bluuebunny/crossref_metadata_2025_split huggingface dataset:
Management of Completion Systems Utilizing State-of-the-Art Technologies
Authors: Thompson Joseph E. , DeVine Carolyn S. , Garner J. Jay , Wood William D. , Eller J. Gary 
Published: December 2007

Abstract
Management of a robust completion approach, utilizing state-of-the-art technologies, has been successfully used to stimulate multiple pay tight gas sand intervals in an environmentally sensitive area near Kenai, Alaska. Management of several unique completion techniques has demonstrated exceptional effectiveness.
Previous stimulation attempts were not successful in developing the Beluga sand resource to an economic level; therefore, a comprehensive study of all processes by reservoir, drilling, completion, and service company engineers was initiated to determine the best techniques to improve recovery and financial delivery.
Engineering and laboratory studies were conducted to develop a complete understanding of the Beluga sandstone reservoir composition; mechanical and chemical properties were analyzed after which an extensive project was undertaken to develop a fit-for-purpose stimulation fluid. For the well completions, a novel Casing Conveyed Perforating System (CCPS), which has revolutionized multi-zone fracturing operations, was utilized. The CCPS facilitates pinpoint stimulation of multiple pay intervals in a relatively short period of time and also improves stimulation quality, hydrocarbon recovery and life-of-well economics.
Recycling of the hydrocarbon-based stimulation fluid provided an additional project enhancement. The recycling process provides a stimulation fluid with excellent rheological properties. Management of the fluid recycling process also reduces the total volume of base hydrocarbon transported and stored in environmentally sensitive areas like those in Alaska. Recycling also minimizes the equipment footprint and minimizes overall completion cost. Wells completed using these unique reservoir evaluations, CCPS, and stimulation fluid recycling techniques have been considered technical and economic successes.
Energy Sources and Energy Intensity for the Twenty-First Century
Authors: Economides M. J. , Demarchos A. S. , Saputelli L. 
Published: December 2007

Abstract
A country's wealth is closely related to its energy consumption. For example, the United States, the richest nation, with a per capita income of about $34,000 is also one of the highest consumers of energy with an annual per capita consumption of about 355 million British thermal units (MMBTU). Energy consumption is the most discernible national characteristic that separates rich from poor countries. The correlation between per capita energy consumption and per capita income among all nations is clear. However, the energy use in other developed countries is also a function of their geography, the makeup of those countries and even the cultural preferences of their citizens.
Throughout the last two centuries, energy consumption in the creation of wealth and the form of primary energy sources, have not been constant. The process has been dynamic and technology has played a considerable role in the changing of the status of many countries, most notably Japan. Efficiencies developed elsewhere are adopted by other countries and lead to an increase in wealth. Globalization of the economy will certainly aid this process in the future.
Energy consumption and heightened demand worldwide may prove perhaps the most formidable international challenge of the twenty first century. It must be emphasized, though, that political events such as the September 11, 2001 terrorist attacks and associated implications may have considerable impact, affecting both the sources of energy and the type of energy. We have not attempted to predict these effects in this paper. As early as 2010, at current energy growth, chronic energy shortages are likely to emerge which may evolve into a serious energy crunch. The most logical way to prevent this situation is to transition rapidly to natural gas and, eventually, to hydrogen.
In this paper, natural gas is viewed as the compelling next fuel of choice and as the necessary stepping-stone towards hydrogen. Also offered here are production, consumption and transition forecasts.
Successful Integration of Sparsely Distributed Core and Welltest Derived Permeability Data in a Viable Model of a Giant Carbonate Reservoir
Authors: Al-Afaleg Nabeel I , Al-Garni Saad , Rahmeh BasemAhmed , Al-Towailib Asaad 
Published: December 2007

Abstract
This paper presents a successful integration of sparsely distributed permeability data including core-derived permeability and welltest-derived permeability into a viable geocellular model of 3.96 million cells for a giant carbonate reservoir. The resulting model required minimum permeability modification to achieve a 40-year history match. Fracture intensity trend was derived by carefully comparing the curvature of the structure, detailed matrix permeability, and welltest-derived permeability. This approach, although intuitive, allows for a better and realistic characterization of this large reservoir in the absence of seismic and other fracture identification tools like image logs while preserving vertical and lateral variation in permeability. Moreover, the paper presents statistical analysis of core-derived permeability illustrating lateral variation of permeability distribution.
New Resin Technology Improves Proppant Flowback Control in HP/HT Environments
Authors: Anderson Robert W. , Johnson Daryl E. , Diep Tom 
Published: December 2007

Abstract
This paper will focus on a new resin technology that improves proppant flowback control under extreme conditions. The combination of dual phase flow and pressure drops in high rate gas wells has made proppant flowback a significant problem. These conditions must be addressed to maximize well productivity and minimize production costs. Moreover, the problems associated with cyclic stress effects can further hamper well production and tax any technology controlling proppant flowback. The most commonly applied proppant flowback control technology is the use of curable resin coated proppant (CRCP) either entirely or as a tail-in for hydraulic fracturing treatments. CRCPs have an established history in the consolidation of proppant packs under defined conditions of time, temperature, and closure stress.
Improvements in CRCP performance have been facilitated by use of a new resin system through chemical and process changes. These changes have enhanced resin bond strength (RBS) characteristics commonly measured as unconfined compressive strength (UCS). Data shows RBS is anything but the dominant trait in preventing proppant flowback. This is most evident when the proppant pack is subjected to a large pressure drop, Non-Darcy multi-phase flow, temperature, and cyclic stress. Further associated effects are prolonged pumping time and elevated temperature exposure during CRCP placement. The CRCP placed under these conditions is subjected to elevated temperatures while the proppant is transported into the fracture and before fracture closure. CRCP performance testing in the laboratory can accurately depict these effects.
A new resin technology is presented that is specifically designed to withstand the aforementioned conditions. The performance benefits are documented by rigorous laboratory testing (under simulated downhole conditions) and case history data from stimulation treatments performed on deep, high flow rate gas wells.
A Comparison of Interventionless Packer Setting Techniques and Enhanced Functionality Considerations
Authors: King James G. 
Published: December 2007

Abstract
Eliminating intervention during well completion reduces operating expense and risk. In deepwater, horizontal and extended-reach applications, interventionless actuation systems for setting completion tools are reducing well intervention and completion time and associated costs without compromising reliability or safety. This paper details the operation of three commercially successful technologies that permit interventionless actuation. This author outlines the selection process for determining the correct technology for a given application.
New C/O Methodology Applied for Reservoir Monitoring in Atypical Casing Completion and Complex Lithology: A Case Study
Authors: Padilha Solon Thomaz , Escobar Elena , Ramónez Miguel , Solórzano Efrén 
Published: December 2007

Abstract
Carbon Oxygen ratio (C/O) logging has been used in the oilfield for a long time as a solution to determine oil and water saturations independent of the formation water salinity. The traditional Sw computation methodologies rely on the use of the tool under standard and uniform completions, and are based either on a data base characterization or on deterministic models. These techniques fail when the casing size, along the logging interval, is variable, or when the tool characterization is not available for unusual casing sizes.
Uncertainties are also encountered in complex lithologies, particularly in the presence of carbonates, due to deposition or diagenesis. In this case, it becomes difficult to compute the correct carbon content of the rock to correct the final volume of oil estimated.
This paper describes a case study with a very atypical completion including downhole sensors as part of the casing, and the presence of a variable carbonate volume in the reservoir rock matrix. It is part of a project to define the evolution of a water flooding between two nearby wells, one the injector and the other the monitoring well. Here, a new computation methodology to calculate the volume of oil using the openhole computed Sw, as a reference, and different time lapse C/O logging passes to define the change in volume of oil in the reservoir during the water injection, is presented. This variation (ΔVuoi), applied to the openhole Sw, enables the computation of precise saturation results, where it is possible to observe the quantitative change in fluid volumes in depth over a period of approximately six months in spite of the nonstandard completion type and complex lithology.
Equipment Strategy Development for Down-hole Tubulars
Authors: Russ P. R. 
Published: December 2007

Abstract
A risk based inspection and equipment strategy program was developed for mature down-hole tubulars in Bass Strait oil and gas wells. This paper outlines the major features of the program including identifying components, describing degradation mechanisms, assigning a credible failure scenario, defining the probability and consequence of failure, development of strategies to mitigate "unacceptable" risk and finally assigning a mitigated risk.
The strategy development is applicable for caliper and proactive work-over candidate selection, work-over rig plans, reservoir depletion strategies, downhole corrosion management and platform life end plans.
A key feature of strategies is determining the probability and consequence of tubing failure. The consequence of failure determined in these reviews is based on financial criteria given that Safety, Health and Environment (SHE) risk is low due to completion design. The basis for obtaining these will be described. Corrosion rate and failure prediction are based on Bass Strait field data and are used in determining probability. Consequence is based on reservoir remaining reserves and when combined with probability is plotted on a risk matrix. A multi-functional team develops strategies to mitigate risks that are determined to be "unacceptable". Strategies include "do nothing", inhibition, patch tubing, coil tubing, work-over, proactive work-over, utilise corrosion resistant alloy, caliper and continue to monitor. The team measures success by determining the resultant mitigated risk.
The paper describes a process that enhances the tubing life cycle management process. Using this tool cost saving can be obtained through proactive preventative programs and utilisation of failure prediction to provide for improved planning and budget management.
Hydraulic Fracturing in a Deep, Naturally Fractured Volcanic Rock in Japan – Design Considerations and Execution Results
Authors: Weijers L. , Griffin L. G. , Sugiyama H. , Shimamoto T. , Takada S. , Chong K. K. , Terracina J. M. , McDaniel B. W. , Wright C. A. 
Published: December 2007

Abstract
In the summer of 2001, the first multi-stage completion in a deep, hot, and naturally fractured volcanic rock of the Minami-Nagaoka Field, Niigata Prefecture, Japan, was successfully completed using six propped fracture treatment stages.
Successful proppant placement in the northern part of the Minami-Nagaoka Field in Japan has proved to be extremely difficult in the past1-2. During two propped fracture treatments pumped more than a decade ago, treatments failed miserably with only about 20% of the designed proppant placed before job termination due to premature screen-outs. Post-frac evaluation showed extremely high levels of net pressure of order 4000 psi prior to pumping any proppant – indicating that proppant placement problems were mainly occurred due to simultaneous propagation of very narrow multiple hydraulic fractures. Detailed pressure build-up tests and production data analysis confirmed the diagnosis of narrow multiple hydraulic fractures, which resulted in extremely poor propped fracture conductivity and non-economic gas production.
As successful development of the northern part of the Minami-Nagaoka reservoir could significantly impact Japan's domestic natural gas production, another attempt at propped fracture stimulation was justified. In the summer of 2001, the first multi-stage completion in a deep, hot, and naturally fractured volcanic rock of the Minami-Nagaoka Field was successfully completed using six propped fracture treatment stages. The new treatments in Minami-Nagaoka focused on the ability to mitigate the adverse effects of multiple hydraulic fracture propagation and the accompanying severe near-wellbore fracture tortuosity. A major equipment mobilization was required for this treatment to be possible as part of this concerted effort. Many unconventional changes, including completion changes to obtain highest possible injection rates to enhance proppant placement, aggressive proppant slug strategy, extensive fluid testing, real-time fracture treatment analysis, careful perforation placement, quality control, extreme overbalance perforating, and use of small-grained proppant, resulted in successful stimulation and favorable production response. This paper discusses all these design changes in detail, and provides final results regarding the fracture geometries obtained and post-fracture production response.
Guntong – Key Challenges and Issues in the Management of a Large Complex Oil Field
Authors: Wan-Mohamad Wan-Nawawi , Coyne Patrick L. , Hinton Paul V. , Razalli Razmahwata M. 
Published: December 2007

Abstract
The Guntong field is currently the largest waterflood field and a major oil producer in Peninsula Malaysia. The field and its development are highly complex, resulting in various challenges in the areas of reservoir description, reservoir management, and facilities optimization.
This paper showcases key challenges and the evolution of the field depletion plan as the complexities were identified and better defined. Based on actual performance, and updated geoscience and reservoir engineering studies, various changes to the original depletion plan are being implemented even after 17 years of production. The changes range from a revision in waterflood operating pressure strategy, to innovative facilities optimization, and the more expensive workovers and infill drilling,. Effective teamwork by multi disciplinary team members also played a major role in transforming the challenges into opportunities. The implemented changes to-date have successfully increased production and reserves.
Practical Experiences of Improvement Oil Recovery for Weizhou 11-4 Bottom Water Oilfield in South China Sea
Authors: Hongyin Zheng , Pengxiao Sun 
Published: December 2007

Abstract
The Weizhou 11-4 oilfield is located in the North Gulf Basin of South China Sea. This oilfield is the massive sandstone reservoir of marine sedimental formation with strong bottom water drive. Its structure is a simple and complete drape anticline without faults. The reservoir geological properties are fairly good. The average porosity is 22%, and the average permeability is 945md. The thickness of sand body is from 30m to 50m. There is a stable distribution of the tight sandstone layer to be developed just above the oil-water contact in the entire oil-bearing area.
During the oil producing period, the operator had emphasized on the combination research of fine reservoir description and reservoir simulation. So the production performance of the oilfield was improved significantly. The original oil in place (OOIP) has been greatly increased from ODP's 1817×104 m3 to updated 2550×104 m3 by the integrated reservoir characterization. The incremental OOIP is about 733×104 m3. By the end of 2001, the cumulative oil production is up to 824.47×104 m3 of which it is about 32.3% OOIP and water-cut is about 71.1%. According to the results newly forecasted, the ultimate cumulative oil production can be up to 1096×104 m3. The 725×104 m3 of incremental oil recoverable reserves has been enhanced than ODP's 371×104 m3, and its oil recovery factor has been improved from ODP's 20.4% OOIP to more than 42.98% OOIP.
Based on more than eight years producing experience of this oilfield, although it is marginal originally, great development effects and economic benefits have been achieved by using effective stimulation measures, such as drilling multilateral or single horizontal sidetrack wells, drilling additional wells, enlarging draw down pressure, enhancing the liquid production rate especially in the middle water cut period. All these stimulation measures have effectively increased the sweep efficiency, extended the period of production plateau, ensured the average yearly oil production to be more than 4% OOIP lasting out eight years, and also improved the oil recovery. This paper, from the point of view of oil field development and reservoir management, presents the main development strategy and technical experience of this oilfield based on its general situation, geological characteristics and production performance.
Advance on the Tracer Test Technology among Wells
Authors: Ji Bingyu , Sui Xinguang , Wang Qinglin , Li Qun , Anjian Liu , Liu Tongjing 
Published: December 2007

Abstract
The development of the tracer test technology among wells in oil fields has been reviewed in this paper. Both advantages and weakness about the tracer test among wells from the first generation to the fourth generation have been briefly analyzed, meanwhile, a more systematic technology, i.e. comprehensive static and dynamic analyses method has been raised here. The authors proposed that the fourth generation technology with professional interpretation and comprehensive analysis had more advantage. This technology applied in the reservoir development of water drive, steam soak and immiscible displacement has been shown and discussed. Meanwhile, the evaluation on several relevant methods that have been widely used in China has been briefly discussed here. In conclusion, the tracer test technology among wells should be a mature and advanced method during the oil field development at the present age, it should have a widely and excellent prospect of application.
Comparison of Displacement Oil Mechanism of Polymer, ASP and Foam of ASP in Micro Pores and Dead Ends of Pores
Authors: Liu Zhongchun , Yue Xiang'an , Hou Jirui , Zhang Lijuan 
Published: December 2007

Abstract
The polymer flood technology has been applied in large-scale scope in Daqing oil field for about ten years. The area of the pilot projects of ASP flood is enlarging too. The foam of ASP flood, as a new technology based on ASP flood, has been presented. Since the technology centralizes two sides of advantages of ASP flood and general foam flood, its oil recovery is more than the others. Though the area of the pilot project of foam of ASP flood in Daqing oil field isn't very large, the oil recovery of 65% is gotten now. The better perspective of this technology's application has been shown in the pilot project.
Even though these EOR technologies have been successful in pilot tests, the argument about the effect of polymer solution on unit displacement efficiency has existed till now, and the displacement mechanism of ASP flood in heterogeneous formation should be realized again. The foam of ASP flood is a new method to enhance oil recovery. So the results of this paper have an important meaning for their application.
For revealing more clearly the displacement oil mechanism of three technologies, the displacement oil process of polymer, ASP and foam of ASP in micro pores and dead ends of pores have been studied by using microphysical simulation. Moreover, the analysis of dynamic and static forces required to remove a discontinuous oil in micro pores has been implemented by using the points of views of chemistry and Physics of interfaces.
New Development in Water Cut Meter with Salinity Compensation
Authors: Busaidi Khamis , Bhaskaran Haridas , Chen Jige 
Published: December 2007

Abstract
Salinity variation partly causes the inaccuracy of water cut measurement that leads failure to optimize wells production within the capacity constrains of production facilities. In this paper, salinity compensation method is introduced using Gamma-ray absorption technology, as well as Haimo FM2000SC Water Cut meter, which have the built-in Gamma-Ray salinity compensation capability. Test has been conducted on Haimo FM2000SC to determine salinity contents. The compensation is realized by analysis the received radiation count with the different saline water, and obtaining the coefficient value between these two factors. Testing shows that Haimo water cut meter can achieve accuracy of water cut measurement ± 2.0% absolute with 85% confidence factor.
Advances in Surface Measurements for Optimization of Artificial Lift Operations
Authors: Podio A. L. , McCoy J. N. , Rowlan O. Lynn , Becker Dieter 
Published: December 2007

Abstract
Acoustic liquid level tests are performed successfully in many different applications throughout the world. Advanced techniques for acoustic liquid level analysis are required for wells where unusual conditions exist such as very shallow liquid levels, annular partial obstructions, flush pipe, short tubing joints, etc. Some wells have liners, upper perforations, paraffin, odd length of tubing joints, poor surface connections and other conditions which result in an acoustic trace that may be very difficult to interpret. Normally, the computer software locates the liquid level and automatically processes collar reflections to accurately count almost all of the collars from the initial blast to the liquid level. This automatic analysis will determine the liquid level depth for 95% of the wells. However, some wells have conditions or anomalies that these procedures will not function as desired. This paper describes special advanced techniques that can be used to determine the liquid level in wells with these unusual conditions.