bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Economics of the West Virginia Natural Gas Exploration and Production Industry, 1977-1987
Authors: Iledare W. O. 
Published: December 2007

ABSTRACT
In this paper, the structure, conduct and performance of the West Virginia natural gas producing industry is discussed. The competitiveness of the gas industry is measured empirically using the concept of concentration ratio and other features of industry structure. Trend analysis of the industry activities and outcomes shows no evidence of "market power" among West Virginia gas producers. The general drilling trends in West Virginia paralleled those of the entire U.S. Similarly, the trends in new gas discoveries, real wellhead price, gas exploratory drilling, to a large extent, are closely related. It was noted, however, that oil and gas operators in West Virginia took less risk in exploratory drilling between 1981-1987. It would appear that more exploration activities must be undertaken to reverse the current downward trends in new reserve additions in the 1990s.
Energy Considerations Associated With the Mechanics of Hydraulic Fracture
Authors: Advani S. H. , Lee T. S. , Moon H. 
Published: December 2007

ABSTRACT
The relative contributions associated with the fracturing fluid dissipation and formation fracture toughness mediated energies play a pivotal role in the design and potential optimization of hydraulic fracture evolution in multi-layered reservoirs. A critique of the salient hydraulic fracture process controllable and uncontrollable parameters is presented. The roles of fracturing fluid rheology, flow rate, reservoir elastic properties, fracture toughness values, and in situ stress contrasts are highlighted by evaluating fracture propagation in isotropic models with pre-defined fracture geometries as well as a symmetric three—layered elliptic crack model. Model validation is conducted by comparison of selected numerical results from these simplified models with previously reported model responses. Application of the formulated concepts is illustrated in terms of hydraulic fracture configuration evolution.
Dukhan Field Multiwell Corrosion Study
Authors: Sharshar A. E. , Nutt R. L. , Smith P. M. 
Published: December 2007

ABSTRACT
Multi-well Data base techniques greatly facilitate the storage, retrieval and manipulation of well log data.
This paper reviews a multi-well approach to the analysis of corrosion logging measurements across 50 wells in the Dukhan field.
The objective of the study was to understand corrosion phenomena throughout the field and to determine the relationships between corrosion in different wells.
Multi-well techniques to optimize the normalisation of logging tool responses to metal losses are described.
Dukhan field production/injection and corrosion problem history is reviewed followed by a description of the basic Corrosion Evaluation logging tool measurements and their incorporation into the multi-well data base.
Results, both field wide and selected individual well, are presented and discussed. These results indicate that the most significant corrosive mechanism is inner wall erosion in the dump flood injection wells. However mild, outer wall metal loss is observed, in some cases, across the un-perforated aquifers suggesting the possibility of other corrosion phenomena which should be monitored in future casing corrosion evaluation programs.
Two-Way Man-Machine Communication Systems for Computer Production Control
Authors: Maruska V.J. 
Published: December 2007

American Institute of Mining, Metallurgical and Petroleum Engineers Inc.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Profitable implementation of Computer Production Profitable implementation of Computer Production Control (CPC) on a large-scale basis requires a highly sophisticated system for man-machine communications. One such system has been developed and is currently undergoing further refinement. Specific factors considered in its development include:
Minimum initial hardware investment with flexibility to incorporate less expensive hardware as it becomes available. Two-way communications with total security. Device-independent system capable of communicating with teletypewriters, cathode ray tubes, card readers, typewriters, matrix keyboard consoles, line printers, etc., with equal ease. Input/output designed for use by nontechnical personnel with maximum manpower efficiency. Message handling software is user oriented and FORTRAN compatible.

Introduction
Computer Production Control (CPC) is the concept of computer controlled telemetering to automatically, remotely, and continuously perform control, measurement, alarm monitoring, and data-gathering functions associated with oil and gas production. Computer hardware is currently production. Computer hardware is currently available which will enable operating several thousand wells under a CPC concept with the aid of a single CPC computer system. However, two general problem areas are encountered in problem areas are encountered in converting to such a total CPC concept:
Some leases cannot justify physical control or monitoring due to geographic, economic, or other considerations. However, a total CPC concept requires that all data of a specific category must be stored within the computer system using the same format regardless of the method originally employed to acquire this data. Incorporating these leases into a CPC operation therefore requires that the data-gathering functions be manually performed and reported to the computer via some type of remote input/output station.
Status of New Wave Forecasting Techniques
Authors: Baer Leodolph , Adamo L.C. , Hamm D.P. 
Published: December 2007

American Institute of Mining, Metallurgical and Petroleum Engineers, Inc.

Abstract
Basic concepts of ocean waves as used in wave-forecasting are reviewed; the historical development of forecasting in the U. S. A. is traced from the first empirical approach of Sverdrup-Munk to the spectral techniques of Pierson-Tick-Baer, and Baer-Adamo-Hamm. Pierson-Tick-Baer, and Baer-Adamo-Hamm. The advantages and shortcomings of the various systems are discussed. Examples of the use of spectral forecasts are given, and some remarks are made on future work.

Introduction
There have been many new developments in wave forecasting within the last few years. In this paper we will attempt to put these in perspective, explain them, show the advantage of perspective, explain them, show the advantage of using these new techniques, and admit the outstanding problems which have not yet been solved. Modern unified physical concepts allow this explanation to be elementary and yet comprehensive. Before we really understood what was going on we had to resort to many complicated empirical and semi-empirical methods which were wrong, but, happily, such is no longer the case.
As a basis for this discussion, let us consider what a wave field really is. When we look at the surface of the sea over which wind is blowing, the sea looks quite irregular. Figure 1 is a contour analysis of an area covering 2670 ft. by 1770 ft. The wind was about 16 knots, significant wave height about 7 ft. Short wavelengths have been smoothed out. The shaded areas are troughs. Occasionally the waves peak up and are shaped like pyramids or mounds. Some of the waves have relatively long crest lengths; others appear to be higher or lower, or moving in different directions. Our first order of business is to define the sea surface in some precise manner so that we can objectively compare various techniques.
In the bottom trace in Figure 2, we have reproduced a wave record that could have been taken with a wave staff, a bottom mounted pressure sensor, a floating accelerometer, or an pressure sensor, a floating accelerometer, or an airborne altimeter. This record is linearized for simplicity. A real case would have peaked crests and flattened troughs. The first methods of analyzing such records in detail were to measure the amplitudes of each wave and compute various statistical descriptions such as the mean of the highest 1/3 of the waves, which has been defined as the "significant height". This value for significant heights was chosen because it approximates what a seaman typically estimates for the general height of the sea. Depending upon our method of recording and our definition of just what constitutes a wave, we can get different values for significant heights. There are no accepted criteria for either of these, although some of us have used the requirement that a wave is not a wave unless it both begins and ends at the mean water level.
Measurement of Steam Injection Tubing Heat Losses Using Pressure/Temperature Survey Data
Authors: Wheaton L. D. 
Published: December 2007

ABSTRACT
The steamflooding of deep reservoirs requires the use of insulated tubing to minimize heat losses and maintain high-quality steam at the sandface. In order to evaluate the effectiveness of tubing used, techniques are needed to measure the heat loss in the wellbore and calculate the thermal conductivity of the insulation.
This paper presents the results of tubing analysis in a well of 4250 ft depth using pressure-temperature survey data. The problem of determining the bottom-hole steam quality under normal operating conditions was overcome by setting the inlet quality at a level estimated to result in zero quality at the sandface. This allowed the calculation of bottom-hole enthalpy and total heat loss using pressure and temperature measurements. The performance of the insulated tubing was evaluated by adjusting variables in a wellbore simulator to obtain a match of the experimental data recorded at several elevations.
Results of the test concluded the heat loss in the injection well was 130% higher than predicted using anticipated tubing properties. The heat loss was uniform through the tubing, and resulted from poor insulation performance. The simulation results eliminated the possibility of heat loss due to refluxing in the tubing annulus.
Evolution of a Successful Steamdrive in a Geologically Complex, Steeply Dipping Reservoir at South Casper Creek Field, Wyoming
Authors: Stevenson V. M. , Mullen C. E. 
Published: December 2007

SUMMARY
South Casper Creek Field provides a field case history of previous and current thermal activities, testing several steamflood strategies in a steeply dipping, geologically complex reservoir with the presence of an active edgewater drive. The thermal experience in the field indicates that geologic factors are the dominant influence on steamflood performance. The accurate interpretation and proper application of an improved geologic model directly affects oil production response.
Fosterton Northwest: Post In-Situ Combustion Corehole Analysis
Authors: Ostapovich E. , Ross M. F. 
Published: December 2007

ABSTRACT
Results of core analysis, including displacement efficiency estimates and the effects of in-situ combustion on reservoir rock and fluids are presented in this paper. High vertical sweep efficiency is evident contrary to predictions by most thermal simulators that little heat would be transported below the burnt zone at this distance from the injector. The usefulness of petrophysical analysis as a diagnostic tool is also demonstrated.
Carbonate Scale Formation in Thermally Stimulated Heavy-Oil Wells Near Lloydminster, Saskatchewan
Authors: Erno B. P. , Chriest J. , Miller K. A. 
Published: December 2007

ABSTRACT
Carbonate scale deposits have been determined to be a major cause of downhole screen plugging in steam stimualted wells in several Lloydminster, Canada heavy oil reservoirs. Lab experiments and analyses of produced fluids have identified the most likely mechanism of scale formation, and a simple method of using compositional data to determine whether downhole scaling is occurring is presented.
Minifrac Analysis for Heterogeneous Reservoirs
Authors: Soliman M. Y. , Kuhlman R. D. , Poulsen D. K. 
Published: December 2007

Abstract
General minifrac analysis type curves for analysis of heterogeneous formations have been developed and are presented in this paper. These type curves apply to a wide variety of formations including coalbeds and naturally fractured formations. The new type curves have been developed for the Perkins and Kern model. The paper presents the development of equations and type curves. and discussion of the technique and criteria for their application.
Conduct and results of a minifrac test in a coal seam are presented in this paper. The test is analyzed using the developed technique. The data in this case fits the new type curve extremely well. The match with existing type curves was poor.
Analyzing the Two-Cycle DST: Quantifying the Horner Plot Error
Authors: Durrett Steven D. 
Published: December 2007

Abstract
The two-cycle drill stem test, consisting of an initial flow period, an initial shut-in period, a second flow period and a second shut-in period, remains the most common type of test run in the field. Unfortunately, the most widely used method of analyzing data for these tests can result in significant errors. By far the most widely used method for DST analysis is a Horner plot prepared using Tp = t1F + t2F. In this method, an average flowrate is used in the calculation. Earlougher1 suggests that plots can be based on Tp = t2F or Tp = t1F + t2F, but is decidedly vague on when one is preferable to the other. Actually, the selection of Tp is not nearly as significant as is the selection of the flowrate to be used in the calculations.
In practice it seems that most tests are analyzed with Tp = t1F + t2F presumably because it generates a straighter line on the Horner plot. Unfortunately, the slope of this straight line can be very misleading. This is not to say that this slope is "wrong" since Horner slope in and of itself is not the parameter we are seeking. Only when combined with a flowrate does the Horner slope take on any physical significance. Thus while a Horner slope itself cannot be "wrong, " the combination of a Horner slope with an inappropriate flowrate can result in a "wrong" answer. Conversely any slope can be the right slope if it is combined with the appropriate flowrate. Thus we must remember that any discussion of Horner slopes must be rate-specific.
Data Acquisition, Analysis, and Control While Drilling with Horizontal Water Jet Drilling Systems
Authors: Dickinson Wade , Pesavento Michael J. , Dickinson R. Wayne 
Published: December 2007

ABSTRACT
Two different horizontal water jet drilling systems have been developed and extensively field tested. The first, the Ultrashort Radius Radial System (URRS) is built around 32 mm (1-1/4 inch) coiled tubing and provides multiple 30 to 60 m (100 to 200 foot) radials from a vertical borehole. Accuracy is ± 2 to 3° in vertical trajectory.
The second system, the Remotely Piloted System, uses 114 mm (4-1/2 inch) conventional flush joint tubing and is designed to drill for many kilometers (miles) with high three dimensional accuracy. Both systems incorporate Control While Drilling of the radial and provide real-time acquisition and display of drill performance with derived formation properties.
Potential Cumulative Impacts of Environmental Regulatory Initiatives on U.S. Crude Oil Supplies
Authors: Godec Michael L. , Biglarbigi Khosrow 
Published: December 2007

ABSTRACT
A number of legislative and regulatory initiatives being considered to protect the environment could affect the economics of U.S. oil and gas exploration and production (E&P). Not all environmental statutes require the Environmental Protection Agency (EPA) or other regulatory agencies to consider costs and/or energy impacts when establishing regulations or standards. Even when energy impact analyses are performed, they are often limited in scope, because they generally only consider the impacts associated with a specific regulation, and almost always assume no impacts from regulations in other areas. Many have expressed concerns that the cumulative costs of multiple regulatory initiatives could significantly impact U.S. oil and gas operations. This paper summarizes the results of a more comprehensive assessment of the potential cumulative energy and economic impacts of environmental regulatory initiatives on U.S. crude oil supplies (ICF Resources, 1990).
The economic recovery potential of various crude oil resource categories at four constant oil prices -- $16, $20, $24, and $32 per barrel (in 1988 dollars) - was considered in this analysis. Future supplies from four categories of U.S. crude oil resources were evaluated: oil recoverable from the continued conventional production of known onshore Lower-48 fields, oil recoverable from future infill drilling and waterflood projects in known onshore Lower-48 fields, oil recoverable from future enhanced oil recovery (EOR) projects in known onshore Lower-48 fields, and oil recoverable from onshore and offshore crude oil fields remaining to be discovered in the Lower-48 and Alaska (onshore and offshore).
The results of this analysis clearly demonstrate that increased regulations on U.S. crude oil E&P operations can have a significant impact on potential ultimate crude oil recovery. The extent of regulations imposed clearly will determine the level of impact, but the results show that significant impacts are felt over a wide range of regulations, over a wide range of crude oil prices, and at two levels of development for extraction technologies. All resource categories analyzed in the study are impacted by the regulations evaluated.
Optimum Well Location for Steamflooding Steeply Dipping Reservoirs
Authors: Hong K. C. 
Published: December 2007

ABSTRACT
A numerical simulation study was conducted to determine the optimum injector location for steamflooding steeply dipping reservoirs with five-spot pattern configurations. The model reservoir has either 20° or 45° dip, is bounded by an updip gas cap and a downdip edgewater and is steamflooded with one, two, or three five-spot patterns in the direction of dip.
The study showed that steamflood performance in dipping reservoirs can be improved by placing the injector downdip from the pattern center. The optimum injector location for most situations was found to be about halfway between the pattern center and the downdip producer row. This off-center, downdip steam injection produces the highest steamflood oil recovery among all injection locations considered in the simulation study.
Fracture Growth in the Presence of Highly Stressed Layers.
Authors: Wang J-J. , Clifton R. J. 
Published: December 2007

ABSTRACT
The paper presents and discusses results of hydraulic fracturing simulations performed for a two-layered reservoir bounded by highly stressed formations. Each reservoir layer was 75 feet thick, separated by a 50 feet thick impermeable formation and bounded on the other sides by similar barrier formations. Stresses in each barrier formation was either 1200 psi or 600 psi greater than in the reservoir layers. Fractures were initiated either from the upper payzone or the highly stressed barrier separating the payzones. Two fracture treatment schedules were considered for the different fracture initiations. In the first treatment, only neat fluid was used; the second treatment incorporated proppant concentrations varying from 1 to 6 lb/gal after pumping 2880 barrels pad volume. For both treatments, Newtonian fluid, with 100 cp viscosity, was injected at a rate of 3 0 bpm for a total slurry injection volume of 7200 barrels. The calculated geometry and width profiles along the wellbore are provided on completing the injection. Fracture length, height, treatment pressure, and maximum opening histories are also presented. Contours of fluid fronts, proppant fronts, and proppant are demonstrated for one case.
The fracture initiated in the highly-stressed middle layer showed: (i) a bell shape fracture with lengths of 400 ft in both payzones but of shorter length in the middle layer at the early pumping stage, (ii) the fracture opening at the wellbore decreased as the fracture initially migrated into the low stress payzone and increased after the fracture reached the outer barriers, and (iii) a higher net fluid pressure was required to initiate the fracture in comparison to the fracture initiated in the payzone.
Fracture Half-Length and Linear Flow in the South Belridge Diatomite.
Authors: Nott D. C. , Hara S. K. 
Published: December 2007

Abstract
The South Belridge Diatomite is a low permeability, high porosity, hydraulically-fractured reservoir. Infill drilling of the South Belridge field focused attention on fracturing. The three topics covered in this paper are a review of re-fracturing performance, an estimate of existing hydraulic fracture length, and application of analytical and simulation models to analyze and predict reservoir behavior.
Re-fracturing treatments successfully extended existing fractures. The productivity of seventeen wells increased 17% for eighteen months after stimulation. The fracture half-length of existing wells is estimated to be 115’ [35 m], while the no flow boundary is known to be 165’ [50 m]. The half-length is calculated based on the productivity of 20 wells and their reservoir pressure profile after 5 years of depletion. It is assumed that the reservoir is still in transient linear flow.
An areal simulation is undertaken which validates the application of linear flow equations to this reservoir. The simulation is also used to predict the incremantal production due to longer fractures in new wells. As the fracture length increases, the marginal production benefit decreases.
Risk Analysis: Over-All Chance Of Success Related To Number Of Ventures
Authors: Campbell W.M. , Schuh F.J. 
Published: December 2007

Publication Rights Reserved
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
We can learn much from the laws of probability that will help us in making wise decisions about exploration programs. Any company searching for mineral deposits wants to have a "reasonable" chance of making money. It is not enough to know that we will make money "on the average." In fact, we must be fairly certain of making a profit from a limited investment.
In our paper we are concerned with two factors in an exploration program:the chance of finding an oil field on any given exploration attempt, such as drilling a well, andthe value of the oil field found.
Both of these variables bear on the reasonable chance of making money.
We know, for instance, that with a 10 per cent chance of success we will not always succeed in 10 per cent of the number of attempts made.
The size of the field found obviously affects the value of the successful find. Most oil fields found contain less oil than the "average" field. The most probable size of any one discovery is much less than the average size of all discoveries. So to have a high chance that the average size of our finds will be close to the average size of all finds, we must find many fields.
Pressure Falloff Tests of New Coal Wells
Authors: Seidle J. P. , Kutas G. M. , Krase L. D. 
Published: December 2007

Abstract
This paper demonstrates field application of pressure falloff testing and analysis methods to new coal degas wells in the San Juan Basin. These tests have provided absolute coalbed permeability, wellbore skin, and initial reservoir pressure. Effects due to free gas and gas desorption on pressure falloff tests are considered. The effects of sorption compressibility are shown to have a significant impact on skin but not on permeability. Influence of the duration of the injection and shutin periods on the design and analysis of coal well PFOTs is also discussed. Field examples of both pre- and post-stimulation falloff tests are presented.