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An innovative ES-PCP system has been developed in conjunction with a major operator and has now entered field trials. The system enables rig-less deployment capability on coiled tubing, and is compatible with conventional jointed tubing. It fundamentally addresses many of the issues associated with horizontal wells and sand management, and provides a highly efficient solution for applications from gas well dewatering, cyclic steam stimulation, and CHOPS. This paper describes some aspects of the design and qualification of the system, and presents initial feedback from the first field trials. The system utilises downhole permanent magnet motor technology and a magnetic torque converter, resulting in both scalability and high operating efficiencies. This dramatically reduces the total power requirements, and the need for expensive surface electrical installations. A progressive cavity pump is incorporated on bottom, allowing this small diameter system to be set at any depth and in the horizontal. Combined with the ability to run at variable speed and rotate in either direction; sand related failures and workovers are reduced. This novel configuration reduces both the surface footprint and environmental impact of the well. It also reduces deployment and workover requirements; resulting in fewer and safer operations. By combining unique technology and a novel configuration an ES-PCP system has been developed which reduces total cost of ownership. The system has entered field trials in the San Joaquin Valley fields in California for a heavy oil production application, and Western Australia for a gas well dewatering application.

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThe Machar field is primarily a naturally fractured chalk reservoir; with the subsea wells requiring acid stimulations in order to be economic. This paper describes the design and implementation of an acid stimulation for a new intelligent well completion. The combination of a subsea development, a high rate boat based acid stimulation and a surface operated intelligent completion provided several challenges.The stimulation challenges arose due to the long reservoir completion and the required use of flow control valves with small tubing within this section. This prevented the traditional use of ball diverters in order to effectively treat the whole reservoir interval. By using the isolation capabilities of the intelligent completion, several intervals were sequentially treated. Within each completion interval, limited entry perforating provided the method of diversion necessary to effectively treat each perforation. In order for this to be successful, the perforations had to be centralised and shot prior to running the completion. Limited entry perforating therefore required physical gun shoot tests and a pump test through the shot holes. The results and conclusions of these tests are included in this paper.The completion challenges related to the stimulation included assurance of the integrity of the sensitive downhole electronics and hydraulics required to operate the downhole valves and sensors. This assurance was vital as, for the first time with an intelligent completion, the stimulation involved pumping concentrated hydrochloric acid down the well at rates of up to 50 bpm.Implementation of the stimulation was achieved with the real time multizone downhole pressure and temperature data providing several fascinating opportunities to view downhole mechanisms. Of particular interest is the pressure transient impact of a stimulation on adjacent zones and the cooldown effect on partially trapped annuli. The analysis of this downhole data is presented.

Intelligent-well completion (IWC) is an emerging technology that allows operators to optimize reservoir management and field facilities performance. The implementation of this technology has generally been restricted to new field development because of the perceived complexity of integrating high-end IWCs (e.g., combined monitoring and flow control) into current subsea-productionsystem (SPS) designs. However, intelligent completions can be applied to mature fields in which reservoir performance and value added by IWC are well understood. The BP Machar well application is a typical example.One of the challenges facing the project team at the BP Machar well was the integration of the IWC-control system within the constraints of the existing SPS. Minimum modification to the existing hardware and control-system equipment was required.A system approach-in line with the forthcoming ISO 13628, Part 6 [intelligent-well interface standardization (IWIS) addendum] standard for integration of IWCs into SPSs-was used to ensure robustness of the design and testing concepts.

This paper describes innovative small diameter electrical pump systems which can be installed through tubing or casing using cable deployment or coil tubing deployment, eliminating the need for a rig during pump installation and retrieval operations in the field. The capability is being developed for 10 bbl/day to 10,000 bbl/day pumping systems.The underlying, new technology which enables small, high force dense pumping systems is permanent magnet technology, including novel permanent magnet motors and permanent magnet transmissions. This technology, which has been under development for the last 3 years, exists for pumps so small they can be retrofitted though 2 3/8" production tubing (low volume pumping) and larger diameter for high volume pumping. Integrated downhole sensors provide valuable data for production management and condition monitoring of the downhole pumping system. Systems utilizing these technologies are currently undergoing qualification testing in preparation for field trials late 2012/ 2013. Numerous rigless intervention opportunities can be realised in most oilfield environments as the technology enables a key industry transition from a workover activity to an intervention activity for installation and retrieval of pumping systems. Conveyance of pumping systems is decoupled from jointed pipe rigs, offering significant opportunities for operational cost savings and production uptime. For example, pumps can be installed and maintained from a riserless light well intervention vessel in a subsea well, or in a well on a normally unmanned offshore installation, or installed in a remote land location without a using rig.