bluuebunny/crossref_metadata_2025_split huggingface dataset:
Why It's Difficult to Learn Lessons: Insights From Decision Theory and Cognitive Science
Authors: Duhon H. J. , Elias J. S. 
Published: December 2007

Abstract
Though engineers and managers routinely express the desire to learn from previous project experience, we typically do not learn effectively from our project experiences. The failure to learn valid and valuable lessons from project experiences can be attributed to a number of cognitive and social factors, which will be discussed below.
Fortunately, there is a great deal of literature in the fields of decision theory and cognitive science that is relevant to the subject. Unfortunately, much of this literature is unknown to most practicing engineers. This paper presents a structured method for identifying learning limits, an introduction to current thinking in areas of knowledge required to implement the method, a summary of the results of applying of the method, and suggestions for improving our ability to learn from project experiences.
Assessing the Past, Present, and Near Future of the Global Energy Market
Authors: Aguilera Roberto F. 
Published: December 2007

Abstract
A new global energy market (GEM) model is developed for examining the global market shares (i.e. the mix) of solids, liquids and gases. The model is successful in matching historical trends for 155 years - from 1850 to 2005 - for solids, liquids and gases. The model also provides a good match of the hydrogen to carbon ratio (which is a good proxy for environmental quality) from 1850 to 2003. Finally, the model matches well the liquid, solid and grid energy sold to consumers in the United Stated since 1900. In all the cases mentioned above, the GEM matches the historical data with coefficients of determination (R2) equal to 0.99.
Given these validations, the GEM is then used to forecast the global energy mix, global hydrogen to carbon ratio, and energy sold to consumers in the US until the year 2030.
Although the past is not always an indication of the future, the good matches observed for historical data lead to the conclusion that the GEM can be used cautiously for evaluating outcomes and opportunities for the near future.
Carbon Management—The Emerging Paradigm for the Oil Industry
Authors: Chakraborty Ashok B. 
Published: December 2007

Abstract
Globally there is concern on the rising concentration of CO2 as it is one of the six Green House Gases (GHG'S) considered responsible for Global warming. Scientifically concluded, the anthropogenic GHG'S are contributing to Global warming. The resultant effect is ‘Climate change’ which is now perceived to be one of the global risk factors, the business faces. The Quantification & Management of Climate related impacts on business, investments, reduction of risk / liability & pursuit of opportunities, is therefore necessary. Along with risk, Carbon emissions (CO2) as a financial commodity currently represent a rapidly growing international market worth over $10 billion. Therefore, it uniquely positions CO2 to leverage opportunities in the carbon emissions trading as well.
Oil & Gas industry is one of major sources for GHG emissions. The O&G activities involve burning, processing, flaring & transporting fossil fuels which emit CO2. It is therefore, imperative that O&G industry need adopt initiatives in mitigating GHG emissions, monitoring & control. The Carbon Management is the key to mitigating CO2 emission. There is an increasing trend amongst oil companies to adopt Carbon Management practices. The challenges include GHG estimation, to internalize externalities, future allocations, caps, low carbon development abatement technologies & the mitigation measures. Globally new developments include energy, fuel consumption & the emissions taxes. There are National control of emission inventories & the forecast, for national planning purposes.
In this paper, development of GHG inventory (& Prediction), GHG accounting system, GHG information system, climate protection policy, protocols, scientific assessments, sustainability reporting, purported benefits to stakeholders, Industry / business, new regulatory requirements , sustainability & economic development, climate change & carbon management opportunities available to the service providers, have been covered. Other issues associated with Climate change briefed are; Scientific complexity, Government policy, International debate and the Competitive pressure.
Carbon Management is going to be a reality in near future for oil companies and the Global trend is in vogue. It is beneficial to adopt proactive approach to be a Competitive, Effective & Credible Organization and realize first mover benefit besides fostering innovation & technology development and influencing global financial systems.
This paper deals with sharing of experience & addresses ‘tomorrow's actions today’.
A Technique for Improving the Accuracy of Wireline Depth Measurements
Authors: Fitzgerald Peter , Pedersen Bengt K. 
Published: December 2007

Abstract
Measurements made with wireline logs are often used as the reference for well depth. However, differences are usually noted between wireline depth ("Logger's Depth") and depth based on the drill pipe tally ("Driller's Depth") or the casing tally, frequently leading to the obvious question: "which one is correct?"
This paper discusses some reasons for these differences, and why the answer to the above question is usually "neither". The reasons why wireline depth may require some environmental corrections are discussed, and a technique for estimating these corrections is presented.
Whilst this may have relatively little impact when considering a single well in isolation, it becomes important when an attempt is made to correlate logs from one well to another, for example to produce field maps or to estimate fluid contacts. As the required depth corrections vary with many factors (for example, well geometry, toolstring weight and cable type used), logs from each well must be corrected independently in order to permit an accurate well to well correlation.
The technique presented is a finite element model that considers changing tension profiles (mostly due to non vertical well profiles, but also well fluid viscosity and changing cable speeds). The model also considers temperature effects on the cable length, which are not trivial. Pressure effects are difficult to evaluate for logging cables, but may also be taken into account if the required parameters are available.
Some examples of these corrections are shown, and the resulting reduction in absolute depth uncertainty is discussed. Finally, reservoir, economic, and operational implications of this work from the perspective of a field operator are presented, as well as recommendations for how to implement depth corrections.
Identifying and Filling Western Europe's Natural-Gas Storage Needs for the Next Decade
Authors: McLeod N. J. , Kelly R. T. 
Published: December 2007

Abstract
During the past 5 years, Western Europe and the U.K. in particular have undergone a sea change in terms of the number of gas storage projects that have been initiated or reached planning/consent stages. This has been largely in response to concerns over the security of gas supply in a market where indigenous gas production is declining at the same time as consumption is on the increase. In addition, EU directives will require member States to maintain a certain minimum volume of gas stocks in some, form of storage (to mitigate against supply interruption).
This paper reviews the outlook for gas storage across Western Europe, and in particular the U.K. which historically has been cushioned from such needs due to its supply of domestic gas from the North Sea. The paper considers the changes that might be expected to happen as indigenous gas is depleted and an ever increasing reliance is placed on imports from potentially less stable areas of the world.
Consideration is given to the drivers that apply to the identification of any gas storage project and in particular the conversion of a depleted natural gas field. Consistent and systematic screening criteria are used to identify the best storage candidates.
The status of the UK's current natural gas field portfolio is considered along with specific examples of fields that may make attractive propositions for conversion over the next 5 15 years. The technical and economic criteria that will play a key role in these decisions are listed and discussed.
Comparison is made between the UK and other countries on a global basis and discussion is included regarding the alternative uses of such depleted fields which may present a (competitive) alternative to the use of depleted fields for gas storage such as CO2 sequestration.
Microseismic Monitoring of a Restimulation Treatment to a Permian Basin San Andres Dolomite Horizontal Well
Authors: Quirein J. A. , Kessler C. , Trela J. M. , Zannoni S. , Cornish B. , Brewer R. J. , Gordy D. , Pettitt W. S. , Walker C. B. , Laney J. , Young R. P. 
Published: December 2007

Abstract
The results of a microseismic monitoring of a multi-stage refracturing treatment of a Permian Basin San Andres dolomite interval in an open-hole horizontal well will be presented in this paper. The treatment well has a horizontal well trajectory of approximately 3,000 feet within the reservoir section and had been extensively acid fractured during earlier production enhancement operations. The microseismic mapping objectives of the re-fracturing treatment for each of the stages were to characterize the azimuthal orientation of the fractures, the length of each wing, fracture height, and overall stimulation effectiveness.
The study discusses mapping microseismic events in a challenging re-fracturing environment. The microseismic activities generated during a re-fracturing treatment may be very low in acoustic energy and detection may be problematic, compared to the acoustic energy released during initial hydraulic fracture propagation. In this study, few microseismic events were detected, and this data indicates that the previously propagated fractures created preferential paths for fluid flow thus reducing the propagation of a new fracture network. In fact, for the stage located the furthest from the monitor well, no microseismic events were detected. This was consistent with an Instrument Magnitude Analysis performed on the located microseismic events from the other stages that showed events further than 1,400 feet away from the monitor well were not detectable.
A chemical packer was used for zonal isolation, and ball- activated sliding sleeves were used for selective injectivity for each stage along the horizontal well in the re-fracturing treatment. The operation of the sliding sleeves, for each stage and the ball drops, generated compressional and shear events which were detected by the geophone array in the monitor well. This confirmed that the instrumentation was able to detect events between the treatment well and monitor well in this job and that the microsesimic events induced during the re-stimulation treatment were at a much lower energy. The low-energy events that were located confirmed the ball- activated sleeve worked correctly and the induced fractures stayed in zone. However, the source locations detected did not delineate clear linear propagation of hydrofractures from the wellbore but described a complex fracture network.
Combining Advanced Real-Time LWD Answers with Accurate and Flexible 3D Rotary-Steerable System for Proactive Reservoir Navigation
Authors: Gravem Trond , Berle Alf , Gundersen Sven S. , Pedersen Jarle , Rorvik Kjell Oddvar , Hansen Atle 
Published: December 2007

Abstract
Development of formation evaluation technologies for azimuthal, deep-reading measurements and accurate and flexible 3D rotary steerable drilling systems have made it possible to provide truly proactive well placement. Real time use of new and advanced LWD data in horizontal drilling gives the opportunity to extend the envelope for well planning and reservoir information gathered in a single run. Optimum interpretation from real time data acquisition facilitates a reformation of the way horizontal wells are planned and drilled. This paper shows a well where the information was extracted and included in the decision making process to an extent that sets a new industry standard. Applying an accurate 3D rotary steerable system with openhole sidetrack capabilities increase well design flexibility and the ability to act on the real-time LWD data. The bottom hole assembly used consisted not only the standard LWD services such as gamma ray, propagation resistivity, density, neutron porosity and LWD gamma ray and density imaging services, but also formation pressure testing while drilling and the newly introduced azimuthal propagation resistivity. The azimuthal propagation resistivity provides unique information of the approaching bed and fluid contacts. Verification or change of the geological model during drilling through comprehensive use of forward resistivity modeling and real-time geological interpretation based on both the newly introduced azimuthal propagation resistivity service and resistivity from multiple depths of detection as well as wellbore images from both density and gamma ray, give a solid and enhanced base for real time well placement in horizontal drilling. The horizontal interpretation of resistivity data together with structural interpretation of image data gives an unmatched understanding of the geology and aids in placing the well better. Horizontal real time wellbore placement is then accompanied by real time reservoir characterization through real time formation pressure measurement to validate any fluid movements and fluid compartmentalization of the reservoir. This paper is based on wells drilled in a chalk field in the North Sea where real time data acquisition plays a significant part and illustrates to what level LWD data can facilitate proactive well placement and comprehensive reservoir characterization.
Analysis of Well-Test Data in a Multiwell Reservoir with Water Injection
Authors: Lin Jia-En , Yang Hui-Zhu 
Published: December 2007

Abstract
In this paper, a general method has been developed by taking into account the production time for analyzing the pressure buildup or falloff data from a well located in a bounded homogeneous rectangular reservoir, with an arbitrary number of both production and injection wells. In the new solution, injection-production ratio (IPR) was introduced to measure the regional strength of fluid injection or well interference. The previous solution developed by Marhaendrajana et al (1999) is a special case of this new solution.
For the analysis of well test data from a well in multiwell reservoir where both production and injection wells exist, we treat the "well interference" effect as a "regional reservoir pressure trend". We use a diagnostic plot comprising the pressure change and pressure derivative calculated with respect to, and graphed vs., equivalent time to recognize the interference of offset wells. For oil/water systems, we assume that saturation gradients are negligible in the drainage area of the tested well. The proposed method enables one to calculate the total mobility or permeability-thickness product and the skin factor with accuracy from pressure buildup (or falloff) data dominated by regional reservoir pressure trend.
A field example has been presented to illustrate the validity and applicability of the proposed method. The significant new contribution of this work is the development of the new multi-well solution by taking into account well interference effects from both production and injection well.
Subsea Slimhole Completions in Deepwater Gulf of Mexico: Case Histories
Authors: Sanford J. R. , Cordeddu C. , Edwards W. J. , Baccigalopi G. D. 
Published: December 2007

Abstract
Typically, deepwater subsea completions are characterized by significant production rates which require large completion hardware. Slim-hole designs (defined as 5½" production casing and smaller) are usually avoided due to increased risk and production concerns.
However, as the deepwater Gulf of Mexico basins grow more mature, sidetracks and challenging new drills become frequent. Sidetracks out of 7¾" to 7" production casing are being performed, ending with 5½" or 5" casing at TD. Additionally, many new drills either have to penetrate multiple depleted intervals or require more aggressive directional plans to reach smaller targets. Both scenarios can result in slim-hole designs.
Historically, the two (2) riskiest phases of the completion are wellbore displacement and sand control. This paper presents the design, the risk assessment, the installation and the actual results for three (3) subsea slim-hole deepwater completions. A summary of the completions are as follows: 5" Frac Pack (FP) at 74 degrees deviation5" FP with &gt; 40000 md-ft kH sand5½" High Rate Water Pack (HRWP) at 25000 ft TVD
As a result of proper planning, the Case Histories were successfully executed in Gulf of Mexico deepwater. However, performance expectations from these type wells must be risked and managed.
The Development of World-Class High Rates, High Ultimate Recovery Wells in Deepwater Turbidites—Bonga Field, Offshore Nigeria
Authors: Inikori Solomon O. , Spring Laurent , Ageh Ebenezer , Van der Bok Jaap 
Published: December 2007

Abstract
Bonga field in deepwater Nigeria produces hydrocarbons from classic deepwater turbidites reservoirs in channel settings. The reservoirs consist of series of amalgamated channel complexes with varying degrees of compartmentalization. This configuration presents significant uncertainties in connected volumes, well placements and sweep efficiency between water injector/producer well pairs. However, due to the high costs of deepwater developments, well count needs to be as low as practical, and production rates must be sustainably high to ensure economic robustness of the project. High rates and high ultimate recoveries are the foundations of successful deepwater projects, where constant pressure maintenance is a key component. Several research studies conducted recommended that water injection wells be designed for fractured injection in order to sustain the required high rates as opposed to matrix injection. This paper presents the results of these research efforts leading to this conclusion and the implications on reservoir management.
Also presented is an overview of the challenges of developing these complex channel deposits as well as the new approach to modeling of high rate wells in deepwater turbidites.
Key to a successful understanding of reservoir behaviour (connectivity) and early indications of future reservoir performance is through a systematic undertaking of interference tests at production start-up.
After about 2 years of production, the results from the Bonga wells demonstrate that sustained high oil rates could be achieved with adequate pressure maintenance. Average oil production rates of vertical/deviated wells range between 15,000 to 22,000 bopd and that of horizontal wells range between 25,000 to 35,000 bopd. Estimated Ultimate recovery (EUR) range from 20 to 100 mmstb for phase 1wells and from 10 to 30 mmstb for phase 11 development wells with several opportunities for infill drilling of low EUR wells. Nameplate capacity of 225,000 bopd is achieved and sustained with just 9 producers and 6 injectors. In order to maintain reservoir pressures from these high uplift rates, world-class water injection rates of between 40,000 to 70,000 bbls per day per well have been sustained since first oil.
The fracture injection approach is applicable both for onshore and offshore reservoir development but more significantly for deepwater reservoir development where sustained high rates and economic considerations are paramount.
Improved Drilling Performance in Lake Maracaibo Using a Low-Salinity, High-Performance Water-Based Drilling Fluid
Authors: Montilva Julio , Van Oort Eric , Brahim Ricardo , Luzardo Juan Pablo , McDonald Mike , Quintero Lirio , Dye Billy , Trenery John 
Published: December 2007

Abstract
Improved drilling techniques have overcome many of the inherent difficulties associated with the delivery of Icotea and Misoa wells in the West Urdaneta Field of Lake Maracaibo. Advancements such as rotary steerable assemblies, logging-while- drilling (LWD) tools, annular pressure subs and new bit designs have allowed drilling of extended reach and horizontal wells to become routine. However, borehole instability and lost circulation problems have continued to negatively impact operations, compounding well delivery costs.
In an effort to address these problems, a variety of non-aqueous fluids (NAF) and water-based muds (WBM) have been used. While each provides distinct advantages, there has never been a system which could solve all problems associated with drilling the Icotea and Misoa formations. Lost circulation and wellbore instability (defined by almost continual caving of shales in the La Rosa formation) have plagued NAF applications in this field. A variety of WBM systems have been used and each one has also presented its own problems including hole enlargement, bit balling, accretion, low rates of penetration, insufficient hole cleaning, and the need for excessive backreaming.
Finding a fluid that would deliver step-change performance in of drilling efficiency compared to previously used systems, while also adhering to the strict environmental limitations for the area, was paramount to continue economically viable drilling operations in the Urdaneta Field. This challenge was met using an environmentally benign, low-salinity high-performance water-based mud (HPWBM), which was field tested in the intermediate section of the Icotea and Misoa wells. The novel fluid was used to drill through the problematic Laguna, Lagunillas, and La Rosa formations.
By analyzing the field tests results, conducting after action reviews (AAR) and maintaining a productive dialogue between all parties involved, the operational performance of these wells showed substantial and continual improvement. The low-salinity HPWBM is now our system of choice for drilling intermediate hole sections in the West Urdaneta Field.
This paper provides a detailed technical overview of the new HPWBM, provides and the results of the early field tests and of subsequent wells, demonstrates enabling impact of this new technology on driving continual operational improvement.
Operation Centres, Realtime Data and Data Management. Quo Vadis?
Authors: Grøvik Lars Olav 
Published: December 2007

Abstract
This presentation is about some of Hydro's experiences with the digital-oilfield. Main topic is Data and Data-management issues related to: Operation-centresRealtime-dataInformation-technology (changing software etc)
It is NOT a presentation of the "perfect" Hydro solution, since it is not perfect (yet)……
I want discussion and cooperation, allowing us to solve mutual problems and challenges.