bluuebunny/crossref_metadata_2025_split huggingface dataset:
Konsas: An Exhaustive Reservoir Model to Evaluate the Contribution of Seismic to Reservoir Characterization
Authors: Andrieux Benoît , Fournier Frédérique , Cailly Frédéric 
Published: December 2007

Abstract
Konsas is a realistic 3D synthetic reservoir model constructed from a real data set . The geological environment of the actual reservoir is a mixed carbonate platform, with tidal to supra- tidal deposits of limestones, dolomites, anhydrite, and sandstones. The Konsas model corresponds to a particular realization of a geostatistical model based on the actual field data. The thickness of the reservoir interval is approximately 100m, with a geometry derived from markers and associated seismic horizons picked on the real seismic data. The reservoir is described in terms of lithofacies, and related porosities and acoustic impedances, with a gridding of 12.5m in the horizontal directions and 1m in the vertical direction, allowing to generate realistic fine-scale heterogeneities. The post-stack seismic image of the reservoir was generated with a 1D convolution, the seismic wavelet being derived from the real seismic data.
The Konsas model is used for better understanding the link between the reservoir properties and their seismic responses. In particular, standard techniques used in lithoseismic interpretation were applied to predict the average porosity variations at the reservoir level from the seismic variability. In this interpretation, only a few "wells" -vertical columns extracted from the 3D model- were used. The lithoseismic interpretation included statistical estimation techniques (linear regression and cokriging), and seismic facies analysis based on a pattern recognition approach. The seismic-derived porosity was compared with the exact porosity distribution for both approaches (statistical estimation and seismic facies analysis). It confirms that despite the limited number of wells, and the bandwidth restricted with respect to the reservoir heterogeneities, seismic data still provides valuable information in the interwell space. However, in this kind of seismic interpretation, some parameters are of crucial importance and should be carefully analyzed, such as the correlation trends. Moreover, Konsas has allowed to illustrate that the calibration population on which the statistical models are established should be representative of the whole reservoir as much as possible. The data should also be stationary as far as possible. For these two issues, the interpretation of the Konsas synthetic data set has shown how a seismic facies analysis could be used. The impact of the seismic attributes chosen to build the statistical model was also discussed, demonstrating the importance of testing the very low frequency component influence, when using attributes derived from the impedances.
The lithoseismic interpretation of the Konsas model has also demonstrated the strong convergence between the results of the estimation techniques and those from seismic facies analysis. It confirms the great interest of this last approach for lithoseismic interpretation, since it remains feasible and robust, even with a very limited number of wells.
An Integrated Approach to Basinwide Management Plans
Authors: Engler T. W. , Brister B. , Henke S. , Zent J. , Dembowski R. 
Published: December 2007

Abstract
The San Juan Basin of Northwest New Mexico is a significant contributor to the energy needs of the United States, accounting for 68% of the natural gas produced in the state (approximately 8% of the U.S. production) or 1.135 Tscf in 1999. The reliance on natural gas to meet future energy needs and the desire to manage these resources in a environmentally responsible manner, led to an integrated team of academia, industry and government to evaluate the Reasonable Foreseeable Development (RFD) in support of BLM's Resource Management Plan. The scope of this study encompasses the New Mexico portion of the San Juan Basin, beginning with an effective date of January 1, 2002, with a duration of 20 years.
Two approaches were used to predict the development potential. The first approach was a survey of operating companies in the San Juan Basin, obtaining their perspective of future development based on current reservoir management practices. The second approach applies engineering and geological techniques to optimize infill drilling in naturally fractured, low permeability gas reservoirs of the basin.
The results of this comprehensive study led to an estimate of 10,000 well locations on federally-managed land predicted as reasonably foreseeable over a 20-year duration. Associated with the well development will be the need for additional surface facilities to efficiently recover the gas and transport it to market. As a result of anticipated expansion of the takeaway capacity out of the basin through enhancement of old pipelines and construction of new pipelines, additional gas gathering systems and central compression will be necessary. Furthermore, an important finding of this work was the significant reduction in the number of wells needed to efficiently drain the multiple reservoirs present through opportunities for commingling and dual completions; consequently reducing the surface impact of additional wells.
Stability of an Openhole Completed in a Limestone Reservoir with and Without Acid Treatments
Authors: Morita Nobuo , Doi Tomoki , Kinoshita Takanori 
Published: December 2007

Abstract
Since a borehole in a limestone formation is more stable than expected, an openhole completion without a slotted/perforated liner has become popular recently. However, the following three items are not clear: (1) Why a borehole in a limestone formation is so stable?; (2) A borehole in a limestone formation can be completed without a liner regardless to the formation strength?; and (3) How about the stability after acid treatments? To answer these questions, two types of laboratory experiments are conducted. One of them is a series of borehole stability experiments using 1.5 and 2.36–2.39 inches diameter borehole in a 10.5×10.5×17.5 inches limestone blocks with polyaxial confining pressures simulating a horizontal well with three different principal in-situ stresses. Two types of limestones are used with and without borehole acid treatments and two borehole sizes are used to check the size effect. Another type of experiments are acid squeezing experiments where 15% Hcl acid solution is squeezed from one end of a cylindrical core and the change of porosity, permeability, and hardness are measured throughout the cores. The results showed that (1) boreholes in a limestone induce a shear failure at the borehole surface after a pore collapse is induced. Note that boreholes in other stones normally collapse with a shear failure before a pore collapse is induced within the depth where hydrocarbon reservoirs are discovered. Because of the highly ductile shear failure after a pore collapse, a horizontal well is stable even though the ratio of effective horizontal stress and vertical effective stress is high. (2) The reaction rate between Hcl acid and limestone is so high that most acid reaction occurs within 0.2 inches from the borehole surface. The surface layer of acid treated borehole becomes malleable due to porosity increase, resulting in protecting formation acting as a soft liner. On the other hand, the borehole surface becomes irregular and enlarged. Because the above two factors compensate each other after acid treatment, the boreholes remain reasonably stable although a small strength reduction is observed. (3) Normally, since limestones are relatively strong, openholes are likely stable, however, the strength must be checked if they need to be completed without a linear protection.
To help a reader applying the laboratory results to field problems, a guideline to complete an openhole without a liner protection in limestone reservoirs is provided with calculation results using a non-linear finite element model.
A New Technology for Resistivity Anisotropy Evaluation in Conductive Borehole Environments
Authors: Frenkel Michael A. , Geldmacher Ingo M. 
Published: December 2007

Abstract
The drilling industry is turning from the use of oil-based mud to environmentally sensitive water-based mud systems. However, highly conductive water-based mud tends to limit the effective dynamic range of induction instruments, such as the multi-component induction well logging tool (3DEXSM).
To illustrate the influence of the conductive borehole and invasion on the 3DEX logs, we performed theoretical simulations for a simple 2-D formation model.
To expand the operational range of the 3DEX technology in a water-based mud environment, we propose logging the 3DEX tool in combination with galvanic tools (Dual Laterolog, DLL and Micro Laterolog, MLL, or array lateral log, HDLL, and MLL) and apply the following sequential data interpretation procedure: Determine the formation resistivity structure of the near wellbore environment and the horizontal resistivity of the uncontaminated zone using the galvanic measurements,Determine the vertical resistivity and formation resistivity anisotropy of the uncontaminated zone using the results of the previous step and the deep 3DEX measurements.
Evaluation of this technology on a series of synthetic models allows us to outline the expanded 3DEX operational environment. The presented field example validates the technology.
The conclusion is that the combination of galvanic and induction measurements along with an inversion-based data interpretation method can effectively extend the dynamic range of the 3DEX technology, allowing the use of this technology in wells drilled with conductive water-based mud systems.
Well-site Resistivity Anisotropy Interpretation: A 2-D Method and a Case Study from the Gulf of Mexico
Authors: Frenkel Michael A. 
Published: December 2007

Abstract
A novel rapid inversion method has proved to be one of the fastest methods designed for accurate, multi-dimensional interpretation of array resistivity logs. In this paper, we discuss the development of this method as a basis for future well-site anisotropy interpretation, using data recorded with the 3D ExplorerSM multi-component induction instrument (3DEXSM).
The new method demonstrates the feasibility for a substantial reduction of computing time by partitioning the two-dimensional (2-D) inverse problem into a sequence of smaller one-dimensional (1-D) problems (radial inversion). It rapidly converges to a true earth model. In the case of a vertical well (2-D), the method requires multiple 1-D, yet only a few 2-D forward model calculations. To achieve this substantial extra increase in computing speed, 1-D forward responses are pre-calculated and stored as look-up tables to be consulted at inversion time. The computations required for a full 2-D interpretation process is thus reduced to a set of four to five 2-D forward response calculations at a limited number of observation points. As a result, the proposed method allows the entire spectrum of measurements to be combined as a part of an interpretation scheme suitable for well-site processing. The method is capable of providing a consistent and accurate picture of formation resistivity anisotropy.
The potential for the technique is presented and illustrated by anisotropy interpretation results from 3DEX data acquired in a vertical well in the Gulf of Mexico. These results are shown to be in excellent agreement with what is inferable directly from the raw 3DEX logs. They are also in good agreement with results from an independently performed anisotropy interpretation based on a rigorous 2-D inversion technique.
A field example confirms the capability of the proposed technique to deliver comparable quality results now achievable with standard log analysis center processing in run times comparable to run times for other familiar well-site deliverables.
Achieving 100 Percent Success in Acid Stimulation of Sandstone Reservoirs
Authors: Rae Phil , Di Lullo Gino 
Published: December 2007

Abstract
Acid stimulation of sandstone reservoirs is viewed by many as a risky enterprise and one that should be undertaken only as a last resort. Much of this reluctance stems from the complex, heterogeneous nature of sandstones(1) and the unpredictability of their response to conventional oilfield acid formulations. Indeed, with an inappropriate acid design, or poor job procedures, even the best candidate well can be damaged, sometimes irreversibly. With the loss of experience and expertise due to industry downsizing, there is some concern that the risk of such failures has increased.
This paper discusses the implementation of an acidising methodology with the goal of attaining 100 percent success in acid stimulation treatments. A cornerstone of the strategy involved the development of a personal acidising mentor for every engineer to help them avoid the pitfalls of inappropriate design. The only practical way to achieve this was by the use of computers, programmed with the many rules used by human experts in the design of acid treatments. These rules take into account such variables as mineralogy, temperature, formation fluids, permeability, porosity and tubular metallurgy, amongst others. Integration of these rules, based on an array of algorithms coupled with heuristic principles, outputs a preferred acid design along with recommended acid volumes, pre- and post-flushes, nitrogen ratios for flowback and a customized message board with hints, tips or warnings about the potential treatment. The design advisor also incorporates recommended loadings of corrosion inhibitors, iron control agents, clay control additives, surfactants, solvents, anti-sludges and diverting agents, etc. as and when required.
Application of this approach has helped fill the gap caused by the widespread loss of experienced industry personnel and has accelerated the learning process among younger engineers. It has also helped ensure that only appropriate acid treatments are recommended and pumped in any location, worldwide. The paper reviews the results of over 100 acid jobs designed using this methodology.
The Economics of CO2 Capture and Geological Storage
Authors: Nguyen D. N. , Allinson W. G. 
Published: December 2007

Abstract
Capturing CO2 from stationary sources such as power stations and petroleum processing plants and storing the CO2 into deep geological formations can potentially reduce greenhouse gas emissions in Australia. The cost of capturing CO2 could vary from below US$30 to above US$70 per tonne of CO2 avoided for coal-fired power stations typical of the stations used in Australia. In addition, storage costs can vary from below US$5 to above US$20 per tonne of CO2 avoided. These figures are based on capturing and storing pure CO2. Capturing other greenhouse gases in addition to CO2 might lower the unit costs of capture significantly. However, this needs to be balanced against the consequent increase in storage costs.
As regards capturing CO2 from petroleum extraction activities, the corporate income tax and Petroleum Resource Rent Tax ("PRRT") regime in Australia could potentially have large effects on the economics of CO2 capture and storage depending on the situation. If capture and storage attracted full income tax and PRRT relief, the after tax cost of CO2 capture and sequestration could be less than 50% of the before tax cost. However, such tax savings would be offset by benefits that might arise from any future carbon tax or carbon credit trading.
Environmental Responsibility: A Panacea for Operational Disturbances in Offshore West Africa
Authors: Ifebajo Adebayo J. , Ibizugbe Osaze 
Published: December 2007

Abstract
Reports from onshore E & P activities in Nigeria have shown that operating in the Niger Delta region poses some of the toughest challenges in the world. This region has witnessed a spate of attacks on oil and gas facilities, staff and contractors. Consequently, major oil and gas players have to contend with complex operational uncertainties due to increase pressure from the local communities for improved environmental control measures.
To effectively de-risk this region of this category of operational uncertainties, the industry must begin to see environmental performance as not only a measure of how well she can comply with existing environmental regulations, but also as a measure of how well she can pre-empt environmental pressures as well as maintain constant harmony with all concerned stakeholders and seeing herself as responsible to the environment with a view to improve performance.
In this project, we have been able to develop SMART* models based on continuous consultation, integrated management approach and continuous improvement attitude (CIA). With a good FOCUS* approach, this will help in safe and effective operations, pre-empt pressures, maintain harmony with local communities and effectively manage operational disturbances within complex environmental settings like the Nigerian Niger Delta area. Finally, we are of the opinion that every industry that seeks to remain efficient and relevant in this millennium should constantly be looking for ways of becoming more environmentally responsible -because no business can call itself efficient if it threatens the environment within which it operates.
• SMART is an acronym for Specific, Measurable, Achievable, Realistic and Time Bond.
• FOCUS is an acronym for Fair, Objective, Consistent, Unbiased and Succinct.
Eliminating Environmental Risks in Well Construction and Workover
Authors: Rae Phil , Di Lullo Gino , bte Ahmad Atikah 
Published: December 2007

AbstractWe are fortunate to live in a world where awareness of the detrimental effects of pollution is on the increase. Such awareness will help ensure protection of the biosphere and safeguard future generations. The oil and petrochemical industries, which have been responsible, to a large extent, for the development of the modern world and vast improvements in living standards in many places, are often targeted mercilessly by environmental activists. This is done without due regard to the criticality of oil both as a fuel and as the fundamental raw material for countless pharmaceuticals, dyes, plastics and consumer products.In general, despite press reports to the contrary, our industry has a fairly good pollution record, when compared to other major businesses. However, there is no room for complacency and it is important that we continue to be proactive in the implementation of strict environmental controls. Oil itself is usually perceived to be the biggest acute environmental threat, but, in addition, there are many well construction and workover operations that involve the use of chemical additives. Some of these materials are toxic and some may not biodegrade at acceptable rates. With an increasing awareness of the potential environmental impact of chemical additives, particularly in the marine environment, there is a continuing need to develop more efficient, less toxic alternatives.Thanks to intense efforts, many potentially harmful chemicals have already been removed from active service and replaced with new, field-proven and eco-friendly systems that have been tested in accordance with OSPARCOM guidelines, or their equivalents. Use of such materials offers benefits in terms of health and safety and, ultimately, potential cost reductions when disposal and waste handling charges are factored in.This paper reviews the development and field application of several novel materials for well completion and stimulation and suggests ways to improve or accelerate the implementation of environmental strategies.
Emulsion Treatment Utilizing Hot Produced Water
Authors: Razalli Ir. Razmahwata Mohd. , Sahat Marwan 
Published: December 2007

AbstractEmulsion treatment has always been a constant challenge in offshore crude production, even more so when the success of chemical treatments are critically dependant on process temperature. In the Guntong Complex operation, production from satellite platforms were cooled by sub-sea transit and made the emulsion processing of crude at the central processing platform(CPP) difficult. Emulsion is broken at the CPP using demulsifier chemical and the effectiveness is temperature dependant. Ineffectiveness of the demulsifier chemical coupled with constraints on BS&W (Basic Sediment & Water) and produced water discharge quality eventually created a production bottleneck as the satellite production water cut increased. Recognizing emulsion chemical treatment is still applicable but ineffective due to insufficient temperature, various heat addition options were evaluated while taking into account the set-up and limitations of existing facilities. The ‘hotwash’ concept, where the ‘hot’ central processing platform fluid is mixed with the incoming ‘cold’ satellite streams to raise processing temperature was implemented as it is also the most cost effective solution. As Guntong Complex is a matured field, the project has greatly increased the ability of CPP's facilities to sustain satellite production by implementing the ‘hotwash’ concept.
Integrated Reservoir Management in an Intelligent Well Environment
Authors: Martinez J. K. , Konopczynski M. R. 
Published: December 2007

Abstract
This paper describes the work process, data management, analysis tools, architecture and capabilities of integrated reservoir management in an intelligent well environment. An example of a "real-time," web-enabled intelligent-well reservoir management system is provided. The challenges associated with implementing the system are described, and benefits realized from its use are documented.
A current hurdle to realizing the economic potential of intelligent wells is the lack of integrated tools and work processes to manage the wealth of production data. The systems described in this paper are designed to overcome this hurdle. The systems are applicable not only to assets employing intelligent wells, but also to conventional assets or those with a mix of intelligent and conventional wells.
Technically, an Internet connection transmits "real-time" data from the wellsite to a central host. The latest in industry standards including communication, security, data warehousing, streaming protocols are utilized. Statistical, nodal analysis and predictive modeling techniques are provided and are continually enhanced in the webenvironment. These allow the petroleum professional to examine what-if scenarios to quantify the effect of changes in reservoir conditions or well geometry and to recommend optimum settings for enhanced recovery.