Revitalizing mature fields embraces multiple objectives, especially maximizing production while minimizing capital expense and reducing the inevitable decline rate and minimizing the operating expense. The collective approach to meet these objectives is application of practical and focused engineering and geology tied with the application of enabling technologies.
Key enabling technologies in the revitalization of mature fields include reservoir simulation, advanced characterization techniques (e.g., 3D seismic and new measurement, tomographic, and visualization techniques), permanent downhole reservoir monitoring, horizontal and multilateral drilling, geosteering, production-enhancement techniques (e.g., secondary- and tertiary-recovery schemes), improved perforation and stimulation methods, new fracturing techniques and fluids, cutting-edge completion technologies, advanced logging techniques, artificial-lift optimization, and conformance control.
Implementation of appropriate enabling technologies can extend the producing life of mature fields. Yet the complexity of some of these fields can still present formidable challenges. It takes the right data, the right tools and techniques, and the right team to create an efficient, cost-effective field-development plan to optimize an aging asset.
Read the paper synopses in the January 2012 issue of JPT.
Syed A. Ali, SPE, is a research advisor with Schlumberger. Previously he was a Chevron Fellow with Chevron Energy Technology Company. Ali received the 2006 SPE Production and Operations Award. He earned BS, MS, and PhD degrees. He served as the Executive Editor of SPE Production & Operations and currently serves on several SPE committees, including the JPT Editorial Committee and Well Completions Subcommittee.
In spite of continued investment and advances in exploiting alternative energy sources, oil and natural gas will continue to be a significant portion of US and global energy portfolios for decades. Enhanced oil recovery (EOR) uses unconventional hydrocarbon-recovery methods that target the approximately two-thirds of the oil volume remaining in reservoirs after conventional-recovery methods have been exhausted. Though limited by high capital and operating costs, EOR techniques will have a substantial effect on the future supply of oil.
In 2011, SPE hosted an EOR conference in Kuala Lumpur, and three workshops to address EOR technologies in Malaysia, Kuwait, and the Syrian Arab Republic. The Malaysia workshop focused on chemical-EOR methods, the Kuwait workshop addressed opportunities and for challenges of EOR methods in the Middle East, and the Syrian Arab Republic workshop discussed EOR in carbonate reservoirs. More than 300 EOR papers were published in SPE conferences, with many additional presentations in EOR workshops. These papers address important issues related to practical application of conventional EOR methods and the development of novel EOR technologies. The topics cover experience with, opportunities for, and challenges of EOR technologies; fundamental study of EOR mechanisms for different methods; feasibility study and improvement of an EOR method for a specific reservoir; EOR-screening criteria; reservoir surveillance, monitoring, and evaluation technologies; reservoir simulation and modeling; lessons learned from EOR pilot and field trials; and some novel EOR methods.
Polymer flooding has been proved the most cost-effective chemical-EOR method in the laboratory and in the field. A recent focus on polymer flooding evaluated associative polymers because of their advantage over traditional hydrolyzed polyacrylamide (HPAM) polymers; thus, one paper about comparing the flow behavior of associative polymer and HPAM in porous media was selected for this feature.
CO2 injection is a win/win strategy because it can enhance oil recovery and be used for CO2 storage in reservoirs to reduce greenhouse-gas levels in the atmosphere. However, CO2 EOR targets maximum oil recovery while CO2 sequestration targets maximum storage capacity without leakage. One paper featured here provides some guidance to balance the two technologies.
Steamflooding has been applied successfully in heavy-oil reservoirs. However, one paper synopsized in this feature will describe successful steamflooding in a lightoil reservoir.
EOR opportunities in the Middle East are also highlighted.
Read the paper synopses in the January 2012 issue of JPT.
Baojun Bai, SPE, is an associate professor of petroleum engineering at Missouri University of Science and Technology. Previously, he was a reservoir engineer and head of a conformance-control team for PetroChina. Bai holds PhD degrees in petroleum engineering and in petroleum geology. He serves on the JPT Editorial Committee and as a technical editor for SPE Journal and SPE Reservoir Evaluation & Engineering.
View the entire contents of the December 2011 issue.
Completion Design and Execution
151970-PA – Completing the First Big Bore Gas Wells in Lunskoye–a Case History
C. Zerbst, SPE, and J. Webers, SPE, Sakhalin Energy Investment Company Limited
134326-PA – Numerical Simulations of Sand-Screen Performance in Standalone Applications
Somnath Mondal, SPE, and Mukul M. Sharma, SPE, University of Texas at Austin; and Rajesh A. Chanpura, SPE, Mehmet Parlar, SPE, and Joseph A. Ayoub, SPE, Schlumberger
Drilling and Completion Fluids
140868-PA – Development of Water-Based Drilling Fluids Customized for Shale Reservoirs
J.P. Deville, B. Fritz, and M. Jarrett, Halliburton
135166-PA – Protecting the Reservoir With Surfactant Micellar Drill-In Fluids in Carbonate-Containing Formations
Tianping Huang, SPE, James B. Crews, SPE, and David E. Clark, SPE, Baker Hughes
141447-PA – Stabilizing Viscoelastic Surfactants in High-Density Brines
R. van Zanten, SPE, Halliburton
130579-PA – Laminar and Turbulent Friction Factors for Annular Flow of Drag-Reducing Polymer Solutions in Coiled-Tubing Operations
Chinenye C. Ogugbue, SPE, and Subhash N. Shah, SPE, Well Construction Technology Center, University of Oklahoma
Robin Beckwith, Staff Writer JPT/JPT Online
On 11 October 2011, the X Prize Foundation announced the winners of the USD 1.4 million Wendy Schmidt Oil Cleanup X CHALLENGE, launched during the summer of 2010 in the wake of the Deepwater Horizon oil spill disaster in the US Gulf of Mexico. According to a press release, “the competition inspired entrepreneurs, engineers, and scientists worldwide to develop innovative, rapidly deployable, and highly efficient methods of capturing crude oil from the ocean surface.” Emerging from an original field of more than 350 submissions from all over the world, Elastec/ American Marine of Carmi, Illinois, captured the USD 1 million first prize, with Norway’s NOFI Tromsø awarded the USD 300,000 second prize; no contestant’s cleanup system qualified to receive third prize.
Testing the 10 finalists’ technologies in order to determine the winner would have been impossible were it not for a facility called Ohmsett (Oil and Hazardous Materials Environmental Test Tank). What is Ohmsett, and why is it so critical to the development of oil spill prevention and mitigation technology?
Read the full article in the December 2011 issue of JPT
John Sheehan, JPT Contributing Editor
BP is ramping up its West of Shetland operations with the UK government approval to push ahead with the second phase of its giant Clair field development, Clair Ridge. Plans to redevelop the Schiehallion and Loyal fields with a new floating production, storage, and offloading vessel (FPSO) are also gathering pace.
The Clair reservoir is the largest known hydrocarbon resource on the UK Continental Shelf (UKCS), occupying an area of 220 sq km. It is located approximately 75 km west of the Shetland Isles in 459 ft of water. Because of its size and complexity, it is being developed in phases.
Clair Ridge, in UKCS Block 206/8, lies to the northeast of Clair Phase 1 and will be tapped with a pair of bridge-linked platforms–a drilling and production (DP) facilities platform and an accommodation and utilities (QU) platform. The new platforms have a 40-year design life and will require a total capital investment of about GBP 4.5 billion (USD 7.16 billion).
Read the entire article in the December 2011 issue of JPT.
International energy and climate organizations have found carbon capture and storage (CCS) to be a promising technology to resolve the squeeze between fast-growing global energy needs and global warming. Even environmental organizations say that making our energy use more efficient and building enough new renewable energy capacity takes too long. We need to get the CCS working to curb the growing greenhouse gas emissions if too large a climate change is to be avoided.
CCS consists of three major interdependent steps:
- Capture the carbon, CO2 out of flue gases, either from the stack of a power plant or the blast furnace top gas in iron making.
- Transport it by pipeline or ship it underground.
- Safely keep it in a storage site for thousands of years.
The technology for each of these steps has been used for decades in the industry, mostly in oil and gas. The important change is the scale–from about 100,000 to 1 million metric tons per year in the past. Today, we see the need for handling 10 million tons in each installation and for perhaps several thousand installations. The amount of CO2 produced from one power station varies from 2 million to 10 million tons; a modern iron-making blast furnace emits up to 10 million tons per year. The costs of the technologies for a large-scale CO2 handling chain are estimated to be split roughly 75%-10%-15% for capture-transport-storage.
Read the entire article in the December 2011 JPT.
Tore A. Torp is adviser for CO2 storage at Statoil, leading the storage part of Statoil’s research and development program (R&D) on CO2 capture and storage. He joined Statoil in 1984 from the steel industry. Between 1984 and 1996, he led large international R&D cooperation projects developing complex offshore field technologies. Since 1997, he has been project manager of Statoil CO2 storage R&D projects. He was vice chairman of the CSLF Technical Group, and was a lead author of the IPCC Special Report on Carbon Dioxide Capture and Storage. He received a PhD in material sciences from Norwegian University of Science and Technology.
The last decade has seen significant change in many areas of the drilling business, particularly with bits and bottomhole assemblies. Rising drilling costs, more-complex and -demanding drilling environments, and the ever-present stimulus of provider competition are continuing to drive improved understanding and decision making in this area. The days when bits were seen as simple commodities, with their leverage on well time and cost unrecognized, are fading. And this is long overdue.
Particularly encouraging is the growing use of field-behavior modeling of the bit and drillstring under realistic conditions, and the development of knowledge- based tool-selection techniques, refined by an intensive study of field data. The migration toward deeper or more-tortuous well designs, often accompanied by simultaneous drilling and hole opening in regions in which vibration effects are prolific and are more punishing, is leading to more understanding and rigor. These are admirable trends that more-traditional operations can and should capitalize on, and sometimes are.
My learned colleague Graham Mensa-Wilmot wrote of these trends a year ago in this feature, correctly pointing out to us that “We have the key, let’s open the door.” Perhaps we can claim to have done so with some challenges and in some geographical areas (e.g., vibration diagnosis and mitigation in deepwater Gulf of Mexico operations). However, with other equally important challenges (quantitative optimizing of the rate of penetration comes to mind), fundamental understanding and rigorous methods are not so widespread; we are still operating with “pockets of excellence.” So, it is appropriate to lay another challenge to those managing drilling operations and providing drilling services–if your teams are relying on a fuzzy definition of downhole processes or on trial and error to deliver drilling performance, it is time to modernize–let’s have the current pockets of excellence show the rest of us the way.
Read the paper synopses in the December 2011 issue of JPT.
Martyn Fear, SPE, is General Manager of Drilling & Completions for Husky Energy’s Atlantic Region, Canada. He has more than 25 years’ experience in drilling optimization and operations management across a wide variety of international locations. Fear serves on the JPT Editorial Committee. He earned a BSc (Honors) degree in geological sciences from the University of Birmingham, England.
Every year, SPE organizes more than 30 conferences worldwide. Critical issues of current interest to the oil industry are reflected in the SPE papers presented at these conferences. When selecting papers for this feature, I was not surprised that many papers deal with topics related to safety in facilities design and to asset integrity.
With recent publicized accidents and the industry’s continuing concern about its public image, operating companies are focusing on process safety and improving asset integrity, and are addressing these issues early in facilities design. Indeed, it can be argued that enhancing safety performance and dealing with the increased environmental risks remain the key challenges facing the industry today. Some concepts relevant to these topics are briefly outlined.
Asset integrity can be defined as the ability of the asset to perform its required function effectively and efficiently while managing health, safety, and the environment. In this context, asset integrity refers to hydrocarbon systems and includes support systems and infrastructure, such as platform structures.
Critical safety elements are those systems and equipment that prevent, control, or mitigate major accidents. They include elements such as pressure-relief valves, shutdown systems, fire- and gas-detection systems, and firefighting equipment.
Safety instrumented systems (SISs)—since its publication in 2003, the International Electrotechnical Commission (IEC) 61511 standard is becoming the basis for the specifications and implementation of SISs in the oil industry. Initially, the industry was relatively slow to adopt this standard. A dilemma facing operating companies is what to do about the existing shutdown safety systems that were installed before 2003 and that are not in compliance with IEC 61511.
Papers selected for this feature along with those recommended for additional reading highlight industry progress in these issues. I hope that they will be of interest to you.
Read the paper synopses in the December 2011 issue of JPT.
Hisham Saadawi, SPE, is Vice President (Engineering) for Abu Dhabi Company for Onshore Oil Operations (ADCO). He has more than 30 years’ experience in the design, construction, startup, and operation of oil- and gas-processing facilities. Saadawi’s current areas of interest include multiphase pumping, CO2 enhanced oil recovery, technical safety, as well as training and development. He is a recipient of the 2011 SPE Regional Projects, Facilities, and Construction Award. Saadawi is a 2010-2011 SPE Distinguished Lecturer and an SPE course instructor. He has served on several committees and subcommittees of SPE conferences and workshops, and he serves on the JPT Editorial Committee. Saadawi holds a PhD degree in mechanical engineering from the University of Manchester, UK, and is a Chartered Engineer in the UK.
As a member of the JPT Editorial Committee, I am privileged to review papers presented at SPE events during the last year in the area of Reserves and Asset Management. I am always impressed by the highly skilled, innovative members of our Society who address the constant change in our industry in these papers.
Recently, many of the reserves papers have focused on changes in reserves and resource estimation resulting from the introduction of the Petroleum Resource Management System (PRMS) and the US Securities and Exchange Commission’s (SEC’s) Modernized Rules. Last year, many of the papers dealt with theoretical aspects of reserves estimation in unconventional plays. This year, most of the papers dealt with unconventional reserves, focusing on integration of theoretical and practical aspects of the engineering principles used to estimate reserves and resources. Several papers went full circle to address how issues around PRMS or the SEC’s Modernized Rules affect reserves and resource estimation in unconventional resources.
There was a similar shift in asset-management papers. Prior years were weighted heavily toward theoretical-optimization approaches, primarily focused on surface facilities. This year, there were many excellent papers addressing the practical application of those principles in technically challenging, high-cost environments. Integration of surface and subsurface components to improve efficiency was another recurring theme.
The fact that I could select only a few of the many outstanding papers that I reviewed highlights the importance of attending the venues at which these papers are presented. The insight provided during the presentation’s opportunity to ask questions yields valuable information that cannot be obtained by reading the paper alone. I selected the papers for highlighting and those recommended for additional reading with a view to the needs and interests of the membership of our global society. I hope I found something that will benefit each of you.
Read the paper synopses in the December 2011 issue of JPT.
Delores Hinkle, SPE, is Director, Corporate Reserves, for Marathon Oil Company. She has worked for Marathon for 25 years and has 35 years of experience in the oil industry, including positions at Atlantic Richfield Company and Sun. Hinkle has served as Chairperson of the SPE Oil and Gas Reserves Committee and served on the 2010 SPE Hydrocarbon Economics and Evaluation Symposium Steering Committee and the 2009 SPE Annual Technical Conference and Exhibition Management Program Subcommittee. She serves on the JPT Editorial Committee and on the SPE Gulf Coast Section Scholarship Committee. Hinkle earned a BS degree in petroleum engineering from the Missouri University of Science and Technology and an MBA degree from the University of Alaska, Anchorage.
140937-PA – Review of Electrical-Submersible-Pump Surging Correlation and Models
Jose Gamboa and Mauricio Prado, The University of Tulsa
142764-PA – Assessing Gas Lift Capability To Support Asset Design
James W. Hall, SPE, and Mubarak A.M. Jaralla, Qatar Petroleum
144573-PA – World’s Deepest Through-Tubing Electrical Submersible Pumps
J.Y. Julian, SPE, BP; J.C. Patterson, SPE, ConocoPhillips; and B.E. Yingst, SPE, and W.R. Dinkins, SPE, Baker Hughes
140228-PA – Case History: Lessons Learned From Retrieval of Coiled Tubing Stuck by Massive Hydrate Plug When Well Testing in an Ultradeepwater Gas Well in Mexico
Victor Vallejo Arrieta, Aciel Olivares Torralba, Pablo Crespo Hernandez, and Eduardo Rafael Román García, PEMEX; and Claudio Tigre Maia and Michael Guajardo, Halliburton
134483-PA – New Perspective on Gas-Well Liquid Loading and Unloading
C.A.M. Veeken, SPE, NAM, and S.P.C. Belfroid, SPE, TNO