Oil and Gas industry use PLT methods to obtain information of the reservoir, dynamic test using ESP artificial lift systems with Bypass to allow have access to the perforations has been commonly used on 9 5/8" Casing on different weights. However not all the time those casing sizes are available raising the requirement of logging on 7" casing configuration which require slim design equipment on both ESP and By pass tools in order to leave enough clearance not only to run and pull the equipment safely but also to make it suitable for PLT logging (using Wireline and Coil tubing) when installed on hi deviated well configurationsi The purpose of the following paper is to present a real example of a successful installation of 7" Bypass Systems with successful PLT logging experience in Rubiales Field (Pacific Rubiales - Colombia), using tools that has been installed and pulled several times to perform the operation on 25 wells introducing savings for over 1MM$ on completion equipment and providing important reservoir information to help develop the field. Also this documents aims to become a reference for logging process planning having the right considerations when installing this system on Hi deviated zones (over 60 Degrees) Evidence explained on this paper helps to conclude that 7" Bypass System installed prove to comply with industry requirements on Hi deviation Wells (over 60 Degrees) and that not only can be run but also by Introducing right redress and inspection process the system can be re used several times (Over 12 times) saving money on completions equipment. Logging on Hi deviation Wells with 7" By pass Systems introduce an alternative for reservoir understanding, promising to have huge impact on the way fields can be developed by having PLT test on wells with these characteristics.

The Oil and Gas industry is always looking for methods that reduce costs associated with the drilling process and, over the last decade, eliminate the environmental impact of well preparation. One new technology provides an option for oil and gas producers to achieve that goal allowing installation of two sets of electrical submersible pumps (ESP) on the same well bore but producing two sands separated by a packer. The purpose of the following paper is to to present a real example of the successful installation of a Dual Concentric Completion System in COPA ASUR3, allowing two ESP systems to produce two different sands on the same well bore separated by a packer, and to demonstrate the economic effects of its use, reducing by 38% the costs associated with the drilling process, 14% on the total drill/completion investment and 50% on the environmental impact in COPA field (Colombia). The design and installation of the system were carried out taking into consideration Local Governmental regulations requiring both production zones remain insulated from each other. Evidence explained on this paper helps to conclude that Dual Concentric Systems are proven to be applicable for specific fields with adequate sand distribution and fluid characteristics, also the use of Dual Concentric Systems complies with Government regulations keeping production from both zones isolated when applying the right integrity test procedure and that the use of Dual Concentric Systems significantly reduces costs and environmental impact associated with the drilling process and surface facilities configuration requirements.