September 2008 – Horizontal Cementing

Horizontal wells have become the most economic well configuration for many plays today. In order to effectively treat and produce horizontal sections, zonal isolation is required through cementing. To achieve this zonal isolation, several steps must be followed in preparing the well for cementing. They are: determining if cementing is necessary, selecting slurry design, and borehole preparation. Some innovations in cement have come in the form of expansive cement, foam cement, and acid soluble cement. These slurries perform specific functions and are reservoir specific. Improvements in borehole preparation over time have come in the form of evolving best practices and spacer and pre-flush chemistry. A successful cement job takes proper planning an preparation and this presentation will outline the guidelines.


Chris Moore received his B.S. degree in Chemical Engineering from Texas A&M University in 2004. After joining BJ in January of 2005 he has held various engineering positions in Kilgore, Mineral Wells, and currently Fort Worth. Most of this time has been spent working on fracturing and cementing in the Barnett Shale. He took part in the first simulfrac and trifrac performed in the Barnett. In cement work he was involved in BJ’s first hydrogen gas generating expansive cement and “light” weight horizontal cement used in the Barnett.



October 2008  - Barnett Shale Reserves – The Evolution

We have a distinguished group of panelists from the oil and gas industry to discuss "Barnett Shale Reserves – The Evolution" for 2008. General topics covered during this panel discussion include:

  • Core data needs
  • Adsorption and Isotherms
  • Business implications
  • Geology
  • Log data needs
  • Historical trends in Barnett reserves

Panelists slated for this panel discussion include:

  • Moderator: Mr. David Henderson, Executive Vice-President, Seely Oil Company
  • Mr. Mark Whitley, Senior Vice-President, Range Resources
  • Mr. Dan Steward, Consulting Geologist, Republic Energy
  • Mr. Chad Hartman, Chief Technical Advisor, Weatherford Laboratories (TICORA)

This promises to be an interesting day, so complete your registration early to ensure that you get a seat.

Shale Gas Core Analyses Required for Gas Reserve Estimates - Chad Hartman, Weatherford Laboratories
North Texas Barnett Shale Gas Potential? - Dan Steward, consulting Geologist with Republic Energy, Inc.
Barnett Shale Development History - Mark Whitley, Range Resources



November 2008 – Appropriate Hydraulic Fracturing Technologies for Mature Oil & Gas Formations


Hydraulic fracturing has been described as one of the three most significant technologies to be developed in the upstream oil and gas industry in the last 50 years (the other two being 3D seismic and horizontal wells). However, the traditional approach to hydraulic fracturing has been that it is a technology best applied to new wells, drilled into low permeability formations. It is true that fracturing has been highly successful in this environment - but it is also true that fracturing can be both technically and economically successful in a very wide range of reservoirs, including depleted oil and gas assets. Various strategies such as skin bypass fracturing, batch fracturing, screenless frac-packs, coiled tubing fracturing and neutral density proppant fracturing can be combined with complimentary techniques for zonal isolation, relative permeability modification and scale inhibition, to produce low-cost, high-value solutions for mature assets. Success in this environment is not necessarily about using the latest and greatest fluid system or computer monitoring technique. The successful application of hydraulic fracturing to mature oil and gas reservoirs is about recognizing that there is a wide range of appropriate solutions available. A number of case histories will be used to illustrate the effectiveness of these techniques, when they are systematically applied.

One idea I would like members to take away from this lecture: hydraulic fracturing is not just for new wells in tight formations.


Tony Martin graduated from Imperial College, London, with an Honors degree in Mechanical Engineering and a Masters Degree in Petroleum Engineering. He has spent 16 years in the service sector and has completed engineering assignments around the world. Throughout his career, Tony's primary interest has been hydraulic fracturing and he has been involved in fracturing projects in more than 15 different countries.

Tony teaches fracturing, acidizing and sand control both in-house and externally to customers. A constant theme in this teaching is the need to de-mystify the world of hydraulic fracturing in an attempt to make the process more accessible and less intimidating. He is the author or co-author of numerous SPE papers and has served on the technical committees for several SPE events. He is also the author of BJ Services' Hydraulic Fracturing Manual.

Tony is currently Business Development Manager for International Stimulation.



December 2008 – Perforating with Lasers

Lasers are on track to provide safe, non-explosive, damage-free perforations.

For decades, experts have considered the potential of laser energy to penetrate rock as an alternative well construction and completion method; however, the technical application of lasers was dismissed as energy intensive and inefficient. Conclusions from 40 years ago continue to influence industry misperceptions despite massive developments in laser systems and applications.

New breakthroughs in laser technology have addressed efficiency, portability and reliability issues required for successful commercial field applications. The latest multimode configuration of fiber lasers are now capable of delivering multiple kilowatts of power from an efficient, compact laser source with excellent beam quality, reliability and long life. They represent an enabling technology that opens the door for near-term subsurface laser applications at remote sites. Examples of remote surface field applications have been made.

The application of high power lasers to create the path between wellbore and target reservoir could significantly reduce the primary drawbacks of using explosives - safety and damage. It is desired that the process of cutting through steel, cement and rock by the laser would leave a relatively damage-free area at the interface of the reservoir and allow a connection free to flow with minimal skin damage. Recent research results have proven the laser perforation concept under multiple downhole conditions, including pressure. Other completion applications are envisioned, as well.


Brian C. Gahan is a Senior Scientist and Technology Manager in the Exploration & Production Research Group at the Gas Technology Institute (GTI) in Des Plaines, Illinois. He holds a BS in Petroleum Engineering, a Masters in Chemical Engineering and an MBA in Finance and is a registered professional engineer. He is a 27-year member of the Society of Petroleum Engineers, and an active member of the American Association of Petroleum Geologists, the American Institute of Chemical Engineers and the Laser Institute of America. Gahan has authored and co-authored several papers and technical publications.



January 2009 – Powerwave Injection Technology – Secondary Recovery, Waterfloods, and CO2 Floods

In the oil industry, any progress in technologies designed to enhance production is most commonly based on empirical discoveries and only later followed by attempts to develop a consistent physical theory to explain, analyze, and predict field behavior. However, in 1997, a group of scientists and engineers sought to change that mindset. Through a series of laboratory tests utilizing a rigorous theory, this group developed a new fluid flow enhancement technology known as the PowerwaveTM process. Powerwave is an injection technology wherein a volume of liquid is introduced through casing or tubing and is pulsed at high accelerations by downhole devices into the reservoir. The injected fluid then increases the porosity, pressure, permeability, saturation, and homogenization of an ever-increasing coherent volume of the porous media through porosity dilation (expansion of the pore throat).

Powerwave is modeled after the effects of earthquakes on the pores in rocks to stimulate the flow of oil. The technology allows oil producers to tap into mature oil fields, in addition to wells that are not producing as well as they should. As early as the 1950s, earthquakes were observed to affect fluid levels in oil wells, and production increases were often reported. Beneficial effects decreased over time following a seismic event. This led to the concept of seismic excitation for flow enhancement.

To increase oil recovery, many field attempts in the United States, Russia and China (among others) have been made to induce and couple seismic waves as a method for secondary oil recovery during traditional oilfield waterflooding. In theory, vibratory forces are thought to promote the movement of oil by diminishing capillary forces thereby reducing adhesion between the rock and fluids. This causes trapped oil to be liberated and flow with the CO2 or waterflood.

Implementation of Powerwave in injection wells has led to injectivity index increases of 40 - 900%.


Brian Brazeal and John Warren head up Wavefront Energy and Environmental Services USA Inc.’s U.S. business development/marketing and field operations with more than 40 years combined industry experience that includes product line management, research and development management and business development leadership. Prior to his current position with Wavefront, Warren held several technical, sales and managerial positions in multiple locations around the world, including positions in West Africa and Norway. His work and experience earned him the Harts Award in 2004. Warren received a BS in Mechanical Engineering from Colorado State University and is recognized as one of the industry’s foremost experts in conformance applications. Brazeal began his oil/gas experience as a rig-hand 20+ years ago and has extensive experience in technical sales/business development as well as an experienced landman.

Dr. Behrooz Fattahi is the Heavy Oil Development Coordinator at Aera Energy LLC, a California exploration and production company jointly owned by affiliates of Shell and ExxonMobil. He began his industry career in 1977 at the Oil Service Company of Iran and worked as a Reservoir Engineer, Reservoir Engineering Manager and Team leader for OSCO/Shell International, Shell Western E&P, Shell Offshore, and Shell-affiliate CalResources. Prior to joining the petroleum industry, he conducted research for the National Aeronautics and Space Administration and the National Science Foundation and taught courses in fluid dynamics and solid mechanics at Iowa State University. He is a past member of the American Institute of Aeronautics and Astronautics and American Association of University Professors.

Dr. Fattahi served as the Executive Editor of the SPE Reservoir Evaluation and Engineering Journal. He served on the Board of the Society as the Director of the Western North America Region (2004-2006), and was the Chairman of the SPE Continuing Education Committee (1999-2001), Chairman of the San Joaquin Valley SPE Section (2001-2002), and a member of SPE President’s Learning Initiatives Task Force (2002). He is also a former Chairman of the Greater Bakersfield Chamber of Commerce Energy Committee. He holds PhD degrees in Aerospace Engineering and Mechanical Engineering from Iowa State University.


February 2009:  The EOR Kiss of Death – It was a Technical Suicide


The One Idea: How business risks of a CO2 enhanced oil recovery project are handled can make or break a project. The first questions that must be answered in a CO2 EOR project are always technical:

  • Can CO2 recover incremental oil?
  • If yes, at what rate and volume?
  • What is the necessary investment?
  • What are the ongoing operating costs?

The answers to these questions will determine whether the project will be a technical success, but then you have to delve into the business aspects of the project. Using real examples and experience from the creation of the Weyburn CO2 Miscible Flood, the business risks for a typical potential project will be highlighted.

The answers for your project will be different than for Weyburn but the questions you have to ask are the same: Will my supplier be around long enough to give me the CO2 I need or will he be bankrupt next year? Should I build the supply pipeline or spread the risk (and the reward) with a third party builder? Can my partners really afford this project? What can I do if I need their vote to get the project approved, etc.?

Understanding these business risks and the measures you must take to quantify and minimize them will go a long way to ensuring your project is both a technical and an economic success.


Ken Brown is a Professional Engineer with 36 years of broad experience in reservoir engineering, project management, production engineering, operations engineering, facilities engineering, environmental engineering and all aspects of technical management of large multi-disciplinary teams. His experience includes:

  • Light oil including the Weyburn CO2 miscible flood and the Swan Hills miscible flood
  • Heavy oil from primary production to SAGD
  • Conventional sweet and sour gas including major processing facilities
  • Shallow gas
  • CBM and shale gas
  • Environmental issues including GHG and management of research projects
  • Teaching, training and senior management/advisory roles
  • Technical dissemination role as Chairman of the National Board of the Petroleum Society

As the Reservoir Manager of Home Oil, he was responsible for reservoir optimization of all Western Canadian properties. This included the introduction of CBM and horizontal drilling technology.

At PanCanadian Petroleum Ltd. he co-chaired a year-long intensive reservoir performance optimization process study. When he joined the Weyburn group at PanCanadian, they had just completed their first horizontal wells. Under his direction, an additional 300 horizontal wells were drilled. He was responsible for the coordination of all technical and business issues leading up to the creation of the Weyburn CO2 miscible flood project. His involvements with the Weyburn group lead to an assignment in the Corporate Environment group to develop and execute a corporate strategy for all greenhouse gases.

After retiring from EnCana (a merger of PanCanadian and Alberta Energy Company) he joined the Alberta Research Council as Manager of the Carbon and Energy Management group. This group consists of three main entities:

  • Geological storage
  • Unconventional gas research
  • Clean energy

Ken is a long time member of APEGGA, SPE, and the Petroleum Society. He has written numerous technical papers and made many technical presentations to a wide range of audiences.


March 2009:  Bit Technology and Application

Basic technology and application information will be discussed for both "Fixed Cutter" (PDC) and tri-cone drill bits currently in use today in the Barnett Shale for drilling, completion, and workover purposes. Their unique features, and applications relative to today's drilling will be discussed, along with the major advantages and disadvantages of both bit types. Special applications and bits will also be discussed such as rotary steerable drilling, coil tubing drilling and clean-out, and slim-hole tools. Attendees will come away with a basic understanding of how each bit type works and the state of the art for bits today in the Barnett Shale.


Robert Gum earned his BS in Mechanical Engineering at Oklahoma State University. He has 31 years of industry experience with SecurityDBS – Halliburton Drill Bits and Services, in Product Design and Development, Manufacturing Engineering, Field Applications, and Project Management.

He is currently the Applications Design Engineer (ADE) for the North Texas region. His responsibilities include Area Bit Application recommendations, post-well evaluation of bit performance, extension of SecuityDBS technology development, and testing, validating, and identifying technology requirements. He also leads quarterly classes on Bit Applications and Design.

Experience includes:

  • 15 years Roller cone Design and Development in Dallas
  • Served as ADE for Mid-Continent in OKC including Northeast US and North Texas, the Permian Basin, and South Texas.
  • Bit Expert in Halliburton Integrated Solutions Group – Houston
  • Special Project Leader for Middle East and Nigeria.


April 2009 – OCTG: Where are we now?

An overview of U. S. Steel’s OCTG (Oil Country Tubular Goods) products and manufacturing processes will be presented along with information about historic pricing trends and future supply. Cost drivers for OCTG products will be provided to help end users understand price fluctuations. Inspection processes will also be covered for both the pipe body and connections. The difference between ERW (electrical resistance welded) and seamless products and manufacturing will be discussed along with recommended uses for each.


Bill Bartos is currently the Resident Sales Manager – Dallas for U. S. Steel Tubular Products. He has 32 years of experience with US Steel beginning his career at the Lorain Works Facility, Lorain, Ohio in 1976. Held various positions throughout career: ranging from several Mill Operations responsibilities, Iron & Steel Division Safety Engineer, Sales Supervisory positions at USS Headquarters, Sales Manager New England/Mid Atlantic Region, Camphill ERW Business Manager, Plant Manager Lorain Tubular Operations, Standard & Line Pipe Marketing Manager and current sales responsibilities for OCTG & S&L Products in the Dallas/Ft. Worth, Oklahoma, East/West Texas regions.

Bill received a Bachelors degree in Business from the University of Kentucky and an MBA from Baldwin-Wallace College.

Darrel Chalette is currently the Manager of Premium Connection Technology for U. S. Steel Tubular Products. He has 21 years in the Oil Country Pipe and Thread business. Darrel has held various positions involved with the development and process of API/Premium thread technology including: Hydril Company developing new connections, VP of Thread Technology International addressing connection design and manufacturing issues, President of Ruska Instrument Corporation, USS Tubular Products Manager of Maintenance & Engineering, & Customer Technical Services-Premium Connection Technology Manager. In addition, Darrel has been awarded 7 patents on pipe thread and sealing technologies, and developed or introduced more than 15 commercially successful products. He has extensive experience resolving pipe and thread manufacturing issues- ie: quench cracking, tempering processes, pipe threading, and heat treat system problems. Darrel received a Mathematics degree from Lamar University and a BSME from the University of Houston.


May 2009 – How Logs can Help You Make Better Shale Wells

Do you know your clay type and percentage? Are there structural or lithology changes? Do you know your borehole stresses and anisotropy? Do you have a good cement job? How will you divide your well for perforations and hydraulic treatment staging? Do you know where your production is coming from?

This presentation addresses which of these questions can be answered by logs at each stage of the life of your horizontal borehole: while drilling, in open hole after reaching total depth, in casing before, during or after hydraulic treatments.


Janice Brown graduated from The University of Texas at Dallas in 1978 with a BS Degree in Geology. She worked 18 years as exploration geologist for Sun Exploration and Production in Dallas, Texas. She has worked as a Borehole Geology Image Interpreter for Schlumberger Oilfield Services for the last 12 years and has done horizontal imaging for the last 6 years.