bluuebunny/crossref_metadata_2025_split huggingface dataset:
Discovery of a Major Coal Deposit in China with the Use of a Modified CSAMT Method
Authors: Xue Guoqiang , Yan Shu , Gelius L-J , Chen Weiying , Zhou Nannan , Li Hai 
Published: February 2015

Conventional use of the controlled-source audio-frequency magneto-telluric (CSAMT) method is based on calculating the apparent or Cagniard resistivity from the amplitude ratio of the horizontal electric and magnetic field components. However, direct comparison between these two components shows that the electric field is more sensitive to the underground medium resistivity than its magnetic counterpart. Thus, use of the electric component only should provide adequate information about the electric properties of the subsurface. The measurements typically belong to the far-field zone, but show a non-dipolar characteristic because of the source. In this paper, we therefore propose a simplified CSAMT technique based on measuring the electric field component only. As part of this new formulation, a related theoretical model for the electric field component accounting for the non-dipolar nature of the transmitter antenna is introduced. This is accompanied with a new apparent resistivity definition, including a procedure to transform it into pseudo-phase data, thus removing the static shifts.The potential of this modified CSAMT method is demonstrated using a field case from the Shanxi province in China. Until recently, it has been thought that no coal deposits exist in this region. However, application of the single-component CSAMT technique as advocated for here, revealed a major coal deposit, which was verified later by drilling.
Evaluation and Current Results of the Seismic Acoustic Impact Monitoring Assessment (SAIMA) System
Authors: Hutchenson Kevin D , Conner Ray B , Johnson Lars B , Bennett Hollis H , Simms Janet E , Yule Don E 
Published: February 2015

For the past several years, Quantum Technology Sciences (QTSI) and U.S. Army Engineering Research and Development Center (ERDC) have been developing a system to actively sustain present and future artillery ranges at zero unexploded ordnance (UXO) gains. With the Department of Defense (DoD) using over two million high-explosive (HE) munitions per year with a significant fraction as UXO, reducing costly range remediation and environmental restoration efforts will offer significant savings. The developed Seismic Acoustic Impact Monitoring Assessment (SAIMA) system is not designed for past ranges, but as a complementary technology to detect, locate within two meters, and classify UXO in near real-time to aid existing cleanup technologies. Feasibility and descriptions of system components have been previously provided ( VanDeMark et al., 2009 , 2010 , 2013 ). The current system is composed of multiple buried seismic arrays encircling a mortar or artillery impact area, communications from the arrays to a central processing station, and a processing unit that employs an algorithm suite based in the seismology and statistical analysis disciplines to detect, locate, and classify the HE or UXO impact. Recent deployments of the SAIMA system have demonstrated hardware maturity and algorithm refinements to nearly enable the goal of locations within two meters. A field deployment at Ft. Sill, Oklahoma, in June 2012 demonstrated acoustic locations at a large range ( QTSI, 2012 ). Subsequent systems tests with five arrays using a synthetic UXO source (kinetic source only; no acoustic phases) on a small field (80 m by 80 m) resolved locations within 0.5 m of ground truth with coverage ellipses at 0.1 m2 (time and azimuth). On a small mortar field, approximately 365 m by 480 m, simulated UXO (inert rounds) were located within an average mislocation distance of 4.1 m and confidence ellipses on the order of 5.8 m by 3.8 m. Scheduled field testing in the near future will validate the system.
Shared Vision: The SPE Forum Series - Wisdom at Work
Authors: Paccaloni Giovanni 
Published: February 2015

I remember that after I attended my fifth SPE Forum Series, as chairperson in 1993, I started considering the SPE mission statement. The part that talks about our mission to collect, disseminate and exchange technical information doesn’t completely define what SPE really does. When you get together 80 or so top experts from all over the world to discuss “frontiers of technology” on a given discipline, you don’t share only information—you share knowledge. As a result, at the end of a week of discussions, you leave the Forum with increased wisdom—i.e., with more chances to make the best decision from among several alternatives in your daily operations.
The following definition of “wisdom at work” applies very well to SPE Forums: “Wisdom at work is reflected in how successfully we learn, how consistently we can tap our deepest creative intelligence, and how effectively we develop the raw material of our inspiration into the insights, concepts, communications, and innovations that can be embodied and translated into action.”
The SPE Forum Series is one of SPE’s most effective programs in accomplishing the Society’s mission to provide a means for the exchange of technology. Forums provide an opportunity for technology leaders in the oil and gas industry to exchange ideas about what should or will be done in the future to accelerate development of technology. Each Forum Series event seeks to bring together the top technologists and managers working on a specific challenge the industry faces to discuss ideas and potential solutions—what are the issues, problems, and barriers, and how will the industry address them to provide future energy needs.
The objective of each Forum is to stimulate thought, accelerate innovation, and inspire the development of new technology. SPE Forums are for participants, not for spectators. Each Forum’s Steering Committee selects attendees on the basis of applicants’ ability to contribute ideas and insights gained from their own experience to the discussion. Attendance is limited to allow everyone an opportunity to have a say.
Discussion and interaction are the focus for all Forums. The physical setting and the technical agenda are both selected to create a climate for informal discussion. Dialogue on unpublished and incomplete results is encouraged, and an off-the-record format, where extensive note-taking and recording are prohibited, is strictly adhered to. Publication of Forum discussions is limited to a summary provided only to participants. Formal presentations are discouraged. Break-out sessions are often used to discuss a topic in smaller groups, which then report back to the full group. Breaks in the schedule allow casual opportunities for one-on-one exchange among participants.
Techbits (January 2005)
Authors: JPT staff _ 
Published: February 2015

The SPE Applied Technology Workshop on “High-CO2 Gasfield Development and Production” held in Hanoi, Vietnam, in September 2004 was attended by 79 participants from 11 countries. The keynote address, given by Joe Gregory, Gorgon Development Manager for ChevronTexaco Australia, highlighted the challenges of the Gorgon CO2 field, discovered 20 years ago.
The technical agenda included Characteristics of High-CO2 Gas Fields; Development, Production, and Monitoring Strategies; Surface Facilities and Removal Techniques; High-CO2 Pipelines and Disposal/Usage of Removed CO2; End-User Requirements; and Business Drivers. Emphasizing the importance of finding solutions to commercialization of high-CO2 gas fields in Vietnam and other countries, Nguyen Dang Lieu, Vice President of PetroVietnam, gave the opening address, and Lawrence Duhon of Unocal Thailand concluded the opening session by outlining participants’ expectations for the workshop.
Two breakout workshop sessions, a poster session, and general discussion completed the workshop. The 21-member Program Committee included Cochairpersons Nguyen Van Minh of PetroVietnam, Lawrence Duhon of Unocal Thailand, and Kanit Sangwongwanich of PTTEP. Committee members included Ahmad Hanif of Pertamina, Kemal Anbarci of ChevronTexaco Australia, Dale Coleman of ExxonMobil E&P Malaysia, Jeffrey Harris of Unocal Vietnam, He Jiangchuan of PetroChina, Huynh (Anthony) Bui of Chevron Offshore Thailand, Khairul Nizam Zaini of Petronas Carigali, Teddy Komaroedin of ConocoPhillips Indonesia, Christopher Lenn of Schlumberger UAE, Kamel Bennaceur of Schlumberger U.K., Nguyen Quynh Lam of Truong Son Joint Operating Co., Lincoln Patterson of CSIRO Petroleum, Phan Trung Nghia of PetroVietnam, Erik Puik of Shell Global Solutions, Hemanta Sarma of the U. of Adelaide, Suhardiman of Pertamina, Tam Thiam Guan of Shell E&P Intl., and Djebbar Tiab of the U. of Oklahoma.
Highlights captured during the workshop are summarized by session.
Rebirth of a Mature Carbonate Gas Pool
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper SPE 88773, "Rebirth of a Mature Carbonate Gas Pool," by K.C. Carr, SPE, and M. Fiori, BP Canada Energy Co., prepared for the 2004 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, UAE, 10-13 October.
Operation of a mature pool requires increasing cost control and infrastructure optimization and consolidation to maintain profitability. The decision to initiate this type of reservoir-management plan, sometimes described as “harvest,” is driven in part by reservoir-performance analysis and in part by commodity prices. The full-length paper presents the account of a 3.7-Tcf sour-gas pool in Alberta, Canada, and the technical impact of harvest on field operations, reservoir performance, and ultimate recovery. The combination of new production-decline analysis and a well workover with surprising results led to a complete change in reservoir interpretation.

Introduction
Management of mature pools is not a new challenge. In the Western Canadian basin, the surge of exploration and development activity in the 1950s and 1960s has left a legacy of very mature pools, with many of these 40- to 50-year-old pools still producing. Records show that of the 30,000 gas pools discovered in Alberta, 2,000 were discovered before 1970. In the aggregate, these pools represent 15 Tcf of remaining recoverable reserves. Each of these pools was at some point declared mature on the basis of the science of the day and treated as a harvest candidate (i.e., a pool with very limited upside where the best strategy is to control cost and produce what is left without further investment).
Overview: Mature Field Revitalization (January 2007)
Authors: Lagerlef David 
Published: February 2015

Every mature field has unique characteristics, and, often, several viable options for revitalization stand out. However, pursuing some options eliminates attempting alternatives. Once a decision is made to implement some revitalization options, it is very expensive, if not impossible, to change course and attempt alternatives that had been identified earlier in the evaluation process. The risk of high costs or pursuing the wrong alternatives must be minimized because, even at higher oil prices, many revitalization projects are marginally economic. Obtaining information specific to the mature field can contribute to reducing these risks. Simulations and pilot projects can use data effectively to narrow down options. Often, though, economic limits constrain how much actual data can be gathered. Thus, previous experience in revitalizing similar types of fields can be very leveraging for mature fields.
SPE membership provides access to archived SPE papers, which can be used to help identify and rank revitalization alternatives. The papers presented in this section are, in many ways, representative of all the papers presented in the last 12 months from which these four were selected. Literally thousands of other SPE papers have been presented over the last few years, providing useful details regarding the success and challenges of hundreds of revitalization techniques. The most recent technical papers include current details on the use of best available technology to revitalize mature fields around the world.
The technology behind revitalization techniques presented in papers more than a year old may be slightly out of date, but much can be learned by reviewing the approach taken to investigate potential solutions, the types of options considered, and the progression from ideas to realities presented in the papers. Just as petroleum-engineering tools advance over time, techniques for revitalizing mature fields improve as lessons are learned from past experiences. Incredible knowledge-sharing dividends are available to SPE members aware of previous work performed in mature fields similar to those fields that now need to be revitalized.
Mature Field Revitalization additional reading available at the SPE eLibrary: www.spe.org
SPE 100024 "Making Our Mature Fields Smarter—An Industry wide Position Paper From the 2005 SPE Forum" by R. Murray, SPE, BP plc, et al. [See JPT (August 2006) 49]
SPE 99948 "Integrated Multizone Low-Cost Intelligent Completion for Mature Fields" by H.L. da C.P. Pinto, Petrobras, et al.
SPE 102964 "The Origin and Resource Potential of Residual Oil Zones" by L.S. Melzer, Melzer Consulting, et al.
SPE 99706 "Enhancing Oil Production From Mature Fields by Focusing on Well-Intervention Management: North Oman" by A. Al-Bimani, SPE, Petroleum Development Oman, et al.
Q&A with Thamir Abbas Ghadhban
Authors: Ghadhban Thamir Abbas , Donnelly John 
Published: February 2015

Q&A
What is Iraq's current oil production and reserves?
Oil production in Iraq is currently about 2.25 million BOPD, with production capacity of 2.8 million BOPD. There has been a recent increase of some 300,000 BOPD because of the resumption of exports of oil in the north through Turkey after the government succeeded in securing the export pipeline. Exports are now about 1.85 million BOPD. Our production target for 2008 is 2.5 million BOPD. Iraq's oil reserves are between 112 and 115 billion bbl of proved reserves.
What is the current status of the hydrocarbons law, which you helped to draft?
Right now it is in Parliament, in the Council of Representatives. There has been a delay on this law for various reasons, some of which are administrative—the council was on holiday for a month in August, and there are other laws pending that require debate. But I expect discussion on the hydrocarbons law to begin soon.
What are the main objections to the law by its opponents?
There have been some differences between the federal government and the regional government of Kurdistan on some details, but they are not of a serious nature. It is not about ownership of the oil but about authority. The ownership question has been solved—oil and gas are the property of the whole nation of Iraq. There is some disagreement about the nature of contracts, particularly production sharing. But the main political parties in the government favor the law.
If the law passes, what role will there be for international oil companies (IOCs) in Iraq?
There is no doubt there will be a big role for IOCs because there is a recognition in Iraq that there is a great need for technology, managerial skills, and speedy development of oil and gas fields. There is agreement that IOCs will have a role. The disagreement is over what type of role or what form of contracts will be implemented.
I would expect that in the coming years, and especially next year, there will be room for IOCs to start taking an active role in oilfield development and exploration. The country's major resources are oil and gas, and the revenue from oil exports constitutes more than 90% of the federal budget. The government is aware that oil and gas development and expansion are priorities for the country, and for speedy development of production capacity and export capacity, the involvement of IOCs is essential.
Examining Marine Safety Operations
Authors: Strong Philip 
Published: February 2015

Management
Millions of crew transfers must be carried out around the world each year to keep the offshore industry going. Crew supply is one of the highest-risk activities in offshore operations, whether passengers are moved by helicopter or boat. Historically, risk management for marine-based crew supply has received little priority, and a lack of reliable information has generated misconceptions about the true risks and has masked breakthroughs. However, many operators are now attaching a high level of importance to all crew-supply activities. Exceptional progress has been made in the development of safer, more efficient alternatives, with operators, vessel owners, and transfer specialists all making important contributions.
Many operators are now looking more closely at their crew-supply options and are re-evaluating established methods. Choices are being influenced by a number of factors, such as cost, downtime risk, passenger comfort, journey times, and safety. A new generation of high-speed crew-supply vessels brings the prospect of fast, efficient, and safe vessel-based crew supply to the industry, which may place even greater focus on the evaluation of these operations.
For industry professionals to make appropriate choices and to drive safety improvements, they need a good appreciation of the risks. In vessel-based crew supply, the crane-transfer operation is widely accepted as the key safety concern. A scarcity of data both on activity levels and on incidents has made it difficult to develop a clear picture of safety performance. However, in the past few years, progress has been made. A major US operator and a major international vessel company have shared their personnel-transfer-incident data with Reflex Marine, and these incidents were added to an existing database gathered from public sites, including the US Minerals Management Service, the Petroleum Safety Authority in Norway, and the UK Health and Safety Executive, as well as from private reports.
It is estimated that more than 5 million crane transfers take place each year, a large-scale activity of an order comparable to the numbers moved by helicopter. The collated sample data include more than 60 crane-transfer incidents, resulting in 48 injuries and seven fatalities. Of those incidents, most of which occurred within the past 10 years, 32% involved lateral impact, 40% falling, 23% heavy landing, and 5% immersion. Although crane transfers are rightly regarded as a high-risk operation, it is important to view this in the wider context. The data indicate that the level of fatalities (per crew transfer) is lower than for helicopters, although injury rates are considerably higher.
Success of SAG-Foam Processes in Heterogeneous Reservoirs
Authors: Denney Dennis 
Published: February 2015

This article, written by Technology Editor Dennis Denney, contains highlights of paper SPE 110408, "Success of SAG-Foam Processes in Heterogeneous Reservoirs," by W.J. Renkema and W.R. Rossen, Delft University of Technology, prepared for the 2007 SPE Annual Technical Conference and Exhibition, Anaheim, California, 11–14 November.
In principle, miscible-gas injection can displace nearly all of the oil from the portions of a reservoir swept by gas. However, reservoir heterogeneity, low gas density, and high gas mobility reduce sweep efficiency and decrease recovery drastically. The use of foam can reduce gas mobility and the effect of heterogeneity, thereby increasing sweep efficiency. An optimal design strategy is proposed for surfactant-alternating-gas (SAG) -foam processes.

Introduction
Primary- and secondary-recovery methods leave behind up to two-thirds of the oil originally in place in the reservoir. Gas injection can increase the recovery from depleted reservoirs. Injected gas tends to rise to the top of the reservoir because of its low density, then over-ride the oil-rich zone, leading to early gas breakthrough. High mobility of the gas leads to viscous instability, which enhances gravity override and makes heterogeneity much worse by forming high-mobility flow paths.
The use of foam for mobility control, proposed in 1958, traps some bubbles and reduces movement of flowing gas, thereby reducing gas mobility. Trapped gas reduces gas relative permeability because foam films (lamellae) block some of the flow channels. In flowing bubbles, the effective gas viscosity is increased because pore walls and constrictions cause significant drag. Foam does not change the water relative permeability function or liquid viscosity.
Foam can be injected into the reservoir by coinjection of gas and water or by SAG injection (alternating slugs of surfactant solution and gas). For CO2-foam projects, the SAG process also reduces corrosion in surface facilities and pipe. In low-permeability porous media, the SAG process increases gas injectivity. When gas is injected, water is displaced from the near-well region farther into the reservoir, weakening foam near the well. As a result, gas mobility in the near-well region rises, and injectivity increases.

Foam Model
Existing models can be divided into local-steady-state models (ranging from simple to more-complex semimechanistic models) and dynamic "population-balance" models. Population-balance models take into account the rate of change of foam texture (i.e., bubble density), which depends on creation, destruction, and trapping of lamellae.
Local-steady-state models use an algebraic relation (which could be empirical or more physically based) between gas mobility and factors determining foam texture (e.g., surfactant concentration). All these models account for foam having no effect on the relative permeability function for water.