Two industry experts will provide insights on new coiled tubing technology applications focused on driving innovation and incremental well performance. This will be a combined webinar presentation that will focus on cost effective abrasive jetting technologies and real time assessment of stimulation fluid diversion by employing coiled tubing fiber optics.

“Abrasive Jetting Applications throughout the Life of a Well-From Drilling to Plug and Abandonment” 

The use of abrasives mixed in a fluid under pressure has been used in the oilfield for over 50 years.  Abrasive jetting was rediscovered as a perforating method on coiled tubing in the late 1990’s and has demonstrated distinct advantages over traditional explosive perforating.  Today’s abrasive jetting technologies seek to find ways to combine the superior performance and safety into increasingly cost efficient methods to save operators time and money. Applications for abrasive jetting can be found from drilling to production to plug and abandonment, making it extremely versatile. 

This presentation educates the participant about new applications for abrasive jetting technology throughout the life cycle of the well. Abrasive jetting is no longer just a means for perforating casing - it can be used to help free stuck pipe in drilling; reduce coiled tubing runs for completing new wells; recomplete and stimulate producing wells; evaluate cement bond during plug and abandonment activities; and more.  Technical improvements are also discussed that improve effectiveness of the technology and are demonstrated in case histories. We will also look at what the future holds for this technology and where the next benefits can be found.

“Overcoming Challenges of Stimulating a Deepwater, Frac Pack Completed Well in the Gulf of Mexico Using Coiled Tubing with Real-Time Downhole Measurements”

Achieving effective fluid coverage of stimulation operations in deep water frac-pack completions is often  challenging due to a variety of factors, including but not limited to the length of screened intervals, the uncertainty of damage mechanisms, and the ability of diversion materials/fluids to divert beyond the screens and into the formation. This case study demonstrates a successful technique used in conditions not previously attempted.  

This particular well had two deep high pressure commingled zones.  Previous operations had indicated the presence of a fish or obstruction near the lower portion of the bottom zone.  Several previous attempts to stimulate the well had failed.  This was one of the deepest uses of fiber optic cable ever attempted, and the tools used needed to be tested and rated for operations outside their rated operating envelope.  

This treatment with fiber optic equipped CT and a rotating, hydraulic high-pressure jetting tool was able to achieve a successful stimulation of a 500 ft long frac packed zone after several previous failures using different techniques.  A 75% increase in production was achieved by using a CT equipped with fiber optics and downhole measurement tools. Engineers were able to perform a data-driven operation based on real-time bottomhole measurements and distributed temperature surveys.

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The well completion process of high volume hydraulic fracturing has become a touchstone for opposition to the development of oil and gas resources from shale source rocks. Although the development of shale gas and oil has brought substantial economic, geopolitical, and climate change benefits to the United States, hydraulic fracturing has displaced global climate change as the most controversial environmental policy issue. As other countries evaluate development of shale oil and gas, these same environmental concerns are available on the internet and media sources. Without data, the concerns become a substantial hindrance to acceptance of shale gas development.

This study presents the first-ever peer-reviewed study that quantifies the effects of two specific high-volume hydraulic fracturing jobs to 14 different environmental resource categories. The objective was to provide factual information supported by a high-quality dataset to guide policy making. None of the measurements detected a change due to hydraulic fracturing, including microseismic effects, ground motion and induced seismicity, water quality, methane migration, community health, well integrity, fracture containment to the target zone, and others.  

The hydraulic fracturing occurred in the center of Los Angeles, California, at the largest urban oil field in the US. The level of community and regional concern, the breadth of the study, and many of the results are applicable to other shale oil and gas areas worldwide. The results provide the first dataset that addresses the range of concerns directly, and finds no adverse effects to any of the environmental resource categories. The results have subsequently been used at state and national levels in the United States to further the understanding of these issues.

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The API Process Safety Site Assessment Program was developed in 2011 as part of the AFPM and API Advancing Process Safety Programs.  PSSAP began conducting assessments in 2012. By the end of 2017, the API Site Assessment program will have conducted 59 General (7 protocols) and 34 HF Alkylation/RP 751 assessments. These assessments have been conducted 63 different refineries and petrochemical facilities. The areas assessed are: Process Safety Leadership, Management of Change, Mechanical Integrity, Safe Work Practices, Operating Practices, Facility Siting, Process Hazards Analysis, and HF Alkylation/RP 751. Mechanical integrity typically scores 10 percentage points lower than the other areas. This presentation will provide an overview of the program and present some of the mechanical integrity learnings, trends and benchmarking data developed from the assessments based on the five-year history of the program.

SPE Webinars are FREE to members courtesy of the

The goal of the Risk Not Chance project is to increase risk awareness, and improve the understanding of risk and choice for STEM students. This project aims to increase the understanding of how risk plays a role in our everyday lives, how it can be misunderstood and how we use it to make decisions. These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.

Thank you to the United Engineering Foundation for supporting the creation of these videos. Without their support, these videos would have never been possible. Please visit https://www.uefoundation.org/ for more information about this project and others.

First responders have a unique role and perspective when dealing with safety at industrial sites. While this video is largely aimed at first responders, it’s a great way for chemical engineers to understand their role and perspective when dealing with industrial facilities. Understand what they require and why, and learn how their emergency response plan prioritizes to manage risk for them, the surrounding community, and those at the facility. 

This video is part of the Risk Not Chance project, which was designed to increase risk awareness, and improve the understanding of risk and choice for first responders. The project aims to increase the understanding of how risk plays a role in our everyday lives, how it can be misunderstood and how we use it to make decisions. These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.

Thank you to the United Engineering Foundation for supporting the creation of these videos. Without their support, these videos would have never been possible. Please visit https://www.uefoundation.org/ for more information about this project and others.

The goal of the Risk Not Chance project is to increase risk awareness, and improve the understanding of risk and choice for the community. This project aims to increase the understanding of how risk plays a role in our everyday lives, how it can be misunderstood and how we use it to make decisions. These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.

Thank you to the United Engineering Foundation for supporting the creation of these videos. Without their support, these videos would have never been possible. Please visit https://www.uefoundation.org/ for more information about this project and others.

Wellbore tortuosity is a critical element in drilling complex horizontal wells and deep verticals. The current three-dimensional borehole trajectory model, based on the minimum curvature method [MCM], tends to mathematically smoothen the wellpath. This is due to the assumption that the borehole is composed of constant curvature arcs. This assumption creates an artificially low tortuosity expressed as dogleg severity [DLS] which leads to the miscalculation of borehole positions, and generating unreliable prediction of torque and drag. A robust three-dimensional trajectory model, the Advanced Spline-Curve [ASC] model, is developed to overcome these limitations. The ASC model provides realistic results and accurately calculates the spatial course of the wellpath. Various applications of the ASC model are presented including [1] production challenges such as ESP failures and liquid loading, [2] wellbore location affect to reservoir modeling and [3] tortuosity effects on torque and drag, limiting the horizontal distance to be drilled, and raising the question: “how far can you go?”.

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Accurate models for multiphase flows in vertical pipes are needed for the design and operation of hydrocarbon production systems. Examples of important application areas are:

•       Predicting the time-of-death of gas wells.
•       Predicting the correct flow rate in liquid-dominated production systems, especially for deep water risers.

In this presentation we show how vertical multiphase flow can be modeled using a 1D approach. Specifically, we explain what kind of assumptions are needed, and which physical mechanisms require closure laws. Furthermore, we show some recent experimental work conducted at industrial conditions, aimed at deriving more accurate models, and we provide some examples of how the certain closure laws have been deduced from this new data. Finally, we assemble the new closures into a unified model, and compare the predicted pressure drop and liquid content with measured values for a large experimental database on vertical flow. We also test the new model against measurements made in a 3600 meters deep gas well, where we are able to match the measured onset of liquid loading.

The aim of the presentation is to show that vertical multiphase flow, which is known to have some very complex features, can be modelled well with 1D methods, using relatively simple assumptions.

SPE Webinars are FREE to members courtesy of the

The Completion Engineer integrates the requirements of a number of other disciplines (Reservoir, Drilling, Production, etc) to maximize the value of a hydrocarbon resource.  This almost always requires evaluating competing and conflicting factors to determine the 'best' option for a particular problem.  This talk will demonstrate a decision making process that allows the stakeholders to compare various options in a fair and robust way.  Two real onshore or offshore examples will be reviewed depending on SPE chapter interest.   

Participants will take away a new methodology on how to compare competing factors that influence a completion or well design.    

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Almost everyone who talks about Artificial Intelligence, nowadays, means neural net-based machine learning from big data, or some other sort of data analytics. Learning and using those patterns is a lot like what our right brain hemispheres do.  It enables AI's to react quickly and -- often -- adequately. But we human beings also have a left brain hemisphere, which reasons more slowly, logically, and causally. And we make good use of both halves our brain! Human beings' "super-power" is harnessing both types of reasoning, and I believe that the most powerful AI solutions in the coming decade will likewise be hybrids of right-brain-like "thinking fast" and left-brain-like "thinking slow". The ability (versus inability) to rationalize their decisions will make near-future AI systems like autonomous cars, household robots, automated assistants to petroleum engineers, AI-powered social media,... far more trusted and far more trustworthy (versus a string of costly and unfortunately newsworthy disasters). This presentation will recap the methods AI has developed for this sort of symbolic representation and automated "thinking slow" reasoning, the progress over the last several decades, and the current state of the art, and illustrate some of this with examples from our applications in the oil and gas industry.

SPE Webinars a FREE to members courtesy of the