bluuebunny/crossref_metadata_2025_split huggingface dataset:
Production Logging Advances in the Fractured Monterey
Authors: Grayson S. T. , Kohring J. J. , Elliot W. B. , Hertfelder G. P. , Goeres T. B. , Horner S. G. 
Published: December 2007

Abstract
Accurate production profiling in the fractured Monterey wells of offshore California is a challenging endeavor. Deviated wells, three-phase flow, and the unpredictable nature of production from natural fractures, makes possible almost any type of flow regime. New production logging sensors have been developed that use distributed probes to directly detect hydrocarbons and provide images of the flow profile. The FloView*, PSP, and GHOST* tools have been used in the Monterey to provide accurate profile data necessary for successful workover efforts. When these data are combined with fluid PVT data in flow modeling software, oil, gas, and water contributions from each perf interval are quantified. Based on this analysis, thru-tubing water shutoff workovers have been designed and successfully implemented in a number of Monterey wells. First hydrocarbon entry is clearly visible on the FloView field image, and the modeling software quantifies the reduction of water with the precise placement of a thru-tubing bridge plug. The caliper measurements included with the PSP provide enhanced spinner interpretation when casing ID changes unexpectedly. The distributed probes of the Ghost tool use optical refractance to positively identify gas in the borehole. With a clear picture of the situation, pinpoint accuracy can be applied when implementing the solution. In the Monterey, the results can be dramatic.
Establishing Gas Phase Well Performance for Gas Condensate Wells Producing Under Three-Phase Conditions
Authors: Jokhio Sarfraz A. , Tiab Djebbar 
Published: December 2007

Abstract
This paper provides a new method of forecasting natural gas production of gas-condensate wells that flow under three phase conditions. Such wells include gas condensate wells that produce liquid condensate and water along with gas phase, their main production. Mathematically treating such systems can be very demanding. A new tedious, but simple method of projecting the gas phase production is proposed. In this method we integrate reservoir production data and the pressure transient data to forecast well performance without prior knowledge of relative permeability as function of saturation. Since pressure transient well test data is usually available on yearly basis, effective permeability as a function of pressure can be updated. It is the true representative of the reservoir conditions of heterogeneity, geometry, and resident fluids.
The total gas production in a gas condensate reservoir is contribution of all the three regions that might exist at certain stage of depletion. Free and dissolved gas in both oil and water in Region-1, free and dissolved gas in water in Region-2, and free and dissolved gas in water in Region-3. Thus to project the production, along with the physical properties of fluids in all the three regions, their phase change with pressure also has to be handled.
It is observed from the solved examples that buildup of condensate liquid phase reduces the gas production as well as water production, a favorable situations. Partially the gas production loss is recovered in form of condensate while reducing water production.
Finally, few examples with simulated data are analyzed to show the use of new method. A step-by-step procedure is also devised to establish the well performance. Small operators will benefit from this method at the most, since data acquisition like relative permeability curves requires to laboratory experiments on cores.

Introduction
We are extending our understanding of the retrograde gas-condensate systems lately. Recently many good papers have been published that treat gas-condensate systems. Retrograde gas-condensate reservoirs are primarily gas reservoirs. A zone of liquid begins to form as the dew point pressure is reached. The liquid keeps accumulating and does not flow until the critical liquid saturation is reached. Once critical saturation of the liquid phase is reached, it begins to flow towards the wellbore along with the gas. Pressure at this point in the reservoir is termed as P*. Interestingly, this liquid may re-vaporize as the pressure further crosses the lower line on two-phase envelope of phase diagram. This behavior of re-vaporization of the oil phase is called the "Retrograde behavior." Fig.1, Fig.2, Fig.3, and Fig.4 show the schematics of such a phenomenon in vertical wells and horizontal wells.
Evidence and Implications for Significant Late and Post-Fold Fracturing on Detachment Folds in the Lisburne Group of the Northeastern Books Range
Authors: Bui T. D. , Brinton J. , Karpov A. V. , Hanks C. L. , Jensen J. L. 
Published: December 2007

Abstract
In exposed detachment-folded Lisburne Group carbonates, field evidence and statistical analysis suggest that a significant population of fractures post-date folding.
Both prefold fractures and penetrative strain associated with peak folding are overprinted by late-folding and post-folding fractures. The fractures in the first set strike EW parallel to the fold axis, are perpendicular to bedding, are often only partially filled with cement, and generally terminate at bedding planes. These and the earlier structures are consistently overprinted by pervasive late NS extension fractures. The later fractures strike perpendicular to the fold axes, are vertically extensive, evenly spaced and unfilled. Both have similar average and median spacings.
Statistical analysis of fold angle and fracture spacing indicates that, as the folds tighten, both the EW and NS fracture spacing increases by a factor of two or three and becomes slightly more variable. This behavior is opposite from that expected if the fractures were closely related to folding. It suggests that the two sets are similar to each other and are only weakly affected by the folding.
This weak genetic relationship between folding and formation of the most obvious and open fractures serves as an important example with major consequences for reservoir modelling. Complex genetic and timing relationships between fractures and folds may result in several fracture sets, each having different characteristics (e.g., size, amount of fill, and termination type). Unless recognized, genetically disparate fractures may be combined into one or a few sets to produce a reservoir model with fracture properties which do not apply to any of the sets. This could result in inappropriate wellbore placement or inaccurate productivity and recovery estimates.
Characterization of Flow Channels, Natural Fractures Orientation and Oil Water Contact Movement from Well Productivity Data
Authors: Zahedi Alireza , Ershaghi Iraj , Horner Steve 
Published: December 2007

Abstract
This paper presents application of innovative conventional reservoir engineering methods to map fracture systems and to track fluid interface movement in naturally fractured reservoirs. Particular emphasis is on reservoirs with fractured-controlled production such as the prolific Monterey Formations in the Pacific Offshore. These reservoirs are characterized by very complex fracture network and trivial matrix porosity. Monterey Formations exhibit unique fracture structures where fault zones and other highly brecciated intervals serve as large conduits of interface and fluid movement. The inspiration for the study is from observations on the South Ellwood Field located off the Coast of Santa Barbara, California.
In the absence of modern fracture identification logs, we developed a methodology to map fractures from individual well productivity and course direction. We introduce a fracture orientation estimation method based on the projected length of the well path, completion profile and cumulative oil. The optimization method correlates well productivities with incident angle of the directional well course, anticipated direction of tectonically generated fractures and the length of wellbore exposure to fractured intervals.
To account for the observed uneven oil-water contact (OWC) in individual brecciated intervals, a saturation tracking methodology is proposed extending the aquifer modeling approach originally proposed by Fetkovich and the transient monitoring of OWC using the Ershaghi x-plot method.
These innovative conventional reservoir engineering analysis techniques deciphering signals imbedded in performance history constitute effective pre-processing steps to building a realistic fracture model for the 3-D simulation of the reservoir.
Experimental Verification of Methods to Calculate Relative Permeability Using Capillary Pressure Data
Authors: Li Kewen , Horne Roland N. 
Published: December 2007

Abstract
The Brooks and Corey model has been accepted widely to calculate relative permeability using capillary pressure data. However the Purcell model was found to be the best fit to the experimental data of the wetting phase relative permeability for the cases studied, as long as the measured capillary pressure curve had the same residual saturation as the relative permeability curve. The differences between the experimental and the Purcell model data were almost negligible. A physical model was developed to explain the insignificance of the effect of tortuosity on the wetting-phase. For nonwetting phase relative permeability, the model results were very close to the experimental values in drainage except for the Purcell model. However, calculated data in imbibition were different than the experimental data. This study showed that relative permeability could be calculated satisfactorily by choosing a suitable capillary pressure technique, especially in drainage processes. In the reverse procedure, capillary pressure could also be computed once relative permeability data are available.
Implementation of an Ultrasonic Cuttings Processing System for Drilling Operations at the Meltwater Field, North Slope, Alaska
Authors: Brockway Thomas A. , Andrews Lloyd , Caza Stan , Simpson Dave 
Published: December 2007

Abstract
This paper describes the successful implementation of a new generation cuttings disposal system being used by Phillips Alaska, Inc. to replace conventional ball mill slurrification at the Meltwater satellite development project.
The vibrating ball mill is currently the dominant technology used on the Alaskan North Slope for processing cuttings and fluids generated during the drilling process. While effective, ball mills have three inherently inefficient and undesirable characteristics – they are large, noisy, and expensive to operate and maintain.
In early 2001, Phillips Alaska, Inc. and Doyon Drilling began researching alternative cuttings disposal solutions for development drilling at Meltwater, a remotely located satellite development project south of the main Kuparuk River Field. A new technology alternative to the traditional ball mill was employed combining ultrasonic cuttings processors, a separation shaker, process pit, and an injection skid into a small, lightweight, and highly mobile unit. To date, this new cuttings processing system has proven to be reliable and highly effective, providing slurry outputs comparable to a traditional ball mill, but with substantial size and cost reductions.
This paper will give a brief overview of the history of the ultrasonic processing system, describe some of the theory behind ultrasonic processing, and illustrate how ultrasonic units are being utilized as part of an overall cuttings disposal "system" on the Meltwater project. An operational and cost comparison between the Meltwater ultrasonic system and a conventional ball mill will also be presented.
Testing and Startup of a Novel Compressor for Miscible Gas Injection
Authors: Klein John M. 
Published: December 2007

Abstract
This paper describes experience with an interesting new high-pressure application of an all-electric centrifugal compressor for miscible injection. Improvements made during the shop testing of the machine were responsible for reducing mechanical issues in the field. However, commissioning and startup proved challenging. Process control of the MI mixture to the compressor was one of several issues that required field resolution in order to complete the start-up.
Maintenance Decision Support Tools for CMMS
Authors: Mofley Guy A. , Cowart J. R. 
Published: December 2007

Abstract
We are all familiar with thinking in terms of upstream and downstream; even oil and gas. However, there is a new product stream that has not captured our attention and is rarely considered: the data stream. Once converted to information, this stream enables processed data, demands an audience, and encourages solutions while requiring technology to better visualize themes. Truly valuing information, leads to better decision making support tools and thus increases the profitability quotient.
Use of Magnetic Clutch to Improve Performance of Sucker Rod Pumps
Authors: Guo Boyun , Zhang Morgan , Jin Feng 
Published: December 2007

Abstract
This paper reports a new type of overrunning clutch that has been developed and installed on sucker rod pumping units. The clutch disengages the power-input shaft of the gear reducer and the unit sheave, and allows free-fall motion of the sucker rod string in down-stroke. Based on the results of more than 100 installations, it was found that the pumping speed increased by 9% in average. Liquid production rate increased by up to 30%. Power saving was 23.6% on average. It was also observed that downhole sand and paraffin deposit problems were greatly alleviated. This paper presents pump performance analyses and clutch selection for sucker rod pumping systems.
Perspective on the Evolution of Petroleum Engineering Education in the New Millennium
Authors: Agbaraji Casmir I. , Khataniar Santanu , Chukwu Godwin A. , Zhu Tao 
Published: December 2007

Abstract
Engineering education, in general, has been undergoing significant changes in recent years with the arrival of groundbreaking technology. Because of this technological revolution, globalization of the economy, and changing perspective on energy issues, the education of petroleum engineers needs to evolve to meet the challenges of the future petroleum industry. The petroleum industry has become more service oriented and diversified than ever before. This will lead to the role of an engineer as a creator of public goods, which are not necessarily tangible, as warranted by the industry. The objectives of this study are to identify the critical challenges facing petroleum engineering education today, to analyze the vision of petroleum engineering in future, and to develop a plan to meet the future educational challenges. The tools available for petroleum engineering education in the past and in the present are reviewed, and those expected to dominate the 21st century are analyzed. The impact of new technological devices on the delivery, quality, scope, and recipient of petroleum education is critically evaluated. The evolving shift in learning model from a traditional, school based one to a non-conventional, virtual one is discussed. The areas of petroleum engineering education that need improvement are highlighted. It is clear that engineering education will be challenged as never before to shape the nature and quality of life in the new millennium. Engineering education must be proactive to meet these challenges.
Near-Well Radial Upscaling for the Accurate Modeling of Nonconventional Wells
Authors: Wolfsteiner Christian , Durlofsky Louis J. 
Published: December 2007

Abstract
The accurate modeling of wells that exhibit arbitrary trajectories and/or multiple laterals (i.e., nonconventional wells) is critical for obtaining reliable well performance predictions. Modeling strategies need to account for both well geometry and reservoir heterogeneity effects, especially in the near-well region. Multiblock grids offer the ability to model complex wells more accurately than standard finite difference procedures. Such grids are globally unstructured, yet maintain structure locally, making them a reasonable compromise between standard (fully structured) techniques and fully unstructured procedures.
In this paper, we develop a near-well upscaling procedure suitable for use with multiblock grids. The technique is applicable for grids that are radial (or nearly so) in the near-well region rather than rectangular. The method is well-suited for models in which the general well trajectory is resolved by the simulation grid and is capable of modeling reservoir heterogeneity down to the scale of the wellbore itself. The high degree of accuracy of the upscaling technique is demonstrated through comparison to fine grid calculations for two different types of reservoir heterogeneity. It is shown that the effects of near-well heterogeneity can be significant and that the new procedure provides much better accuracy than simpler well models that assume near-well homogeneity and isotropy.
Carrying Capacity Design for Directional Wells
Authors: Jawad Riayde H. , Akgun Ferda 
Published: December 2007

ABSTRACT
Effective hole cleaning is an important task in directional and/or horizontal well drilling. Inadequate hole cleaning can lead to severe problems such as; stuck pipe, high rotary torque, low penetration rate and cutting bed formation which may lead to micro channel formation.
It is well known that for the same drilling conditions the directional wells require significantly higher flow rates than that of vertical ones in order to obtain the same cleaning efficiency. However, for many cases the required flow rates are not practically achievable due to pump limitations and/or borehole washouts.
Determining cutting carrying capacity by assuming concentric annulus is far from realistic for horizontal and deviated wells as the pipes have a tendency to lay on the low side of the hole under the influence of gravity. Therefore, it becomes necessary to develop a design model for drilling fluid carrying capacity for directional wells taking into consideration the actual mechanism of cutting transport through an inclined eccentric annulus.
A new design model for cutting carrying capacity for directional wells has been developed in this study by taking into consideration the non-Newtonian flow through an inclined eccentric annulus for both laminar and turbulent flow regimes. The proposed method calls for the determination of four different flow rates. The first one is the minimum flow rate required to ensure the flow occurs through the entire eccentric annulus (i.e., there is no stagnant fluid). The second one is the critical flow rate below which the pipe may get stuck due to cutting bed formation. The third one is the minimum rate above which the particles are not able to segregate and form steady bed. The fourth one is the optimum flow rate, which minimizes the bottom hole hydrodynamic pressure. Then these flow rates are compared with each other in order to obtain the recommended flow rate for a given drilling condition.
Cement Matrix Evaluation
Authors: Al Hammad Mansour A. , Altameimi Yehya M. 
Published: December 2007

Abstract
In the Saudi Aramco gas campaign, during the last few years, a high casing-casing annulus phenomenon was observed clearly days or months after rig released. Some of these casing or liner set and cemented across abnormally pressured formations, which contains salt water, gas or combinations of both. These zones were cemented using various cement density ranging from normal to high-density slurries.
The integrity of cement sheath is commonly measured by its ability to provide long term zonal isolation, at the time of completion and for the life of the well. It also has to physically support the casing, withstand pressure cycles, temperature cycles and protect the casing against corrosive fluids. Not all cement applications perform these functions with equal success, and many of those that do, they do not stand up against the forces that exert upon them during time.
This paper is evaluating the expansion and the shrinkage property using class " G" cement in Saudi Arabia, and its effect on the cement matrix. One of the potential problems causing the failure of cement zonal isolation, can be attribute to the over use of chemical expansion additives. The cement bond failure can cause migration of fluid from one zone to another, losses of reservoir fluid, well control issues and poor stimulation operations.
Multiple Zone Open Hole Gravel Packing Techniques with Zonal Isolation
Authors: Corbett T. Gary , Vickery E. Harold 
Published: December 2007

Abstract
This paper describes techniques to gravel pack multiple pay zones in a single open hole wellbore with positive zonal isolation between zones. For vertical and moderately deviated wells, these techniques provide an alternative to traditional stacked cased hole frac-packs. Open hole gravel packing eliminates the cost of cementing and perforating casing and can be pumped with considerably less hydraulic horsepower and blending equipment than a cased hole frac-pack. Therefore, open hole gravel packs can be performed at lower cost using more readily available, skid mounted equipment set on the rig versus a stimulation vessel typically required for frac-packs.
In addition, using current state-of-the-art technology, open hole gravel packs are capable of achieving high efficiency well completions with little or no productivity impairment. Open hole gravel packing has typically been limited to single massive sandstone reservoirs or the bottom pay zone in wells containing multiple zones. The techniques described in this paper allow open hole gravel packs to be applied in wellbores intersecting multiple pay zones. These methods can save considerable time and cost in suitable candidate wells.
Advanced Evaluation of Transitional Zones for Drilling Optimization
Authors: Khafizov Segey F. , Syngaevsky Pavel E. 
Published: December 2007

Abstract
The paper reviews tectonic influence on pore pressure distribution in overpressured sealing zones, and their recognition on logs. Based on materials from West Siberia (Russia) and Gulf-of-Mexico (Texas and Louisiana) a study of tectonic and diagenetic impact on transitional zones forming and associated drilling problems is performed.
Faults play an important role in overpressure forming, but they can also cause partial or total damage of the seal. A fault can enhance sealing properties of shale cap or partially destroy them, allow «escape» of formation fluids and pressures from down-dip formations, forming a shallow overpressure zone (Matagorda Island 622/623 and East Cameroon). Various stages of shale diagenesis are related to water expulsion and can aid to abnormally height formation pressure forming. A nature of Bazenov abnormal pressure is related to TOC (total organic carbon) alteration, specifically to hydrocarbon generation. This overpressure was "translated" into Abalak shaly formation with complex fractured-cavernous reservoirs (Severo-Demyanskoe, Em-Egovskoe fields). Both events are causing drilling problems and could be recognized on NMR (nuclear-magnetic resonance) and conventional (resistivity, gamma-ray) log diagrams. By incorporating such information into the drilling model one can characterize complex formations and avoid them when possible from penetrating.
Application of Leaky Aquifer Type Curves for Coalbed Methane Characterization
Authors: Cox D. O. , Onsager P. R. 
Published: December 2007

Abstract
Many coalbed methane (CBM) reservoirs are part of larger aquifer units that also contain water-saturated sandstones. To account for connections to aquifers, this paper presents "leaky aquifer" type curves for radial flow in leaky aquifers with wellbore storage and skin, and for vertically fractured wells in leaky aquifers. The type curves are similar to those with a constant pressure boundary, and in some cases, the characteristic flat derivative of infinite-acting radial flow may be completely masked. Examples from several CBM basins are presented that demonstrate the methodology.