Much more accurate formation evaluation is now made possible by new generation propagation resistivity tools that make more measurements than previous systems. The additional measurements provide new information from the borehole and the near borehole environment as well as the formation itself. They also provide the capability to identify and differentiate between environmental effects. An new, advanced processing method combines many of the measurements collected by the tool then identifies and corrects for environmental effects. This includes a new method for dielectric constant correction. The method also calculates horizontal (Rh) and vertical resistivity (Rv) for high angle wells where anisotropic effects are present. A global solution for Rh and Rv is derived using a minimum of four measurements. This eliminates uncertainty where multiple solutions of Rh and Rv are possible. After corrections are made for environmental effects the method then generates four resolution-matched resistivity curves with fixed depths of investigation (radii) at 10", 20", 35", and 60". This format facilitates invasion interpretation, particularly where both resistive and conductive invasion are occurring proximal to one another. Field comparisons to wireline array resistivity measurements demonstrate the robustness of the method under a variety of formation resistivity environments and clearly shows where interpretation methodology is improved. P. 431

In horizontal tight and unconventional reservoirs there is currently a lack of low-cost/low risk data that could be used for optimizing completions and hydraulic fracturing designs. The objective for optimizing completion and frac designs is to achieve more consistent stimulation and production from every stage in the lateral. Most wells are completed based on geometric stage lengths and cluster spacings. Evidence is beginning to suggest that using geometric frac stage lengths does not provide consistent production from each perf cluster within a particular stage.Traditionally, unconventional lateral well completion planning uses mostly vertical pilot-hole wireline log data where available. The resulting rock and reservoir characterization is projected along the entire length of the lateral. This methodology does not account for reservoir/mineralogical heterogeneities that can adversely affect stimulation efficiencies for each stage and ultimately, production. By properly characterizing the lateral, the completion design can be optimized with strategic staging and cluster selection that should result in a more consistent production from every perf cluster in each stage. This paper demonstrates a process for correlating mineralogical and textural formation properties from drill cuttings with data from the pilot-hole (including wireline, mud-logging and drilling data and any available core data) with drilling and mud-logging data from the lateral. This process improves lateral well characterization in real time and provides the basis for an optimal completion design. This paper will illustrate the process using currently available data.

In this day and age of rapidly evolving technologies coupled with a dynamic workforce environment, in terms of age, experience, and geographic diversity, it is becoming increasingly challenging to ensure quality personnel are available to meet the ever-increasing technical demands of the oilfield. With the growing trend toward precision wellbore placement in horizontal, highly-deviated and multilateral wellbores, advanced geosteering services are critical to a project’s success. Reservoir navigation has become a fundamental part of the modern field development program where simple geometric well targets do not capture the capabilities and value of today’s technologies. Reservoir navigation refers to those activities designed to place the wellbore in a predetermined location and maintain it within a desired location within the reservoir. Proper geosteering optimizes wellbore placement in the productive reservoir, maximising both drilling efficiency and hydrocarbon production. It involves real-time interpretation and decisions while drilling to properly and accurately place the wellbore in the most productive zone in the reservoir. The process can be complex and requires a high level of expertise. Historically, the industry has relied on field engineers with years of field experience and a geosciences background as a talent pool for reservoir navigation engineers. It can then take several months of classroom, on-the-job training, guidance, and mentoring before a reservoir navigation engineer can break out on his/her own. A growing demand for these complex, precision wellbore placement applications are out-pacing our ability to fully develop the required competencies of reservoir navigation engineers using traditional training methods. The challenge is to decrease competency development time without compromising the technical proficiency of the individual (Hearn, et al., 2008). That is, how do you develop engineers to work with, and eventually step into the shoes of, existing experts? How is knowledge transferred, and how do we ensure the next generation of engineers can supply the same level of service with the same fundamental knowledge in this fast-paced world of answers while drilling? While experience is always the best teacher, proper mentoring and a clearly defined framework of skills and processes for acquiring those skills is required. This paper maps out such a framework and explores the results of two years of development of several new reservoir navigation engineers.

The Dual Propagation Resistivity (DPR, tool provides two electromagnetic propagation resistivity measurements to improve formation evaluation in all types of muds. It transmits a 2 MHz signal into the formation and measures the phase difference and amplitude ratio between two closely spaced antennas. These measurements are converted into phase difference resistivity, Rpd, and amplitude ratio resistivity, Rar, and together with gamma ray they are transmitted to the surface for real-time decision making. They are also stored in downhole memory and can be sampled as fast as every 5 seconds producing a high density data log for petrophysical analysis. The sample rate can be adjusted on the rig for changes in the drilling rate of penetration.The depth of investigation of Rar is deeper than Rpd but both are deep enough to eliminate most borehole effects. Beds as thin as the antenna spacing can be detected and the vertical resolutions are such that no corrections are needed in beds too thin for conventional induction tools. Two curves allow the effects of invasion and hydrocarbon to be distinguished, and log quality to be better controlled.Log behavior is similar to a dual induction log in most lithologies but there are important differences. Normally, the DPR logs are made just after drilling when invasion is not deep enough to affect either Rar or Rpd. In this case they both will read true formation resistivity, Rt. In a hydrocarbon sand Rpd and Rar will both read high, though Rar will be less accurate than Rpd if Rt is over 20 ohm-meters. Ideally, Rpd and Rar should read the same in impermeable lithologies, regardless of resistivity. In high resistivity formations Rpd is more accurate than Rar and it is less affected by the dielectric constant of the formation.Log quality is monitored in real-time by evaluating the References and illustrations at end of paper. 521 separation of the two resistivities as a function of the lithology. In an impermeable, low resistivity formation the curves will read the same. If they do not, and the lithology does not change, then damage to one, or both, of Fhe antennas is indicated. The DPR tool is calibrated for temperature and the antennas are hardened against the effects of hydrostatic pressure.

Traditionally in the oil and gas industry, expertise in the geoscience disciplines has been built largely upon the acquisition, interpretation, and post-processing of measurements obtained from wireline-conveyed logging instruments after the well was drilled. However, the recent shift in acquisition strategies toward logging while drilling (LWD) and the evolution of while drilling applications require a new generation of geoscientist equipped with a new set of skills. An in-depth understanding of the latest LWD technology combined with knowledge of the dynamic drilling environment is essential for successful integration of while drilling applications. A new competency management system has been implemented to facilitate the accelerated development of geoscientists in company core competencies to more effectively adapt to today's while drilling environment. The system consists of a drilling and evaluation competency framework with core disciplines, skills specific to each, and common skills that bridge these disciplines. Mentors assigned to each geoscientist assess skills and skill gaps, provide guidance and accelerate development through direct knowledge transfer. The competency development system also includes a formal certification process and tracking system that ensures each geoscientist meets or exceeds development expectations. There are 12 primary geoscience and drilling certifications and six advanced certifications in areas of drilling, geology, geomechanics, formation evaluation and petrophysics, reservoir engineering, reservoir navigation, integrated pressure management, wellbore integrity, and completions and production. The certification process also provides the direct link between competency development, required peripheral training (technical and non-technical), and the career ladder for geoscientists and application engineers. Introduction Until recently, geoscientists worked in a post-acquisition environment. Wireline open-hole logging acquisition occurred at the end of each hole section and at total depth. Logs were evaluated during the post-drilling phase to identify pay, and decisions were made on whether to plug and abandon or put the hole behind pipe and make a well. The evolution of high-quality LWD technologies has led to the replacement of most post-drilling open-hole wireline logging operations in high-spread cost environments with LWD. Eliminating the need for wireline logging after drilling greatly reduces non-productive time (NPT) and subsequently reduces drilling costs significantly. Although LWD technologies are similar to their wireline counterparts, there can be important differences in the physics behind each measurement. More importantly, LWD and wireline logging environments have stark contrasts: wireline logs in a static environment, whereas LWD occurs in a dynamic environment (i.e., tools rotating in the borehole with constant axial and lateral vibration; bit and bottom-hole assembly whirl; and drilling fluid circulating with its properties constantly changing). These factors can greatly affect the response of the measurements and need to be considered when evaluating every log. Geoscientists today not only require an in-depth understanding of the latest LWD technology, but also knowledge of the dynamic drilling environment. Additionally, LWD and drilling-related measurements are being integrated in real time to address while drilling challenges in drilling performance, hazard mitigation, advanced wellbore placement, and reservoir characterization. Consequently, the need has evolved for a new-generation geoscientist equipped with a newly defined set of skills.