of the hole and change bit types for better, unaltered cuttings; andidentify a carbonate sequence in the lower section, which ultimately led to the decision to plug and abandon the lower section and produce the upper reservoir, with very good results. Real time annular temperature measurements provided accurate temperature data for mud program optimization and operational considerations that are not usually available in exploration wells. This paper will discuss the characteristics and operating limitations of the Villafortuna-Trecate HT/HP field; the objectives of the Cascina Cardama 1 Dir well; the LWD planning and implementation, and the operations, logs and results. Based on the experience and results of this well, the operator will continue to use the high temperature LWD suite to drill future wells and projects. Introduction - High Temperature (HT) / High Pressure (HP) drilling: searching for hydrocarbons in deep wells The original definition of high temperature (HT) /high pressure (HP) was first introduced by the Department of Trade Industry (DTI) for the United Kingdom Continental Shelf (UKCS). It was defined as "Where the undisturbed bottom hole temperature at prospective reservoir depth is greater than 149°C (300°F) and the maximum anticipated pore pressure of any porous formation to be drilled through exceeds 18,000 Newton/meter2/meter (0.8 psi/ft) or around 10,000 psi". Other industry bodies use a different definition. For example, the Norwegian Petroleum Directorate (NPD) defines HT/HP wells as deeper than 4,000 m true vertical and/or having an expected wellhead shut-in pressure exceeding 69 MPa (10,000 psi) and/or having a temperature exceeding 150°C. These definitions are more restrictive and require a more extensive technical interpretation of potential conditions for each well. The first challenge in drilling a HT/HP well has been from pressure surges or kicks that have caused the majority of HT/HP incidents reported to health and safety managers. Drilling practices and well control procedures have been refined jointly with rig owners, and drilling crews are given well specific training to handle kick situations safely, quickly, and confidently.