bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Minifrac Procedure for Simultaneous Determination of Early and Late Time Fluid Loss During Fracturing
Authors: Lee W. S. 
Published: December 2007

ABSTRACT
Subject paper describes a novel new minifrac treatment procedure that allows the simultaneous determination of both early time fluid loss rate, (Cvc), and late time fluid loss rate, (Cw) when a filter cake has become the controlling factor. One of the primary uses of minifrac tests prior to stimulation of a zone is to determine the fluid loss coefficient, (Ceff), which plays a key role in treatment design. The value is the weighted average of Cvc and Cw. In applications in which early time fluid loss is low, this method gives reasonable results; if permeability is high the method is not valid. An excessive pad volume can be predicted in simulators when values computed by present methods are used.
Experimental and Modeling Evidence for Major Changes in Hydraulic Fracturing Design and Field Procedures
Authors: Cleary M. P. , Wright C. A. , Wright T. B. 
Published: December 2007

Abstract
The paper presents some important conclusions obtained by analysis of data from many hydraulic fracturing treatments monitored over the past five years. These conclusions involve some major changes from conventional concepts about hydraulic fracturing, many of which have been based on inadequate models of the process and a commensurate lack of adequate data or motivation to check those models. Recommendations are, therefore, also made about simple, low-cost procedures for adequate data collection, such as the use of flow-rate changes and/or multiple injection/shut-in cycles for stringent model evaluation. Our conclusions from such careful analysis include: shorter, wider fractures; relative insensitivity of fracture width to frac-fluid rheology; dangerously fast convection vs. settlement of proppant in imperfectly-contained fractures; and a potential role of natural fractures in explaining many phenomena formerly regarded as evidence for long contained fractures. Although serendipity may sometimes compensate for poor job design, we recommend that many existing approaches to fracture design and execution be re-considered and that more credible efforts at treatment optimization be achieved by more careful (on-site) analysis of properly monitored and more flexible field execution schedules.
Improving Fracture Conductivities with a Delayed Breaker System: A Case History
Authors: Small Joe , Wallace Mike , Howe Steve Van , Brown Ernie , Pferdehirt Doug , Thompson John 
Published: December 2007

ABSTRACT
A case study has been conducted on over 90 gas wells in West Texas to optimize fracture conductivity and well profitability. This study provides direct comparisons evaluating the effectiveness of treatments incorporating various designs and breaker systems. The wells stimulated with new designs focusing on methods to improve fracture conductivity have shown significant increases in production rates. These same wells have also shown improved clean-up properties, as compared to surrounding wells, by eliminating swabbing time and returning higher volumes of fracturing fluid.
Recent laboratory studies have demonstrated that realistic in-situ fracture conductivity values are significantly lower than previously thought. New testing procedures have concluded that proppant permeability values are greatly reduced when exposed to long term tests. Additionally, fluid damage and polymer concentration further impair these permeability numbers. When breaker concentrations are increased to a level to effectively degrade the concentrated polymer the rheology of the fluid will be adversely affected, thus sacrificing the execution of the treatment.
New designs have evolved placing emphasis on proper fluid selection, increasing proppant volumes and concentrations, and improved breaker scheduling. Encapsulation techniques have been developed allowing a controlled delay of breaker activation until after the proppant is placed. Extremely high breaker concentrations are now obtainable without adversely effecting the rheological properties of the fracturing fluids.
The Development of a Low-Permeability Gas Reservoir, Hamitabat Field, Turkey
Authors: Memioglu E. , Agca C. 
Published: December 2007

ABSTRACT
The purpose of this study is to evaluate and summarize the production history, tests, hydraulic fracturing operations and previous reservoir engineering and deliverability studies performed for Hamitabat natural gas field located in Thrace Region, Turkey (Figure 1). The structure and description of the reservoir, deliverability of the field, production increase as the result of stimulation operations, existence of an aquifer and change in reservoir pressure due to production have been either revised or determined.
Proseparator: A Novel Separator/Scrubber Design Program
Authors: Baker M. , Dick D. R. 
Published: December 2007

ABSTRACT
Prediction of performance of Separators and Gas Scrubbers is difficult with the traditional design methods - especially if inlet liquid loadings are high. BP Engineering has developed a novel Separator Design Program that can quantify the performance of both conventional and proprietary separation units.
The technique predicts the particle size distribution in the inlet pipework and determines the liquid Knock-Out in the vessel body. The quantity and size of remaining particles is calculated to enable the expected performance of the internals (Vanes, Cyclones or Demister Pad) to be estimated.
Initial verification work of this method by checking against existing operating units is now complete and a programme of further research work and development is in progress by BP Research, AEA-Harwell and BP Engineering.
Recent Developments in Gas Dehydration and Hydrate Inhibition
Authors: Hubbard R. A. 
Published: December 2007

ABSTRACT
Dehydration is an essential step in the processing of natural gas to meet pipeline specifications. Water removal is required to prevent condensation of an aqueous phase which can lead to hydrate formation and corrosion in the gas handling system.
The purpose of this paper is to review commercial natural gas dehydration processes and recent developments which impact the installation and operation of these facilities.
The paper will be divided into three sections 1) review and history of gas dehydration processes, 2) water-hydrocarbon equilibrium behavior and 3) new developments in gas dehydration processes.
Effects of Orifice Meter Installation Condition on Orifice Coefficient Accuracy
Authors: Morrow T. B. , Park J. T. , McKee R. J. 
Published: December 2007

ABSTRACT
The effects of tube bundle straightening vane location on orifice meter Cd and axial velocity profile have been investigated for nitrogen flow at a Reynolds number of 9*105 in a long (45 D), 4 inch diameter (100 mm) meter tube downstream of a 90° elbow. A 19 tube bundle straightening vane was modified to allow changing the vane to orifice distance, (x/D), without reassembling the meter tube. Results are presented for Cd variation for β=0.75 and 0.40, and for axial velocity profile as a function of x/D from 5 to 42.5.
Application of a New Wave Theory to Offshore Design Problems
Authors: Wallace Norman R. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 43rd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Sept. 29-Oct. 2, 1968. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A theory has been developed to describe the shape and velocity field of nonlinear waves in extreme states of deformation equally as well as in the undeformed state. The wave properties can be calculated for successive instants during the deformation process. Thus, the entire time-history and distribution of forces on objects causing the wave deformation are determinable.
A description is given of the method and application to the case of solitary waves impinging on a 45 degrees slope. Extension of the method to treatment of nonlinear, periodic waves and to forces on submerged pipelines is discussed.

Introduction
Offshore structures must be designed to withstand forces exerted by the largest waves expected to occur at the site of installation. Often these design waves are assumed to be the largest that can be supported by the depth of water, but even in less extreme situations the nonlinear character of finite-amplitude wave motion is usually taken into account. Stokes' waves in the third and fifth order of approximation are commonly used for the design wave in water of intermediate depth. For very large waves in shallow water, cnoidal wave theory has been found appropriate. As a third alternative, the individual crests of a shallow water system can be considered solitary waves, and McCowan's description (reference 1) of this wave and its particle velocity has found wide acceptance.
All of these theoretical methods pertain to periodic wave trains or pertain to periodic wave trains or single waves in water of constant depth. These methods cannot accommodate changes in the shape of the wave caused by the structure on which it impacts, yet these changes can be highly significant.
A new theory will be discussed here.
Gas Well Test Analysis in Complex Heterogeneous Reservoirs
Authors: Kocberber S. , Collins R. E. 
Published: December 2007

ABSTRACT
Today reservoir engineers are faced with the challenge of evaluating well tests in heterogeneous, complex reservoirs which may include fractures. For such reservoirs analytical methods are not available so numerical simulation is required. We present a finite element simulation system for gas well test analysis in such reservoirs. An automatic finite element grid generation technique provides grid refinement only in regions where it is needed. In this way wells and fractures are rigorously represented. Also wellbore storage and skin effects can be included in the model. Analytical coupling of fracture flow equations with reservoir flow equations, and nonlinear treatment of gas viscosity and compressibility, make the model ideal for gas well testing in fractured reservoirs. Also included in this 2-D model is the the capability of simulating multi-layer, 2-D reservoirs with crossflow only at the wells in a numerically efficient way. The model has been validated against analytical solutions for liquid flow in homogeneous media and has been shown to be correct to high order accuracy.
Sensitivity Analysis of Key Reservoir Parameters in Gas Reservoirs
Authors: Arastoopour H. , Chen S-T. 
Published: December 2007

ABSTRACT
A history match for gas and water production from Travis Peak Formation in the Eastern Texas Basin using our numerical simulator was performed. In our simulator, unlike dual porosity models, we used one general equation for both fracture and matrix, and variable computational cells. This enabled us to reduce the size of the computational cell close to fracture size which is closer to real situations in the gas reservoirs, and in turn, we believe our prediction is more accurate and reliable. Other advantages of our approach are: a) the flow equations in the fracture are not oversimplified, and b) the fracture system is not restricted to network of fractures.
Gas and water production predicted using our modified program agreed well with 30 days of production data from SFE No. 1 in Travis Peak formation. The effect of permeability, porosity, capillary pressure, viscosity of fracturing fluid, the level of invasion of formation by fracturing fluid and presence of single and multiple fractures on production were studied. Our calculation showed that interfacial forces between gas, water and porous medium are the most sensitive parameter effecting the enhancement of the gas production. Furthermore, the increase in overall mobility of the porous medium of reservoir due to presence of the fractures does not have significant effect on production in comparison with the location and distribution of the fractures.
On the Effect of Viscosity and Sand Thickness on Kern River Field, Single-Zone, Steamflood Performance
Authors: Restine J. L. 
Published: December 2007

ABSTRACT
Since the early 1960's, steamflooding has been completed in 1,600 five-spot 2-1/2 acre (10,000 m2) pattern zones in the Kern River Field. The data from 61 completed projects (averaging 25.8 patterns per project) and 91 cored postflood zones has been used to develop a correlation to predict oil recovery for a given gross sand thickness, oil viscosity, and initial oil saturation.
This correlation to predict oil recovery is based on the injection and operating strategies in past use, and changes that have been made in those strategies may result in higher recoveries. In several Projects, average pattern size 4.0 acres (16,000 m2) and 50 feet (15 m) thickness, initial injection rates of 500 BWPD (3.3 m3/hr) were sustained past steam breakthrough. These initial past steam breakthrough. These initial injection rates may have been too high and perhaps should have been reduced at steam perhaps should have been reduced at steam breakthrough.
Current Status Of The Duri Steamflood Project Sumatra, Indonesia
Authors: Pearce J. C. , Megginson E. A. 
Published: December 2007

ABSTRACT
The Duri Steamflood (DSF) Project is the largest thermal enhanced oil recovery (EOR) project in the world, surpassing in production both the Kern River and Belridge Fields in the San Joaquin valley of California. The field is located in Riau Province, on the island of Sumatra, in Indonesia. Duri is the second largest field in the country, producing nearly 200,000 BOPD of steamflood production. The field is operated and developed by P.T. Caltex Pacific Indonesia (CPI), a production sharing contractor to Pertamina, the Indonesian national oil company.
The DSF Project will develop over 15,000 acres of reservoir utilizing over 4,000 producing wells. At present, only about one third of the field is under active steamflood. The DSF Project is divided into twelve development units called Areas. New Areas are about 1,400 acres in size, and are developed, that is, drilled and put on injection, in about 1-3/4 to two years.
The steamflood development involves the use of symmetric patterns of varying size and configuration. Inverted seven spots, approximately 11-5/8 acres in size have been the principal pattern configuration for Area development, including the Area currently being drilled [1]*. For future Areas, inverted five and nine spots, approximately 15-1/2 acres in size are planned. This change has been implemented as a result of detailed reservoir simulation studies conducted in CPI [2,3].
The Duri Steamflood Project is unique in that it simultaneously involves the management of existing steamflood Areas, the development of new steamflood Areas, and the design of future Areas to maximize both oil recovery and production efficiency. The balancing of these three objectives is both a complex and vitally important project management task. The approach taken by CPI is a multi-disciplinary one involving development geology, petroleum engineering, and surface facility engineering. Improvements in well stimulation techniques, well completions, flood monitoring and flood design have been realized.
San Ardo Field Production Testing System Upgrade
Authors: Christianson B. A. , Berger E. L. 
Published: December 2007

ABSTRACT
In 1985, as part of a field-wide upgrade of surface facilities, Texaco's San Ardo field engineers began an extensive program to improve the quality of the field's production testing systems. Analysis of the existing systems showed that they were capable of delivering tests no more frequently than once per well per month, while the field's gauge factor ranged by ±40%. Moreover, component reliability, layout, and process control made hardware troubleshooting, maintenance, and repair difficult and slow.
The program that was completed nearly three years later created a production testing system, which while outfitted with 83% more testing equipment, delivered a fivefold improvement in testing frequency. Gauging variability was reduced to one eighth that of the replaced systems.
This paper discusses the project accomplishments in hardware design, process control, and the operator interface, which have significantly improved the quality of Texaco's San Ardo field production operation.
Heavy-Oil Dehydration Facility Retrofitted With Computer Monitoring
Authors: Strome R. K. , Beal K. P. 
Published: December 2007

ABSTRACT
The largest oil-fired oil dehydration plant in America was partially retrofitted with a state-of-the-art computer monitoring and data acquisition system. This paper describes Phase I of that system, and the benefits obtained. The new operator-interface software and future Phase II expansion plans are also discussed.
Recovery Mechanisms: Fireflooding a High-Gravity Crude in a Waterflooded Sandstone Reservoir; Countess Field, Alberta
Authors: Metwally M. 
Published: December 2007

ABSTRACT
This paper summarizes the results obtained from laboratory and field tests conducted for the Countess "B" Fireflood Project, and attempts to explain the recovery mechanisms of the fireflooding application in a waterflooded Glauconitic Sandstone reservoir of the Upper Mannville Group containing a 28°C API crude in southeastern Alberta.
Results of coreflood tests, combustion tube tests and field observations, suggest that combustion gas drive supported by efficient displacement from the burned volume is the most important mechanism in fireflooding the Countess "B" Pool and the propagation of combustion gas and water ahead of the firefront is of considerable importance for oil recovery. Laboratory observations from coreflood tests confirm that combustion gas was equally important in recovery both before as well as after breakthrough and oil production response due to fireflooding occurs almost immediately after initiating air injection. The history of the combustion gas composition and properties of the produced oil, which are not significantly different from those of the native oil, indicate the existence of a stable high temperature region and low temperature oxidation reactions. Analyses of recombined oil and gas samples simulating in-situ fireflooding conditions, indicate favorable mobility under fireflooding.
The Pilot Project is operated by PanCanadian Petroleum Limited, jointly owned with LL&E Canada Limited and supported by the Alberta Oil Sands Technology and Research Authority. The Pilot Project was initiated in 1983 and still continues. It is currently being expanded to a prototype commercial project.
Thermal Conductivity Estimation From Temperature Logs
Authors: Seto A. C. , Bharatha S. 
Published: December 2007

Abstract
Heat losses to over/underburden play an important role in determining the efficiency of a thermal oil recovery process such as cyclic steam stimulation. Thermal conductivity is a key parameter for evaluating heat losses. Since there is generally little information concerning in situ thermal conductivity values, it is often assumed in reservoir simulation models that the reservoir and its over/underlying formations possess the same value of thermal conductivity. If the over/underlying formations possess significantly higher values of thermal conductivity compared to the reservoir, the heat losses will be underestimated in calculations based on uniform thermal properties. Systematic procedures to estimate thermal conductivity values from temperature logs and core measurements are presented in this paper and applied to field and laboratory data.
Applying a Novel Steam-CO2 Combination Process in Heavy Oil and Tar Sands
Authors: Clampitte R. L. , Eson R. L. , Cooke R. W. 
Published: December 2007

ABSTRACT
It is estimated that there are 85-110 billion barrels of heavy oil reserves in the U.S.. Since the 1960's, steam has been the predominant Enhanced Oil Recovery (EOR) method for these high viscosity, heavy oil reservoirs worldwide. However, some experimentation utilizing immiscible carbondioxide injection in heavy oil reservoirs has shown encouraging results. This paper documents the efforts of a 2-1/2 year, two phase project conducted in the Midway-Sunset field of California applying a novel steam/carbon-dioxide combination process to recover heavy oil.
In many instances in thermal recovery projects, steam channeling and/or steam override reduces the efficiency of the process. This inefficiency has been corrected, or at least somewhat mitigated, through the use of steam foams. A cost effective alternative to foams was developed as part of the research phase of this project. A high temperature, stable polymer gel/surfactant solution has been developed and has proven in field tests to be extremely effective at diverting steam from steam channels and the override zone to areas of the reservoir higher in oil saturation. By accomplishing this diversion, it allowed carbon-dioxide, injected along with the steam, to enter a potentially more productive portion of the reservoir. During the 2-1/2 years of the project, nine cyclic steam stimulation wells and two continuous steam drive injection wells were treated with the novel EOR process.
Well Visualization and Analysis
Authors: Podio A. L. , McCoy J. N. 
Published: December 2007

Abstract
A system has been developed based on a powerful portable microcomputer and an integrated data acquisition package which allows real-time visualization of pumping well performance.
The system combines all the necessary elements to obtain a complete analysis of the performance of the pumping system which includes the pumping unit, the wellbore, and the reservoir.
The data acquisition package is connected to the expansion slot of the computer and consists of the necessary analog and digital channels to process data from standard transducers such as acoustic, pressure, temperature, rod load, displacement. etc. Detailed surface unit performance curves such as dynamometer, speed, acceleration, power etc. can be obtained and analyzed. When the instrument is used in conjunction with an acoustic pulse generator and receiver, it digitizes and stores the reflected acoustic signals which are digitally filtered and automatically processed to determine the liquid level. This is undertaken under program control so that a continuous recording of fluid level vs. time is obtained along with the pumping unit performance parameters.
Fluid level data is processed by the software to calculate bottom-hole pressure as well as flow into and out of the well bore. Changing the well from flowing to shut in conditions allows recording of pressure buildup data which is then interpreted in terms of reservoir parameters.
The Well Visualization display can be used as a diagnostic tool to optimize pumping well performance on a periodic basis. The present performance of the well is compared to its recorded past performance and in the case where significant differences are noted, a more detailed analysis is undertaken to recommend changes in operation or remedial actions. In critical well applications, the system can function as a stand-alone dedicated controller.