All Fall 2009 & Spring 2010 Trans-Pecos Section Meetings
Will be held at the CEED Building located at 1400 North F.M. 1788, at FM 1788 & Highway 191, Midland, TX, 79706. Meetings will start at 11:30 AM and the Cost will be $20.00 unless otherwise noted. Please RSVP to Jared Booker at 432-571-8615, 432-238-0070, or email at Jared Booker, or Rick Snyder .
 Chemical Conformance Treatments for Injection and Production Wells The production of unwanted fluids (either water or gas) and poor injection profiles are major problems in hydrocarbon fields throughout the world. Undesirable effects on surface and subsurface equipment, the cost of handling water, and bypassed reserves due to poor injection profiles all reduce profitability of a field. Numerous techniques and chemicals have been used down through the years to combat all of these problems. This talk will address the major chemical methods currently used to combat these problems, with a focus on sealants, disproportionate permeability modifiers and swellable polymers.
Larry Eoff is a research and development chemist for Halliburton Energy Services in conformance technology. He obtained a bachelors degree from the University of Central Arkansas and a PhD from the University of Arkansas. He has been with Halliburton for 18 years and has worked in cement product development as well as in conformance. In addition, he spent 2 years with Baker Performance Chemicals in Houston, Texas.
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INTEK Inc. 2009-2010 SPE Distinguished Lecturer Unlocking Ten Trillion Barrels of Global Oil Shale Resources: The State of the Industry Khosrow Biglarbigi, INTEK Inc. The development of domestic oil shale resources has regained significant attention in the past few years. Several factors have contributed to this, including high oil prices, emerging recovery technologies, increasing world demand for liquid hydrocarbons, and the continued decline in U.S. conventional oil production. In recent years, several initiatives have been taken by the U.S. Government and the private sector to encourage the development of a domestic oil shale industry. The United States has vast deposits of oil shale, nearly 2.0 trillion barrels across the eastern and western states. The development of this massive resource, however, is constrained, by a number of key factors including, but not limited to 1) resource access, 2) technology, 3) economics, 4) environmental and regulatory issues, and 5) infrastructure. A comprehensive analysis has been completed to address these issues and identify options to accelerate the development of this resource. The analysis is based on a representative sample (about 70 billion barrels) of Western oil shale resource divided among multiple development “tracts.” Four production technologies were also considered. These technologies included emerging in-situ processes as well as traditional mining with surface retorting technology. Each development tract was screened for the potential application of each recovery technology. A detailed economic evaluation was conducted for each tract, and the selected technology with consideration for development under alternative economics, environmental, technology, and socioeconomic options. The analysis indicated that with a concerted effort from industry, local, state, and federal governments, the oil shale production potential could reach 2.5 million barrels per day (MMBbl/d) with substantial benefits to the local and national economy. Khosrow Biglarbigi is the president and director of petroleum engineering ofINTEK Inc, an energy management consulting firm in Arlington, VA. He has more than 16 years experience in evaluating conventional and unconventional oil and gas resources, economic analysis, and public policy analysis. Biglarbigi recently provided engineering and analytical support to the Task Force on Unconventional Fuels (mandated by Energy Policy Act of 2005) as they identified and analyzed development hurdles for oil shale, tar sands, coal liquids, heavy oil, and CO2 flooding; and conducted cost/benefit analyses of potential options to overcome these hurdles. Biglarbigi has earned both M.S. and B.S. degrees in petroleum engineering from the University of Tulsa. He has written numerous publications related to oil shale, enhanced oil recovery, horizontal wells, resource evaluation, and development of oil and gas models
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Multiple Pay Tight Gas Sands: Can the Lessons Learned in the Rockies Help You? Mike Eberhard, Halliburton Energy Services In tight gas sand provinces such as the Rocky Mountain region of North America, more than 90 percent of new wells require hydraulic fracturing to be economic. With the growing development of marginal multiple pay tight gas sands, economic completions have become more difficult. Continued improvements in evaluation and completion technologies for multiple pay intervals is essential to meet an operator’s economic criteria. For operators with a large drilling program, one solution has been the development of a “factory” approach to drilling and completing wells. While this approach provides economic benefit in reducing cycle time and economy-of-scale savings, it is not without complication. Some factors that affect the economic optimization of a well completion for the factory approach are: Determining well productivity from logs Completing multiple pay intervals during the initial completion process Determining which multiple-pay fracture treatment technique to use Timely fracture treatment recommendations for a high volume of work Evaluating production results and adopting improvements This presentation will discuss how these five factors are currently being addressed, with focus on the Rockies. The overall process will be reviewed as a holistic approach to well completion and optimization. The presentation will emphasize the different completion techniques being used throughout the Rockies. Operational difficulties of high volume operations also will be discussed. Actual case study data will be presented showing the benefits of this approach. People attending this presentation will become very familiar with the variety of different fracturing techniques being used in completing multiple pay tight gas sands.
entire career in pumping services including cementing, acidizing, and hydraulic fracturing. He has worked in the Williston Basin, Bakersfield, CA., Brighton, CO. and lastly Denver, CO. During this time, he held various engineering and technical sales
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WAVEFRONT TECHNOLOGIES
Powerwave Injection Technology – Secondary/Tertiary Recovery Waterfloods and CO2 Floods Leveraging our unique process marketed as Powerwave and Primawave, Wavefront dramatically improves liquid flow in the ground for improved oil recovery (IOR Waterfloods, CO2, Surfactants), near wellbore intervention cleanouts, and environmental groundwater remediation. These identical processes generate a fluid pulse that momentarily expands the pore structure of rock and soil. Using this pressure pulse approach, these processes move fluid through the ground much like your heart pumps blood through your body. As a result, fluid that has never moved before flows freely. In the oil sector. IOR/EOR is a "Contact Sport" Powerwave improves the contact game and can transform low-producing or even abandoned fields into newly profitable reservoirs. The process is accomplished by use of a 1.75 OD Thru Tubing Tool deployed from a nipple profile in an injection well. 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% at the same average daily pressures. Please click on the link below to view a short video that puts the process in perspective. http://www.onthewavefront.com/Files/Download/Videos/Video1/video1.html
Biography 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. |
2009-2010 SPE Distinguished LecturerWhy Coiled Tubing Fails and How to Avoid Failures in Your WellSteven M. Tipton, University of TulsaCoiled tubing (CT) is a simple concept: continuous metal tubing, wound onto a spool like a garden hose. Its uniform outer diameter affords deployment, storage and operational benefits that allow it to outperform jointed tubulars in many applications. However, CT is not as simple as it looks. The cyclic bending strains imposed on CT during routine use are far beyond range typically imposed on engineering alloys. Therefore, fatigue is inevitable with CT. Understanding fatigue and plasticity behavior are critical to the successful implementation of CT in the field. The bending strains in CT can cause its diameter to grow (balloon) by more than 30%. The tubing also can elongate on the order of 10-12 feet each trip in and out of a 10,000 ft well. These events occur despite the fact that neither the circumferential pressure stresses nor the applied axial forces ever come close to yield stress magnitudes. The development and growth of fatigue cracks in CT also defy engineering logic. They appear where you might least expect, and sometimes (fortunately) not on schedule. Not surprisingly, the fatigue endurance of CT can be affected by the presence of defects, which occur regularly in harsh oilfield environments. Shallow defects that penetrate the wall thickness by only a small percentage can reduce fatigue lives by an order of magnitude. On the other hand, large defects, driven through 1/3 of the wall thickness, have been shown to cause no reduction in fatigue life. Ongoing research is helping to quantify the influence of defects, and to develop techniques for making quick and cost-effective repairs in the field. Defects must be detected to be analyzed. The development of reliable inspection technology provides another key to CT reliability. Magnetic flux leakage is the most common technique for finding flaws in CT. However, research is underway to adapt 3D laser imaging NDE, such that defect dimensions and geometry are fully characterized. Output from such techniques is directly compatible with software that can quantify defect severity in real time.
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Trans-Pecos SPE Meeting – Distinguished Lecturer Wednesday, March 10th, 11:30am Odessa Country Club, #1 Fairway Drive, Odessa, TX Meeting Cost: $20 Lunch is provided
2009-2010 SPE Distinguished LecturerWays To Reduce Successfully Well BlowoutsOtto Luiz Alcantara Santos, PetrobrasThe objective of this presentation is to show important aspects of well control safety that have been conducted in Brazil by Petrobras that result in an almost ten-year period without a blowout. This has been done adopting the following actions: training and certificating the personnel in well control, monitoring operational activities, elaborating standards and operational procedures, and doing research. The first line of action to be addressed is the training and certification program. The important aspects and results of the well control certification program in effect in Brazil are shown. Since its creation in 1996, the program has already issued more than 5500 WellCAP certificates, the certification program adopted in Brazil. Following, the presentation shows operational actions that were implemented in the field, such as annual inspections of well control equipment, monitoring of the well control equipment tests for function and pressure, and monitoring of the kick detection equipment tests. The most important well control standards and operational procedures recently elaborated, especially those related to deepwater situations, are also commented. The last part of the presentation focuses on research and development projects that have been conducted in Brazil on well safety, especially in deepwater. Thus, the operational difficulties and technological challenges for drilling and producing safely in deep and ultra deep waters are presented. The research projects dealing with these operational difficulties conducted recently in Brazil are presented and discussed. These deepwater projects include the development of a kick simulator, the study of drilling hydraulic and kick control using an actual drillship, the study of gas solubility in synthetic oil based drilling fluids, and blowout control considerations. The most important aspect of presentation is to show how a major oil company can act to preserve its personnel, assets, and image from the consequences of a well blowout.
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Steven M. Tipton
is the Frank W. Murphy Distinguished Professor of Mechanical Engineering at
the University of Tulsa, where he has taught for 25 years. He holds Ph.D.
and M.S. degrees from Stanford University and a BS degree from Oklahoma
State University, all in mechanical engineering. He conducts research in
multiaxial fatigue and plasticity analysis, and is an expert on coiled
tubing mechanics. He is the director of the TU Coiled Tubing Mechanics
Research Consortium. He is an active consultant to a wide range of
industries, including petroleum, ground vehicle, aerospace, and sporting
goods companies. He has 8 patents and others pending. He developed
algorithms that predict the mechanical behavior and fatigue life of coiled
tubing. Dr. Tipton’s algorithms are currently used by the majority of the
industry to monitor coiled tubing fatigue all over the world