Anadarko has created an internal drone department called the Aerial and Visual Analytics Team and one of their primary responsibilities is the safe and efficient deployment and management of drones in our theaters of operations around the world. Information will cover the areas of interest for training pilots to conduct safe and productive flights to generate the data our business units need to make better, more timely decisions. This enhanced training program also reduces net risk and effects lower LOE.

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Historically supply of subsea equipment has been mainly a product business: the operating company (client) has generated a specification and the equipment vendor designs, manufactures, tests and delivers a product to meet that specification. Over time some clients began to see the value of instead ordering integrated products (e.g. trees + controls) or in some cases “systems" (e.g. trees, controls, umbilical, manifolds, jumpers, connectors) – more scope for supplier innovation, fewer interfaces to manage, fewer integration issues. OneSubsea was formed in 2013 with the intention to take this evolution one stage further by strengthening the link between the subsea equipment supplier and the reservoir. To this end, integrated reservoir and production system simulation workflows have been developed and applied to expedite and improve the field development planning process. This talk will give an overview of these workflows and examples of how they have been applied in practice.

Minifrac Tests are also known as: Fracture Diagnostic Tests (FDT), Fracture Calibration Tests (FCT), or Diagnostic Fracture Injection Tests (DFIT). 

The objectives of Minifrac Tests differ depending on the permeability of the formation, which dictates the type of test that is appropriate for the analogue treatments: Frac-Pack, Conventional Prop Frac, Acid Frac or Unconventional Frac. The design of the appropriate Minifrac Test also depends on the permeability of the formation; while the aim is to obtain the most information at the least cost, least time, and least formation damage.  The test procedures also differ, that is, we can have a Pump-in Shut-in Test, a Pump-in Flow-back Test, etc.

Basic analysis techniques include: Linear Plots, Square Root Plots, Log-Log Plots, and G-Function Plots. A major parameter determined is the Closure Pressure, which is used to determine almost all other parameters: Efficiency, Pad size, Net-Pressure, etc. The Rate Step-Down Test analysis determines the three friction components: Pipe, Perforation, and Near-wellbore advanced analysis techniques include Before Closure Analysis, and After Closure Analysis. Besides the Flow regime (Bilinear, Linear, or Radial), other parameters can be determined: Permeability, Fracture Length, Reservoir Pressure, etc.  Step-Up Rate Test, useful for Acid Fracturing, includes the determination of The Fracture Extension Pressure, and the Minimum Horizontal Stress.

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Scenarios for outlooks of energy demand and supply are important tools for policy makers and the industry to evaluate the impact of policy options on a number of societal development issues. Most of the outlooks incorporate a scenario with current (or announced) policies; they may also include variations, such as sensitivity analysis on exogenous factors (such as economic growth), or more fundamental changes such as strong carbon-reduction measures.

The current trends of energy demand would lead to continuous greenhouse gas emissions, testing the limits of sustainability. Additionally, meeting the United Nations’ Sustainable Development Goals, that target a major reduction in energy poverty would be very challenging.

The International Energy Agency (IEA) developed a scenario, named Sustainable Development Scenario (SDS), that would address three major energy-related aspects, namely universal energy access, reduced greenhouse gas emissions that would be compatible with a (less than) 2-degree trajectory, and improvement in air quality. The presentation highlights major implications of the SDS in terms of global energy supply and demand, as well as policy and technology requirements. It also compares the investments requirements compared to current trends, and the implications for the oil and gas industry.

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After several decades, the understanding of asphaltene precipitation and deposition still remains a problem for the oil industry due to the lack of reliable laboratory tests able to represent the field conditions. This makes the mitigation of asphaltene issues a greater challenge. This talk will present different techniques developed to understand the asphaltene behavior and their associated assumptions, limitations and uncertainties. Additional R&D efforts are required to improve the current state of art of asphaltene knowledge.

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Leadership is always important in any strategic program, but is the leadership challenge different in a digital world any different than for safety, environmental or for operational excellence programs? How is it different in today’s digital oilfield? How is emerging technology, commodity price cycles and increasing regulation impacting a leader’s role? The webinar will summarize the perspectives and insights from industry experts in leadership positions on how leadership challenges are similar or different in the world of digital transformation.

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Many project look-backs from unsuccessful digital transformation projects point to the lack of the right organizational culture for the adoption of digital oilfield solutions. What is the right organizational culture for a data-driven enterprise? What is the role of executives versus bench level engineers? What is the importance of standardization versus local customization? How can an effective change management program help lower the barriers to adoption?  These are some of the questions that will be asked during this interview.

Tune in to this 30-minute interview to gain insight into this industry expert’s personal views and professional experiences on why many digital transformation projects fail, due to the lack of organizational culture.

Interview with: Helen Gilman, VP at Wipro, Oil & Gas Consulting and Solutions  

Interviewed by:  Jim Crompton, Reflections Data Consulting / CO School of Mines

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This series of industry interviews will focus on understanding and capturing the historical legacy of petroleum geomechanics from the experts who created it. From this historical foundation, these same experts with consider the future path, focus and value of petroleum geomechanics.

Tune in to this 30-minute interview to gain insight into this industry expert’s personal views and professional experiences on why they chose to focus on the Geomechanics field; what it was like when they began working in it; its evolution and where they see Geomechanics going in the future.

Interview with: Jean-Claude (J-C) Roegiers, Professor, University of Oklahoma School of Petroleum and Geological Engineering.

Interviewed by: Neal B. Nagel, PhD, Chief Engineer and Principal, Oilfield Geomechanics LLC; Chair, SPE Geomechanics Technical Section (GTS)

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For many years, the benchmark for indicating perforation performance in the well was a surface gun test into concrete. However, it became recognized that shooting an API concrete target at a surface could not be effectively correlated with actual downhole conditions of overburden, reservoir pressure and rock properties. After many years of effort on behalf of the Operators, the service contractors and manufacturers were finally persuaded to accept that the correlating of real well conditions with concrete was not helpful to the Operators and their well performance. Since then, new standards have been written to promote shots into stressed rock targets as the standard for identifying performance down hole. All the contractors and manufacturers now have dedicated facilities to provide stressed rock tests and are actively developing improved charges that work well in real reservoir conditions, rather than concrete at surface. Having passed through over a decade with almost no new developments in perforating, the last 5 years have seen significant developments in  technology, with contractors and manufacturers working actively to improve performance and technology.

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One idea: Our industry is in the new era of greater competition and must become more efficient to continue to prosper. Only about 15 years ago "peak oil" theories were quite popular and accepted by the general public.  Another school of thought, based on the concept of resource triangle, stated that as technology develops and as prices increase, vast amounts of hydrocarbon resources will become commercial. Oil and gas prices did increase and this led to the unconventional oil and gas revolution. Recent analysis of resource potential based on technical data collected for North American basins (S.A.Holditch et al) showed that we may think of hydrocarbon resources as being essentially infinite for practical purposes.

However  the cost of the resource development, as expressed by the production activation index (the CapEx required to create production stream of 1 stb/day) increased over the decade  from about  1000-10,000 USD/bopd range for conventional oil, up to 15,000 USD /bopd, and more in some cases. Maintaining production levels with unconventional resources requires continuous drilling. The rapid rate of decline of unconventional wells translates to roughly a three-fold increase in the cost of generating a unit of energy compared to conventional wells. At this order of magnitude of energy cost, other sources of energy and combinations of technologies become competitive with conventional fossil fuel based energy and transportation.

3/4 of all the oil that we produce is used for 3 purposes: ground transportation, heating and electricity generation, and jet fuel. In this lecture we will discuss competitive technologies, their technical limitations, their progress in application and market penetration trends. These competitive technologies are solar power, electric automobiles, and magnetic levitation trains. The  high energy density of gasoline made conventional internal combustion engine cars prevalent at the turn of the  20th  century. But today, the higher energy efficiency of electric cars and improvements in battery technology are making electric vehicles competitive. We review how the future may look like and how our industry may adapt and change.  As the transition starts there will probably be long term demand destruction trend in OECD countries.

It is likely that the industry will experience significant downward oil price pressure as alternative technologies become more competitive. We need to train young engineers in energy engineering rather than just petroleum engineering.

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