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A new logging tool that is will identify the free point in drill collars, drill pipe, tubing, or casing has been developed and field tested. The tool is commercially available in the wireline service sector for drilling support and well abandonment operations. Unlike previous free point methods, which used strain measurements of the pipe obtained as a series of stations with and without the application of pipe stretch or torque at each station, this new method is simply overlay of two logging passes. The first logging pass is recorded with the pipe in a neutral weight condition, and the second logging pass is recorded with tension or torque applied to the pipe. The tool utilizes the property of steel called magnetostrictive effect. When a mechanical stress is applied to the steel, the magnetization of the material is modified. Thus when torque or tension is applied to the pipe that is free to move, their magnetization will change. If the pipe is not free to move their magnetization will remain the same. The tool has been successfully tested in steel alloys that have minimal magnetic properties. This new logging tool has many advantages over legacy free pipe determination methods. First, from a rig safety standpoint, the application of pipe stretch, or torque is applied only once for a few minutes for the logging pass. With legacy free point methods numerous stationary measurements were required, with the pipe being stretched/torqued at each station. Since determination of free point is a comparison of two logging passes, real time operations and 24/7 satellite communications allow remote based operator and service company pipe recovery experts to be involved with the well site decisions. While this new technology uses a comparison of two logging passes, well site operations is not dependent on a pipe recovery expert with extensive hands on experience to be on location, or delays waiting for pipe recovery experts to arrive on location. This benefit is extremely important with the aging of the industries workforce. The small diameter logging tool is run centralized, and does not require weight bars added to the tool for slip engagement, this shortens the length of the tool string and simplifies e-line rig up procedures. Introduction Previous generation free point tools utilized strain gauge measurements which detected the stretch or rotation of the drill sting when the free point tool was mechanically anchored in the drill sting and force applied to the pipe. The determination of the free point required many stationary measurements over the estimated stuck point region with the drill string in a neutral condition and then again with either tension, or torque being applied during each recording. Mechanical slip engagement of the strain gauge sensor in the vertical and azimuthal planes is critical. This method often requires many hours of rig time and the talents of a highly skilled free point logging expert. The tool utilizes the property of steel called magnetostrictive effect1. When a mechanical stress is applied on steel material; the magnetization of the material is modified. When torque or tension is applied to the pipe that is free to move, their magnetization will change. If the pipe is not free to move their magnetization will remain the same.

Multiple perforation laboratory programs have been conducted during recent years to support high-pressure/high-temperature (HP/HT) and ultrahigh-pressure (UHP) oil and gas field developments at various offshore locations globally. This paper highlights six such projects that supported activities within the Asia-Pacific, North Sea, and US Gulf of Mexico (GOM) (both Miocene and Lower Tertiary) regions. Each program was designed and conducted in collaboration with an operator and field operations personnel to help reduce potential risks, improve operational efficiency, and optimize well performance across a variety of challenging environments. Laboratory experiments were based on API RP 19B Sections 2 and 4, with test conditions customized to match specific downhole environments of interest (rock and fluid properties, stress, pressure, temperature, and flow scenarios). Matching downhole conditions at the laboratory proved important because this yields results that can be quite different from those obtained at surface (or scaled) test conditions. Reliable estimations of field perforation skin, sanding propensity, and the effectiveness of subsequent stimulation operations depend on realistic perforation and flow data obtained at relevant downhole conditions. The overriding goal for test design is to create and expose the laboratory perforation in an environment that matches its field counterpart as closely as possible. Beyond obtaining accurate flow data for skin and/or sanding propensity determination, post-test diagnostics, such as computed tomography (CT) and optical techniques, provide additional essential insight into the characteristics of the perforation tunnel, core interior, and the hole through the casing and cement. Results from these various programs were used to confirm or, in some cases, guide the field perforating strategy.

A growing number of publications focus on Knowledge Management (KM) programs, but to date very little has been written about what those programs can do to ensure their success. Not all implementations are flawless. As a result, developing the right knowledge management measurement model can be the most critical component in the ongoing viability of any KM initiative. The right measures can quickly indicate the health of a knowledge management program and provide insight into opportunities for enhancement. A KM program for Perforating was initiated due to a compelling business need. The program design included a measurement model that adopted recognized business metrics and indicators, as well as daily KM activity measures to gauge the health, growth, and reach of the community. With early and consistent monitoring, this balanced model for measurement allowed the quick identification of several key opportunities. Expansion and enrichment of the KM program immediately ensued, using techniques such as knowledge mapping and the appointment of Local Knowledge Champions. This paper will discuss in detail the balanced scorecard approach that was critical for timely adjustments in strategy and scope, the change management interventions that were undertaken, and the application of lessons learned and the best practices that resulted in a successful KM program. This success is evidenced by a decrease in the top failure modes, a decrease in the cost of poor quality, and an increased awareness of correct procedures and processes. Introduction A scoping team was assembled in July of 2001 to define the direction of KM at Halliburton with a goal of increasing service quality. Members represented a cross section of the Energy Services Group organization. Rather than an enterprise wide approach using IT technologies, the team recommended a focused project approach, implementing KM solutions directed toward a specific business need in four months. The project approach, led by a small KM core team, would support a small project team of community members with emphasis placed on the people, processes, and content. IT solutions would be applied only as needed to support the community. Three pilot KM projects were selected using three basic criteria:Capability of deploying a solution within four monthsAbility to improve service qualityOpportunity for a valid test of KM concepts This paper reviews the development and deployment efforts of the KM solution designed around Halliburton's internal perforating community. The solution began in a pilot project focused on a segment of the community which was later expanded to serve the entire community. Ownership Defined For a KM solution to work, the business unit to which it belongs and the community in which it operates should own it. The power of KM is in the people it serves. Knowledge Management leverages the intellectual assets of the community, enabling information and knowledge sharing, leading to better employee performance and business results. Ownership by the business unit and its management is also crucial to sustain and build KM success. Key resources were allocated and selected by two business units that provide perforating services. The vice Presidents responsible for the two business units, along with the General Manager of the Perforating Technology Center and the Chief Technology Officer were executive sponsors for the pilot. Five individuals were selected to participate in the pilot project, including end users and recognized subject matter experts. The team was assigned to the project full time from September to December 2001. Best Practice: The business must own the KM solution. Best Practice: Assign individuals to the project full time. An intense effort over a short time creates value quickly.

Hydraulically fractured completions dominate industry perforating activity, particularly in North American land basins. This has led to the development of fracture-optimized perforating systems in recent years. Aside from overarching safety, reliability, and efficiency priorities, the main technical performance attribute of these systems is consistent hole size in the casing, driven by limited entry fracture design considerations. While the industry continues to seek further improvements in hole size consistency, attention is also being directed to the perforations more holistically, from a perspective of maximizing the effectiveness of subsequent hydraulic fracturing and ultimately production operations. To this end, this paper presents two related activities addressing the development, qualification, and optimization of perf-for-frac systems. The first is a surface testing protocol used to characterize perforating system performance, in particular casing hole size and consistency. The second is a laboratory program, recently conducted to investigate perforating stressed Eagle Ford shale samples at downhole conditions. This program explored the influences of charge size, formation lamination direction, pore fluid, and dynamic underbalance on perforation characteristics. Casing hole size was also assessed. For the first activity (surface testing), we find that using cement-backed casing can be an important feature to ensure more downhole-realistic results. For the second activity (laboratory program), perforation casing hole sizes for the charges tested were in line with expectations based on existing surface test data, exhibiting negligible pressure dependency. Corresponding penetration depths into the stressed shale samples generally ranged from 3.5-in to 5-in, which is much shallower than might be expected based on surface concrete performance. Dynamic underbalance was found to exhibit some slight effect on the tunnel fill characteristics, while pore system fluid was found to have minimal influence on the results. An interesting feature of the perforated samples was the complex fracture network at the perforation tips, which appeared "propped" to some extent with charge liner debris. Some of these fractures were formation beds which had delaminated during the shot, a phenomenon observed for perforations both parallel and perpendicular to the laminations. The implications of these results to the downhole environment continues to be assessed. Of particular interest is the impact these phenomena might have on fracture initiation, formation breakdown, and treatment stages which accompany subsequent hydraulic fracturing pumping operations.