Preliminary & Scheduled Meeting Dates [ Fall 2006 - Spring 2007 ]        

Monday May 14, 2007

Formation Testing in the Dynamic Drilling Environment

Mark A. Proett
Halliburton Energy Services

Abstract:

Formation testing objectives have changed little since their introduction in the early 1950's. A formation test is used to determine the formation pressure, obtain fluid samples, estimate formation rock properties, and, ultimately, evaluate reservoir producibilty.  Wireline formation testers (WFT) were introduced soon after drill stem testing (DST), but they have now nearly replaced DST through a succession of technical innovations. More recently, formation testing while drilling (FTWD) has been introduced. FTWD tools introduce new capabilities that address the drilling environment.

The drilling environment truly offers challenges for testing because mud column pressures are indeed dynamic, and invasion while drilling is in its early stages of progression. Dynamic changes typically introduce pressure transients that are not detected in other forms of testing. New pressure-transient analysis techniques have therefore been developed and introduced to analyze these changes. The advantages in analyzing pressure transients are that they can determine properties of interest to drilling, such as filtrate loss rate and depth of invasion. Traditionally, it had been assumed that measured pressures only reflect formation pressures, an assumption that is not always valid.

FTWD testing is still in its infancy; and if history repeats itself, this form of testing will take a larger role in formation evaluation in the future. Some applications have already been developed, applied, and successfully demonstrated. Highlights of these developments will be emphasized in this talk. New applications very likely will be developed as this testing technology evolves.

Biography:

Mark A. Proett is a Senior Scientific Advisor for Halliburton Energy Services in the Strategic Research group. He received a BSME degree from the University of Maryland and a MS degree from Johns Hopkins. He has been involved with the development of formation testing systems since the early 1980’s, and has published extensively. Proett holds 27 patents, 23 of which deal with well testing and fluid flow analysis methods. He has served on the SPWLA and SPE technical committees and served as the Chairman for the SPE Pressure Transient Testing Committee. Mark also served as an SPWLA Distinguished Speaker in 2004 and was recently elected to the position of Vice President (Northside) of the Houston Chapter of SPWLA.   

Monday Dec 11, 2006

Managed Pressure Drilling Technology: Applications, Variations and Case Histories

Don M. Hannegan, P.E.
Weatherford International Ltd.

Abstract:

As opposed to an open-to-the-atmosphere drilling nipple, bell nipple or upper marine riser, a litany of drilling techniques utilizing a closed and pressurizable mud returns system at the rig floor have been evolving over the past decade. This is particularly the case in the U.S. today where almost 75% of the land-drilling programs drill at least one section with such a system, up from approximately 10% in 1995.  Some are drilling with compressible fluids (air, mist, foam) and others are practicing underbalanced drilling (UBD) where a closed annulus returns system is a necessity. The balance, almost 50%, are practicing what the industry has rather recently defined as a technology within itself, Managed Pressure Drilling (MPD). The desire to reduce drilling non-productive time and other costs associated with loss circulation, narrow downhole pressure environment windows, slow ROP, excessive casing programs and enhanced control of the well are key incentives to practice MPD.

The technology is uniquely applicable to offshore drilling for two reasons; the rewards of dealing more effectively with trouble zones are higher than onshore and MPD, unlike UBD, discourages hydrocarbons influx during the drilling process.  With several dozen "first adopters" of MPD in marine environments to date, all have experienced safe and effective programs and plan future MPD projects.

There are two Categories of MPD, Reactive and Proactive. There are four Variations of MPD; Pressurized Mud Cap Drilling, Constant Bottomhole Pressure, Dual Gradient, and HSE (Health, Safety, and Environment). Each variation of MPD addresses different conventional drilling related issues with the common theme of reducing drilling non-productive time.

This talk will address the background of MPD, provide several  recent case examples where specific drilling-related barriers are overcome, and illustrate equipment layouts required to practice each variation of MPD from all types of rigs,

Biography:

Don Hannegan is a Registered Professional Engineer, a founding Officer of the Arkansas Section of SPE, past Chair of the SPE MPD/UBO Technical Interest Group, and recipient of the World Oil 2004 Innovative Thinkers Award for his work in defining and developing MPD technology. He is primary technical content provider for the MPD Chapter in SPE's new textbook-in-progress, Advanced Drilling Technology & Well Construction. He is inventor of several offshore designs of Rotating Control Devices and fit-for-purpose elastomers for rotating annular seal elements. He has authored numerous technical papers and published articles speaking to well control considerations of Performance Drilling, Underbalanced Drilling and Managed Pressure Drilling.

Michael Smith
Distinguished Lecture Presentation
"Hydraulic Fracturing - The Multi Discipline Process"

Michael B. Smith is the President of NSI Technologies, Inc. He has over 20 years experience with a major operator and as a consultant. He has served as an SPE Distinguished Lecturer and authored two chapters in the SPE Monograph Recent Advances in Hydraulic Fracturing. Most recently, he was awarded the Lester C. Uren award for his technical contributions. He is a graduate of Rice University with a PhD degree in Mechanical Engineering.
 

April 6, 2006 - Thursday
American Legion Hall - Midland
Joint Meeting
11:30 AM Presentation
Cost $15

SW Tour and visit by Giovanni Paccaloni, ENni AGIP, SPE President 2005
Giovanni Paccaloni
Eni Agip
SPE Today and Tomorrow

Giovanni Paccaloni currently serves as Senior Advisor at Eni Agip’s headquarters in Milan. Since joining Eni Agip in 1971, Paccaloni has worked worldwide in various leadership roles, including Vice President, Corporate E&P Laboratories (1997-99); Vice President, Drilling and Production Optimization (2000-02; and Vice President of R&D and Technology Planning (2003). 

An SPE member since 1986, Paccaloni served as SPE Director Europe and Africa Region during 1995-99 and was named an SPE Distinguished Member in 2000. He has served twice as chairperson of the Italian Section and has played an active role in that section’s governance for more than 15 years. 

His many SPE activities include service as chairperson of the Forum Series Implementation Committee (1993-95), the Forum Series Coordinating Committee (1995-97) and the 1992 Forum Series in Europe Steering Committee. He served as an SPE Distinguished Lecturer during 1988-89 on the topic “Optimization of Matrix Stimulation Treatments.” 

Paccaloni is honorary professor at the Daqing Petroleum Institute (China) and the University of Guayaquil (Ecuador), and Visiting Professor at the Xian Shiyou University (China). During his career, he has authored and co-authored several technical papers, including articles published in JPT and SPE Production Engineering. Paccaloni holds an MS degree in industrial chemistry from the University of Bologna.

February 15   - Wednesday
American Legion Hall - Midland
Permian Basin Section Meeting - Invitation
11:30 AM Presentation
Cost $15        

Stephanie Sparkman
Executive Director
West Texas Energy Technology Initiative

Permian Basin Future Developments 

February 14 - Tuesday
Odessa Country Club
11:30 AM Presentation
Cost $20

Steve Metcalf
BJ Services
"Carbonate Acidizing, designs for Success"

Abstract:

Hydraulic fracturing has been routinely applied for many decades now, with mostly positive economic results. However, our understanding of hydraulic fracturing was quite limited until relatively recent advancements in technology allowed engineers to see what hydraulic fractures really look like and better understand what governs fracture growth and well performance. The introduction of tiltmeter and microseismic fracture mapping, along with advances in tracer technology, now provides our industry with the tools to truly understand fracture growth. But as with all newly acquired knowledge, it is often difficult to fully evaluate the implications of the information and reap the economic benefits.  Too often, engineers focus on one aspect of hydraulic fracturing, such as fracture modeling or performance evaluation and now maybe even fracture mapping – resulting in at best a limited understanding of how to improve future treatments and many times miss-diagnosing critical problems. This approach often times leads to inappropriate, sometime costly changes in hydraulic fracture designs and field development strategies.  However, by utilizing and fully integrating fracture treatment, production, well test, geological, and fracture mapping information, the right designs changes and better field development strategies can be implemented – thus realizing the economic benefits that technology AND engineering have to offer. To illustrate this process, several examples are presented that document how utilizing a number of independent technologies and integrating their results can lead to a much better understanding of fracture and overall field performance, resulting in changes to both treatment designs and field development practices that significantly improve production economics. Conversely, the pit-falls of a myopic approach to hydraulic fracturing are also illustrated. The case histories presented will illustrate that the appropriate technologies to apply depend on the questions you need to answer, the cost of the technologies and the potential benefits, and the economic environment. 

Biography:

Pinnacle Technologies - Vice President Engineering Services                          

Mr. Cipolla has over 20 years experience focused on hydraulic fracturing. Craig directs Pinnacle’s engineering services group, providing technical support to both fracture mapping and consulting projects. In addition to managing projects and supervising personnel, Craig’s responsibilities include the design and evaluation of hydraulic fracturing treatments, training engineers in the use of “real-time” data analysis, reservoir engineering, integrated field studies, and supervising stimulation treatments. In addition, Craig is an expert in the application of fracture mapping technologies to optimize treatment designs and field development strategies. Craig’s worldwide experience includes work in the US, Canada, Mexico, South East Asia, North Sea, West Africa, Australia, Russia, and the People’s Republic of China. Prior to joining Pinnacle in 1996, Craig worked for Union Pacific Resources, where his responsibilities included integrated field studies, economic evaluation and acquisition of oil and gas properties, fracturing technology, and engineering support of exploration and infill drilling programs.  Since joining Pinnacle in 1996, Mr. Cipolla has worked extensively applying state-of-the-art fracture technology worldwide, including the application of tiltmeter and microseismic fracture mapping to directly measure fracture geometry and the integration of well testing, reservoir simulation, and fracture modeling to evaluate & optimize hydraulic fracture treatments and field development. He is currently serving on the SPE Well Stimulation committee and was a member of the SPE Completions committee from 1994-1997. He also served as the technical advisor for the JPT Well Stimulation feature from 2000-2003. Mr. Cipolla was a member of the 1992 SPE Gas Reservoir Engineering Forum committee and the 1998 SPE Hydraulic Fracture Diagnostics Methods Forum committee. Mr. Cipolla has authored 34 technical papers and conducted numerous presentations in conjunction with the Society of Petroleum Engineers, Gas Research Institute, Department of Energy, and other petroleum industry organizations.

11:30 AM Presentation
Cost $20

Cory Frederick - Drilling Engineer
Yates Petroleum Corporation

Director and Chair Meeting

Operating Cost Trends in the Permian Basin - The Efficiency Challenge

During the 1990’s, Mr. Tucker was a Vice President with Petroleum Information Corporation (now IHS Energy), responsible for managing a number of commercial energy databases utilized by natural gas producers, pipelines, marketers and local distribution utilities. 

During the late 1970’s and early 1980’s, Mr. Tucker consulted to electric utility clients as Senior Managing Consultant with DRI/McGraw-Hill’s Energy/Utility Consulting Practice, and prior as Utility Economist with Chase Econometrics.  Mr. Tucker built and forecast with econometric models of electricity demand.  Mr. Tucker also forecast industrial production and prices as Senior Economist-Industry Economics with Evans Economics, a macro-economic forecasting firm.

Mr. Tucker graduate Summa Cum Laude, with Departmental Honors in Economics from Western Maryland College (now McDaniel College), and attended graduate studies in Economics at the University of Chicago and Virginia Polytechnic Institute.

The presentation will provide an informative operators' perspective on field operating costs in the Permian Basin.  Significant results and findings from Ziff Energy Group's 2003 Permian Basin Reducing Field Operating Cost (RFOC) benchmarking study will be discussed, along with suggestions for actions to be taken by operators to use benchmarking study results to create value by improving field cost performance.

Patrick R. Oenbring - Executive Associate, Ziff Energy Group, has 29 years experience in the Exploration and Production business.  Upon graduating from the University of Kansas in 1974, Mr. Oenbring worked for Conoco Inc. for 23 years and for Occidental Petroleum for 6 years in positions of increasing responsibility.  His professional postings and travels took him to Canada, the US, Indonesia, Dubai, Egypt, Venezuela, the North Sea, Nigeria, Qatar, Yemen, and Pakistan in a variety of project management, operations, and executive roles.  In 1997, he became President and General Manager of Occidental Petroleum of Qatar, Oxy's largest international E&P operation.  From 2000 to 2003, Pat Oenbring served as President and General Manager of Occidental Permian, the largest oil producer in Texas.

Arden McCracken
Object Reservoir

Improving Reservoir Characterization Through Early Knowledge

Abstract

Object Reservoir's process and technology have been developed to allow members of the asset team to collaborate in ways that have not been possible before. This is due to OR's ability to model actual reservoir shapes using an new gridding methodology, as well as being able to integrate a geoscientific approach with an engineering approach. McCracken's presentation will describe the process and technology that make these things possible, as well as what this has meant to our clients so far. The session will be interactive, with questions and discussion welcomed.

Biography

Dr. Arden McCracken, a veteran reservoir engineer with more than 30 years of both domestic and international experience with both major and independent oil companies. McCracken's  geographic experience spans nearly all productive basins in the U.S. and Canada and most of the North Sea, Middle East, North Africa, Indonesia, Vietnam, China, and South America. Arden is currently a Senior Reservoir Engineer with Object Reservoir.

Donald L. Whitfill
Technology Application Leader
Wellbore Pressure Containment
Baroid Technology

Managing Circulation Losses with Nonaqueous Drilling Fluid—Past and Present

Controlling circulation loss during well construction is more than just selecting the proper type of lost circulation material (LCM). A fully engineered approach is recommended. This approach incorporates a number of planning tools, including: borehole stability analysis; hydraulics modeling to estimate equivalent circulating density (ECD); and drilling fluid and LCM material selection to help minimize effects on ECD. Planning should include means to provide on-site monitoring using pressure while drilling (PWD) and connection flow monitoring, plus timely application of LCM and treatments. The following practices are advocated to provide the best available technology: base the amount of LCM on volume rather than weight; pretreat with LCM before drilling high risk lost circulation zones; add subsequent treatments as sweeps, rather than adding into the bulk drilling fluid system in the suction pit. Results from a new joint industry laboratory study on LCM testing are discussed and compared to more classic large scale laboratory data from Drilling Engineering Association (DEA) joint industry experiments conducted in the 1980s.

Donald L. Whitfill received his PhD in chemistry and taught one year as an instructor at the University of Oklahoma before joining Conoco Inc. in 1967.  He served in a variety of R&D assignments in drilling and completions including Group Leader and as Section Manager of the Reservoir & Recovery Section. He joined Baroid Drilling Fluids in 1997 as a member of the High Impact Technology Team. He is Technical Applications Leader for Wellbore Pressure Containment for Halliburton's Baroid Drilling Fluids unit. He has twenty-five publications plus seventeen patents. During his career in the petroleum industry he has served in a variety of professional capacities throughout the industry including: Chairman, Reservoir and Recovery Forum, 1995-96; Board of Directors, Society of Petroleum Engineers, 1989-92; Distinguished  Lecturer, Society of Petroleum Engineers, 1987, and Chairman, API Committee on Standardization of Drilling Fluid Materials, 1985-86.

281-871-6042
281-381-1829 (cell)
don.whitfill@halliburton.com

RICHARD J. ERDLAC, JR., Ph.D.

·         Ph.D. in Structural Geology, 1985-1988, The University of Texas at Austin, Austin, TX
(Structural Development Of The Terlingua Uplift, Brewster And Presidio Counties, Texas – [Committee: William R. Muehlberger, Amos Salvador, Sharon Mosher, Christopher D. Henry, George A. Thompson])

·         MS in Geology, 1975-1979, University of Pittsburgh, Pittsburgh, PA
(A Study Of The Chixoy-Polochic Fault And Its Nature In Western Guatemala – [Committee: Thomas H. Anderson, Edward G. Lidiak, Victor A. Schmidt])

·         1 Graduate Year in Physics, 1974-1975, University of Pittsburgh, Pittsburgh, PA

·         BS in Physics, 1970-1974, University of Pittsburgh, Pittsburgh, PA

Over 20 years experience within oil and gas exploration activities, applied geoscience research, management, and teaching.  Energy experience with majors and independent oil and gas companies through direct company employment and by company support of exploration research.  Abilities as an exploration geophysicist (seismic interpretation and processing) and geologist (log interpretation), with strong expertise in structural geology.  Identified numerous oil and gas exploration trends within the Permian Basin.  Co-investigated exploration prospects as part of team effort.  Developed a diversified, multiphase capability in applying geological and geophysical technologies, and data sets, combined with computer skills, including GeoGraphix, Geophysical Micro Applications, Seismic Processing Workshop, ProMAX, Seisviewer, Seisvision, Geological Services well top database, various GIS platforms including DLG Viewer, MicroDEM, and ImageMate, as well as other software packages.  Chairman and co-developer of a non-profit applied natural resources research center.  Acquired over $1 million in exploration research funds from energy industry.  Co-developed a concept for using deep depleted gas wells as geothermal energy extraction wells. 

4900 Thomason Drive                                            The University of Texas of the Permian Basin
Midland, TX 79703                                               Center for Energy & Economic Diversification
432-699-5288                                                      4901 E. University, Odessa, TX 79762
rcerdlac@cleansed.net                                                         432-552-2442
erdlac_r@utpb.edu

  Download document - Article on Permian Basin as a source of geothermal energy

The Application and Technology of Slickwater Fracturing

Gary W. Schein
BJ Services Company

 Abstract

Much has been said and asked about the use of slickwater as the primary fracture fluid to stimulate wells throughout the U.S. Operations. Slickwater has been used for years in many naturally fractured carbonates with great success. In recent years and since the 1996 publication of SPE Paper 38611 “Proppants. We Don’t Need No Proppants” the “technology “ and applications of this method to complete tight gas sands have generating significant discussion. This presentation will focus on the criteria for slickwater frac stimulation candidates and their success. There are many areas and formations where this technique is being utilized. The successes in these areas have been dependent on continual change on the completion to find the optimal treatment. The stimulation design then becomes based on how specific reservoirs respond to the treatment during pumping requiring much more than doing in one area what works in another area. These changes include determining the optimum volume, proppant concentration, proppant size/type and pumping technique used to place the best treatment. The final test for the success of these treatments is the production results for areas where slickwater fracturing treatments are performed.

Biography

Gary has BS degree from Northern Arizona University in 1978 and joined BJ Services. He has worked in well completions and stimulation for 25 years. He began work in the Mid-Continent Area as a Service Supervisor and District Engineer prior to moving to Houston where he was Product Manager and Engineer analyzing well treatments and design. He transferred to Dallas, Texas as Region Technical Manager in 1993 and has been responsible for the treatment design and completions engineering for the East Region, which includes North Texas, East Texas, North Louisiana, and Mississippi. He is responsible for over 2,000 jobs per year performed within the Region.

11:30 AM
Odessa Country Club
Cost $20

Production Optimization At The Surface Level  

Abstract

The elimination of all failures within the artificial lift system is impractical, if not impossible, and the cost associated with such an undertaking would be astronomical!  Therefore, you must efficiently manage your failure rates to generate the highest revenue possible for you or your company.  Trending and understanding failure patterns helps correctly identify failure causes and is paramount to managing failure causes.

 Bibliography

Russell Stevens is the Technical Services Coordinator for Norris Sucker Rods.  Stevens has been with Norris for 21 years and has served in various sales/technical capacities.  His previous experience includes 10 years with Norris/O’Bannon during which time he became a District Sales Manager for the Permian Basin.  In 1993 he became involved with the sales group for Norris Sucker Rods until 1996 when he was promoted to his current position of Technical Services Coordinator.  Stevens is a member of SPE, NACE, and ASM.  He serves as an alternate task group member of API Committee 1, Subcommittee 11, and Field Operating Equipment.

Russell Stevens
Office:    (432) 561-8101
Facsimile: (432) 561-8182
Cellular:  (432) 559-4895
rstevens@norrisrods.com

TBA
 - Irran
 - Monahans

No title or speaker information is available at this time.

For more information regarding this meeting, please contact Matt Lippman @ (432) 368-1267 or Prentice Creel at (432) 683-0246.

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Scheduled Meeting Dates [ Fall 2003 - Spring 2004 ]        

W. Hoxie Smith, M.S., P.G. - Director
Petroleum Geotechnology Training Center
Midland College

Continuing Education Units - Need to fulfill your educational credits for the Texas Professional Engineer's License? Coming - the required one hour Ethics course

W. Hoxie Smith, M.S., P.G. - Mr. Smith is the Director of Midland College’s Petroleum Geotechnology Training Center.  He graduated from Colorado State University with a B.S. Degree in Geology (1982) and began his career in the oil and gas industry in 1983 with ARCO Exploration Company. Mr. Smith received his Master's Degree in Geology from the University of Texas of the Permian Basin (1995) while working for Dawson Geophysical Company where he also served as the Project Manager for a U.S. Department of Energy Project.  From 1996 to 2003 he served full-time as a Principal and Vice President of GeoSpectrum, Inc., a reservoir development and Internet engineering company based in Midland, Texas.  Mr. Smith has presented at numerous professional society meetings, including national conventions of the American Association of Petroleum Geologists, the Society of Exploration Geophysicists, and the Society of Petroleum Engineers.  He has authored and/or co-authored over twenty-five publications in his field and is a member of six professional societies including the SPE.

Thursday -  April 15, 2004
11:30 AM
Odessa Country Club
Cost $15

Dave Cramer
Distinguished Lecturer 2003-2004 Tour

Evaluating Well Performance and Completion Effectiveness in Hydraulically Fractured Gas Wells

Abstract

Hydraulic fracture stimulation often dictates the economic outcome of wells completed in gas reservoirs, especially in reservoirs exhibiting low permeability.  Making the effort to understand well performance—the rate and pressure behavior of a well over its productive life—provides the opportunity to discover the key elements driving stimulation and completion effectiveness in any particular environment.  This presentation demonstrates the integrated use of reservoir engineering tools to evaluate well performance, identify flow regimes, and distinguish between reservoir and completion induced behavior.  These tools include well log analysis (for pay identification and petrophysical calculations), the reciprocal productivity semilog method (to normalize the inevitable variations in flow rate when evaluating the post-linear, infinite acting radial flow period), type-curve analysis, material balance (estimation of reservoir volume during pseudo-steady state flow) using the Cartesian plot, pressure buildup analysis (prefracture and post-fracture), finite-difference reservoir simulation, and systems analysis.  Case studies of single wells and entire fields draining low permeability gas reservoirs are used to demonstrate this methodology, and significant reservoir, completion, and production factors affecting well performance are identified as an outcome.  The above results are compared to history-matched output from 3D or pseudo-3D hydraulic fracturing simulators, comparing the simulated hydraulic fracture characteristics with the actual impact of the emplaced fracture, offering additional clues to stimulation effectiveness.  The impact of critical completion and production factors will be revealed and discussed.  These problems and factors include wellbore liquid loading (in reducing or eliminating the effective hydraulic fracture length), treatment fluid and proppant volumes, proppant concentration, fracturing fluid systems, treatment isolation strategies and sequencing of multipay completions, treatment flowback strategy, use of velocity/ tubing strings and selection of landing depths, and shutting in a producing well.  Remedies are suggested for stimulation and completion induced problems.

Biography

Dave Cramer is the Rocky Mountain Region technical manager for BJ Services.  He has 25 years of experience in well stimulation and cementing.  Cramer has authored 33 papers, delivered more than 100 technical-society presentations on well completion and performance topics, and is a co-inventor of two U.S. patents.  He was awarded the Henry Mattson Technical Achievement Award by the Denver SPE chapter in 1993. Cramer was Director of the SPE Denver Section in 1995–96, Section Chairperson in 1994–95, Vice Chairperson and Program Chairperson in 1993–94, and Membership Chairperson in 1992–93. He also has been a Session Chairperson for numerous regional meetings and a frequent speaker at SPE and American Petroleum Inst. events. He earned a BA degree in economics from Rutgers U.

Monday - March 8, 2004
11:30 AM
MCM Elegante' Hotel
Cost $15

Andrew Wojtanowicz
Distinguished Lecturer 2003-2004 Tour

 Downhole Water Separation

Abstract

During the economic life of a producing field, the volume of produced water may exceed the volume of hydrocarbon produced by 10 times. During late stages of production, it is not uncommon to find that produced water can account for as much as 98% of the extracted fluids. Historically, the average worldwide water cut is 75%, while the average water handling Opex cost to the oil industry is $0.50 per barrel of water, amounting to $40 billion total.

Since the conventional process of fluid separation is energy intensive and very costly, the industry has searched for innovative techniques that would move the separation upstream the production process, i.e. to the wells’ bottom, or even back to the reservoir.

The presentation will introduce modern technologies for separation of water in oil and gas wells. In principle, these techniques fall into one of two categories: bottomhole separation and separation in situ. The bottomhole separation techniques utilize separation inside the well. Discussion will include bottomhole systems based on gravity separation of gas and water (modified plunger, bypass tool, ESP) and gravity separation of oil and water—dual/triple action pumping (DAPS/TAPS), hydraulic submersible pump (HSP), and horizontal gravity separator (HSep). The discussion will include field performance and several case histories, since some of these systems have been successfully commercialized.

Also presented will be the downhole oil water separation (DHOWS) technology using bottomhole mechanical separators—hydro cyclones with or without ESP. The presentation will discuss downhole installation and completion aspects of these techniques as well as the limitations of hydro cyclones as separation devices. Several case histories of DHOWS demonstration projects will be also presented.

The final part of the presentation will concern a dual-completion technology using in-situ separation of water from oil or gas in the reservoir outside a producing well (downhole-water-sink technology, or DWS). In DWS wells, the second (bottom) completion is used for draining water in order to maintain the well’s potential for production of oil/gas from the top completion. Explained will be principles of DWS well performance in the bottom water and edge water reservoirs. A case history will show details of downhole installation and production data. Also discussed will be the comparison of DWS with conventional wells and incremental recovery due to the technology.

Biography

Andrew K. Wojtanowicz is Texaco-endowed Environmental Chair in Petroleum Engineering at Louisiana State U. and U.N. expert in drilling engineering.  He has worked in the petroleum industry as a drilling engineer, drilling supervisor, and drilling fluids technologist in Europe and Africa. Wojtanowicz has held faculty positions at three universities and conducted research in drilling, completion, and production operations with emphasis on environmental effects and prevention techniques. His studies are reported in 180 publications and four books. He is an Editor-in-Chief of ASME Transactions Journal of Energy Resources Technology and a registered petroleum and environmental engineer in Louisiana. As a Conoco Environmental Research Fellow ’91/92, he developed dewatering technology for closed-loop drilling systems. He has also developed water coning-control technique with Downhole Water Sink (DWS) well completion, for which he received Special Meritorious Award for Engineering Innovation in 1996. He has directed a DWS Joint Industry Project at LSU since 1997.

  awojtan@lsu.edu

  To obtain a copy of "Downhole Water Sink Technology," a presentation (Adobe) covering the presented subject - use this link.

The complete SPE Lecture presentation will be available at Andrew's LSU website http://www.pete.lsu.edu/faculty/wojtanowicz.htm at the end of the SPE lecture season in June 2204. Also, you may link the information on DWS to: http://www.pttc.org/98casestuds/casestudy1.htm where one will find case history on field application. Please, let me know if I could be of any help to your SPE section members.

Tuesday - February 24, 2004
11:30 AM
Odessa Country Club
Cost $15

James Crafton
Distinguished Lecturer 2003-2004 Tour

Why Shut the Well in?
You've Already Got the Data

Tuesday - January 13, 2004
11:30 AM
Odessa Country Club
Cost $15

Ali Daneshy, Ph. D.
Daneshy Consultants International

Dr. Daneshy has taught hydraulic fracturing as a guest lecturer in many universities in US and outside. He has made numerous technical presentations on the subject to a worldwide audience. Mr. Daneshy will begin serving as a SPE At-large Director in 2005.

Ali Daneshy
www.daneshy.com
281 584 9444

Tuesday - December 9, 2003
11:30 AM
Odessa Country Club
Cost $15

Report from the SACROC

An update on Kinder Morgan CO₂ Co.'s operations in the SACROC Unit.  Kinder Morgan is investing about $145 million in new wells and additional infrastructure projects to expand its carbon dioxide flood program at the SACROC unit in Scurry County.

Rebecca Larkin is a Senior Engineer for Kinder Morgan CO₂ assigned to production operations at the SACROC Unit in Scurry County, Texas.  She’s spent the last decade at SACROC participating in the rebirth of this aging oil giant while working for Pennzoil, PennzEnergy, Devon Energy and now Kinder Morgan.  In what seems like a former life, Rebecca has worked in other parts of Texas for Pennzoil, Chevron, Carbon Dioxide Technology, and Amoco.  She studied Petroleum Engineering at Texas Tech and Geological Engineering at Michigan Tech.

Tuesday - November 18, 2003
11:30 AM
Odessa Country Club
Cost $15

Tuesday - October 14, 2003
11:30 AM
Odessa Country Club
Cost $15

Tuesday - September 9, 2003
11:30 AM
Odessa Country Club
Cost $15

 B.W. (Buddy) McDaniel
Halliburton Energy Services

 Abstract

Buddy McDaniel is a three-time SPE Distinguished Lecturer, having also been involved in 1989-90 and in 1997-98.  He has worked primarily in the application of well stimulation technology for more than 30 years since joining Halliburton Energy Services with a BS degree in Chemical Engineering from the University of Oklahoma.  He has served on numerous API and SPE committees, several technical review panels, and authored more than thirty technical papers or articles.  Topics of those papers include fracturing fluid selection and treatment design, proppant evaluation, fracturing of coal bed methane wells, and stimulation of highly deviated and horizontal wells.

Tuesday - May 13, 2003
11:30 AM
Place: Odessa Country Club

Biography

The Texas Railroad Commission

Conoco Towers,
10 Desta Drive
Suite 500E,
Midland, TX.

Oil & Gas Division (915) 684-5881
Gas Services and Pipeline Safety  (915) 570-5884

Railroad Commission of Texas  www.rrc.state.tx.us

Andrew Young's visit to SW Sections during the week of May 12th - 15th.  If an SPE meeting is not arranged in your location, I would encourage you to try to visit one of the near-by sections, as mentioned below, where he will be speaking.

His itinerary is as follows:
1. Monday May 12th - Balcones Section - San Antonio, TX  (Evening meeting) - will invite Austin Section and University of Texas student chapter members to come and participate, if possible.
2. Tuesday May 13th - Amarillo Section - Amarillo, TX (Lunch meeting) - will invite North Texas (Wichita Falls) Section to come and participate.
3. Wednesday May 14th - Permian Basin & Trans-Pecos Sections - Midland/Odessa, TX (Lunch meeting) - will invite South Plains Section and Texas Tech University student chapter members to attend. Midland Petroleum Club
4. Thursday May 15th - Four Corners Section - Farmington, NM - (Lunch meeting)
5. Thursday May 15th - Roswell Section - Socorro, NM - (Dinner meeting)- will invite the New Mexico Tech student chapter to attend.
 

Friday April 18, 2003
11:30 AM
Place: Odessa Country Club

Coiled Tubing Drilling from Algeria to Alaska; Praise, Pitfalls, Potential and Perils 

Monday -  March 24, 2003
11:30 AM
Place: Elegante' Hotel

Bob Skopec - Rock Mechanics in Reservoir Evaluation and Engineering
Distinguished Lecturer

 Operators are constantly looking for stimulation methods to optimize the production of horizontal wells. One of these methods has been to cement a liner in the lateral and using composite bridge plugs (CBP) to selectively sand frac multiple zones. This method has improved production in some cases, but running and drilling the CBP can be a challenge if there is proppant still in the wellbore.

Madden Systems

Production Logging, Reservoir Analysis, and Production Optimization

Maximizing The Effective Depletion of Reservoirs

Presentation by Raymond Madden

Madden Systems Inc. was established as an engineering and manufacturing center in 1983 to be an independent product development and research firm. The manufacturing center's mission is to provide dependable, technological products for the oil and gas, geothermal, and scientific communities. The employees of MSI have decades of experience in most phases of geophysical measurement, downhole microprocessor technology, packaging for hostile environments, and many other critical areas that ensure reliability in successful downhole data acquisition.

No Meeting in December

Tuesday - November 12, 2002
11:30 AM

 Abstract

Presentation covers ongoing security implementations and the current state of security preparedness in the Oil & Gas Industry.
Discussions on Oilfield theft and ways to combat this growing problem.

Biographies

Mike LaPlante 

Mike is a graduate from the University of Texas at Austin with a BBA in Management.  He spent four years in the US Navy and entered the FBI in March 1996.  He spent his first two years in the FBI in San Jose, California.  He was transferred to Midland in 1998.  He is currently working Cyber crimes and specifically Computer Intrusion matters and Intellectual Property Crimes.

In 1999, Matt was assigned to the Midland Resident Agency (MRA) where he serves as the principal relief supervisor. 

Throughout Matt’s career he has participated in Victim/Witness initiatives in relation to the TWA 800 crash investigation, the US embassy bombings, and several other lesser known cases. 

Meeting was Cancelled

Tuesday - September 10, 2002

Tommy Herring has been with Tree Savers International Inc. for the past three years.  Mr. Herring has worked in the oilfield for 20+ years, 15 years with Amerada Hess.

For more info about TSI products, the web location is below.

www.tsiworldwide.com

Alex Crabtree
BJ Services

Abstract

Despite advancements in coiled tubing (CT), the development of its application to a wider range of operations continues to be hampered by the perception that CT is prone to failure. Although CT can suffer unexpected failure, nondestructive testing (NDT) techniques are being developed and applied to reduce the number of such incidents. This lecture will focus on the causes of the unexpected failures and how they can be detected before inducing failure, how failures can be prevented, when NDT inspection should be undertaken, when the additional cost of NDT is justified, and the levels of certainty that inspection can provide. 

Coiled Tubing (CT) has evolved from tentative beginnings into an established method of performing well interventions within the oil and gas industry. Initial hesitancy was due to the perception that CT was unreliable and prone to failure, either developing pinhole leaks leading to the loss of pressure integrity or even catastrophic breaks resulting in tubing being left in the well.  The advent of the continuous milling process that allowed the manufacture of long CT strings, together with more rigorous raw steel specifications, enabled the study of the tubing’s  plastic fatigue response and subsequent prediction of tubing service life. Several low-cycle fatigue models are now available to assist in the management of CT, to ensure that it is not used beyond the point at which it might fail due to plastic overwork. These models also offer the service provider the opportunity to maximise the life of its CT fleet. Failures due to purely plastic fatigue have almost been eradicated, as a result of these studies and models.

Despite the advancements, and the immense potential of CT, the development of its application to a wider range of operations continues to be hampered by the perception that CT is prone to failure. As a recent industry survey confirmed, many in the industry still view CT as unreliable.  It would appear that, until such perceptions change, further development of the use of CT into more diverse areas of well intervention would be inhibited.

That CT can suffer unexpected failure is not disputed and it is in order to reduce the number of such incidents that Non-Destructive Testing (NDT) techniques are being developed and applied.  What are the causes of these unexpected failures and how can they be detected prior to inducing failure? How can they be prevented? When should NDT inspection be undertaken and at what point is the additional cost of NDT justified? What levels of certainty can inspection provide? These are some of the issues that will be examined.

Biography

Alex Crabtree graduated from UMIST with a B.Sc. in Mechanical Engineering in 1982. During his career he has been involved in the engineering, operation and management of cementing, DST, acidizing, fracturing, fishing, nitrogen and Coiled Tubing services worldwide. His first involvement with Coiled Tubing was in 1985 and in 1996 he became Group Leader for Worldwide Technical Support at BJ Services’ Coiled Tubing Research and Engineering facility. For the last two years he has been a member of the SPE/ICoTA Round Table Technical Review Committee.  He holds two patents, with a third applied for, and has authored four papers.

For information - contact Jeff Harris:   mailto:jharris@bjservices.com

Tuesday, December 11, 2001
11:30 a.m.
Odessa Country Club
Cost  $15.00

Coiled Tubing Fracturing – Cobra Frac 

 Doug Love, Halliburton Energy Services

Abstract

Coiled tubing operations have evolved dramatically over the past 15 years.  The advent of better tubing manufacturing techniques; introduction of higher grade and larger tubing sizes; and the development of equipment to handle the larger coiled tubing sizes has enabled many new processes.  One of the new processes that has evolved in the past few years is coiled tubing fracturing – Cobra Frac.

The ability to individually stimulate multiple zones in a wellbore in a single trip has many appealing qualities.  These include more effective stimulation of zones, better recoverable reserves, reduced cycle time to sales, and less environmental impact due to smaller footprint of equipment required and number of trips to the wellbore.

What is involved in a coiled tubing fracturing operation? Where have these type operations taken place to date? When does coiled tubing fracturing make sense for a well? How have coiled tubing fracturing candidates performed to date? These are some of the issues that will be examined during this presentation and discussion.

Biography

Mr. Love is the North American Coiled Tubing Frac Manager for Halliburton Energy Services.  He received his BS Degree in Mechanical Engineering from Texas Tech University at Lubbock, Texas.  Mr. Love has 14 years experience with Halliburton serving in various operational and engineering positions addressing cementing, stimulation, tools, and conformance with an emphasis on Coiled Tubing Services.  He is a member of the Society of Petroleum Engineers and the International Coiled Tubing Association.

To contact Doug:   mailto:doug.love@halliburton.com

Tuesday, January 8, 2002
11:30 a.m.
Odessa Country Club
Cost  $15.00

HBVI: An NMR Method to Determine Bulk Volume Irreducible as a Function of Reservoir Capillarity
Distinguished Lecture Series

Dave Marschall is Manager of Reservoir Description for NUMAR, a Halliburton Company, in Houston. He holds a M.S. degree in Biological Science from California State University, Long Beach, California. He joined NUMAR in 1994 to develop NMR lab, core, and MRIL log interpretation models. Before joining NUMAR, he spent 15 years with Core Laboratories where he held several petrophysical and management positions in research and development, operations, and industry training.

Tuesday, February 12, 2002
11:30 a.m.
Odessa Country Club
Cost  $15.00

The ABC's of Improving Production from Hydraulically Fractured Wells
Distinguished Lecture Series

Biography

Dr. Pearson has conducted extensive research into different methods of well production enhancement, published over 30 technical papers and holds several patents.  He has been a frequent contributor to SPE programs and held a number of positions at both the local section and international level.  He currently is Chairperson of both the JPT Editorial Committee and the 2002 ATCE Well Completions Program Committee. 

Tuesday, March 12, 2002
11:30 a.m.
Odessa Country Club
Cost  $15.00

A Present Alternative to “Rod” Pumping,
Something New to Think About

By Jeff Harris
BJ Services

Abstract

If a system could be developed to eliminate rod wear and other related problems, would you look into developing this system? There is a system presently working, and being further developed to address this problem.  It definitely offers other benefits as well, and more may be revealed.

Coiled Tubing Rod Strings could be the answer to an old problem. What is the concept behind this system and what are the potential benefits? This presentation is an open discussion to explore the possibilities of this system. The concept and mechanics of this system will be explained and explored. Case histories to date will also be described.

If you are interested in something new in rod pumping and ways to cut your production cost, then attend this presentation with an open mind and bring your thinking cap because this will be a proactive brainstorming presentation.

Biography

Jeffery G. Harris attended the University of Louisville and graduated from the University of Arkansas at Little Rock with a Batchelor of Science in Math.  He has been a member of SPE since 1981 (Trans-Pecos Section) where he has served in various offices over the years.  He was Chairman over Membership (‘90-’91), Secretary (‘91-’92), Newsletter (‘92-’93), Publicity (‘93-’94), and Golf Tournament Co-Chairman  (‘94-’95).  He served as Section Chairman (‘95-’96) and has been serving as a Director (97 - current).  Jeff has served as the SW Region – U.S.A. Council Representative.

Jeff’s Oil Field Career spans from 1977 to the present.  He has worked with and specialized in Coiled Tubing and Nitrogen Services, both offshore and onshore, from the North Atlantic to West Texas.  He spent six years working in pumping services.  He is currently employed by BJ Services Company in Midland, Texas as the Permian Region Technical Advisor for Coiled Tubing and Nitrogen Services.

Jeff has authored several papers and written articles for European and US oil and gas publications.

Tuesday, April 9, 2002
11:30 a.m.
Odessa Country Club
Cost  $15.00

Solving the Puzzle of Fracture Optimization

Abstract

After nearly a decade of mapping hydraulic fracture geometry, we are still often humbled by fracture complexity and lack of dimensional correlation to fracture models in most areas.  At the end of a job, we know almost everything about a frac: the pump rate, pressures, volumes, chemical additives, fluid viscosity, etc – everything except “What size fracture did I create and where did it grow?”  The ability to incorporate measured fracture dimensions along with net pressure matching and other data remains the industry ideal so that a 3-D model can be calibrated which accurately predicts frac geometry resulting from a specific treatment.  Pinnacle Technologies maps fracture geometry on more than 1500 fracs per year in many different reservoirs and will describe the technologies available to map hydraulic fractures using real-world cases where fracture diagnostics have been incorporated with net pressure and other data to optimize fracturing projects.

A discussion of Frac Diagnostic Technology including Tiltmeter mapping and Microseismic Mapping. Case Histories along with Frac Model Calibration will be shown.

Bibliography

Kevin Fisher has a B.S.  in Physics from Cameron University and worked for Halliburton for 15 years as a logging engineer, supervisor, log analyst and sales manager.  He joined ProTechnics as Director of Sales and Marketing in 1993 and was awarded several patents related to spectral gamma ray and gravel pack density logging.  In 2000, he became VP of Business Development for Pinnacle Technologies and is involved today in integrating fracturing diagnostic measurements with real-time fracture modeling.  He has written numerous technical papers and articles on well logging and fracture diagnostics.

You can reach Kevin at 281.876.2323 or mailto:kevin.fisher@pinntech.com

Pinnacle Technologies website can be found at www.pinntech.com

Tuesday, May 14 2002
11:30 a.m.
Odessa Country Club
Cost  $15.00

The Increasing Role of Unconventional Resources in the Future of the Oil and Gas Business

 Stephen A. Holditch
Schlumberger

The oil and gas industry began in the 1800’s, yet the volumes of oil and gas being produced world wide in the year 2000 are at record highs and are still increasing.   How much oil and gas remain to be discovered and produced?  The answer to this question is quite complex and depends upon what resources one considers when answering the question.

In this presentation, we will look at the oil and gas resources in two separate categories – conventional and unconventional.  Even though less than one-half of the conventional supply of oil has been produced, it is apparent that unconventional sources of oil and gas will play a much larger role in the petroleum industry during the next decade, and beyond.  The location and sources of these unconventional supplies will be discussed.  The importance of unconventional oil and gas production will be explained in terms of current production in the United States, Canada and other countries.   The importance of new technology developments and how world oil and gas prices will affect the supply of oil and gas from unconventional reservoirs will be discussed.

The conclusion is that unconventional sources of oil and gas currently play an important role in the world supply of petroleum, and this role will grow substantially in the foreseeable future.

Bibliography

2002 SPE President Stephen A. Holditch

Holditch is a leading management and consultant expert in the upstream oil and gas industry.  As a Schlumberger Fellow, he serves as the Production and Reservoir Engineering advisor to the top managers at Schlumberger.  Holditch also consults for Holditch Reservoir Technologies, a Schlumberger company.

He founded S. A. Holditch and Associates in 1977 and was Chairman, President and CEO of the company until 1999, when it became part of Schlumberger.  An author of more than 100 technical papers, Holditch has received some of the industry’s top awards and continues to serve in leadership roles in various organizations.  He served as Vice President Finance on the SPE Board of Directors from 1998-2000 and is a member of the Board until 2003.  He also served as an AIME Trustee from 1997 to 1998.

Holditch has received several SPE technical and professional awards, including becoming a Distinguished Member in 1989 and recipient of the Lester C. Uren Award, the John Franklin Carll Award, and the Distinguished Achievement Award for Petroleum Engineering Faculty.  He is a member of the National Academy of Engineering, the Russian Academy of Natural Sciences, and the Petroleum Engineering Academy of Distinguished Graduates of Texas A&M University, where Holditch received BS, MS and PhD degrees and currently serves as an adjunct faculty member.

Tuesday, September 12, 2000
11:30 a.m.
Odessa Country Club

Excape Completion System
Mark Malone

Abstract

The Excape completion process is a multi-company joint venture which provides a method of performing multiple fracture stimulation treatments incorporating the use of perforating guns and isolation tools on the outside of the production casing. The presentation will discuss the inefficiencies associated with current methods of multi-zone stimulation, the benefits of the Excape process, system components and recent case histories.

 Biography

Mark Malone currently holds the position of Region Technical Manager for the Permian Basin at BJ Services Company. Malone has held various engineering and sales positions during his 13 years in the pressure pumping services business, working in the Denver-Julesburg Basin of Colorado, Raton Basin of Northern New Mexico and the Permian Basin of West Texas and South East New Mexico. As the Region Technical Manager for BJ Services Mr. Malone’s focus has been on the practical application of new pumping services technologies. Malone is an SPE member, author and holds a Bachelor of Science in Agricultural Engineering from Texas Tech University.

Tuesday, October 10, 2000
11:30 a.m.
Odessa Country Club

Enventure Expandable Casing/Hole Liners
Bill Dean

Abstract

Enventure Global Technology, the leading provider of solid expandable tubular solutions, is a limited liability company organized and owned by Shell Technology Ventures, Inc. and Halliburton Energy Services. Enventure was formed to further develop and commercialize Shell’s original expandable-tubular technology.

Enventure Global Technology recently installed three Expandable Cased-Hole Liners in a well for Occidental Permian Ltd. in West Texas, restoring a 51-year old P&A candidate to an injector well. These three expandable liner systems, one of which is the longest expandable cased-hole liner ever installed, brings to seven the total number of solid expandable tubular installations completed by Enventure – four expandable cased-hole liner systems and three expandable openhole liner systems.

Enventure’s expandable tubular technology (SET) converted the five-decade old borderline producer into an active field injection well by installing three Expandable Cased-Hole Liners at critical sections in the wellbore: (1) a 914-ft section where the casing had been damaged from years of exposure to a corrosive clay formation, known locally as the "red beds", (2) another 537-ft area where the severely deteriorated casing was leaking, and (3) positioning a packer seat of an effective-inside-diameter below the casing repairs. The expandable liners used in each application interval were configured with the same basic components, varying in length from about 200 ft to 900 ft. Each liner was made of 4-1/4 in. 10.7 ppf casing with a series of elastomer seals at each end, which served both as a seal and as an anchor for the expanded liner.

The original production casing was 5-1/2 in., comprised of several weights. Prior to installing the liners, the casing condition throughout the five-decade old well, including OD and ID, was mapped using a Halliburton CAST-V ultra-sonic log. Then the three 4-1/4 in.-expandable-to-5 1/2 in. cased-hole liners were installed to secure sealing integrity inside the in-situ 5-1/2 in. casing.

Working from the bottom of the cased wellbore to the top, the first installation was deployed as the well’s new packer seat, positioned below the two upper casing repairs. This installation interval was from a depth of 4,835 to 4,640 ft (193 ft). The second installation, positioned from 3,773 to 3,236 ft, sealed 537 ft of deteriorated casing. The third, and world record length cased-hole liner, was installed to repair the casing damage due to the "red bed" formation. This cladded interval, from 1,824 to 910 ft (914 ft), was pressure tested to 880 psi. The upper liner system was also tested to 880 psi, and the packer seat was tested to 2,000 psi – all three had zero leak-off.

Post-expansion ID of the 4-1/4 in. expandable liner was 4.349 in. (compared to a pre-expansion figure of 3.750), while post-expansion yield was 4,680 psi (pre-expansion 5,660) and post-expansion collapse came in at 3,050 psi (5,495 pre-expansion).

Biography

Bill joined Enventure from Halliburton Energy Services where he worked for 20 years involved in engineering, sales, technology management, and operations management throughout the Mid-Continent area. Bill graduated from the University of Illinois Champaign, Il with a BS in civil engineering.

Tuesday November 14, 2000
11:30 a.m.
Odessa Country Club

Jim Weaver
Distinguished Lecture Series

Abstract

The production of proppant after hydraulic fracture stimulation treatments is a common problem that results in significant loss of revenue. It is so prevalent that many operators have accepted it as a 'normal' part of a well stimulation, choosing not to recognize it as a problem. There are many direct and indirect cost associated with proppant flowback that can reduce profitability of stimulation treatments. An often overlooked, but significant problem is loss of potential well productivity that results as fracture width is lost due to proppant flowback.

Several studies aimed at understanding proppant flowback have been reported in the literature and much is known about the importance of individual factors involved in flowback. However, there is not a complete understanding of the interrelationship of these controlling mechanisms, partially owing to the difficulty associated with realistic simulation of this problem in a controlled laboratory environment. This has led to considerable controversy in dealing with flowback issues.

A number of methods are used to minimize proppant flowback after fracture treatments. These include fluids designed to break rapidly, permitting wells to be produced back immediately at the conclusion of the fracture stimulation in order to 'force' formation closure to lock the proppant in place. Another is selection of angular proppant or the inclusion of fibrous material to enhance proppant bridging. Curable resin coated proppants have been extensively used in wells with severe flowback problems. A more recent innovation involves the coating of proppant with a non-curing, 'tacky' resin, which enhances proppant bridging and reduces flowback.

There is no single method that will universally eliminate proppant flowback. An understanding of the principals involved in flowback mechanisms permit selection of the method to minimize cost and frustration associated with excessive flowback. It is the objective of this presentation is to provide general understanding of flowback mechanisms and the choices available for flowback control. This is accomplished by use of multimedia presentation of data acquired from simulations performed in multiple laboratories and animations of mechanistic concepts.

Biography

Jim Weaver is a Senior Scientific Advisor for Halliburton Energy Services in Duncan Technology Center where he has 25 years of experience. His expertise is in organic chemistry and polymer science. He holds a Ph.D. degree from Oklahoma State University and a postdoctoral study at the University of Georgia. Majority of his work has been aimed at the application of polymers in water control, sand control, viscosity control and fluid loss control applications in cementing, stimulation, completions, EOR and production applications. He has been awarded 50 U.S. patents and has published more than 60 papers.

Tuesday, December 12, 2000
11:30 a.m.
Odessa Country Club

No December Section Meeting
 

January 9, 2001
11:30 a.m.
Odessa Country Club

James Rodgerson
BJ Services

Midland County Devonian Horizontal Stimulation Overview and Case History

Abstract

The stimulation of horizontal well bores has long been an illusive if not heated topic of debate. Much interest has been generated as of late, to determine the best method of stimulation. A wide variety of stimulation and completion techniques have been employed with reasonable success and in most cases common sense economics has been a major factor in determination of the overall treatment strategy. Everything from coiled tubing clean-outs to massive pad acid fracs has been employed.

We will also attempt to show possible reasonable methods of modeling reservoir properties, fracture geometry and stimulation effectiveness.

Biography

James Rodgerson is the bp Permian alliance engineer for BJ Services. James joined BJ Hughes in 1981 after receiving his BS in Industrial Distribution from Texas A&M University. James has authored several SPE papers.

February 13, 2001
11:30 a.m.
Odessa Country Club

Darien O'Brien
Distinguished Lecture Series

Star Wars Lazer Technology for Well Drilling and Completions

Abstract

Star Wars laser technology developed for air defense but may find use for in drilling and completing. Rotary drilling, a century after replacing the cable tool rig, shows recently only marginal improvements. Despite the improvements, the bit is "on bottom, turning right" only half of the time required to drill a well, and there are limits in perforating beyond the damaged zone. A drilling and completing revolution may be forthcoming with high-powered lasers.

Tremendous advances have occurred in power generation, efficiency and transmission capabilities since the laser was introduced in the 1960’s. Research on applying laser technologies has been undertaken to determine which laser(s) have the required power, portability, reliability, durability, safety and environmental impacts for economically drilling and completing wells. The possibility exists to revolutionize drilling for petroleum resources by:

Significantly increasing the rate of penetration (ROP)

Reducing or eliminating rig day rate, casing requirements, bit life and trip time

Providing enhanced well control, perforating and side-tracking capabilities

Achieving the above with environmentally attractive, safe and cost effective technology.

Initial testing on reservoir rocks conducted with the U.S. Army's satellite decommissioning Mid-Infrared Advanced Chemical Laser (MIRACL), showed the potential for laser drilling. The laser beam drilled at a speed that indicates penetration could be increased by more than 100 times current rates.

Tests were conducted with the Chemical Oxygen-Iodine Laser (COIL) invented by the U.S. Air Force for air-to-air defense. More than 100 rock samples – including sandstones, limestones, shales, salt, granites and concrete – were exposed to laser beams of varying power and duration. The results were encouraging in that the laser was able to penetrate all rock types with and without borehole fluids, water, and gas. Test results from the U.S. Air Force and the U.S. Army’s high-power laser research facilities will be presented

Biography

Darien G. O’Brien, PE is Director of Engineering for Solutions Engineering, a petroleum and environmental engineering consulting firm located in Lakewood, Colorado. Mr. O’Brien’s involvement with laser technology began while working in the Laser Division of the U.S. National Bureau of Standards in the early 1980’s as part of the Star Wars research initiatives. Since 1996, Mr. O’Brien has been the Principal Investigator for the laser well drilling and completions research. A registered professional engineer, Mr. O’Brien holds a BS in Petroleum Engineering from the Colorado School of Mines and a Masters of Business Administration from the University of Alaska.

March 13, 2001
11:30 a.m.
Odessa Country Club

Downhole Video as a Diagnostic Tool
Jeff Whittaker - DHV International Inc.

Abstract

Biography

Jeff Whittaker is a sales engineer for DHV International Inc. in Houston and has worked for DHVI for 8 years. Previous assignments include Gulf Coast District Manager in Lafayette Louisiana and Business Development Manager in Bakersfield California. DHVI is presently head quartered in Oxnard, California and provides downhole video systems and services to the to the oil and gas industry. Jeff is involved in field application, training, and marketing DHVI services. He has published several technical papers on video logging including the use of video of logs in aiding water shutoff remediation work. His previous background includes eight years with Schlumberger Well Services in the Gulf Coast and Offshore California areas and three years with Shell Western E&P Inc. as a Petrophysical Engineer.

Tuesday April 10, 2001
11:30 a.m.
Odessa Country Club

Norman Morrow
Distinguished Lecture Series

Abstract

Waterflooding is by far the most widely applied method of improved oil recovery. Laboratory waterfloods and field observations show that the efficiency of oil recovery from the swept zone of a waterflood can be strongly dependent on reservoir wettability.

The talk develops the relationship between wettability and oil recovery observed over the past fifty years. The once common assumption that most reservoirs are very strongly water wet has given way to the conclusion that complex crude oil/brine/rock interactions can result in a broad spectrum of wettability conditions. It is now accepted that mixed wettability is prevalent in most reservoirs. Measurements of reservoir residual oil saturation show that waterfloods recovery efficiencies for mixed wet reservoirs can show great variation and are often much higher than expected. Relationships between waterflood recoveries and quantitative measures of wettability indicate that weakly water wet conditions are optimum.

The past five years have shown that concern injection brine composition effect oil recovery. Traditionally it was believed that injection brine composition had no effect on oil recovery. Laboratory waterfloods using injection brine with varying composition, trends between oil recovery and wettability showed unexpected behavior including instances of increased breakthrough and subsequent recovery with injection of low salinity brine. The mechanism of increased recovery depends on adsorption from crude oil and the presence of mobile clay and connate water; results to date indicate higher recovery for paraffinic than asphaltic crude oils. A further observation which is indicative of the role of surface interactions is that, at high water to oil ratios, production can be increased or curtailed according to injection brine composition.

The discussion will conclude with practical application of this work. Results will be summarized as screening criteria for selection of candidate reservoirs for improved waterflood recovery through manipulation of injection brine composition.

Biography

Dr. Morrow is J.E. Warren Distinguished Professor in the Department of Chemical and Petroleum Engineering at the University of Wyoming. His research on capillarity, surface chemistry, wetttability and oil recovery has been recognized through numerous awards. His program is currently supported by twelve major oil companies from seven nations, the Enhanced Oil Recovery Institute at UW and the National Petroleum Technology Office of the U.S. Department of Energy. He has over 100 publications and serves on many technical committees and editorial boards. He founded the international symposium series "Evaluation of Reservoir Wettability and Its Effect on Oil Recovery".

May 8, 2001
11:30 a.m.
Odessa Country Club

Kimberly Dollens
Distinguished Lecture Series

"The Application of Horizontal Lateral Wells in Secondary and Tertiary Recovery Operations"

Abstract

Horizontal lateral well technology is increasingly being employed in secondary and tertiary oil recovery projects. Horizontal wells are generally expected to recovery approximately three times the initial rate and about twice the reserves of a conventional vertical well in a field (depending primarily on the amount of pay zone penetrated), thus they can be utilized to increase throughput in low permeability zones. Conventional five- or nine-spot injection patterns can easily be converted into horizontal line-drive patterns, thus increasing the horizontal sweep efficiency.  Finally, the use of horizontal laterals for injection and production in low permeability layers within a multi-layered system allows for increased vertical sweep efficiency. Thus, the ultimate recoveries in secondary and tertiary floods can be significantly increased through the application of horizontal well technology currently available.

This presentation reviews the basic concepts for the application of horizontal technology in secondary and tertiary projects, including waterflooding basics, horizontal and vertical sweep efficiency concepts, and CO2 issues. Particular emphasis will be placed on actual field examples of small, medium, and large secondary and tertiary recovery projects, primarily based on published information available in textbooks, industry periodicals and DOE Publications. A review will be made of both the upside and the downside of horizontal wells, including operational and reservoir monitoring issues and concerns.

Biography

Kimberly B.  Dollens is an operations reservoir engineer with expertise in the use of horizontal lateral wells in waterfloods and tertiary flood operations of the Permian Basin of west Texas and the Paradox Basin of southwestern Utah.   Kimberly served as the Flood Management Team Leader for Mobil E&P U.S. during the final year of the 1996-1998 Ratherford Unit horizontal lateral  drilling program, and as the Principal Investigator (1996-1997) on the DOE Oil Recovery Program project at Phillips Petroleum Company's South Cowden (Grayburg/San Andres)Unit.

Ms. Dollens has co-authored two SPE papers on the subject of horizontal wells in secondary and tertiary projects. Kimberly holds a Bachelor of Science degree in Petroleum Engineering from the Colorado School of Mines, and a Masters in Business Administration from the University of Texas of the Permian Basin.  She is currently assigned to ExxonMobil's Central Technology Group as a Surveillance Engineer for two OBO properties in Venezuela and Argentina.

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