bluuebunny/crossref_metadata_2025_split huggingface dataset:
Discussion of Visual Technology of the Big Scene of Virtual Reality on WEB
Authors: Jia ShaoFei , Tian XueSong , Wang Tong , Shan ChunYan , Li ZhuoYi 
Published: December 2007

Abstract
Using virtual reality technology to build the scene of big scope and many scenery, it exist the question of network bottleneck and drawing difficulty when WEB browses.
For this question, according to rules of Virtual Reality Modeling Language, we make the big scene effective division and layered attemper and capability optimization.
The effective division means partition a big scene into several small rectangle scene pieces, every scene piece all can run alone and the easy and smooth operating on WEB, thus realizes that the scene is partitioned effectively. The layered attemper means using the node in the VRML, realized the scenery model in the scene piece delamination load by step. the scene piece Again conformity and whole attemper. The capability optimization means adopting reducing number of subsection, Instances and text compression methods etc. Carrying on the scene capability optimizes. Thus realize that the big scene is run on WEB.
Uses the above technology to have accomplished big scene development work in "virtual history of No.8 Production Plant" system, that is runing. The realization of this technology, for show the large-scale virtual jointly station and oilfield templet engineering on the net in future etc, all have the very important meaning. Establish the technology foundation for forges "Digital Oil Field".
Casing Collapse Strength Reduction Under Lateral Loads From Yielding Shales in the Daqing Oil Field
Authors: Ai Chi , Zhao Wanchun , Guo Boyun 
Published: December 2007

Abstract
Casing failure has been found in nearly 20% of production wells in the Daqing Oilfield after 45 years of oil production history. Plastic failure of casing strings has been recognized in the zones of yielding shales overlaying reservoir pay zones in the field. This type of casing failure is one of the most costly problems in the field. No research has been done to study the resistance of casing string against the lateral loads from the yielding shales. This paper fills the gap.
Assuming a lateral load uniformly distributed along a casing section from a clay zone clamped between an upper and a lower sandstone zone, a mechanistic model was developed in this study. Results of the model indicate that the resistance of casing string to the lateral loads drops sharply in the early stage of development of radial deformation. The resistance of casing string to the lateral loads is not very sensitive to the longitudinal deformation. The remaining strength of casing string also depends on properties of the casing string.
A calculation example is illustrated in this paper. This work provides an analytical tool that can be used for optimizing casing programs against lateral loads from yielding clay zones to minimize casing failure and field operation cost.
Reservoir Management Ingredients for Optimizing the Water-Injection Performance in Small and Medium-Sized Fields
Authors: Tewari Raj Deo , Abd Raub Mohd Razib Bin , Xi Wang Yin , Abdallah Fahmi 
Published: December 2007

Abstract
Greater Unity a multilayered clastic reservoir in Sudan is a conglomeration of number of fault blocks- lacustrine deposits of late cretaceous age. Reservoir characteristics are mostly heterogeneous with varying degree of heterogeneities both vertically and horizontally. Reservoirs are highly undersaturated and have poor aquifer support. Rapid pressure decline was observed in early phase of production, severely affecting the performance of pumps resulting into frequent failures and causing sharp production decline. Water injection in low pressure mode was resorted in some blocks. Failure rates of ESP and PCP reduced significantly as dynamic fluid level (DFL) increased noticeably, provided sufficient submergence, and improvement in efficiency of the pumps.
Significant decline in injectivity in Aradeiba formation compelled to change the strategy of injection. Step rate tests were the guiding factor for selecting the low and high pressure injections and also stimulation. Paper discusses application of diagnostic methods like Hall plot, Jordan plot and other empirical relations using Pressure, injection and production data for understanding and improving the injection process. Profile modification for better conformance control gained early importance in view of smaller sizes of the pools.
Nonparametric statistical method known as Spearman rank analysis has been used to understand and analyze the degree of communication between injectors and producers. This analysis quickly identifies the communication between injectors and producers, or lack of communication and helps in understanding the response of injection. Preferential flow trends are reflected by the correlation in rates between injectors and producers alongwith lead time response of injection on production.
Paper illustrates the important ingredients which can add value to asset and improve the reserves and overall development strategy. Therefore, it is highlighted that success and failure of water injection project depends on why, when, where, what, how and how much to inject, plus what will happen to the formation once the water injection starts.
Gas Storage in a Depleted Gas/Condensate Reservoir in the Appalachian Basin
Authors: Aminian K. , Brannon A. , Ameri S. 
Published: December 2007

Abstract
A depleted gas condensate reservoir in the Appalachian Basin has been under investigation for possible conversion to a gas storage reservoir. When depleted gas condensate reservoirs are used for gas storage, the injected gas will pressurize the reservoir and will evaporate the retrograde condensate that is remaining in the reservoir upon completion of the primary production. This will result in significant compositional alteration of the withdrawn gas from the storage. The produced gas during withdrawal cycle must be processed to remove condensible hydrocarbons prior to pipeline transportation to prevent liquid drop out by retrograde condensation in the pipeline. The composition of produced gas will depend on the degree of mixing between the injected and the residue fluids.
To investigate the impact of the formation on the mixing, a compositional reservoir simulator was utilized in this study. The primary production history of the reservoir was first modeled with simulator using available data and the results of the data analysis. The phase behavior studies with Peng-Robinson equation of state (PR-EOS) provided a reliable estimate for reservoir fluid composition. Upon successfully history matching the primary production, the reservoir model was utilized to predict the composition of the withdrawn gas from the storage. Pipeline gas was injected into the reservoir and the reservoir was pressurized to its original pressure. Both vertical and horizontal wells were considered for injection to evaluate the extent of mixing among residue gas, residue condensate, and the injected gas. Subsequently, a withdrawal cycle was simulated to predict the liquid yields and gas heating contents based on the design of the surface facilities. The results of simulation study were then used to finalize the design storage field and surface facilities. The preliminary data collected after pressurizing the reservoir confirms the simulation results.
Innovations in Drilling Using Replaceable Bits
Authors: Banerjee S. N. 
Published: December 2007

Abstract
In conventional drilling a majority of drilling problems occur during tripping such as key seating and wall sticking. This leads to increase in rig time hence cost is unnecessarily high, especially in deep sea drilling.
Conventional drilling techniques use rotary drill bits which need to be replaced depending on the formations encountered. If the formation is very hard, the bit has to be replaced by a diamond bit. These bit changes unnecessary increase trip time and eventually rig cost. This trip time which can take up to a day, especially for deep wells can be eliminated by using a novel "Replaceable Drill Bit" system.
The concept of replaceable drilling bits is attractive for deep drilling because of the high rig costs and the lengthy round trips needed to replace worn bits. These bits are sturdy, capable of withstanding the high dynamic loads imparted by the vibrating drillstring and are capable of operating with highly abrasive drilling mud containing large amounts of sand and drill cuttings.
Thus an entire hole can be drilled conveniently without frequent tripping operation to change the bit. Maximum efficiency can be achieved by this mechanism during drilling.
Using Induced Microseismicity To Monitor Hydraulic Fracture Treatment: A Tool To Improve Completion Techniques and Reservoir Management
Authors: Le Calvez J. H. , Tanner K. V. , Glenn S. , Kaufman P. , Sarver D. S. , Bennett L. , Panse R. , Palacio J. C. 
Published: December 2007

Abstract
The organic-rich shale gas fields underlying the Appalachian, Illinois and Michigan basins are potentially the most productive source of natural gas in the northeast United States. Similarly to the Barnett Shale in Texas and the Fayetteville Shale in Arkansas, considerable volumes of gas are currently produced from these unconventional Devonian shale reservoirs using traditional and more modern well log evaluations techniques and completion methods.
Among others, two main geologic factors govern the production from these gas-bearing formations: ultra low matrix porosity and permeability and fracture-induced permeability. Devonian Shales are extremely low porosity reservoirs that must be effectively hydraulically fracture stimulated. Additionally, analysis of these gas fields illustrates how structural geology (by the means of basement structure influence, differential shortening effect, etc.) yields stress field variations both laterally and with depth.
To avoid making too many assumptions as to the induced fracture geometry and to better understand the created fracture geometry for various completion designs, monitoring of the induced microseismic activity may be used. Using a couple of examples from various formations (e.g., tight gas sand, shale gas, etc.), this paper highlights how microseismic monitoring of hydraulic fracture treatments can provide key information to characterize fracture development and geometry.
Transient Behavior of Multilateral Wells in Numerical Models: A Hybrid Analytical-Numerical Approach
Authors: Aguilar C. , Alaska BP , Ozkan E. , Kazemi H. , Al-Kobaisi M. , Ramirez B. 
Published: December 2007

Abstract
This paper presents an extension of transient well index approach to simulate pressure transient behavior of multilateral wells. This approach uses an analytical solution for the well index at early times and switches to the numerical well index at late times. The use of the transient well index eliminates the need for excessive grid refinement around the well. In this paper, we have improved the accuracy of the transient well index approach and have provided for a flexible and easily implementable approach to place multilaterals in conventional, Cartesian-grid reservoir models.
Plunger Lift Optimization by Monitoring and Analyzing Wellbore Acoustic Signals and Tubing and Casing Pressures
Authors: Becker Dieter Joseph , Rowlan O. L. , McCoy J. N. , Podio A. L. 
Published: December 2007

Abstract
Plunger Lift operations are oftentimes not optimized due to lack of knowledge of plunger location and changes in tubing pressures, casing pressures and bottomhole pressures. Monitoring the plunger location in the tubing helps the operator to optimize the production of liquid and gas from the well.
In low liquid volume wells, the plunger position can be tracked from the surface by monitoring acoustic signals generated as the plunger falls down the tubing. When the plunger falls through a tubing collar recess, an acoustic pulse is generated. These acoustic pulses, generated at the tubing collar recesses, travel through the gas in the tubing and can be monitored at the surface to obtain plunger depth. These acoustic pulses are converted to an electrical signal by use of a microphone or pressure transducer. The signal is digitized, stored and processed in a computer to determine plunger depth. In some high liquid volume wells, the acoustic pulses generated as the plunger falls past the tubing collar recesses may be masked and not detectable due to liquid accumulation around the plunger. However, in both low and high liquid volume wells, the plunger depth can be determined by generating an acoustic pulse in the tubing at the surface, and monitoring the acoustic reflection from the top of the plunger. Multiple shots are taken, so the plunger descent rate can be determined throughout the plunger fall.
Software processes this plunger depth data along with the tubing and casing pressure data to display plunger depth, plunger velocity and well pressures vs. time. Plunger arrival at the liquid level in the tubing, and plunger arrival at the bottom of the tubing are identified on the data plots. Well inflow performance is calculated and plotted.
Software displays the data and analysis in several formats including a pictorial representation of the well showing the tubing and casing pressures, plunger location, gas and liquid flow rates in the tubing and annulus, and inflow performance relationship at operator selected intervals throughout the cycle. A field case is presented to show how this field data analysis is applied to optimization of Plunger Lift operations.
Novel Approach for Estimating Pore Fluid Pressures Ahead of the Drill Bit
Authors: Jones John , Matthews Martin D. , Standifird William 
Published: December 2007

Abstract
The use of forward basin models in pore pressure prediction for well planning offers several advantages over conventional techniques. The extension of this technique to enable real time updates of pore pressure estimation ahead of the bit as new data becomes available represents a significant improvement in modeling that allows decision makers to be proactive instead of reactive during well construction.
Pressure-purposed basin modeling technology has been applied during real time drilling in ten wells. Success is measured through minimal differences between the post well interpretation to the pre-drill and periodic updates of the model.
This analysis revealed the pre-drill predictions from the pressure-purposed basin model were within 0.5 ppg over the entire drilled depth in three wells. Two of these three wells were updated during drilling in an attempt to maintain a closer tolerance. A fourth well was accurately predicted in an alternative stratigraphic scenario but the incorrect model was chosen as most likely. The remaining six wells were updated multiple times as new data from the well invalidated the previous predictions. Overall, 80% of the ten wells were within 0.5 ppg for the first 2000 feet after update, 90% were within 1.0 ppg. As distance from the last update increased, the accuracy of the prediction generally decreased depending on the particular conditions in the well.
Development and Utilization of a Bit-Based Data-Acquisition System in Hard-Rock PDC Applications
Authors: Pastusek Paul , Sullivan Eric , Harris Tommy 
Published: December 2007

Abstract
Drill bits are iteratively developed for specific applications to meet performance objectives such as aggressiveness, durability, stability, steerability, etc. The transition from one iteration to the next occurs when dull bits are examined, run data is analyzed and the inferences are implemented as revisions to the bit design and/or the operating parameters. Experience has shown that the efficiency of the process depends strongly upon the appropriateness and significance of the data collected. If, for example, a dominant cutter failure mechanism is incorrectly characterized as abrasive wear and is, in fact, impact wear, then the proposed solution and the development time will both be significantly affected.
One method for improving the significance of the data collected is to implement a special-purpose data-acquisition system within the bit. Such a device has at least three significant advantages over available sub-based data-acquisition systems: (1) its bit-based sensors will more accurately detect bit-based events, (2) it can be economically deployed over many bits and (3) it is relatively transparent to the user.
The paper describes an effort to develop, validate, and utilize a bit-based module designed to monitor accelerometer and magnetometer sensors and to record selected data. The authors also describe the effort to infer dynamic dysfunction(s) from the data in the fast-growing hard rock PDC bit application and to mitigate them via modifications to drilling parameters and bit designs.
Kikeh Batch Setting: Case Study
Authors: Flannery Chris , Choo Benjamin 
Published: December 2007

Abstract
The semi-submersible rig Ocean Rover was used by Murphy to batch set 23 wellheads in 4,350 ft water depth with zero Health, Safety and Environment incidents.
The batch set team worked together to maintain safety, performance, and to overcome numerous logistical and operational challenges. Implementing lessons learned and development of recommended practices resulted in continuous improvement throughout the project.
The program was completed in 63 days. Average installation time for conductor and surface casing was 3.36 days from start to finish. Total materials used were 50,000 ft of casing, 3,060MT of cement, and 78,000 bbls of 16.6ppg DKD mud.
Perforating for Fracturing—Best Practices and Case Histories
Authors: Pongratz Reinhard , von Gijtenbeek Klaas , Kontarev Roman , McDaniel B. W. 
Published: December 2007

Abstract
In 2004, SPE 90238, "Perforating and Hydraulic Proppant Fracturing in Western Siberia, Russia," provided recommendations for perforating in Western Siberia,1 an area where hydraulic fracturing is booming and considered second only to the North America region, with over 5,000 fracturing treatments performed each year. One of the issues that has become obvious over the past two years is the limited understanding of the importance of using well and reservoir data as major factors in the selection of perforating programs to prevent premature screenouts.
In recent years, several operators have concluded that maximizing production from most wells in western Siberia fields requires the placement of large quantities of coarsesized proppant using the least damaging fluid systems possible in the fracturing applications. For production optimization, the proven trend is "larger (proppant sizes) and bigger (jobs)" using the lowest acceptable polymer loading in the frac fluids to minimize gel damage.
To achieve successful placement of the designed optimized fracturing treatment, all factors that could lead to a premature screenout should be eliminated. Improper perforating practices have proven to be one of the primary limitations and are often proven as the number one reason for past screenouts. Using the preferred perforating guns and charges for a specific application reduced the total screen-out percentage to less than 5%. The key to proper selection of perforating methods included using API RP 19B data and simulation software that calculates downhole conditions.
This paper describes several case histories in moderately hard and moderately soft rock reservoirs, using both big hole and deep penetrating guns, showing results that proved using proper perforating practices could eliminate screenouts. Furthermore, the authors describe how a different approach (hydrajet perforating) was used to provide entry from the wellbore to the formation. Hydrajetting will be compared with conventional (shape-charge) perforating techniques prior to hydraulic fracturing. Case histories for multi-zone pin-point stimulation will be provided.
Streamline Simulation for Reservoir Management of a Super Giant: Sabiriyah Field North Kuwait Case Study
Authors: Ibrahim Muhammad N. , Clark Robert A. , Al-Matar Bader S. 
Published: December 2007

Abstract
This paper discusses the incorporation of Streamline simulation into the Reservoir Management Processes of the super giant Sabriyah oil field.
For the Middle East region, streamline simulation has particular significance due to the magnitude of reserves and scale of development. Streamline simulation brings immediate added value, due to its ability to handle high-resolution full three-dimensional models with hundreds of thousands to millions of cells, incorporating large amounts of field and well events over substantial operation periods, be they historical (i.e. history-matching phase), immediate (i.e. on-going) or in the future (i.e. prediction phase). This technology can be used to guide and optimize development strategy.
By incorporating streamline technology into existing and new reservoir development planning, we are able to demonstrate significant benefits and added value.
This paper will conclude with an analysis and discussion of some of the results accrued from the incorporation of streamline technology in the case under review. These include:
Reduced cycle time, leading to many more iterations of the entire decision-making workflow. Faster scenario analyses and decision-making. Better understanding of intra-reservoir communication. Better understanding of producer – injector relationships. Development planning for both producers and injectors.
This paper also demonstrates where streamline technology should fit within the overall reservoir management processes:
How the streamline simulation technology fits into reservoir management workflows. Where this technology fits into reservoir management workflows. What are the general benefits derived from incorporating and using this technology in reservoir management. When the streamline technology should be considered in reservoir management.
A Need for Converting Produced Waters to Useable Waters
Authors: Holliday George H. 
Published: December 2007

Abstract
There is a perennial and long standing lack of potable and useable irrigation water in the Western United States. U.S. oil and gas operators dispose of billions of barrels of produced water per year. The coalbed methane (CBM) operations produce about 825 million barrels of low salinity produced water per year. To a large extent, CBM is produced in the Rocky Mountain States, a large portion of the western states. Some of the CBM produced water is beneficially used, but the majority of the produced water is injected into subsurface formations or used without treatment for irrigation. There is an obvious need for potable and useable irrigation water in the western states. Also, there is an obvious over supply of produced water being injected into subsurface formations or being used for harmful irrigation purposes. Having a litigious society poses a restraint on Exploration and Production (E&P) operators who consider desalinating produced water. However, that same constraint is not imposed on state governments, who could purchase the produced water, ship the water to treatment plants and sell the water as potable and useable irrigation water after treatment.
Currently, state and federal agencies are encouraging use of untreated produced water for irrigation. This use of saline water destroys soil structure, kills vegetation, and eventually will result in litigation against producers. Constructive use of CBM produced water is needed. Converting the produced water into potable and useable irrigation water is needed and could be profitable for all concerned.
Viable produced water treating/desalinization methods are available and tested. Government agencies support the concept, but have offered no financial or regulatory help. The probability of legal action against E&P Operators for perceived or suspected adverse impacts from the desalinated water is too great for the industry to sponsor treating of produced waters. Thus, the states must assume that responsibility. There is a desperate need for potable and irrigation waters in the western states. Government needs to be encouraged to take the lead.