bluuebunny/crossref_metadata_2025_split huggingface dataset:
Coping with Change: Preparing for Survival and Growth—The Human Resources View
Authors: Frantz L. 
Published: December 2007

Abstract
I appreciate the chance to come and talk with you today. I began my career with Phillips Petroleum in the mid-1960s with a civil engineering degree.
Through a variety of jobs in West Texas, then the waters of Norway, I learned about the nuts and bolts of the oil business. Then Phillips asked me to take a new job ... that of vice president of human resources. A whole new kind of science was laid before me ... the science of the workforce.
It's been a real education ... and a sobering one, too, because I have learned that some big challenges lie ahead of us in the human resources in our companies. Now, I know that you may not want to hear that. Everyone here knows how tough the '80s were for the petroleum industry, especially in the engineering and research departments of the petroleum industry. I honestly don't expect the '90s to be any less turbulent but they can be more fruitful if our industry puts more muscle into the hard sciences. We need to do it now ... because we are living on borrowed time.
Maybe you read the report put out last year by the Geoscience Institute for Oil and Gas Recovery. The report said proved reserves in the lower 48 states peaked in 1961! And production peaked in 1970, except for a short-lived spike in the early 1980s when prices were much higher than they are today. The reason our energy situation isn't worse today is technology. Our strong research and engineering experience helped us pull more oil from our aging fields.
But while our engineering expertise helped us develop oilfields, we neglected another valuable resource ... people.
We are about to pay for that neglect because the petroleum industry is facing a shortage of a valuable natural resource:New employees with training in the hard sciences — the very lifeblood of our industry.
Wettability Evaluation During Restored-State Core Analysis
Authors: Hirasaki G. J. , Rohan J. A. , Dubey S. T. , Niko H. 
Published: December 2007

ABSTRACT
Wettability changes during stages of restored state core analysis were evaluated for a North Sea reservoir. The goal was to determine the proper technique for estimating the remaining oil saturation after waterflooding from core analysis.
The traditional methods for quantifying wettability, i.e., USBM and Amott indices and the Brownell-Katz correlation, were evaluated. It was found that the USBM and Amott procedures, when modified slightly, could be interpreted to give a good indication of wettability.
The traditional method of cleaning cores by Dean-Stark extraction with toluene followed by chloroform/methanol was found to be ineffective in making a core water-wet. To overcome this difficulty, we evaluated core cleaning procedures that employ a sequence of solvents. The remaining oil saturation increased from 9% with crude oil in the "as received" state to 28% with refined oil after the third cleaning.
Once the cores were made water-wet, aging the cores in a North Sea crude oil returned them to a mixed-wet state. However, the restored state cores were not as oil-wet as the "as received" state cores. Even after aging, there was a significant difference between the cores cleaned by Dean-Stark extraction and by a sequence of solvents. The mixed-wet condition with the North Sea crude oil is, therefore, expected to apply to the field: the crude oil base number, isoelectric point, effluent pH during core floods, and bottle wettability tests support this contention.
Examination of the Brownell-Katz number correlation and the capillary pressure curves showed that much of the remaining oil saturation in a mixed-wet core, during core analysis could be due to retention by a capillary end effect. This was supported by a CT scan of the core. In this mixed-wet reservoir, the remaining oil saturation is not equal to the residual oil saturation, but must be calculated using the appropriate relative permeability curve and the effect of buoyancy.
An Integral Equation Formulation for Two-Phase Flow and Other Nonlinear Flow Problems Through Porous Media
Authors: Chen Zhongxiang , Bodvarsson G. S. , Witherspoon P. A. 
Published: December 2007

ABSTRACT
Many flow problems encountered in petroleum reservoir engineering are characterized by nonlinearities and are difficult to solve analytically. The concept of a relative mass flow rate function is used to arrive at an integral equation formulation for some of these nonlinear flow problems. This formulation has some distinct advantages over existing methods of handling such nonlinear flow problems because of its generality and simplicity.
The problems considered include two-phase fluid displacement including the effect of capillary pressure and isothermal transient flow of gas. These problems can be described by nonlinear parabolic partial differential equations that have self-similar solutions.
Exact semi-analytical solutions are obtained which can be easily evaluated using a rapidly-converging iteration process. A new understanding of the mechanism of the displacement of a non-wetting phase by a wetting phase has been developed that is dependent on a critical value of the dimensionless injection rate constant.
Ultrasonic Measurements of the Bubble Nucleation Rate During Depletion Experiments in a Rock Sample
Authors: Hoyos M. , Moulu J-C. , Deflandre F. , Lenormand R. 
Published: December 2007

ABSTRACT
By means of an ultrasonic technique, the nucleation rate J in depletion experiments has been measured. An array of 8 ultrasonic transducers, fixed along a rock sample, continuously scans the sound velocity and the attenuation in the sample. Due to the great difference in sound velocity between the gas and the liquid, bubbles are easily detected and located by transducers. The sample is also set up with capillary tube at one end for the observation of production by the displacement of a meniscus. The main advantage of ultrasonic technique is the capacity to work at high pressure and temperature. An improvement in the accuracy over the standard techniques is observed.
Analysis of 15 Years of Thermal Laboratory Data: Relative Permeability and Saturation Endpoint Correlations for Heavy Oils
Authors: Frizzell D. F. 
Published: December 2007

ABSTRACT
Fifteen years of laboratory high temperature relative permeability and endpoint saturation data are analyzed. Equations are given for estimating the irreducible water and residual oil saturation to water, gas and steam based on temperature, crude oil API gravity, and absolute permeability to water. Other equations provide estimates of the permeability endpoints. These equations are applicable for heavy oils in the gravity range of 7° to 20° API, the temperature range of 75° to 400°F, and for unconsolidated sands. The calculated estimates should serve as initial input for reservoir computations; they do not substitute for measured laboratory data.
Laminated Sands: An Assessment of Log Interpretation Accuracy by an Oil-Base Mud Coring Program
Authors: Dawe B. A. , Murdock D. M. 
Published: December 2007

ABSTRACT
An assessment of log interpretation accuracy in laminated sand/shale intervals of selected Malay basin formations has shown excellent overall agreement to core derived standards of hydrocarbon pore volume. In the reservoirs studied the log interpretation indicated 4.7% less original oil-in-place overall. Log calculated hydrocarbon pore volume ranged from +2 to −18% of the core derived values in individual reservoirs.
Accurate and precise standards of hydrocarbon pore volume were derived from a coring program that required the development of an oil-base mud system, closely monitored drilling and coring operations, totally integrated logistics and pertinent core testing procedures. Extensive quality control measures comprising mud system monitoring by interfacial tension measurements, chemical tracing of the mud system, invasion studies by core layering tests and core analysis procedures were implemented to validate the core data.
Representative core porosity and saturation data were weighted to emulate logging tool response. The simulated log responses were compared to actual log responses to identify and quantify intervals of difference.
Spin Echo Magnetic Resonance Logging: Porosity and Free Fluid index Determination
Authors: Miller M. N. , Paltiel Z. , Gillen M. E. , Granot J. , Bouton J. C. 
Published: December 2007

Abstract
The paper describes the first spin echo Magnetic Resonance Imaging Logging (MRIL*) system. The system makes measurements while logging and does not require special borehole treatment. The tool employs static and radio-frequency magnetic fields to perform downhole the spin-echo magnetic resonance measurements with short "dead time" that previously have been possible only in the laboratory.
Logs of lithology independent porosity, irreducible water saturation and fluid diffusion coefficient are provided from real-time analysis of the spin-spin relaxation time (To) decay of the fluids contained within the pore space of the formation. Spin-lattice relaxation time (T1) behavior is directly measured by the MRIL system.
Engineering prototypes have undergone several field tests, including two tests at the Conoco Borehole Test Facility well in Newkirk, Oklahoma. Field data, including the demonstration of accuracy and repeatability are discussed. The magnetic resonance logs correlate well with measurements of porosity and irreducible water saturation made on core samples and with porosity data from standard density and neutron logging tools.
Such data, from magnetic resonance logs, can be applied to the determination of porosity and irreducible water saturation, and thus to the estimation of permeability.
A Comprehensive Study of Pressure Transient Analysis with Sorption Phenomena for Single-Phase Gas Flow in Coal Seams
Authors: Anbarci K. , Ertekin T. 
Published: December 2007

ABSTRACT
This paper identifies the need for the development of specialized solutions for pressure transient analysis in coal seams and, subsequently, provides a comprehensive solution package for these reservoirs. The proposed solutions are applicable to radial systems with finite wellbore radius and with either an infinite outer boundary, a constant pressure outer boundary or a closed outer boundary. At the inner boundary constant pressure or constant terminal rate cases can be specified.
The single-phase flow formulation for coalbed methane includes non-equilibrium sorption phenomena in the coal matrix and laminar gas transport in the natural fracture network (cleat system). The transport of methane in the coal matrix is described by using spherical elements. The mathematical models which account for unsteady state and pseudosteady state matrix/fissure methane transfer are incorporated to the transport equation.
In order to obtain a closed form solution in real time domain and avoid the pitfalls of numerical inversion approximate inversions of the solutions from the Laplacian space are also developed. These closed form solutions are found to be in good agreement with the numerically inverted solutions. The effects of different models of matrix/fissure flow on the solution are also discussed. The validity of the proposed analytical solutions are checked against a numerical simulator and comparisons showing good agreements between the two are presented.
The solution package describes forward solutions which have the potential to be used in an interpretation method for in-situ characterization of coal seams and other gas reservoirs where adsorption and desorption phenomena are considered to be active.
Horizontal Well Test Analysis System
Authors: Suzuki K. , Nanba T. 
Published: December 2007

Abstract
In this paper, rigorous automated horizontal well test analysis system is presented to obtain vertical and horizontal permeabilities, and skin factor for single phase and primary porosity reservoirs, which system is applicable in both constant and variable rate cases.
Although a plenty of papers on transient behaviour of horizontal wells have been published, the following two important aspects in terms of real pressure data analysis have rarely beentouched.
Firstly, most of the existing methods are based on the assumption that production rate isconstant. However, this assumption is rarely acceptable, especially for the reservoirs with low vertical/horizontal permeability ratio (KV/KH) where production rate usuallydecreases rapidly. Secondly, the early-time data, which is critical to estimate KV/KH are often masked by the wellbore storage effect.
The developed analysis system overcomes the difficulties mentioned above by using a robust nonlinear regression algorithm. Some examples including real field data are presented in this paper.
The Use of Modern On-Site Bioremediation Systems To Reduce Crude Oil Contamination on Oilfield Properties
Authors: Hildebrandt W. W. , Wilson S. B. 
Published: December 2007

ABSTRACT
Oilfield properties frequently have areas in which the soil has been degraded with crude oil. Soil contaminated in this manner is often considered either a hazardous waste or designated waste under regulatory guidelines. As a result, there is often concern about an owner's liabilities and the financial institution's liabilities whenever oilfield properties are transferred to new operators, abandoned, or converted to other uses such as real estate. There is also concern about the methods and relative costs to remediate soil which has been contaminated with crude oil.
Modern, well-designed, soil bioremediation systems are cost-effective for the treatment of crude oil contamination, and these systems can eliminate an owner's subsequent liabilities. Compared to traditional landfarming practices, a modern on-site bioremediation system (a) requires significantly less surface area, (b) results in lower operating costs, and (c) provides more expeditious results. Compared to excavation and off-site disposal of the contaminated soil, on-site bioremediation will eliminate subsequent liabilities and is typically more cost-effective.
Case studies indicate that on-site bioremediation systems have been successful at reducing the crude oil contamination in soil to levels which are acceptable to regulatory agencies in less than 10 weeks. Totals costs for on-site bioremediation has ranged from $35 to $40 per cubic yard of treated soil, including excavation.
Laboratory/Field Study of Oil-Soluble Resin-Diverting Agents in Prudhoe Bay, Alaska, Acidizing Operations
Authors: Strassner J. E. , Townsend M. A. , Tucker H. E. 
Published: December 2007

Abstract
Treatment of long intervals of varying permeabilities and thief zones requires fluid diversion control to assure well distributed fluid placement. Oil Soluble Resins (OSR) , when properIy appl i ed, ar e effective, readily removable diverting agents. Application of laboratory studies of 15 OSR products from 5 service companies combined with additional OSR field experiments at Prudhoe Bay ( PB) , br ought about the use of higher concentrations and larger size OSR particles and resulted in improved diversion during acid stimulation and scale inhibitor squeeze treatments. Successful OSR field applications depend both on selecting proper OSR particle size distributi ons and sufficient OSR concentrations for rapid bridging on pores and/or fractures being contacted. Tests of sand/gravel packs, confirmed that effective sealing was achieved when the median OSR size was equal to or greater than 1/3 of the calculated mean sand pore diameter. With fractured cor es, however, effective seal i ng by OSR concentrations up to 10 wt% required that 1020% of the OSR particles be as large or slightly larger than the fracture width. Smaller volumes of higher OSR concentrations were more effective in diversion than larger volumes of lower concentrations. Generally, a broad particle size distribution was desirable for sealing fractures whereas fine particle sizes were better for 350 md to 3500 md sandstone cores.
A Comprehensive Mechanistic Model for Upward Two-Phase Flow in Wellbores
Authors: Ansari A. M. , Sylvester N. D. , Shoham O. , Brill J. P. 
Published: December 2007

ABSTRACT
A comprehensive model is formulated to predict the flow behavior for upward two-phase flow. The comprehensive model is composed of a model for flow pattern prediction and a set of independent models for predicting the flow characteristics such as holdup and pressure drop in bubble, slug and annular flows.
The comprehensive model is evaluated by using a well databank that is composed of 1775 well cases covering a wide variety of field data. The performance of the model is also compared with the six commonly used empirical correlations.
The overall performance of the model is in good agreement with the data. In comparison with the empirical correlations, the comprehensive model performs the best, with the least average error and the smallest scattering of the results.
Casing Crush Resistance Loss to High-Density Perforating: Casing Tests
Authors: King G. E. 
Published: December 2007

Abstract
The tests on crush resistance loss in casing following high density perforating has been expanded from the model study of SPE 18843 to include several perforated casing samples. The test set now includes high density, very large hole perforations in 9-5/8" and spiral and planar, high density patterns in var-ious casing sizes. The effect of hole size and location have now been separated from the effects of the explosion of the charge. Samples of full size, perforated casing have been compared for crush resistance to companion samples of casing drilled with the same size and pattern of holes.
New, Generalized Criteria for Determining the Level of Underbalance for Obtaining Clean Perforations
Authors: Tariq S. M. 
Published: December 2007

ABSTRACT:
New criteria for estimating underbalance requirements for obtaining clean perforations are presented. These criteria are based on analysis of flow velocities and pressure gradients in the near wellbore region at early times using finite element method, existing field data and a physical model of perforation cleanup. The results indicate that the required level of underbalance is one that will introduce non-Darcy effects in the vicinity of perforations at early times. Simple equations based on pseudosteady-state, radial and turbulent flow in the crushed zone have been presented to approximate the required level of underbalance for a given set of formation and fluid properties.
Automated Gas Delivery to Gas Treatment Plants Saves Flare Gas Volumes and Improves Field Operations
Authors: Fletcher B. W. , Kowalski R. A. 
Published: December 2007

Abstract
An automation project to control gas deliverabilities and gather production data was installed at the ARCO Oil and Gas Company's Empire Abo Unit located just east of Artesia, New Mexico. The unit has 383 wells and produces approximately 4000 BOPD and 65 MMCFD. Eleven satellite batteries throughout the unit handle the unit's liquid and gas production. Each satellite delivers gas to two different gas plants operating in the area. Due to the New Mexico state gas production regulations, the unit is limited to a gas delivery rate of 65 MMCFD. Unit operational problems occur when either one or both of the plants require a change in gas delivery. Before the automation control was installed, field gas production was flared at the plant when plant throughput decreased. Unit operations personnel manually adjusted the gas delivery by shutting in wells. When plant throughput increased, plants were not fully loaded until additional production was put on stream. To minimize the operational problems and the amount of revenue lost to flared gas, an automation system was installed to the provide steady, maintainable gas flow to each plant under varying conditions. Automation equipment at each satellite battery measures and controls gas flow to each pipeline to a specified setpoint.
When a change in deliverability is desired by a gas plant, plant personnel enter the desired rate at a remote terminal located within the plant. That change is communicated to the central field office unit, which in turn establishes new flow setpoints and communicates the same to the individual satellite batteries remote controllers. In addition the system monitors satellite batteries operations for abnormal or alarm conditions and provides a means for notifying the operating personnel.
A Production Optimization System for Western Prudhoe Bay Field, Alaska
Authors: Barnes D. A. , Humphrey K. , Muellenberg L. 
Published: December 2007

ABSTRACT
For almost a decade the Prudhoe Bay field on the North Slope of Alaska has produced at a yearly average offtake rate of 1.5 million stock tank barrels of oil per day. As the reservoir depletes and field gas-oil ratios (GORs) increase, gas handling constraints make it difficult to achieve oil rate targets. The Western Production Optimization Model (WPOM) was developed by BPX to deliver an offtake strategy that maximizes oil rate while minimizing processed gas. The model is based on the "incremental GOR" concept, or the lowest GOR selection for the next incremental barrel of produced oil.
The model is supported by a sophisticated Supervisory Control and Data Acquisition system. Data are transferred into a large relational database in BPX's Anchorage office, allowing access to current well performance data. Oil rate vs. GOR functions are generated for the ~460 BPX operated production wells. The WPOM combines well functions in an incremental manner, honoring facility limitations, to generate an optimized oil rate vs. gas rate curve. For any given gas rate, the curve defines an optimized oil rate target, which is then broken down into targets for the production facilities, flowlines, and individual production wells. The model can be updated in a matter of minutes to allow for evaluation of sensitivities or to account for changing field conditions.