bluuebunny/crossref_metadata_2025_split huggingface dataset:
A "Top Down" Approach for Applying Modern Portfolio Theory to Oil and Gas Property Investments
Authors: Faulder D. D. , Moseley F. L. 
Published: December 2007

ABSTRACTPetroleum companies commonly use a "bottom up" approach for constructing and evaluating their petroleum portfolios, i.e. the "fill the data cube approach." Extensive information for each well is coded into the economic software including but not limited to rock and fluid properties, production profiles, operating and capital costs and then aggregated to fields, business units and finally the total petroleum asset base. This approach requires a significant commitment in technical, managerial and computer resources "to fill the data cube;" seriously limiting portfolio analysis to companies willing to commit to those resources.An alternative to the "bottom up" approach is the "top down" approach. Financial fund managers on Wall Street use this "top down" approach for the construction of financial portfolios. The financial analysts are first involved in making forecasts for the economy, then for industries and finally for companies. This same concept and process can be applied to the petroleum industry, greatly reducing the effort to prepare for and conduct portfolio analysis.One of the touted benefits of the "bottom up" approach is that it preserves the uncertainty in reservoir and economic properties and this uncertainty is included when conducting portfolio analysis. However, at some point in the analysis, one must realize all that is being manipulated are aggregated distributions of properties. The central limit theorem suggests that these aggregated properties all tend toward a normal/lognormal distribution. The "top down approach" recognizes and uses this insight in constructing portfolios.This insight is combined with advanced production decline curves methods to generate a production profile consistent with theoretical reservoir response. The advanced production decline curves include oil and gas phases for both radial and fractured flow regimes, thus assuring the modeled responses are based on sound reservoir engineering principals using probabilistic reservoir properties. The production response when combined with probabilistic economic calculation creates an integrated stochastic reservoir and economic model. These models can be combined to create a replicating portfolio of a company's asset base. Portfolio analysis is performed on this replicating portfolio, examining the current asset performance, as well as acquisition and divestiture candidates. Using this methodology significantly simplifies the process, reduces the staff and computing resources required, dramatically speeding the process. An asset class is further de-aggregated into subsets and portfolio analysis conducted on an expanded description of a company's asset portfolio for additional detail as required.
Technical Competencies for Geoscience Professionals
Authors: Fattahi B. , Murer A. S. , Myers G. A. 
Published: December 2007

Abstract
In today’s fast paced business environment, our attention is continually occupied by measuring ourselves against increasing expectations. The life cycle of our skill sets grows shorter as the information age revolutionizes our workplace. We wonder if we can continue to prove our worth to the organization, or we lose ground. These are important questions that are also asked by organizations to determine our value. Often the answers to such questions determine the fate of our careers. It is then highly important to have clear technical competency measures by which such expectations are defined and understood.
In the late 1990’s, having recognized the importance of defining standard-setting measures, the Society of Petroleum Engineers developed guidelines for minimum technical competence for many of the industry’s engineering disciplines. This paper proposes complementary guidelines for geoscience professionals. Similar to the previous work, the required competencies have been identified in terms of breadth and depth. An attached timeline completes the formation of a competency matrix and identifies the expectation time frame for acquiring various skills and competencies.
Global Warming and Petroleum Production
Authors: Khilyuk Leonid F. , Chilingar George V. , Al-Hamdan M. R. 
Published: December 2007

Abstract
The writers show that recent global warming of the Earth’s atmosphere is not due to increase in the man-induced carbon dioxide emission but rather to the long term global factors (such as increased solar activity). Rising global temperature drives very large volumes of CO2 from the ocean water to the atmosphere. The human contribution to the increase in CO2 content in the atmosphere is negligible in comparison. Thus, there will be no need to cut petroleum production and consumption in the near future.
Enhanced Oil Recovery Possibilities For Pembina Nisku C-Pool
Authors: Mungan N. , Nelson D.J. , Wing B.M. Lee 
Published: December 2007

Abstract
West Pembina is being regarded as the most significant oil discovery in Canada since the Rainbow Field was discovered in 1966. Six different recovery processes have been studied to arrive at the best strategy of oil recovery from one of the pinnacle, reef pools in West Pembina, the Pembina Nisku C Pool. It was concluded that bottomwater injection, with the reservoir pressure being maintained above the bubble point pressure was the best process, recovering 4528MSTB of oil (i.e., approximately 44.8% of the original oil-in-place) in 28.4years. It is anticipated that this recovery could be increased further by optimum design of waterflood operations.

Introduction
The Pembina Nisku C Pool was discovered with the drilling of Well Home Pembina 01-32-050-10W5M. The well encountered 64 ft of net oil pay in the Niskumember, of the Devonian Period. A subsequent well, Home Pembina 05-33-050-10W5M, was drilled and encountered 71 ft of net oil pay in the Niskumember. The oil zone is underlain by an aquifer 145 ft thick. Figs. 1 and 2 show the location of the Pembina Nisku C Pool and structural cross-section of the Pool, respectively.
The Nisku C Pool had an original reservoir pressure of 3,809 psig, at adatum of 5,648 ft subsea. Reservoir fluid study showed the bubble-pointpressure to be 2,492 psig at the average reservoir temperature of 183 °F. Asummary of the average reservoir and fluid data are given in Table 1.
The objectives of the present study were to determine the performance and ultimate recovery under various depletion mechanisms with a view of identifying the best recovery process for the pool. The following six studies were carriedout using a three-phase, three-dimensional reservoir simulator:primary depletion - no pressure maintenance,primary depletion with injection of produced gas - partial pressure maintenance,bottomwater injection -pressure maintained above the bubble-point pressure,bottomwater injection- pressure maintained below the bubble-point pressure to create a trapped gas saturation,crestal miscible gas injection, andcrestal miscible gas injecton followed by bottomwater injection.

Reservoir Characterization
The reservoir description for the Pembina Nisku C Pool was developed from petrophysical evaluation of logs from the two wells, 01-32-050-10W5M and 05-33-050-10W5M, and from the core analyes data of Well 05-33-050-10W5M. Coreanalyses data were also available from the discovery well located in Lsd.01-32-050-10W5M, but were not used because the data had been scrambled such that depths for the data were not known. A careful evaluation of the logs from the two wells showed no apparent layering. By analogy to similar reef reservoirs elsewhere in Alberta, it was decided that the most appropriate technique to generate the reservoir parameters was to use a random distribution of properties.
Experimental Investigation of Foamy Oil Flow Using a High Pressure Etched Glass Micromodel
Authors: Bora Rupam , Chakma Amit , Maini Brij B. 
Published: December 2007

Abstract
A series of flow visualization experiments were carried out using a high-pressure etched glass micromodel to gain insight into the pore level processes involved in foamy oil flow. The micromodel incorporated a realistic heterogeneous pore network with well-defined pore size distribution and pore throat size distribution. Solution gas drive experiments were conducted using a crude heavy-oil, a deasphalted fraction of the same crude oil, a synthetic mineral oil and a much lighter crude oil. The experimental results show that the rate of pressure drawdown was the most important parameter that altered the flow behaviour in the pore scale level and induced "foaminess" during the solution gas drive process. The dispersed gas flow occurred only in high rate tests and the dispersion was created by break-up of mobilized gas ganglia.
Mathematical expressions for nucleation rate were derived for various oil samples. A metering section at the downstream end of the micromodel was used to measure the volume of fluids expelled from the pore network. These volume measurements were used to estimate the total compressibility of the reservoir fluids before the formation of visible bubbles. The compressibility numbers were used to infer the presence or absence of micro-bubbles that would be too small to be seen but could contribute significantly to oil recovery. The estimated compressibility values suggest thatt some microbubbles were perhaps evolved during the depletion process. However, it appears that most of these microbubbles remained attached to the pore walls; only a handful became detached and grew into larger bubbles.
Experimental Study of Overburden and Stress Influence on Non-Darcy Gas Flow in Dakota Sandstone
Authors: Zeng Zhengwen , Grigg Reid , Ganda Sukesh 
Published: December 2007

Abstract
A series of laboratory experiments were conducted to investigate the influence of overburden and in-situ stresses on non-Darcy gas flow behavior in Dakota sandstone. Nitrogen was flooded through cylindrical core in a triaxial core holder under specific condition of temperature at 100°F, with core outlet pore pressure at 500 psi, axial and radial stress from 2.000 to 10,000 psi, and. nitrogen reservoir pump pressure at 2.000 psi with pump flow rates from 25 to 10,000 cc/hr at 80°F. Permeability and non-Darcy coefficient were determined using Forchheimer's method. It was found that with the increase of overburden and in-situ stresses, permeability decreases while non-Darcy flow coefficient increases. Average effective normal stress and shear stress were used to quantitatively express the influence of overburden and in-situ stresses. It was found that average effective normal stress has a good linear relationship with both permeability and non-Darcy flow coefficient. In contrast, average shear stress did not appear to influence the permeability and non-Darcy coefficient.
Streamline-based Production Data Integration Under Realistic Field Conditions: Experience in a Giant Middle-Eastern Reservoir
Authors: Qassab H. , Pavlas M. Khalifa R. , Afaleg N. , Ali H. , Kharghoria A. , He Z. , Lee S. H. , Datta-Gupta A. 
Published: December 2007

Abstract
In this paper we apply the streamline-based production data integration method to condition a multimillion cell geologic model to historical production response for a giant Saudi Arabian reservoir. The field has been under peripheral water injection with 16 injectors and 70 producers. There is also a strong aquifer influx into the field. A total of 30 years of production history with detailed rate, infill well and reperforation schedule were incorporated via multiple pressure updates during streamline simulation. Also, gravity and compressibility effects were included to account for water slumping and aquifer support. To our knowledge, this is the first and the largest such application of production data integration to geologic models accounting for realistic field conditions. We have developed novel techniques to analytically compute the sensitivities of the production response in the presence of gravity and changing field conditions. This makes our method extremely computationally efficient. For the field application, the production data integration is carried out in less than 6 hours in a PC.
The geologic model derived after conditioning to production response was validated using field surveillance data. In particular, the flood front movement, the aquifer encroachment and bypassed oil locations obtained from the geologic model was found to be consistent with field observations. Finally, an examination of the permeability changes during production data integration revealed that most of these changes were aligned along the facies distribution, particularly the ‘good’ facies distribution with no resulting loss in geologic realism.
Optimizing Helium Gas Recovery: A Compositional Dual Porosity Reservoir Simulation Study of the Bush Dome Helium Storage Reservoir, Amarillo, Texas
Authors: Weinstein Charles , Firincioglu Tuba , Albertoni Alejandro 
Published: December 2007

Abstract
This paper describes the process and results of the integrated field study for the Bush Dome reservoir in Amarillo, Texas, which is the world's only helium gas storage reservoir. Starting in 2003 the BLM is required by law to begin producing the stored helium in order to recover all of the helium reserves by 2015. The purpose of this study was to provide the BLM with a reservoir characterization that would have the predictive capability to optimally recover the stored helium within the restrictions imposed by the surface facilities and the requirements of the Helium Privatization Act of 1996. While optimizing the helium recovery prediction cases, innovative applications of the simulator features were implemented. The final optimization provided the BLM with production guidelines to meet the helium recovery objectives. The results not only provided a detailed production schedule, but also the information necessary to make appropriate decisions during the 13 year recovery period.
Turbulent Flow of Non-Newtonian Fluid in Coiled Tubing: Numerical Simulation and Experimental Verification
Authors: Zhou Y. , Shah S. N. 
Published: December 2007

Abstract
A comprehensive theoretical analysis of turbulent flow of a power law fluid in coiled tubing was conducted with the approach of boundary layer approximation. Equations of momentum integrals for the boundary layer flow were derived and solved numerically. Based on the results of the numerical analysis, a new friction factor correlation was developed which is applicable to a wide range of fluids used with coiled tubing operations. The new correlation was verified by comparing it with the published Ito correlation for the special case of Newtonian fluid. For non-Newtonian fluids, there is also a close agreement between the new correlation and the experimental data from recent full-scale experiments.
Evaluation of a Safe, Slightly Acidic Tubing Clean-Out Fluid
Authors: Berry Sandra L. , Boles Joel L. , Di Lullo Gino Francesco 
Published: December 2007

Abstract
Traditional "Best Practices" completion procedures recommend an acid pickle treatment to clean-out all tubulars in a wellbore prior to pumping an acid treatment or a "solids-free" completion brine system. The potential contaminants (iron oxidation, hydrocarbon deposits and pipe dope) can create formation damage if pumped into the formation during the main treatment. In addition, contamination of "solids-free" completion brine can lead to increased location diatomaceous earth (D.E.) filtration time.
Tubing clean-out treatments normally consist of a slug of acid (10 to 15wt% hydrochloric) being pumped inside the tubulars and then reverse circulated back to surface without fluids being lost to the formation. A solvent is typically added to assist in the removal of pipe dope and organic deposits. Inhibitor and a surfactant, to facilitate wetting, are the normal fluid additives. Handling and disposal of this fluid after clean up of the tubulars can be dangerous and very costly due to its corrosive nature (pH &lt;0).
A slightly acidic (pH of 5.8-6.3) fluid has been evaluated in the laboratory for use as a pickling fluid to replace the traditional acids. This fluid's capability to remove iron scales on coiled tubing, prevent rust from reforming, clean up commercial pipe dopes and reduce corrosion rates, was compared to traditional hydrochloric acid. This fluid performed as efficiently as 15wt% hydrochloric acid in removing all potential contaminants associated with a workstring, while producing one fifth the corrosion rate. Furthermore, a work string treated with this fluid prior to being laid down on a pipe rack retained a protective coating that resisted re-oxidization for up to 30 days.
Optimization of Plunger-Lift Performance in Liquid Loading Gas Wells
Authors: Ozkan E. , Keefer B. , Miller M. G. 
Published: December 2007

Abstract
This paper presents an algorithm to optimize the production and shut-in periods of plunger-lift based on reservoir performance. The algorithm combines analytical models of reservoir and wellbore fluid flow. The implementation of the algorithm requires a relatively simple and inexpensive electronic control system. The new system may be connected to existing wellheads with minimal modification. One of the advantages of the new algorithm is the ability to automatically incorporate the changes in the line pressure. An example application is presented to indicate that the new algorithm may increase plunger-lift production by a factor of two.
Interpretation of Diagnostics-While-Drilling Data
Authors: Mansure A. J. , Finger J. T. , Knudsen S. D. , Wise J. L. 
Published: December 2007

Abstract
A number of dynamic drilling problems, such as whirl, chatter, and torsional oscillations require real-time downhole data if they are to be mitigated. Current measurement-while-drilling data transfer rates are too slow for these problems to be adequately addressed in a timely manner. Furthermore, data received at the surface must be displayed in real-time in an interpretable fashion if problems are to be recognized.
A Diagnostics-While-Drilling (DWD) system has been built and used in a series of proof-of-concept (POC) tests at the GTI Catoosa Test Facility. Test results demonstrate that real-time, high-speed, downhole drilling-dynamics data allow the recognition of, and reaction to, undesirable downhole conditions, thereby mitigating bit-damaging events that frequently occur but are unseen in surface data.
While the primary purpose of the system is to display information in real time, data are also archived for later analysis. For this reason, the system does not process data downhole. All data are transmitted to the surface. This requires a high-speed data link. The bandwidth available with mud pulse telemetry is several orders of magnitude too low for this application.
The volume and complexity of downhole information necessitates careful data-management techniques. Tests accomplished thus far with the DWD system have yielded many observations and lessons that pave the way for future improvements to the system and its function. These improvements promise to drastically reduce drilling-dynamics problems.
Effects of Mandrel, Borehole, and Invasion for Tilt-Coil Antennas
Authors: Hagiwara Terry , Banning Erik J. , Ostermeier Richard M. , Haugland S. Mark 
Published: December 2007

Abstract
Several recently published studies discuss the concept of inductive resistivity logging devices with oblique transmitting and/or receiving coils. Both wireline induction and LWD propagation resistivity tool concepts have been considered. Directional resistivity measurements and improved anisotropy measurements are among the benefits promised by this type of device. Analyses based on point-magnetic dipole antennas were used to illustrate these potential benefits. The effects of a metallic mandrel, borehole, and invasion were not considered due to the absence of a suitable forward model.
This paper characterizes mandrel, borehole, and invasion effects for a variety of candidate tilt-coil devices with antenna array parameters similar to those of the previous studies. The characterization is based on calculations from a new forward model that includes tilted transmitting and receiving coils of finite diameter embedded in a concentric cylindrical structure.
Important details of the forward model used in the calculations are also provided.
Innovative Concentric Reamer Enhances Deepwater Drilling Operations
Authors: Miller Gregory C. , Childers Ronald D. 
Published: December 2007

Abstract
A prevailing challenge in today's deepwater drilling arena is to have a reliable and cost-effective system able to simultaneously drill and enlarge a borehole for accommodating multiple casing string programs. This paper presents an innovative practice that advances hole enlargement capabilities and offers a cost-effective solution to wellbore enlargement in deepwater wellbores. The key component is the concentric reamer that is compatible with all rotary steerable and directional drilling systems. The design of this concentric reamer addresses known technical challenges and minimizes performance risks associated with using hole enlarging devices.
This paper profiles the development and testing, from concept to field-proofing, of a new tool for deepwater Gulf of Mexico applications in various lithologies and drilling scenarios.
CNG Transport Technology is Delivering on Promises
Authors: Dunlop John P. , White Charles N. 
Published: December 2007

Abstract
Natural gas supply shortfalls are forecasted for the next decade in the U.S. and certain other markets worldwide. Most ongoing efforts to address these shortfalls, such as LNG enhancements and the transition of GTL science from the laboratory to the field, require low gas prices and huge volumes to generate adequate economic returns, and thus have necessitated the targeting of large and remote sources.
The marine transport of compressed natural gas (CNG) represents a different approach to the delivery challenge, and recent breakthroughs in technology are providing CNG with the ability to cost effectively ship much larger volumes of gas over greater distances. Thus, CNG is expected to help economically access moderately sized resources (typically 1-5 Tcf) with greater scalability and flexibility while lowering overall capital requirements. Adding to CNG's attractiveness are the modest fixed infrastructure investments needed at the production and market delivery points, and a high degree of security through the use of offshore loading and offloading operations.
Wellbore Stability Challenges in the Deep Water, Gulf of Mexico: Case History Examples from the Pompano Field
Authors: Willson S. M. , Edwards S. , Heppard P. D. , Li X. , Coltrin G. , Chester D. K. , Harrison H. L. , Cocales B. W. 
Published: December 2007

Abstract
Several wellbore stability challenges are faced when drilling in deep water. Overburden sediments are typically weak and overpressured; pore-frac windows are therefore narrow; salt bodies may have to be penetrated; rubble zones may exist adjacent to the salt bodies; reservoir formations may be depleted, with consequent risks of lost circulation and differential sticking. Extended reach wells, required to access satellite reserves, require close monitoring of ECDs when drilling. The pore-frac drilling window may be further complicated by changes in water depth existing over the length of the well path being drilled.
All these challenges have arisen in the various wells drilled at BP's Pompano field in the deepwater Gulf of Mexico. This paper describes the wellbore stability challenges faced. Citing well case history examples, the paper describes the experiences gained in tackling these challenges through the pre-well analyses and post-well observations. The paper concludes by providing guidelines and recommendations for data collection, pre-planning activities, drilling practices and real-time ECD / wellbore stability management that should be implemented to eliminate non-productive time when drilling in these challenging environments.