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The primary fluids encountered are brines and hydrocarbon oils and gases. Drilling, completion, and fracturing fluids can also be present, and their effects are typically studied to prevent formation damage. This page will concentrate on the role of water and, in particular, how water saturation can influence rock strengths measured in the laboratory or derived from well logs. Pore fluid pressures will reduce the effective stress supported by the rock mineral frame. This effect has been well known since the publication of Terzaghi and Peck and has been documented by numerous investigators.
Mature oil and gas wells will underperform due to different damage mechanisms and/or low permeability, and the unconventional oil and gas wells could not produce at economical rates unless stimulated successfully. The key is to understand and identify the damage mechanism and sources of low productivity in both conventional and unconventional reservoirs, and then to design economical and successful stimulation treatments. In this course, participants will first learn the fundamental science related to geosciences, rock mechanics, and fluid mechanics, and then gain know-how knowledge on the principles of well stimulations followed by practical skills related to design and evaluation of stimulation treatments. At the end of this course, participants will gain the ability and confidence in solving real-world problems by integrating physics, geology, rock mechanics, formation evaluation, production and reservoir engineering. Examples, case studies, and leading software demonstration/practices will further enhance participants' knowledge and skills acquired in this course.
It goes on to detail the mechanisms, applications, and challenges of the various sand control options in both vertical and horizontal applications. It mainly focuses on a practical project requiring the participants to apply what they have learned by selecting, designing and presenting the most appropriate sand control completion for several case study wells for both cold primary and thermal application. The course reviews several field failure examples and case studies to guide engineers to better understand the factors contributing to sand control failure and how they can operate their wells to minimize the failure potential. This training is geared towards petroleum engineers and production managers who wish to strengthen their technical understanding of sand control and to make confident purchasing decisions. Completion, drilling, reservoir, and production engineers involved in sand control design, installation and operating wells with sand control completion.
Describing operational sequences, Modern Well Design presents a unified approach to well design process and walks through an overview from spudding the well through drilling and completion to startup and production. Attendees will learn elementary rock mechanics and simple ways to analyze borehole stability. The information is then applied to fracture gradient curve design, which serves as input to the well design process. Discussions regarding the potential for optimization will conclude the course. Some of the practical solutions given in the course come from many years' experience in the North Sea, and are not published elsewhere.
This course presents the fundamentals of fracturing pressure analysis. This includes design parameters that can be determined, uses and limitations of such analysis for on-site design, and field examples. Sessions include real world examples from a variety of environments, from "tight" gas to high permeability, offshore, and "frac-pack" treatments. Topics covered include in-situ stresses, fracture geometry, closure pressure determination, bottom hole treating pressure interpretation, pressure decline analysis, fluid efficiency, Fluid loss coefficient, pressure vs. fracture height growth--stress profile, proppant/fluid scheduling from pressure decline data. Engineers those involved in design and evaluation of hydraulic fracturing jobs.
This course covers the fundamental principles concerning how hydraulic fracturing treatments can be used to stimulate oil and gas wells. It includes discussions on how to select wells for stimulation, what controls fracture propagation, fracture width, etc., how to develop data sets, and how to calculate fracture dimensions. The course also covers information concerning fracturing fluids, propping agents, and how to design and pump successful fracturing treatments. Rock mechanics/in-situ stress aspects of fracturing Reservoir aspects of fracturing (How much fracture do I need?) Fracture design variables Perforating for fracturing Fracture diagnostics You will receive a sound engineering approach to fracture treatment design and a thorough analysis of fluid/proppant selection and ancillary fracturing topics. Production and completion engineers and field operations staff with basic to moderate knowledge or experience in designing, pumping or evaluating hydraulic fracture treatments can benefit from this course.
The main objective of the course is to apply geophysics to petroleum engineering aspects of reservoir analysis by demonstrating how the models arrived. Several key topics will be discussed in detail including: stress analysis, rock physics, rock mechanics, and reserve estimate. The integration of multiple seismic inversion models will be described in a manner that improves communication. Students should have an existing understanding of ESP equipment and operations. All cancellations must be received no later than 14 days prior to the course start date.
The course presents the fundamentals of hydraulic fracturing, along with addressing the general process, the "terminology," and many of the "real-world" problems - in a concise format. The overall emphasis of the day is how hydraulic fracturing fits-in with, is impacted by, or impacts geologic concerns, reservoir engineering, and operations. The day will provide a general familiarity with fundamentals of the complete hydraulic fracturing process. That is - why it works (or doesn't), where is it applicable, and what might be considered in order to "do better." Introduction – What is fracturing?
This course is a critical examination of microseismic results to evaluate engineering decisions that can and should be made in unconventional reservoirs, based upon microseismicity and other information that is available to supplement it. Case studies, particularly those where other technologies have been used to validate the microseismicity, are given to illustrate the value of interpreting such results with respect to concepts such a stimulated reservoir volume and optimization of stimulations, completions, and well plans. The building of calibrated models is examined, as well as methods to improve such models in multi-stage horizontal-well treatments and use in reservoir simulators. Microseismic monitoring is a great tool for obtaining a general understanding of fracturing behavior in unconventional reservoirs, but there are many uncertainties and limitations that can result in misinterpretation of the results and potentially harmful decisions about the development of the reservoir. The purpose of this course is to discuss what can be reasonably determined from microseismic data, where other types of diagnostics can provide additional clarifying information, and how the results should be used in analysis and modeling.
This course is intended to introduce the principles, applications and tools of geomechanics to practicing, petroleum engineers and geoscientists. It will cover the basic knowledge of rock mechanics, relevant mechanical properties and geomechanics simulations to non rock mechanic specialist. Engineers those involved in exploration, well planning and drilling and geomechanics studies. Participants should have moderate experience or exposure to the topic. All cancellations must be received no later than 14 days prior to the course start date.