bluuebunny/crossref_metadata_2025_split huggingface dataset:
Performance of Beta Titanium in a Salton Sea Field Geothermal Production Well
Authors: Holligan D. , Cron C. J. , Love W. W. , Buster J. L. 
Published: December 2007

ABSTRACT
Carbon steel tubulars have shown an unacceptably short life in Salton Sea field geothermal production wells. Corrosion testing identified a beta titanium alloy which is immune to corrosion and cracking in the saline brine.
A development program has resulted in the commercial production of 9-5/8 in. (24 cm) betatitanium. A 1,500 ft (457 m) string was threaded with a premium connection. The string has been run and retrieved twice with less than 1% of the connections requiring shop repair.
Because of its modulus, beta titanium has a lower collapse resistance than carbon steel, butacceptable performance can be obtained by increasing the wall thickness. However, titanium's low modulus is also beneficial, because it reduces the stress level experienced when a cemented completion is thermally cycled.
Good performance in this geothermal service makes the beta titanium a candidate for some hostile oil and gas environments.
How To Build and Hold a 90° Angle Hole
Authors: Jourdan A. P. , Mariotti C. 
Published: December 2007

ABSTRACT
Horizontal drilling is now a well established technique with growing popularity for exploiting a number of reservoirs which would otherwise be uncommercial.
However a horizontal well requires a substantial engineering work, compared to a conventional deviated well. The target has new dimensions. The design of the optimum trajectory must take into account a large number of datum. Directional control is severe. Drags and torque have an increased and adverse action on the overall drilling mechanics. The inverted drill string is a new concept.
This paper provides guide lines for planning a horizontal wellbore. Among the 16 horizontal wells drilled by ELF AQUITAINE, typical application of three different methods are also reported.
A Dual Shale Pore Pressure Detection Technique
Authors: Bryant T. M. 
Published: December 2007

Abstract
A dual-basis application of the shale resistivity pore pressure detection technique has been developed that emphasizes the availability of MWD formation resistivity measurements while minimizing input from the operator.
This method is based upon accepted petrophysical and mechanical principles.
Operator inputs are streamlined, requiring one-time-only entry of local air gap, water depth, normal pore pressure gradient, and a baseline value of shale water resistivity.
MWD shale resistivity is utilized in the Archie equation to solve for shale porosity. The Baldwin-Butler normal shale compaction relationship uses this porosity to estimate an actual vertical matrix stress component. Overburden pressure is calculated using a generalized Tertiary basin equation. The difference between normal and actual matrix stress values represents the magnitude of change from normal to abnormal pore pressure conditions.
Unlike traditional empirical approaches and other, more recent petrophysical-mechanical techniques, this technique does not need data from a normally pressured section for establishment of a normal trend, does not require the degree of local knowledge associated with the use of overlays, and involves neither guesswork nor comprehensive expertise on the part of the operator.
The model has been successfully tested on approximately 100 well locations in the Gulf of Mexico, offshore Alaska, North Sea, and Niger Delta. Field examples are presented that demonstrate the technique's consistency with principles, quantitative accuracy, and relative ease of use.
The Effect of Intercalated Barriers on Heavy Oil Recovery by Steam Injection
Authors: Zeng Yie , Wang Jianshe , Huang Yan Zhang , Liu Wenzhang 
Published: December 2007

ABSTRACTMany heavy oil reservoirs in China are charactered with multi-layer horizons with barriers in between of them. During steam injection those very tight clay layers act as heat absorbing media with heat conductivity varies with the changing of aqueous saturation and as barriers against steam transpiration and/or penetration. However, very few works have been done on this subject, and the consequent effect on steam injection remained unknown.In this work, started with brine/air capillary pressure curve measurement of the barriers at different temperature by vapour pressure desorption method, relative permeabilities were calculated, which would be otherwise extremely difficult to be obtained by conventional appoaches if is not imposible.Overall effects of barriers on steam stimulation and steam flooding were studied by numerical simulation based upon the experimental data on the effects of: absolute permeability; capillary force; barrier distribution; and heat loss. Results from simulation suggested that capillary forces of the barriers contribute about 7% increase in terms of heavy oil production, oil steam ratio and recovery efficiency. Attempts of explanation of these positive influence were made.
Quality Assurance for PVT Sampling and Testing - Endicott Field, Alaska
Authors: Pestak M. W. , Pande P. K. , Swanson G. 
Published: December 2007

ABSTRACT
Endicott is an offshore North Slope of Alaska field with approximately 1 billion barrels of oil in place. An extensive PVT sampling program was conducted shortly after field start up in 1987 in order to capture true "initial condition" fluids for laboratory studies. This paper is a case history of an unusually successful and thorough quality assurance program which covered each step from wellsite sampling to final PVT laboratory report generation.
Wellsite sampling practices utilized to obtain representative bottomhole fluids from 5 wells and surface samples from 19 wells included well conditioning, customized sampling techniques, and field checks for sample quality.
In the PVT lab, a rigorous test sequence was followed to identify data quality problems due to loss of sample integrity or inadequately precise laboratory procedures. Raw, unsmoothed data were reviewed to track problems to their root causes. Emphasis was placed on material balance checks, calibration procedures, and comparison of properties which were measured by different techniques.
Major contributions in this paper include design details of an integrated PVT quality assurance program, a case history of implementing such a program with real problems and solutions, and a meaningful assessment of the quality of the laboratory PVT data.
A Comprehensive Analysis of Steam Foam Diverters and Application Methods
Authors: Eson R. L. , Cooke R. W. 
Published: December 2007

ABSTRACT
Steam injection in California heavy oil reservoirs began in 1960 in Yorba Linda. Within the first five years, more than 280 additional thermal projects were initiated in California, thus thrusting thermal enhanced oil recovery (EOR) to the forefront. Today, it continues to dominate EOR, accounting for approximately 78% of all the oil produced by EOR methods. Despite the fact that steam injection is the most widely accepted EOR technology, it is not without its problems.
Overall, recovery of oil has always been hampered by gravity segregation within the steam flood area as well as channeling from directional permeability or viscous fingering. After steam has been injected for some period of time, these areas of high permeability tend to act as steam thieves. Once swept of oil, the pressure drops between the injector and the producer causing the depleted zones to receive the majority of the injected steam. The less permeable, oil-saturated areas remain virtually untouched by continued steaming. In an effort to reduce channeling and steam injection into the depleted, steamed-out portions of the reservoir, various foaming surfactants and methods of application have been experimented with in the laboratory. This experimentation has been progressing for more than 20 years and has been followed by extensive field testing in heavy oil reservoirs in the San Joaquin Valley.
This paper deals with the development of the field application technology from its first pilots in 1974 to current field practices. Some discussion is provided regarding outside driving forces which have a substantial influence on not only the rate of growth of foam applications, but the methods of application as well.
New Control for Completing Multizone Steam Injectors Utilizing Limited/Metered Entry Techniques
Authors: Schwab C. M. , Mitchell III R. F. 
Published: December 2007

ABSTRACT
Steam mass placement can be controlled by utilizing new tubing limited entry systems and procedures when completing multizone single string injectors.
A metered entry steam injection system that has been field tested is described. The system incorporates two phase flow control, limited entry devices and special completion design and analysis techniques.
Solvent and Acid Stimulation Increase Production in Los Angeles Basin Waterflood
Authors: Dayvault G. P. , Patterson D. E. 
Published: December 2007

ABSTRACT
A detailed review of 69 acid stimulation jobs completed from 1984 through 1986 in the Inglewood field, California led to mechanical and chemical improvements that dramatically increased production response to acidizing. Average peak oil production gain from stimulation has increased from 22 to 45 bopd using the improved system. Significant procedure changes introduced in late 1987 included using a 40 foot circulation wash tool, overflushing acid immediately and modifying the stimulation chemicals. Damage mechanisms being treated are: 1) calcium carbonate scale; 2) asphaltenes and paraffins; 3) migrating clays and formation fines, and 4) drilling and completion fluid damage caused while gravel packing.
An Engineering Approach to Gas Anchor Design
Authors: Campbell J. H. , Brimhall R. M. 
Published: December 2007

ABSTRACT
Free gas is the most common cause for low pump efficiency in sucker rod pumping wells. The installation of a gas anchor on the bottom of the downhole pump is a method used to help combat this problem. This paper describes improved gas anchor design for sucker rod pumping wells with gas problems. A computer program is described which will aid in the design of a gas anchor system and which evaluates pressure drops to determine the efficiency of the gas anchor.
The major parameters in gas anchor design are gas bubble velocity, diameter of the mud anchor, length of the dip tube, and the pressure drops associated with the gas anchor system. Validation of rules of thumb used in the past for gas anchor design is made. Gas bubble velocity of 0.5 ft/sec is a valid assumption if the API gravity of the liquid is greater than 300, the flow is turbulent and the temperature is greater than 100 OF. The principles behind the operation of an efficient gas anchor are presented with suggestions on how more efficient gas anchors may be designed by production engineers.
Engineered Perforation Design and Evaluat
Authors: Morris C. W. , Ayoub J. A 
Published: December 2007

ABSTRACT
Underbalanced perforating has become accepted as one of the best methods for creating open, undamaged perforations.1’2 However, the magnitude of the underbalanced pressure which can safely be used to complete the well is a major uncertainty, especially in unconsolidated or poorly consolidated sands. This paper describes an integrated well data analysis procedure to estimate the safe underbalance perforating pressure and the well response to a short ‘cleanup’ flow period. The design procedure utilizes open-hole logs, fluid data, and reservoir data to determine the formation mechanical properties and to build a reservoir fluid flow model. The design results can then be compared to the actual well performance. This is evaluated using transient pressure analysis of the data acquired in conjunction with the underbalance perforating. A field example is used to illustrate the design and evaluation of a tubing-conveyed perforating well completion.
An Effective Completion Method Utilizing the Tubing Stability Latch
Authors: Gonzalez M. E. , Rubbo R. P. , Moody W. D. 
Published: December 2007

ABSTRACT
The successful design of a cost effective oil or gas well completion system depends on the efficient use and integrity of the production tubing and related equipment. A tubing to packer landing technique made possible through the use of the Tubing Stability Latch (TSL) is described which can reduce the chance of catastrophic equipment failure and allow the use of lower cost production tubing when compared with traditional techniques. The characteristics of several tubing to packer sealing arrangements including the TSL are compared.
Predicting Horizontal/Slanted Well Production by Mathematical Modeling
Authors: Chang M-M. , Tomutsa L. , Tham M. K. 
Published: December 2007

ABSTRACT
A horizontal and slanted well model was developed and incorporated into BOAST, a black oil simulator, to predict potential production rates for such wells. The slanted/horizontal well model can be used to calculate the productivity index, based on the length and location of the wellbore within the block, for each reservoir grid block penetrated by the slanted/horizontal wellbore. The well model can be run under either pressure or rate constraints in which wellbore pressures can be calculated as an option of infinite-conductivity. The model is easy to use and can simulate the performance of multiple horizontal/slanted wells in any geometric combination within reservoirs.
The model was checked against the analytical formulas of transient wellbore pressure in an infinite slab reservoir. A close match having an average deviation of only ±4% was found between the analytical formula and the fully penetrating slanted well model after a production period of early radial flow. A good agreement was also obtained between the simulation results of the horizontal well model and published analytical curves. This is the first reported mathematical model that has been validated for slanted well simulation.
Production rates from vertical wells, horizontal wells, and slanted wells of variable well lengths in a field of 40-acre well spacing were compared. During the pressure-depletion phase, about the same improvements in production rates over those of vertical wells were observed for horizontal and slanted wells which extended the same length from the plan view.
Horizontal/slanted wells showed more advantage over vertical wells at lower formation permeability (≤ 1 md) than at higher permeability (≥ 100 md). The effects of eccentricity on horizontal well performance were examined. The effects of vertical permeability on the production rates of horizontal and slanted wells were also studied. As expected, the vertical discontinuity of reservoirs showed insignificant effects on the production from slanted wells.
Field simulations of a horizontal well and of multiple slanted/horizontal wells demonstrated the application of the developed well model.
Second Law Analysis of Petroleum Reservoirs for Optimized Performance
Authors: Civan F. , Tiab D. 
Published: December 2007

ABSTRACT
The second law of thermodynamics determines the practical limits of operating systems. However, within these limits, conditions leading to optimum performance can be found.
In reservoir analyses the conditions or variables which are controllable are somewhat limited. These include well head pressure, production or injection rate, number of wells and their locations and the recovery technique. The efficiency of reservoir exploitation decreases as the entropy generation increases. Since entropy generation translates into irreversible loss of fluid energy, the operating conditions of a reservoir should be selected to minimize the entropy generation over the productive life of the reservoir.
In this paper, it is shown how entropy generation function is calculated and used as a guideline for selecting the conditions leading to high ultimate recovery. This is accomplished by calculating the cumulative entropy generation over the reservoir volume and the production period and by determining the conditions minimizing the entropy generation.
Detection of Interlayer Communication at a Fault Using Type Curves
Authors: Tiefenthal S. A. , Wattenbarger R. A. 
Published: December 2007

ABSTRACT
Previous work has shown that it is possible to detect the distance to a sealing fault. Recent work by several authors has been directed towards analyzing the effect of partially communicating faults on pressure transient responses. This current work concerns itself with a formation that has a fault which, rather than partially sealing the producing formation, allows influx from an adjacent formation (such as underlying aquifer). The goal is to determine the distance to this interlayer communication and the degree of communication by the use of type curve analysis.
The response caused by the producing zone alone can be filtered out using desuperposition. The remaining response is the "deviation function" caused by the "leaking" fault. Type curves were developed based on this deviation function response using dimensionless times and pressures and a dimensionless fault transmissibility as a matching parameter. The development of these type curves was based on numerical simulation.
The analysis technique is straightforward. The actual pressure response is subtracted from the extrapolated initial semi-log straight line and plotted. The resulting plot, which is the deviation function caused by the leaking fault, is compared to the type curve. The time match point provides the wel1-to-fault distance, while the matching parameter reveals the transmissibility of the interlayer communication.
A field example from a North Sea oil field illustrates the geological conditions under which the analysis technique is applicable, and how it is applied. The pressure transient data from an actual well test were first corrected for tidal effects and then analyzed using the above technique. As suspected from seismic and geologic interpretations, communication between the reservoir and an underlying aquifer could be detected. The distance to the leaking fault and its transmissibility were found. In this example case, the new analysis technique was able to provide input data essential to the reservoir description.
A New Approach for Decline-Curve Analysis
Authors: Duong A. N. 
Published: December 2007

Abstract
This paper presents a new approach which can be used for the computer-automated curve fitting for decline curve analysis. Arps' empirical-decline-curve equations for the exponential, hyperbolic and harmonic solutions are manipulated to produce a single relation which is a linear combination of variables: q, Np and qt. A linear multiple regression is performed for these variables to obtain optimal coefficients of the relation which are related to qi, Di and b in Arps' equations. Once qi, Di and b are known, the future production rate can be determined. Thus, the type-curve matching is not needed.
The proposed approach is, therefore, useful in application of the computer-aided analysis for the production forecast for oil and gas wells.
Current Trends in the Placement of Proppant During Fracture Stimulation in Southern Oklahoma
Authors: Freeman E. R. , Worley H. W. , Marple G. T. 
Published: December 2007

ABSTRACT
Fracture stimulations in Southern Oklahoma over the last few years, that utilize sand as proppant, have undergone a marked change toward more aggressive sand placement. Since initial development of ‘modified fracturing treatments’ in Carter County was reported in 19871, the number of jobs employing higher sand concentrations has continued to wise. This manifestation may be supported by post frac well performance data, which in Carter county indicates that the more aggressive or higher sand concentration treatment is the economically preferable stimulation. The progressive placement of higher sand concentrations has since become more frequent in other counties (e.g. Stephens), and producing formations (e.g. Tussy and Deese).
The Progressing Cavity Pump: Principle and Capabilities
Authors: Saveth K. J. , Klein S. T. 
Published: December 2007

ABSTRACT
The progressing cavity.(PC) pump has been. used, as a fluid transfer pump for many years. From various industrial applications to surface transfer of oilfield fluids. Within the last several years the progressing cavity pump has been widely used as a method of artificial lift for the oil and gas industry. The use of progressing cavity pumps as a means of artificial lift has numerous advantages over other artificial lift methods. Through years of research and development in progressing cavity pump design, the production and lift capabilities are expanding to cover a wide range of applications. With various elastomeric materials available, a wide range of well fluids can be handled efficiently using the progressing cavity pump. The ability to pump abrasive fluids lends itself well to many of the viscous sand laden crudes found throughout the world. With present lift capabilities from 4000 feet and capacities to 1000 BFPD, the progressing cavity pump is ever expanding and becoming a viable alternative for wells utilizing artificial lift.
Design of Acid Fracturing Treatment with Double Fluid System
Authors: Wang Hong Xun , Zhou Yun Xu 
Published: December 2007

ABSTRACT
A new acid fracturing design model called double fluid system model is presented in this paper. In this model the difference in the ability to create fracture geometry between acid and pad fluids is considered. The fracture width during acid fluid injection period does not increase, nor remains constant as some papers stated, but decrease. This may be inportant because many design aspects, such as acid concentration along the fracture, effective fracture length and acid–etched fracture conductivity etc., depend on fracture width. According to this new idea the concentration in the fracture is lower, and the effective length is shorter because the fracture width is narrower than the data published previously.