GENERAL MEETING | Analytics, Physics, and the Truth
When: Wednesday, February 20, 2019 | 11:30 AM
Where: Denver Athletic Club | 1325 Glenarm Pl., Denver, CO
Speakers: Donny Keighley and Kerstan Wallace, Encana
As engineers and geoscientists, a big part of our job is creating models to explain and predict well performance. We have no problem running physics based simulators, feeding machine learning algorithms, and creating mental models. Unfortunately, we also have no problem believing our models without bothering to check if they’re any good. While there is no perfect way to predict reservoir behavior given time, budgetary, and physical constraints, we think that reservoir management can be improved by questioning personal biases, making/checking rigorous predictions, and simply being honest about what we do and don’t know.
Donny Keighley graduated from the Colorado School of Mines in 2004 with a BS in Geophysical Engineering and again in 2006 with an MS in Geophysics. Since then, he has worked at Encana in Denver on various teams including Jonah, New Ventures, Permian, and Business Development. Like many geophysicists, Keighley slowly morphed into a different role -- in his case, a data analyst. Currently, he works on the Business Development team analyzing all types of data, making and using predictive models, and streamlining processes using R programming.
Kerstan Wallace received his B.S. and M.S in geology from the University of Texas at Austin. After graduating in 2013, Wallace joined Encana and has been working with the company for 5+ years. During that time he has held various roles in operations and reservoir characterization. Wallace's primary areas of focus is in subsurface data analysis, geomechanical modeling, and, most recently, well performance data analytics. Over the last few years, Wallace has been responsible for developing a predictive well performance model in the Permian Basin used to help guide program development decisions.
FACILITIES STUDY GROUP | DJ Basin Production Equipment Corrosion
When: Thursday, February 21st, 2019 | 11:30 AM to 1:00 PM
Where: Granite Tower - Anadarko's 7th Floor Conferene Center | 1099 18th St. (18th and Arapahoe) Denver, CO
Title: DJ Basin Production Equipment Corrosion – One Operator’s Observations
Speaker(s): Eric Onacila, Jacob Behling, Anadarko Petroleum Corp.
Short Description: An investigation of production equipment corrosion with an overview of prevention and mitigation methods.
SPE 39th Annual Winter Racquetball / Handball Tournament
When: February 22, 2019 | 12:30 p.m.
Where: Denver Athletic Club | 1325 Glenarm Pl, Denver, CO 80204
What: Racquetball / Handball
All skill levels. Ticket includes baquet with drinks, food, awards and door prizes.
- Platinum for $600
- Gold for $450
- Silver for $300
For sponsorship questions, please contact John: firstname.lastname@example.org
Link: Racquetball 2019
CONTINUING EDUCATION | Artificial Lift and Production Optimization Solutions
When: Tuesday, February 26th and Wednesday, February 27th, 2019 | 8:00 AM - 5:00 PM
Location: Liberty Oilfield Training Room, 950 17th Street, Floor 24 Denver, Colorado 80202
Registration Cutoff: Friday, February 22nd, 2019
This course is designed to give trainees an overview of various artificial lift solutions and related production optimization concepts. After introducing participants to the need for an artificial lift system, training will focus on each of the following lift methods: Gas lift, Reciprocating Rod Lift, Progressing Cavity Pumping, Hydraulic Pumping, Electrical Submersible Pumping, Plunger and Capillary System. For each lift type, the course covers main components, application envelope, relative strengths and weaknesses. Animations, field cases, and example-calculations are used to reinforce concepts. A unique feature of this course is discussion on digital oil field as applicable to lift optimization. The course will close with a discussion session wherein trainees would discuss their challenges and plans for lift systems with a view to understand applicability of the concepts learned during the training.
Intermediate to Advanced, depending on course length selected.
2-5 Days (The course length may be adjusted to meet the learning level of the target audience.)
Why You Should Attend
Every oil and gas well requires a lift mechanism at some time-point. Often times during a well’s life cycle, changing conditions, necessitate switching from one to another lift method. Each lift system’s applicability often overlaps with other lift systems and it is important to understand when to use one and why not to use another. This course while providing instructions at awareness level will arm attendees with sufficient details to participate in informative decision making process.
Who Should Attend
Anyone interested in learning about lift systems application. Production and field operations engineers, operators, geoscientists, and reservoir engineers who wish to understand the implications of lift systems on their field/reservoirs.
Calculator for example calculations.
Engineers are responsible for enhancing their professional competence throughout their careers. Licensed, chartered, and or/ certified engineers are sometimes required by government entities to provide proof of continued professional development and training. Training credits are defined as Continuing Education Units (CEUs) or Professional Development Hours (PDH). Attendees of SPE training courses earn 0.8 CEUs for each day of training. We provide each attendee a certificate upon completion of the training course.
All cancellations must be received no later than 14 days prior to the course start date. Cancellations made after the 14 day window will not be refunded. Refunds will not be given due to no show situations.
Training sessions attached to SPE conferences and workshops follow the cancellation policies stated on the event information page. Please check that page for specific cancellation information.
SPE reserves the right to cancel or re-schedule courses at will. Notification of changes will be made as quickly as possible; please keep this in mind when arranging travel, as SPE is not responsible for any fees charged for cancelling or changing travel arrangements.
We reserve the right to substitute course instructors as necessary.
Full Regional cancellation policies can be found at the “Cancellation Policy” link on the SPE Training Course Catalog page: http://www.spe.org/training/catalog.php.
Dr. Rajan Chokshi works as Optimizer for Accutant Solutions of Houston – A training and consulting services provider for production optimization.
In a career spanning over 30 years, Chokshi has worked on petroleum and software engineering projects globally in the areas of multi-phase flow, artificial lift design, and production optimization in oil and gas industries for national oil company and service providers. He continues to consult and teach professional courses in these areas. His interests are developing and nurturing young talent globally, technology integration and commercialization.
Dr. Chokshi is a Society of Petroleum Engineers’ Distinguished Lecturer for the 2015-2016 year. He also serves on the SPE global committees for training and production awards. He holds a Bachelors and a Masters in Chemical Engineering from the Gujarat University and IIT-Kanpur, India respectively; and a Ph.D. in Petroleum Engineering from the University of Tulsa, USA.
Other Courses by Instructor
COMPLETIONS & PROD STUDY GROUP | Addressing Well Interaction with the Help of Microseismic...
When: Thursday February 28, 2019 | 11:30 a.m to 1:00 p.m.
Where: Halliburton | 1125 17th Street, Suite 1900 Denver, CO
Title: Adressing Well Interaction with the Help of Microseismic: Enhancing Integrated Diagnostic Data Streams with Heatmaps.
Speaker: Hannah Chittenden, Geophysical Analyst and Project Coordinator, ESG Global Energy
It is well understood that in today’s field development, well communication and interaction is a problem influencing production in both parent and child wells. While frac-hits are not a new phenomenon, infill drilling and tighter well spacing of horizontal pads in areas like the Permian and Eagle Ford have intensified the issue, leading to appreciable production losses or diminished producing capacity in many wells. 1 Some operators have taken a broader field wide approach to mitigate production loss, using techniques such as simultaneous operations or tank development2 while others propose pre-loading parent wells3 or customized well sequencing4 , all in efforts to generate protective pressure barriers between wells. However, with the added complexity of subsurface heterogeneity, operators need to consider a custom approach to developing their own mitigation solutions. Microseismic analysis, in conjunction with other diagnostic data streams such as tracers, fiber, geomechanical modeling and pressure data, can provide key feedback on the nature of well interaction. While assessment of microseismic event clouds can provide evidence of interaction, it lacks the resolution required to fully assess the mechanisms driving this interaction. Building on a new approach to interpreting microseismic data that emphasizes spatial and temporal trends in seismicity over discrete event locations, zones of “wet” and “dry” seismicity are visualized in heatmaps as a function of reservoir stress conditions, providing operators with a visual tool to evaluate the degree of interaction between wells. Looking at trends in seismicity at the stage-level and across a pad in conjunction with additional diagnostic data streams provides greater clarity on zones of communication or interaction between wells. With a better understanding of the nature of this well interaction, operators can make important decisions around well spacing, frac sequencing and completions design to optimally stimulate a reservoir while minimizing production losses associated with unintended interaction. Here we present a case study from the Permian basin to demonstrate how integrated data streams can be enhanced with microseismic data to provide additional knowledge of the mechanisms driving well interaction, and offer insights to operators to help mitigate the risk of frac-hits.
Hannah Chittenden is a Geophysical Analyst and Project Coordinator with ESG’s global energy services division, where she oversees analysis and reporting for hydraulic fracture monitoring projects. Hannah joined ESG in 2014 as a geophysicist and has since taken on many responsibilities both in the office and in the field. Hannah is currently a G.I.T. pursuing her professional designation (P.Geo) and a member of the AAPG. She holds a Master’s Degree in Tectonic Geology from the University of Bern and a B.Sc. in Geology from McMaster University in Canada where she worked as an intern for the Stable Isotope Laboratory. Prior to joining ESG, Hannah worked as a research assistant where she published her work investigating foreland basins and the influence of bedrock architecture on the development of alpine landscapes.
DRILLING STUDY GROUP| A Discussion of Bradenhead Challenges...
When: Thursday February 28, 2019| 11:30 a.m. to 1:00 p.m.
Where: Schlumberger office | 1675 Broadway, 7th Floor, Denver, CO
Title: A Discussion of Bradenhead Challenges Related to Well Construction and Production Operations in the DJ Basin.
Speakers: Jeff Eulberg, Drilling Engineer and Chris Cordaro, Sr. Production Engineer, Anadarko
This is the first in what will be a series of talks on existing solutions to Sustained Casing Pressure (or Bradenhead pressure) in the DJ Basin. Jeff & Chris will discuss recent drilling team solutions to specifically target placement of a lifecycle of the well annular barrier preventing Bradenhead on new drills as well as precise efforts to eliminate casing pressure and safely abandon wells that have surpassed their economic limits.
Please note that the Drilling Study Group is a bring your own lunch event.
SPE & DAPL | 2019 Ski Fast Oil Bash
When: March 1-3, 2019
Where: Copper Mountain
Welcome to the annual Oil Industry Ski Trip! This year, SPE and DAPL are partnering up to make a true Oilfield Ski Bash! Don thy onesie and prepare your favorite mountainside drinking container, for this year is sure to be the best year of petroleum shenanigans to hit the slopes since 2015! We'll have a ski bus traveling up on Friday, après ski party Friday, and other networking opportunities for the remainder of the weekend. More details will be provided in February! Registration this year is a-la-carte. You can have a fun ski day on Friday OR stay for the entire weekend! If you plan to ski for all 3 days, make sure to buy 3 lift tickets. The over 30 year tradition of the après ski party on Friday will be hosted at the base of Copper. Feel free to attend even if you don't ski! If you don't take the bus up on Friday, then be sure to pick up your lift tickets prior to March 1 from Tabatha at the DAPL offices: 535 16th. St Suite #850, Denver, Colorado 80202 (email@example.com). Registration closes on February 14, 2019 ... don't miss the window! We have plenty of opportunities to sponsor! Descriptions for each of these options is in the ticket section. If you would like to mail a check instead of registering online (to avoid fees), please email Mark (firstname.lastname@example.org) at SPE or Meg Gibson (email@example.com; 720.515.5580) at DAPL.
RSVP Link: 2019 Fast Oil Bash
SPE YP | Lunch & Learn: Integrating Rock Properties and Fracture Treatment Data...
When: Wednesday, March 13, 2019 | 11:30 AM
Where: Liberty Oilfield Services | 950 17th Street #24, Denver, CO 80202
RSVP Link: YP Lunch & Learn
Title: Integrating Rock Properties and Fracture Treatment Data to Optimize Completions Design.
Speakers: Joel Mazza, Technical Solutions Manager & Carrie Glaser, Pethropysist, FractureID
A horizontal well landed in a single formation rarely encounters homogeneous rock from the heel to the toe of the wellbore. When analyzing treatment responses that occur during hydraulic fracturing, a decreasing trend in surface treating pressure in sequential stages is typically attributed to reduced friction within the casing or frac string. However, there are several variances in treating pressure that are not readily explained by examining the surface pressures and pipe friction in isolation. These variances are also apparent when looking at bottom hole injectivity. Combining surface data and geomechanical data quickly reveals the degree of variability in rock properties along a lateral and the impact that variability can have on a completion, leading to a more optimal design. This paper demonstrates how engineers can take advantage of their most detailed completions and geomechanical data by looking for trends arising from past detailed treatment analyses and applying that gained knowledge to future completions.
This study relies on the analysis of proprietary high-resolution geomechanical data derived from the processing of accelerations measured at the drillbit and high-frequency fracture treatment data recorded at one-second intervals. The data were standardized to a common format, screened for quality control, normalized, and analyzed using a data management platform. The methodology combines critical mechanical rock properties such as Young's Modulus, and Poisson's ratio with high-frequency fracture treatment data, including treating pressures, rates, and fluid and proppant volumes. Further application of the geomechanical data to derive brittleness allows for construction of a more predictive petromechanical model to optimize completion approaches.
A brief analysis of past completions indicated virtually no correlation between gamma ray measurements along the stage and fracture treating conditions. However, when evaluating high-resolution mechanical rock properties along the lateral, a much more useful correlation exists between minimum horizontal stress variations (calculated from Poisson's Ratio) and eventual treating pressure and proppant placement difficulties. Calculated brittleness and bottomhole injectivity (which accounts for changes in slurry rate and pipe friction) also show a relationship, especially when cluster efficiency factors are included. This study of six Eagle Ford wells suggests that rock properties are the dominant variables affecting fracture treatment pressure and bottomhole injectivity. This method can be used to predict trouble stages, improve operational efficiencies, and optimize proppant placement.
This paper proposes a process to improve completion efficiency while demonstrating the value of information contained in high-resolution and high-frequency datasets. Historically underutilized, these datasets are playing an increasingly prevalent role in advanced analytics due to improved and novel technologies for data management and interpretation. This process is useful to ask better questions and to improve critical decision making with real data.
DGS | 25th Annual 3D Seismic Symposium
When: Tuesday March 19, 2019 | 8:30 a.m to 5:00 p.m.
Where: Ellie Caulkins Auditorium, Denver Center for the Performing Arts Complex
The 25th annual 3D Seismic Symposium, sponsored by the Denver Geophysical Society (DGS), will be held Tuesday 19 March, 2019 at the Ellie Caulkins Auditorium, Denver Center for the Performing Arts Complex in downtown Denver, Colorado. This year’s theme, 3D Seismic Symposium Silver Anniversary, celebrates the 25 year history of the 3D Seismic Symposium with a program that is a rich mix of case studies from across the United States and leading-edge technology workflows.
Dr. Joe Davis of Kalnin Ventures will kick off the day by outlining his petroleum system-based methodology for risking unconventional plays in his talk Defining Unconventional Sweet Spots. And Chris Wright, CEO and Chairman of Liberty Oilfield Services, Executive Chairman of Liberty Resources, and founder of microseismic pioneering Pinnacle Technologies, will energize the lunchtime crowd with his observations and learnings of unconventional resources.
Presentations on complex interpretations include overthrust depth imaging in Beaver Creek Field, Wyoming from Devon Energy’s Robert Horine, and geosteering high angle, Lycoming county Marcellus horizontal wells by Bob Grundy of Inflection Energy. Continuing the complexity theme, Laurence Letki, DUG, will present seismic acquisition and processing challenges in the SCOOP play of Oklahoma.
California Resources’ Darren Williams will discuss derisking unconventional reservoirs through integrated data analysis while Chad Severson, Aera Energy, will discuss delineation of tectonically controlled submarine channels with seismic attributes, both highlighting work in the San Joaquin Basin.
Multiple aspects and scales of the Permian Basin will be on show throughout the program. In the Midland Basin, Aaron Fisher, of Tracker Resource Development, will outline the use of 3D seismic to map rock quality and landing target selection while QEP’s Cory Christie will discuss using geophysical applications to identify and minimize well interference. Details of the Delaware Basin will be revealed through data integration studies as Devon Energy’s Marianne Rauch-Davies will discuss pore pressure prediction and rock properties insight from the Bone Springs Limestone and Wolfcamp will be outlined by Andrew Lewis of Fairfield Technologies. Scott Cook of Tricon Geophysics and Mike McKee of Jetta Permian LP will present Wolfcamp fracture hazards as highlighted with the use of HTI fracture analysis.
As the use of fiber continues to gain traction in the industry, two presentations will discuss various applications of distributed acoustic sensing (DAS). Ge Jin, ConocoPhilips, will present the value of different frequency ranges of DAS data for well spacing and completion design optimization. Gary Binder, of Colorado School of Mines, will discuss the value of incorporating time-lapse vertical seismic profiling (VSP) and DAS data together to identify stress induced velocity changes.
Registration and sponsorship is open and available through the DGS website: https://www.denvergeo.org/events
Please contact committee chairs Angie Southcott and Brad Birkelo for more information at 3DSS@denvergeo.org