Abstract
Economically marginal wells, sometimes critical in their own right, can require tight equivalent-circulating-density (ECD) control just like their expensive HTHP, deepwater, and extended-reach counterparts. Limited budgets or well conditions, however, may preclude use of pressure-while-drilling (PWD) technology. This paper presents a case history where the ability to manage ECDs from within a remote, real-time operations center was tested on an HTHP well in the Gulf of Mexico and subsequently on a low-budget land well in the western United States. Field results demonstrate that it is possible to obtain high-quality ECD information without running PWD tools.
Special hydraulics software run at the operations center provided virtual sensors for equivalent circulating and static densities while drilling, tripping, and running casing. PWD data was available for comparison on both wells, except for the lower intervals of the HTHP well. In the latter well, high formation temperatures exceeded tool limits, so it was necessary to rely strictly on computer simulations for ECD management.
The primary purpose of this paper is to critically review these case histories to help assess the spectrum of opportunities for ECD management from remote operations centers. Field results, operational issues, planning requirements, training efforts, and technical and business drivers are among the topics that will be presented and discussed. Lessons learned and recommendations for future efforts are also included.
