bluuebunny/crossref_metadata_2025_split huggingface dataset:
Field Testing and Commercial Application of High-Efficiency Nonpolymeric Gas Hydrate Inhibitor in Offshore Platforms
Authors: Pakulski Marek , Pukop Gabriel , Mitchell Caesar 
Published: December 2007

Abstract
A nonpolymeric gas hydrate inhibitor has been successfully field tested on a platform containing ten gas lift injection wells in an offshore location on Gulf of Paria near Trinidad. Several wells are connected to a common 2" pipeline with a typical pressure in the system of 1800-1900 psi. Gas decompression at the wellhead results in lowering the temperature below freezing and creates favorable conditions for hydrate formation. Prior to the test and in spite of using methanol, the field operator, Trinmar Ltd. experienced frequent flow disruptions due to gas hydrate formation. The inhibitor formulated in hydrocarbon solvent solution was injected into a gas line at initial concentration 1/2 of the previous methanol usage and the dosage concentration was gradually lowered to 1/15 of methanol until hydrate formation was observed. The hydrate disappeared upon inhibitor concentration increase to 1/10 of methanol. The treatment with the gas hydrate inhibitor was finally optimized at 1/8 of the former methanol usage. The entire field has been converted from methanol hydrates protection to the inhibitor following the successful test and the treatment has been running since late 1996 without any problems. No product accumulation in the system (gunking, agglomerating, etc.) has been observed. This is a result of the fact that the neat inhibitor is a liquid oligomer. Trinmar realized large direct and indirect monetary gains due to this new treatment.
P. 711
Characterization of a Vertically Compartmentalized Reservoir in a Supergiant Field, Burgan Formation, Greater Burgan Field, Kuwait; Part 2: Evolving Concepts of Reservoir Performance
Authors: Carr Brian S. , Kirby Robert H. , Al-Humoud Jamal , Al-Matar Dawood , Naser Waleed , Safar Ahmed 
Published: December 2007

Abstract
This is the second of two papers which describe a comprehensive multi-discipline effort toward characterizing the Burgan formation of Greater Burgan field in Kuwait, as a necessary precursor toward effective reservoir management. This level of foundation-building work toward characterizing Burgan stratigraphy, rock properties, fluid properties, and fluid distributions had not previously been undertaken during the prior fifty years of reservoir exploitation. However, during the late l98Os, water production became an issue. Then, as a result of the sabotage of Greater Burgan field during the Gulf War, the reservoir experienced a period of uncontrolled production during the blowouts of 1991. Subsequently, a concerted effort has been made to understand and characterize this huge reservoir.
This paper, Part 2, describes the evaluation of petrophysical data and heavy oil (tar) distributions, and the resulting understanding of movable oil within the formation. The paper also addresses issues regarding the integrity of historical production data, and the resulting approach toward predicting field performance. Lessons learned are discussed, including the importance of a strong data foundation, and the importance of ground truthing history-match adjustments. The planned way forward to a better understanding of this supergiant reservoir is also discussed; the way forward deemphasizes history-matching. (The focus of this paper is primarily the Burgan formation, which is the dominant producing horizon of Greater Burgan field. The Wara, Mauddud, Minagish, and Marrat formations also contribute to field production. Part 1 of this two-paper series describes the stratigraphy and water encroachment of the Burgan formation.)
P. 521
Characterizing the Greater Burgan Field Using Geochemical and Other Field Data
Authors: Kaufman R.L. , Kabir C.S. , Abdul-Rahman B. , Quttainah R. , Dashti H. , Pederson J.M. , Moon M.S. 
Published: December 2007

Abstract
This paper describes recent results from an ongoing geochemical study of the supergiant Greater Burgan field, Kuwait. Oil occurs in a number of vertically separated reservoirs including the Cretaceous Third Burgan, Fourth Burgan, Mauddud, and Wara. The Third and Fourth Burgan sands are the most important producing reservoirs. Over 100 oils representing all major producing reservoirs have been analyzed using oil fingerprinting as the principal method, but also supported by gravity and sulfur measurements.
From a reservoir management perspective, an important feature of the field is the approximately 1,200-ft long hydrocarbon column which extends across the Burgan reservoirs. Oil compositions vary with depth in this thick oil column. For example, oil gravity varies in a nonlinear fashion from about 10 API near the oil-water contact to about 39 API at the shallowest Wara reservoir. This gravity-depth relationship makes identification of reservoir compartments solely from fluid property data difficult. Including oil geochemistry in the traditional mix of PVT and production logging data improves the understanding of compartmentalization and fluid flow in the reservoir, both in a vertical and lateral sense.
The composition of reservoir fluids is controlled by a number of geological and physical processes. We attempted to identify unique sets of geochemical parameters that were sensitive to specific oil alteration processes. One set of geochemical properties correlated strongly with gravity and is therefore related to the gravity-segregation process. A second set of parameters showed essentially no correlation with gravity or depth but established unique oil fingerprints for most of the major producing reservoirs and identified a number of different oil groups within the Burgan and Wara reservoirs. We interpret the presence of these oil groups to indicate reservoir compartments owing to laterally continuous shales and faults, which act as seals on a geologic time frame. Compositional differences between groups of oils arise from the reservoir filling process. A third set of parameters correlate with water washing and/or biodegradation processes, indicating oil alteration during production. We are investigating these parameters to determine if they can identify production-time-frame barriers. The geochemical data were integrated with PVT-data for better understanding of the fluid distribution.
P. 533
Application of Petrophysically Derived "Flow Facies" for Reservoir Characterization and Simulation: Wara Reservoir, Greater Burgan Field
Authors: Moon Mark S. , Pederson John M. , Osmon Kamal , Al-Saied Mariam , Al-Sabea Salem H. , Al-Shammari Hana'a 
Published: December 2007

Abstract
In fluvially dornihated delta plain reservoirs, such as the Wara formation in the Greater Burgan Field, characterizing a reservoir's flow properties accurately is essential in developing a sound reservoir model. This is easier said than done. Typically, lithofacies identified in cores are correlated to multiple log suite characteristics. These are then used to help define simulation flow properties in wells. In Greater Burgan, with over fifty years of production, much of the field development occurred before modern diagnostic logging tools became available. Therefore, direct correlation of core lithologies and corresponding lithofacies description to multi- log character is not possible in the majority of wells.
Relationships discovered between shale volume (VSH) ranges and effective porosity to permeability transforms allowed us to apply unique rock properties to flow units or "facies" defmed by the VSH-porosity ranges. These flow facies eliminated the difficult task of trying to predict changing lithologies and lithofacies in wells with limited log traces and no core.
P. 547
Managing Wet/Dry Crude Production with Reservoir Simulation in the Greater Burgan Field, Kuwait
Authors: Harris Dan E. , Yardumian Hrant E. , Al-Naqi Meqdad A. 
Published: December 2007

Abstract
We designed, coded, and successfully installed wet/dry producing rules in an in-house multipurpose reservoir simulator. This paper discusses how we are using this feature to manage the development of the Greater Burgan Field.
Wet/dry reservoir simulation played an important role in deciding the future production rate of Greater Burgan. We studied plateau rates ranging from 1.25 to 2.5 MMBOPD to see which production rates will or (more importantly) will not require facility upgrades for many years. For development scenarios that require upgrades, wet/dry was a key contributor for assisting with facility sizing and timing. The wet/dry producing rules demonstrated that substantial production increases were sustainable by segregating commingled flowlines. Wet/dry also indicated whether wet or dry production strategies were possible at planned development rates. Management selected a future rate of 1.7 MMBOPD as a result of this work.
A Short-Time Model to Correct Environmental Effects in PNC Logging
Authors: Harris C.K. , Kimminau S.J. 
Published: December 2007

Abstract
Current Pulsed Neutron Capture (PNC) logs used for the location of unswept and bypassed hydrocarbons rely upon empirical environmental correction methods, which limit their application in low-contrast situations. A physical, analytical model is derived and applied to the problem of the ultimate sensitivity possible for hydrocarbon~water differentiation in timelapse mode. It appears that significantly better borehole effect correction can be possible compared to current methods. For classical low-contrast situations involving low porosities and low salinity water drives, it should be possible to extend the usefulness of the PNC method in differentiating oil and gas from fresh water in timelapse mode.
P. 581
Progress and Future of Pulsed Neutron Technology in Oil Field Management
Authors: Badruzzaman A. , Neuman C. H. , Adeyemo A. O. , Dodman C. A. , Skillin R. H. , Zalan T. A. , Badruzzaman T. , Bilodeau B. J. , Logan J. P. , Limon M. A. , Belanger D. L. , Featherstone C. J. , Nguyen P. T. 
Published: December 2007

Abstract
The recent advances in pulsed-neutron technology for oil field applications are discussed. The progress includes applying the technology to a number of formation evaluation and production logging problems, use of Monte Carlo modeling to understand response in complex field-like conditions, and development of interpretation algorithms in non-calibrated conditions. The remaining challenges in current applications and a number of emerging or proposed measurements using the technology are described.
A New Water-Flow Velocity Log for Use in Conformance Evaluation
Authors: Simpson Gary A. , Jacobson Larry A. , Ethridge Ray 
Published: December 2007

Abstract
The conformance of unwanted water in producing wells is becoming increasingly important because of costs associated with separation and disposal. A new water-velocity log based on oxygen-activation measurements was recently introduced. The measurements are made with a new small-diameter (1-11/16-in., 43 mm) tool whose design was directed towards enhanced evaluation of water conformance.
This paper discusses the laboratory measurements that characterize the logging technique. Field logs from the Gulf of Mexico region illustrate various water-flow regimes that can be identified with the technique. An interesting example of simultaneous upward and downward flow demonstrates the utility of the tool.
The tool uses two spectral gamma ray detectors and a pulsed neutron generator with a special timing sequence designed to emphasize activation measurements. Spectral measurements enhance velocity estimates by allowing gamma rays from oxygen activation to be distinguished from those arising from iron activation, silicon activation, and natural activity. Furthermore, spectral measurements permit analysis of Compton scattering to indicate whether water is flowing inside or outside the casing.
Water velocity is determined by two methods:
Use of a count-rate ratio from the two spectral gamma detectors, which provides a continuous log but requires well-calibrated detectors. Use of an impulse/shutdown sequence, which is performed while the tool is stationary and which is calibration independent.
The latter method is preferred. Velocity measurements can be performed at water flow rates from 3 to 50 ft/min when detectors are spaced 3 and 4 ft from the neutron generator. With additional longer-spaced natural gamma ray measurements, the range can be expanded to approximately 00 ft/min with the impulse/shutdown method.
Modular design allows the tool to be configured with additional gamma detectors placed both uphole and downhole relative to the neutron generator. This configuration allows the tool to measure simultaneous upward and downward water flow with the impulse/shutdown method. Additionally, modular design permits the tool to be combined with production logging sensors, such as spinner, temperature, density, and hold-up tools, for more comprehensive flow analysis.
A Semi-Analytical Approach for Productivity Evaluation of Wells with Complex Geometry in Multilayered Reservoirs
Authors: Basquet R. , Alabert F. G. , Caltagirone J. P. , Batsale J. C. 
Published: December 2007

Abstract
We present a new approach to solve the problem of complex wells located in layered reservoirs with crossflow.
First, well path is discretized into a carefully chosen series of source points. Secondly, pressure solution for each source point is obtained in the Laplace domain anywhere in a rectangular reservoir, where crossflow is permitted between layers and with possibly mixed boundary conditions (no-flow or constant pressure). We used the Fourier transforms in the space-variables after removing the time-variable by the Laplace transformation. The problem is reduced to a matrix product to solve in the transformed domain.
The above method is validated through comparisons with known line source solutions and numerical simulations.
It can be used to compute the pressure distribution within a well with complex geometry in a stratified bounded reservoir under the assumption of infinite well conductivity. The well can be located anywhere in the reservoir. Boundaries can be no-flow or constant pressure. Last, variable skins along the well-path can be imposed.
An application on a field located in the deep offshore of the Gulf of Guinea demonstrates the great value for wells design optimization in the context of complex heterogeneous reservoir where classical analytical approaches are typically inappropriate.
New Solutions for Pressure Transient Response for a Horizontal or a Hydraulically Fractured Well at an Arbitrary Orientation in an Anisotropic Reservoir
Authors: Spivey J.P. , Lee W. John 
Published: December 2007

Abstract
This paper presents a method for finding the equivalent isotropic system for a horizontal well or a hydraulically fractured well at an arbitrary azimuth in an anisotropic reservoir. The equivalent isotropic system can then be used to calculate the pressure response for constant rate production or the rate response for constant pressure production.
The horizontal well solution is compared with previous solutions reported in the literature. The general hydraulically fractured well case has not, to the knowledge of the authors, been presented before.
This study confirms the observation by Yildiz and Ozkan that small deviations (up to 20 degrees) from the optimal azimuth for a horizontal well do not have a major effect on the pressure response. Because this solution is obtained by finding an equivalent isotropic system, this study also confirms the observation by Earlougher that an anisotropic system cannot be identified from single-well test.
P. 627
Worldwide Turbidite Exploration and Production: A Globally Immature Play with Opportunities in Stratigraphic Traps
Authors: Pettingill Henry S. 
Published: December 2007

Abstract
An analysis of 925 discoveries from 54 basins worldwide demonstrates the importance of turbidites to future petroleum Exploration and Production. A plot of cumulative worldwide turbidite reserves versus time is currently at a slope maxima, indicating a globally immature play with significant remaining opportunity. 41 turbidite giants &gt;500 MMBOE) illustrate the relatively recent importance of turbidites: in the 75 years before 1970, 14 BBOE was discovered in 11 fields, whereas since 1970, 34 BBOE have been found in 30 fields.
Cumulative turbidite reserve's plots do not always follow the pattern typical of most plays, where larger fields are discovered early. The steepest climb in cumulative turbidite reserves usually results from traps with a stratigraphic component, which are often discovered later. This dominance of stratigraphic trapping occurs in various basin settings, shown here by the 5 basins with highest ultimate turbidite reserves: the North Sea, Campos, Gulf of Mexico, Los Angeles and San Joaquin basins. Turbidite giants further demonstrate the importance of the partial stratigraphic trap: 25% of the reserves come from structural traps, 9% from stratigraphic traps. and 66% from combination structural-stratigraphic traps. So if a turbidite play is judged solely on its structural prospect inventory, then the reserve potential will be underestimated. Additionally, basins with turbidite production limited to structural traps may have a bright Exploration and Production future.
As most major turbidite hydrocarbon provinces are in basins that produce from other reservoir types, lessons from past exploration could be applied to major producing basins which contain turbidites but lack significant turbidite production - even in basins that are in a relatively mature state of Exploration and Production.
P. 637
Propant Free-Shear Dilation: An Emerging Techology for Exploiting Tight to Ultra-Tight Gas Resources
Authors: Narayan S.P. , Yang Z. , Rahman S.S. , Jing Z. 
Published: December 2007

Abstract
In recent years there has been a growing interest in applying proppant free fracturing technique to stimulate tight to ultra tight gas reservoirs. The permeability enhancement mechanism for proppant free fracture stimulation has, in the HDR geothermal industry, been long recognised as shear dilation induced by elevated fluid pressure. Passive micro seismic monitoring technique has been well established in the HDR geothermal industry for imaging growth and geometry of reservoirs created by proppant free stimulation. Both field evidence from seismic monitoring and 3D stochastic stimulation modelling show clearly the volumetric nature of the stimulated rock mass with the proppant free stimulation technology. The detailed reservoir geometry, however, is complex due to interaction of natural fractures and in-situ stress regimes, and may be controlled either by dominant fracture sets or in-situ stresses. There exists a threshold stimulation fluid pressure above which permeability of stimulated fractures increases rapidly with increase in fluid pressure. The threshold pressure is inversely related to the deviatoric stresses. In regions with strong deviatoric stresses such as in Central Australia, the threshold stimulation pressure is expected to be low. Thus, creation of a large volume of reservoir by relatively low stimulation pressure could make the proppant free stimulation a viable alternative to conventional massive hydraulic stimulation from both technical and economical stand point.
P. 687
Stabilizing Wellbores in Unconsolidated Formations for Fracture Stimulation
Authors: Nguyen P.D. , Brumley J.L. , Dewprashad B.T. , Dusterhoft R.G. , Weaver J.D. 
Published: December 2007

Abstract
A wellbore stabilization system incorporating fracture stimulation has been developed and modeled in the laboratory for unconsolidated and dilatant formations. The profile of resin leakoff and penetration depth into the formation is relatively dependent on the pattern of perforations. Use of dissolvable particulates as a fluid-loss control agent proved to be effective in diverting resin, resulting in a uniform distribution of resin over the highly varying permeability interval. A significant drop in permeability of the near-wellbore area occurred after the resin treatment, but high productivity was re-established by connecting the wellbore with the untreated formation through highly conductive fractures. During companion testing of the resin-consolidation technique, the unconsolidated sand pack became a competent formation with compressive strength in excess of 2,000 psi. This competent material will be affected less by high drawdown pressures and stress cycling during production/shut-in cycles. The injection pressure required to fracture the consolidated wellbore showed an increase when compared to that of the untreated wellbore. Stress levels existing in the formation were shown to control the number and direction of generated fractures bypassing the consolidated zone.
P. 703
Applications and Limitations of Advanced Steel Body PDC Bit Technology
Authors: Smith L.M. , Perrin V.P. , Al-Habsi M. , Mody F. , Delwiche R. , Akin E. 
Published: December 2007

Abstract
New steel body PDC bit technology is shown to enhance drilling performance in a range of applications previously limited to matrix body bits. Specific aspects of the technology are detailed, including various proven design features, and unique manufacturing and materials treatment. In addition, the paper addresses the impact of increasing energy available at the bit face through utilization of a new hydraulic jet technology in combination with the advanced features of steel body PDC bits. Case histories are included to describe the application range of the new steel body bits, in terms of both drilling performance and economic impact.
P. 733
Gear Reduction Turbodrills Improve Drilling Results
Authors: Derkach N.D. , Krutik E.N. , Korotaev Yu. A. 
Published: December 2007

Abstract
The subject of the paper is development of a new class downhole hydraulic motors - gear reduction turbodrills, results of their application, advantages over the other motor classes. The first gear reduction turbodrill TRM-195 developed is widely used in oil and gas well drilling in Russia. It was the gear reduction turbodrill that drilled more than 3,5 mln metres of rocks. The best results were obtained in its conjunction with rolling-cutter bits of Western companie's production while well completion in West Siberia. Heat-resistant version of the turbodrill was successfully used in drilling the world deepest Kola well (12260 m). Based on the experience gained new designs and modifications of the gear reduction turbodrills are being developed to improve their performances while drilling directional and horizontal wells. They should be most advantageous in enhanced temperature wells (exceeding 150- 200 C) using PDC bits.
P. 755