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.
In the 2 years since the Macondo incident, we have seen a lot of action toward new regulations, procedures, and norms to be implemented in an attempt to reduce the risks of those tragic events happening again. But the industry did not stop working; wells were drilled and completed, even in the Gulf of Mexico after the long period of inactivity. As expected, we saw a big focus on subsea-equipment testing and procedures and on needed equipment improvements. But we also saw many reports highlighting improved operational performance, confirming that the industry continues with significant activity.
We should work proactively with the public and regulators to bring a framework that will lead to a safer environment for everyone. And we should not be happy with just more paperwork that may not bring needed effective improvement. For obvious reasons, the first step has been focused on the equipment responsible for providing the last barrier of protection, the blowout preventer (BOP). One paper describes BOP upgrades, and another one discusses software-based deepwater-BOP testing. We all must recognize that there has not been a significant advance in terms of BOP testing in
the last 30 years. We are still relying, most of the time, on the old paper disks to record tests and on forms filled in by hand to confirm the pressure and duration of the tests prepared on each component tested. We should do much better than that.
The third paper highlights the drilling campaign in a promising offshore area in Brazil. But do not forget the underground blowout that leaked oil into the ocean offshore Brazil a few months ago, reminding us that continuous improvement of all offshore operations must take place. The alternative is that we again will face setbacks like those in the Gulf of Mexico after the Macondo accident.
Read the paper synopses in the April 2012 issue of JPT.
Helio Santos, SPE, is President of Safekick Limited. In his 29 years in the industry, Santos worked as a Drilling Engineer for Petrobras both onshore and offshore and led several projects in the Research and Development Center. He also was with Impact Engineering Solutions as Vice-President of Technology, President of Impact Solutions Group, and President of Secure Drilling, which was acquired by Weatherford. Santos earned BS and MS degrees in civil engineering from Catholic University of Rio de Janeiro and a PhD degree in geological engineering from the University of Oklahoma. He has authored several SPE papers, holds two patents, has served on SPE conference and Advanced Technology Workshop committees, and serves on the JPT Editorial Committee.
See the entire March 2012 issue.
See the current issue at http://www.spe.org/go/spedc.
Hydraulic Fracturing: 2012 and Beyond
It is a good time to be in the oil industry. The rig count, drilling activity, and oil prices are high, and shale plays are a significant reason for each. And, because it is shale, it is an especially good time to be a completion engineer!
Even though we have been able to make these unconventional reservoirs economic by drilling horizontal wells and by multistage fracturing, it is important for us to realize (especially with low gas prices) that there is still plenty to learn about shale fracing (not spelled “fracking”). Buzz words fly around the industry: complex fractures, brittle vs. ductile shale, proppant transport in slickwater, and more. Each is a start, but what I challenge everyone to do is to ask the questions: What is really happening when we are fracturing the various shale plays; and how do we model it so that
we can predict and optimize performance?
Economic and political implications of shale are enormous. The USA recently, for the first time in many years, became a net exporter of energy. The USA has clear shale development advantages compared with other countries at this time because it has the rigs, hydraulic horsepower, personnel, and a long history of hydraulic fracturing.
But truth be told, there are disadvantages that must be dealt with. The USA is dealing with an oversupply of gas, which is reducing prices and making shale-gas plays marginally economical. To date, despite industry efforts, there still is no political will to substitute fuel sources on a large scale, create a widespread gas-fueling infrastructure, or increase automobile shale-gas usage appreciably.
So even though it is a good time to be in the oil field, remember that as completion engineers it is our job/duty to understand what is happening downhole when we are fracturing—Do we really have complexity? Does complexity occur in every shale interval or just the brittle ones? Does proppant “turn the corner” and go into the natural fractures? Knowing the answers to these and other questions can make the economics of shale plays become even better.
Read the paper synopses in the March 2012 issue of JPT.
Karen Olson, SPE, is the Completion Expert for Southwestern Energy. She has worked in the oil industry for 28 years, including positions with the Western Company of North America; Mobil E&P, working in west Texas, the Gulf of Mexico, and Norway; and most recently with BP as a Deepwater Completion Engineering Team Leader. Olson has written and presented many SPE papers and has been a discussion leader at SPE workshops and forums. She has served on several SPE committees and serves on the JPT Editorial Committee. Olson earned a BS degree in petroleum engineering from Louisiana State University and an MS degree in petroleum engineering from Texas A&M University.
Since the first downhole electric measurement was made in 1927 by the Schlumberger brothers (first electrical-resistivity well log), the oil/gas industry has been striving to develop and improve new tools and sensors for downhole measurements. Indeed, these sensors aim at measuring many parameters, such as physical properties of rocks and fluids (formation evaluation), wellbore position (inclination and azimuth), or downhole drilling-mechanics conditions. Over the last 12 months, I have been impressed by the number of papers and news articles dealing with drilling mechanics and with vibration-data measurement, transmission, processing, and interpretation. Dynamics and vibration events still are responsible for high nonproductive time (NPT) (e.g., tool failures in many cases) and suboptimal drilling performances. With advances in electronics components, tool reliability, battery technology, and sensors, many companies have begun to develop their own memory-based drilling-measurement tools and to offer the associated service (data processing and interpretation) to operators to maximize drilling efficiency and, thus, reduce NPT.
These downhole drilling-mechanics-measurement tools, rated up to 150°C, generally integrate the following sensors: bending moment, vibration (three-axis accelerometers), weight on bit, torque on bit, annular pressure, temperature, and magnetometers (downhole rotational speed). Data are stored in a memory-based subassembly powered by a lithium-based battery (capacity up to 200 hours), or are transmitted to the surface (by use of mud-pulse, electromagnetic, or wired-pipe telemetry). The latest developments include ingenious sensors placed in the pin of the drill bit (avoiding an extra subassembly in the bottomhole assembly). Though measurements originally were captured close to the bit in the bottom portion of the drillstring, the industry has identified the need to have multiple sensors deployed all along the string (from the bit to the topdrive) to monitor continuously and anticipate any drilling event.
This outbreak of downhole-sensor technology is good news for the industry because it will probably accelerate the understanding of what is happening downhole even more, thus improving the overall drilling efficiency. Downhole drilling measurements should not be limited to only high-cost environments, but should be used in the early stage of the field development to accelerate the learning curve and, thus, optimize the drilling process for the next wells. Even though some downhole drilling and dynamics tools were developed in the 1980s, the industry now has more-accurate sensors, better physical models, and more computational power to process and analyze this huge amount of drilling data.
Read the synopses in the February 2012 issue of JPT.
Stéphane Menand, SPE, is Managing Director of DrillScan US. Previously, he held a research position at Mines ParisTech University. Menand has 14 years of experience as an R&D project manager in drilling engineering–more specifically in directional drilling, drillstring mechanics (torque, drag, and buckling), drilling dynamics, and drill-bit performance. He has authored several SPE and other technical papers and holds several patents. Menand earned a PhD degree in drilling engineering from Mines ParisTech University. He serves on the JPT Editorial Committee, the SPE Books Development Committee, and the SPE Drilling and Completions Advisory Committee.
Real-time data is not about well control, it is about well control avoidance. Recent catastrophic blowouts have underscored the value of real-time data and, more importantly, they have also underscored the value of having the right kind of experience to understand well data interpretation in real time.
What is the well telling us? How do we use real-time data to ensure a stable wellbore? Real-time monitoring integrated with rigorous total well control analysis is required to embrace and achieve continuous improvement and ensure the safest possible environment. Next generation monitoring requires a step change that includes hazards avoidance as a precursor to drilling optimization.
Real-time data can be used effectively to avoid, minimize, and better manage drilling and completion operations. They can also provide the foundational support to improve training in the industry as well as develop hands-on simulators for hazards avoidance.
Read the entire article in the January 2012 issue of JPT.