Please join SPE in congratulating the 2012 SPE International Award recipients. The SPE Board of Directors approved the 2012 International Award recipients at their recent meeting. Seventeen international award committees recommended these winners to the board because of their outstanding and significant technical, professional, and service contributions to SPE and the petroleum industry. The winners were chosen from a pool of first rate candidates. SPE President Ganesh Thakur will present the awards to the winners at ATCE in San Antonio Texas.
Drilling Engineering Award
Fred E. Dupriest, ExxonMobil, Houston, Texas, USA
Kenneth E. Gray, University of Texas, Austin, Texas, USA
Multifunctional Handling tool launched
Weatherford International recently announced the launch of its UniSlips all-in-one handling tool, the industry’s first rotary-mounted, multifunctional slip for casing, tubing, or drillpipe operations. Read more »
New subsea system launched for jack-up drilling units
Argus Subsea has recently introduced the AZ-15J subsea tree and wellhead system, specially designed for jack-up mobile drilling units. The company states that the new system is the world’s first purpose-built system that allows operators to drill and complete wells at up to 15,000 PSI working pressure without special riser systems or temporary abandonments. Read more »
New drilling motor promises performance boost in challenging environments
Mpact Downhole Motors has introduced a new proprietary downhole drilling motor that promises significant increases in performance and reliability. Designated Model 775 7822 HTS, the drilling motor’s ultralow speed and robust design have helped reduced drilling downtime in field trials in Texas and Louisiana. Read more »
Papers in the following areas are featured:
- Drilling Engineering Training with Directional Drilling Examples
- Well Control and Managed Pressure Drilling
- Drillstring Dynamics
- Casing Drilling
- Formation Damage
- Well Integrity
- Wellbore Strengthening
- Classic SPE Drilling Paper
Read the latest content at www.spe.org/go/spedc
We wear small bands on our fingers for many reasons. The rings have many meanings; the wedding ring may be the most common. This band, signifying no beginning or end, represents a union or reminds the wearer that he or she is married. It is traditionally worn on the left hand, on the vena amoris, the digit that the Romans believed was connected directly to the heart. Puzzle rings, or gimmel bands, are another type of ring used as wedding bands that has dual meanings. The word “gimmel” comes from the Latin gemellus and means “twin” or “paired.” Engaged couples would each wear one piece of the puzzle ring and, upon marriage, join the two bands with another provided by the priest. Once joined, the bands formed a puzzle that, if removed, was difficult to piece back together. Deceit that led to infidelity was made more difficult because the wearer might not be able to put the puzzle back together. Wedding rings have different traditions in eastern and western cultures, but they always hold a strong mental connection for the wearers.
Rings also tie us to our accomplishments or recollections. School rings and championship rings can tie us to a collegiate career or a significant athletic accomplishment. The purpose of these rings is to remember. I have always been inspired by a tradition that many Canadian engineers have of wearing an iron ring. The ring is worn on the little finger of the engineer’s dominant hand so that, when writing or tasking with the dominant hand, the engineer is reminded of his or her obligations. The tradition holds that the iron in the ring came from a bridge that failed and cost many lives. The ring is small and is designed to be a constant reminder. The tradition continues when the engineer retires; the ring is returned to service as an “experienced ring.”
Preventing failures in our field is imperative for safety and economic operation. Learning from these failures, properly documenting and remembering them, is important for avoiding catastrophes. We may engineer a process, a method, or a particular part to reduce failures and enhance operations. Solid-expandable-tubular technology is a fairly new technology that is gaining more promising and important applications in oil- and gas-wellbore design. Constant improvements to the deployment of this technology are increasing its reliability and number of applications. Heat treatment of the expansion-cone material used in an expanding tubular is one such modification. The drillpipe-connection phase of the drilling operation can be one of the greater opportunities for failures and mishaps. An improperly handled connection procedure can damage drillpipe; stick a drillstring; and, in the case of managed- pressure drilling, induce an unwanted influx. One of the selected papers reviews a database of drillpipe-connection damage, and another reviews a method for making connections in the managed-pressure environment.
Read the paper synopses in the June 2012 issue of JPT.
Casey McDonough, SPE, is a drilling engineer for Chesapeake Operating. He has 7 years of practical drilling experience working in the Permian Basin and with the Barnett and Marcellus shale. McDonough has nearly 20 years of combined consulting, managerial, technical, and field experience in the oil and gas industry. He has worked as a consultant for Knowledge Systems, providing clients with pore-pressure and wellbore-stability studies. McDonough also held technical and managerial positions in downhole logging-while-drilling development for Dresser and Halliburton, where he contributed to density, neutron, vibration, and hot-hole technology. He began his career as a field engineer for Sperry Sun Drilling Services and holds a BS degree in industrial engineering from the University of Oklahoma. McDonough serves on the JPT Editorial Committee.
Well stimulation continues to be a hot topic in our industry, particularly with hydraulic fracturing of shales. Having been in the industry since the Dark Ages, (at least, it seems like it at times), it is interesting to see the technology changes over time and what areas are currently in the spotlight. Certainly, hydraulic fracturing continues to lead the industry interest; however, we do pump a lot of acid, and we have not forgotten its importance. Our acid blends have not changed much since the very early days— the late 1800s—of acidizing. Hydrochloric acid has been the mainstay, with primarily hydrofluoric acid and formic and acetic acids being the complimenting acids. Specialty acids, such as phosphonic, sulfamic, and others, have also been playing a role.
Major technology developments in nonproppant-fracturing well stimulation, as evidenced by the numerous publications over the last few years, have been primarily in carbonate acidizing. This is a continuing trend brought about by the significance of the carbonates to the world’s oil supply. However, our industry does use a lot of acid in the noncarbonates. One of those areas is in spearheading fracturing treatments to reduce near-wellbore tortuosity, most of these in sands and shales. My experience with this approach in horizontal shale wells has not always been successful; however, one of the papers selected for this month’s feature shows a unique acid blend that has shown some success in tight-gas-sand fracturing. Perhaps this and other unique acid blends could provide increased success in shales.
Horizontal wells in all reservoir types are now quite common, allowing our industry to exploit lesser-quality reservoirs economically. Shales are excellent examples. Many reservoirs have a high water cut, and stimulating wells in these reservoirs can be a real challenge. Acid-placement techniques, as well as diagnostics while acidizing, are a significant challenge to our industry. Of course, in our industry, challenges beget solutions. A recent development helping with well stimulation and production diagnostics is distributed temperature sensing (DTS) and distributed acoustic sensing (DAS). From reviewing numerous technical papers from worldwide SPE meetings held in the last year or so, the development and application of DTS and DAS appear to be in the forefront. Two of the papers selected for this month’s feature reflect on these developments and applications.
Readers are advised to review the following synopsized papers as well as the recommended additional reading to gain information on recent advancements in well stimulation.
Read the paper synopses in the June 2012 issue of JPT.
Gerald R. Coulter, SPE, is a consulting petroleum engineer and president of Coulter Energy International. He is involved in consulting and technology transfer of well-completion, formation-damage, and well-stimulation technology. Coulter is currently an instructor with PetroSkills. His industry experience includes work with Sun Oil/Oryx Energy Company, Halliburton, and Conoco. Coulter has authored numerous technical papers and holds numerous patents, has been chairman of and has served on numerous SPE committees, and is currently serving on the JPT Editorial Committee. He holds a BS degree in geology and a BA degree in chemistry from Oklahoma State University and an MS degree in petroleum engineering from the University of Oklahoma.
The coiled-tubing (CT) industry has experience unparalleled growth in the past year, driven directly by the massive expansion in multistage-fracturing operations in North America. Various sources estimate that the US consumed 50% of the world’s CT in the past 12 months, helping to contribute to a massive 80% growth in product coming off the CT production lines.
The growth in the United States was fueled primarily by three applications: milling out composite plugs, milling out fracture-sleeve ball seats, and toe shoots (the name given to the first perforating operation before plug-and-perforate operations). Because toe shoots take place without any pressure on the well, the amount of CT life consumed by fatigue during the operation is small. Plug or seat milling, on the other hand, takes place after fracturing operations are complete and with the wellbore fully pressure charged by the formation; therefore, the CT life consumed by fatigue is high. Superimposed over the wellbore pressures are the pressures arising from circulating fluids through the CT and the milling assemblies. In some of the higher-pressure shale plays, CT strings last only for a few jobs.
Accordingly, any technology that reduces the superimposed pressure could lead to longer CT life and potentially to lower completion costs. Two of the papers selected for this month’s issue involve new technologies that might be helpful to operators in this respect.
However, of possible greater concern to CT companies in North America is the fact that CT use is now clearly dominated by well-completion operations, or, to put it another way, by rig count. Until recently, the CT intervention business was primarily remedial in nature and, thus, was partially cushioned from the extreme cycles experienced by drillers. However, in North America, a change has already arrived and, with gas prices at historic lows, CT service companies, CT pipe manufacturers, and CT equipment manufacturers probably need to prepare for the same swings that the rest of the well-construction industry is used to.
Read the paper synopses in the June 2012 issue of JPT.
John Misselbrook, SPE, is senior advisor global coiled tubing with Baker Hughes. Previously, he was with Nowsco Well Service Company, which merged with BJ Services in 1996. Misselbrook has worked in various operational, engineering, research, and management roles involving CT in the North Sea, Canada, Southeast Asia, and theUnited States. He was a member of the original team of engineers involved directly in the development of improved engineering techniques for underbalanced drilling in western Canada in 1991. Misselbrook subsequently became responsible for Nowsco’s initiative to develop underbalanced-drilling technology by use of CT. He holds several US patents and has authored several SPE papers on the use of CT. Misselbrook is a mechanical sciences graduate of Cambridge University. He served on the 2008 and 2009 SPE/ICoTA Coiled Tubing and Well Intervention Conference Committees and serves on the JPT Editorial Committee.
The number and economic contribution of unconventional (tight gas/shale and steamflood) wells continued to increase rapidly in 2011, as did the participation of major operators. That increased industry focus was evident again in the distribution of papers. Also, there were more papers relating advances in plug-and-abandonment, Arctic, high-pressure/high-temperature (HP/HT), and carbon-capture technologies.
Manny Gonzalez, Chevron Energy Technology Company’s Alliance Manager, noted that the huge interest in shale-formation completions calls for efficient controlled fracturing technology to ensure economic viability and an environmentally responsible well completion. SPE 152185 outlines a direct comparison of openhole vs. cased-hole fracturing in a tight gas reservoir. The presented results are surprising, and the effects on incremental production, fracture height, and fracture half-length are significant—a good read.
Operators have been plugging nonproductive and storm-damaged wells at an increasing rate, and effective abandonment operations can prove costly and challenging. SPE 148640 relates a novel and well-detailed approach to a more efficient plug-and-abandon process and to the process of confirming plug integrity across an uncemented section of annulus. Check it out.
Industry emphasis on long-term well reliability has continued to increase, especially for steamflood projects. SPE 150022 details a very thorough look into the many design and operational factors that affect well reliability in a high-temperature (285°C) steamflood. While only briefly mentioned, the authors undertook controlling the rate of temperature change, and thus controlling temperature disparity (∆T) between casing, cement sheath, and formation during injection cycles. Controlling injection events can have a strong effect on the reliability of a steamflood well or even a deepwater or HP/HT well. This is the first field effort at controlling such events that I recall.
Read the paper synopses in the May 2012 issue of JPT.
Bob Carpenter, SPE, Research Consultant with Chevron Exploration and Technology Company’s Cement Team, has 33 years’ experience in field operations, technical support, and R&D. Previously, he was with Arco Exploration and Production Technology and BJ Services’ Technology Center. Carpenter serves on the SPE Drilling and Completions Advisory Committee, along with other industry groups. He has authored or coauthored 15 SPE papers and several JPT articles and has been granted 23 US patents. Carpenter’s areas of expertise include technical support and R&D of all areas of primary and remedial cementing. He also has extensive expertise in coiled-tubing cementing, spacer-fluid development, and remediation of sustained casing pressure. Carpenter serves on the JPT Editorial Committee.
Mitigating Risks in Development Projects
Our industry has been involved in incidents that demonstrated the need of a new approach for evaluating and mitigating the risks in well construction.
The “what’s worked well in the past” conservative approach is not possible anymore, in face of the damaged trust of the public about upstream activity. Though the criticism soars against exploration and production activities, the industry has allocated substantial investments in research for new technologies aimed to preclude risk events of recent years. New procedures and technologies, in addition to existing ones, will be deployed in the near future to eliminate blowouts or underground contamination from upstream operations.
The initial results can be seen in field operations such as the application of managed-pressure drilling (MPD) for offshore and onshore, the use of long horizontals or extended reach in the shale plays, and new fluids and techniques for fracture treatments that minimize the amount of water required in such operations.
The effects of drilling operations in the shale plays of the USA are clear, but recent research will result in a consistent reduction of environmental damage. Research is minimizing fluid losses into reservoirs and helping with mitigation of well-control situations when applying the MPD technique.
The use of nanotechnology will provide fluids that improve fracture treatments through the control of fluid losses, with a subsequent reduction in the amount of fresh water required. Today, an average fracture treatment in the Barnett shale requires 235,000 bbl of water. These treatments are essential to reduce the number of wells and to improve the performance of the fracture treatments for environmental-impact reduction.
The use of extended-reach drilling or long horizontal wells, combined with multilaterals, will reduce the number of wells without impairing expected production. This will mitigate the effect on aquifers or shallow formations with a reduction in surface infrastructure. Some of the papers featured or listed for reading show advances in the technology of extended-reach and multilateral wells that will help achieve such objectives.
Finally, the combined use of extended-reach and multilateral wells, nanotechnology fluids, and MPD will result in a more environmentally-friendly operation with a cost-effective development plan, which is essential for improving the industry’s image.
Read the paper synopses in the May 2012 issue of JPT.
Alvaro Felippe Negrão, SPE, is Senior Advisor for Woodside Energy USA. Previously, he was with Repsol, Halliburton, and Petrobras. In his 33-year career, Negrão has been involved in drilling and completion engineering and operations for wells in deepwater Gulf of Mexico, Brazil, the North Sea, West Africa, the Mediterranean, the Caribbean, and North/South America and in new-ventures evaluation and asset management. He has served on several SPE committees and currently serves on the JPT Editorial Committee and serves as vice chairperson for the SPE Subcommittee for the Offshore Technology Conference. Negrão holds a BS degree in civil engineering from the Universidade de São Paulo in Brazil, an MS degree in petroleum engineering from the Universidade de Campinas in Brazil, and a PhD degree in petroleum engineering from Louisiana State University.
No word defines deepwater projects better than “innovation,” and on 25 February 2012, one of the most innovative field-development projects came on stream: Cas- cade and Chinook (C&C) in the US Gulf of Mexico (GOM). One well is producing from Cascade to the first floating production, storage, and offloading (FPSO) vessel in the US GOM. The project brings several firsts and innovations that will be available to the entire oil industry in the near future. I would like to call attention to some of those innovations. First, the FPSO uses a detachable buoy that allows early installation of the buoy and all umbilicals before arrival of the FPSO. This feature will allow the FPSO to disconnect and sail away from hurricanes, avoiding damages to the facilities. C&C also presents the first freestanding riser in the US GOM. Subsea boosting will increase production and reduce workover costs. These examples are just a few that show inno- vation applied to a deepwater development. I believe strongly that C&C will lead the way for future development of Lower Tertiary plays in the GOM.
I selected one paper for this feature that describes the planning, logistics, and technology of the two largest deepwater high-pressure perforation jobs executed suc- cessfully in the GOM; certainly, this provides very interesting reading if your company is in the Tertiary play or is planning to be.
Drilling management in deep water has always been a great challenge because of several constraints, including high cost; well engineering (exploratory wells); logistics (remote locations); health, safety, and environmental (local and international laws); licenses; and personnel management. One of the papers presents a very objective and clear explanation of the well-management process, describing the design methodolo- gy and the well-execution procedures used by Petrobras International in a remote and challenging area. This methodology can be applied to any well and could bring huge benefits for any drilling operation.
Are you lost in a “cloud” of drilling data? You are not the only one! Drilling-data management is one of the biggest challenges in our industry today. One of the feature papers presents solutions, gives examples, and shows the benefits of a correct use of drilling data.
Enjoy your reading.
Read the paper synopses in the May 2012 issue of JPT.
Jacques Braile Saliés, SPE, is the Drilling Manager of Queiroz
Galvão E&P. His 30-year career at Petrobras included various engineering and management positions in E&P: coordination of the Petrobras Technological Program on Ultradeepwater Exploitation Systems— PROCAP 3000, drilling manager for Petrobras America, and well operation manager for Petrobras International. Saliés holds a BS degree in mechanical engineering from the Military Institute of Engineering, Brazil, an MS degree in petroleum engineering from the Federal University of Ouro Petro, Brazil; and a PhD degree in petroleum engineering from the University of Tulsa. He has authored or coauthored several papers on drilling and subsea technology. Saliés served several terms on the SPE Board of Directors for the Brazil Section and serves on the JPT Editorial Committee.
Exciting operations are ongoing on the shallow-water US offshore continen- tal shelf (OCS) that will influence the entire high-pressure/high-temperature (HP/HT) community going forward. McMoran and their operating partners are actively drill- ing, evaluating, testing, and bringing to production several deep HP/HT plays. These prospects are named in the Treasure Island theme with identities such as Davy Jones, Blackbeard, and Lafitte. The Davy Jones 1 is in the completion phase, incorporating multiple Eocene Wilcox sands, and it represents the first 25,000-psi completion of its kind in the world. The Davy Jones 2 encountered confirmed pay and is progressing well. The original Blackbeard well was taken to 32,997-ft total depth, and operations on Blackbeard East have been permitted to 34,000 ft. As with Davy Jones, these wells represent substantial extensions to or step changes in current HP/HT technologies.
To address the substantial engineering challenges associated with these wells, the operator formed a significant project team and is drawing on the expertise of several vendors in a collaborative manner to make the many advances necessary in HP/HT drilling and completion procedures and in production equipment and proce- dures. Downhole tools have been upgraded to 30,000 psi and 500°F. It will take con- siderable effort to catalog all of the “industry firsts” and “Serial-Number 1s” associat- ed with these ongoing operations. Both Davy Jones wells are expected to be flow tested and put on production later this year.
HP/HT continues to be of international interest, with global operations ongoing from the North Sea, to Latin America, to the Middle East, and of course in the “ring- of-fire” regions in Southeast Asia. Operators, service companies, equipment suppli- ers, drilling contractors, and other involved parties share a common goal of address- ing the many HP/HT challenges successfully and in a safe and efficient manner. These goals create a need to exchange information effectively, openly share lessons learned, and embrace a collaborative spirit that respects the competitive nature of business while valuing the shared interest that we all have in safe and reliable operations. Thus, the industry looks forward to learning more from the success of these HP/HT step changes in the US OCS ventures and from advances in other HP/HT operations around the globe.
Read the paper synopses in the April 2012 issue of JPT.
Mike Payne, SPE, is a Senior Advisor in BP’s Exploration and Production Technology group. He has 29 years’ experience including drilling operations, computing technology, and consulting. Payne holds BS and PhD degrees in mechanical engineering from Rice University, an MS degree in petroleum engineering from the University of Houston, and an Executive Business Education degree from the University of Chicago. He has extensive industry publications and has held key leadership positions with the American Petroleum Institute and the International Organization for Standardization. Payne has been an SPE Distinguished Lecturer and received the SPE International Drilling Engineering Award in 2000. He has chaired or cochaired several SPE Advanced Technology Workshops and serves on the JPT Editorial Committee.