bluuebunny/crossref_metadata_2025_split huggingface dataset:
Simplified Gas Porosimeter
Authors: Bousaid Issam 
Published: December 2007

Described is a simple glass apparatus for rapidly obtaining gas porosities of porous rocks. The method consists of fast volume measurements of samples at atmospheric and lower pressures. This method applies basically the same principle as Boyle's law, P1V1 = P2V2, however, volume measurements are obtained at atmospheric pressure and lower in one simple operation. The apparatus is easily built from readily available glass components. A diagram of the glass porosimeter is shown in Fig. 1. The porosimeter has five basic components: two 500-cc glass burettes, a glass sample holder, a three-way glass valve, a 1/4-in. glass tube next to a meter stick and a 500-cc glass leveling bulb containing about 200 cc of mercury. The sample holder can be designed to contain samples of any dimensions; in this case, cores of 1 in. diameter X 3.0 in. long are used. The samples initially were placed in a perforated plastic holder that reduced direct handling of the samples and easily allowed their insertion in and removal from the glass sample holder. A relationship was obtained between the volume drop in cc of Hg and the height drop in cm for the right-hand burette. The value of this slope m is shown in Table 1. The method consists of measuring a new gas volume at a pressure below atmospheric. Briefly, the operational procedure consists of two steps for obtaining the grain volume measurements and a third step for obtaining the bulk volume.
- The sample is placed inside the glass sample holder with the lid firmly secured (Fig. 1). Initially, the leveling bulb is brought to Position 1 where the mercury level is adjusted to the zero mark on the right burette.
- The valve to the atmosphere is closed and the leveling bulb is lowered a distance L equal to the room pressure in cm of Hg (read on the meter stick). The new mercury level on the right burette is obtained directly and corresponds to the increase in gas volume in cc at the lower pressure p2. The bulk volume of the sample can be measured from the following step.
- The leveling bulb is adjusted to Position 3 and the valve to the atmosphere is opened gradually, allowing the mercury to rise slowly and submerge the sample up to the reference mark.
The three-way valve is turned slowly to the position connecting the left burette to the right burette. Mercury is drained from the sample holder until the level reaches the zero mark on the right burette. The volume on the left burette v, is obtained directly. Caution must be exercised to prevent any air bubbles from being trapped in the system. All samples are dried
TABLE 1-DESCRIPTION AND OPERATIONOF POROSIMETER
Calibration Data of Porosimeter
Volume of sample holder 79.6 cc Volume of plastic holder 2.6 cc Net volume of sample holder:For grain volume measurements 77.0 ccFor bulk volume measurements 76.2 cc
Average value of slope m in cm of Hg per cc of Hg drop1.137 + 0002
Sample Measurements and Calculations
True volume of aluminum rod = 36.63 cc Volume increase at p2, = 35.5 cc Atmospheric pressure p1 = 75.88 cm Hg
Grain volume of rod = 77.0
P. 335ˆ
Heterogeneities and Geometry of Sedimentary Bodies in a Fluvio-Deltaic Reservoir
Authors: Ravenne C. , Eschard R. , Galli A. , Mathieu Y. , Montadert L. , Rudkiewicz J. -L. 
Published: December 2007

Summary
This paper gives the initial results of a two- and three-dimensional (2D and 3D) geological study that aimed at describing reservoir heterogeneities. This study serves as a basis for the conditional simulation of the geometry of a fluvio-deltaic reservoir presented in a companion paper. These two studies should solve the difficult problem of interpolating between wells and thereby the problem of forecasting the extension of sedimentary bodies. The research is being carried out by Inst. Français du Pétrole and Center of Geostatistics, Paris School of Mines.
The study was made in the middle Jurassic in Yorkshire, which is very similar to the Brent formation in the North Sea. In the 2D phase, an outcrop consisting of a 1-km [0.6-mile] -long and approximately 30-m [100-ft] -high cliff was described with a photogeological interpretation. The sedimentological representation was carried out by means of several vertical cross sections. In the 3D phase, 36 boreholes were continuously cored and logged behind the cliff over an area of 1 km2 [0.4 sq miles]. The boreholes were about 300 m [985 ft] apart except in one grid where the distance was progressively reduced to 20 m [66 ft]. This phase was designed to follow the evolution of the sedimentary bodies and their physical properties and to compare the correlation that could have been made (1) with fewer boreholes and (2) without the existence of the cliff. These studies provide new tools for understanding and describing the shape and heterogeneities of a reservoir.
Calculation of Bottom-Hole Pressure in Gas Wells
Authors: Aziz Khalid 
Published: December 2007

Abstract
A simple, fact and accurate method for computing flowing and static bottom-hole pressures in gas wells is presented. The method employs any of the well known methods for numerical integration and the Newton-Raphson iteration scheme. The proposed method may he easily programed for digital computers or it may be used for hand calculations. The method is superior to previously proposed methods in accuracy and rate of convergence. Accuracy of the method depends mainly on the type of integration scheme and input data. Several integration schemes are evaluated here for use with this method.

Introduction
The basic equation for flow in a vertical pipe and hydrostatic head are well known and are reviewed in a recent manual published by the Oil & Gas Conservation Board of Alberta and in a series of papers published by the author. Only the most general form of these equations used for practical calculations will be presented here. This form of the equations was first proposed by Cullender and Smith. For static bottom-hole calculation we have,
........................................(1)
and for flowing bottom-hole pressure,
........................................(2)
The usual procedure in bottom-hole calculations is to (1 ) assume a value of p, (2) compute the right-hand side of Eq. 1 or 2 depending on the type of calculation being performed (static or flowing) and (3) check to see if the computed value of the integral is equal to the known left-hand side of the equation. If the two sides of the equation are not equal within a certain allowable tolerance, the calculations are repeated with a new estimate of ps. The numerical method used for evaluating the integral is usually either the trapezoidal rule or Simpson's rule.

Proposed Method
A method is proposed here for performing bottom-hole pressure calculations so that a minimum number of iterations is required. The method could be used with any numerical integration scheme. Rewrite Eq. 1 or 2 in the following form,........................................(3)
in this equation, K. y and, hence, 0 take on different values depending on the problem being considered. For the static case,
........................................(4)
Microinduction Sensor for the Oil-Based Mud Dipmeter
Authors: Kleinberg R. L. , Chew W. C. , Chow E. Y. , Clark B. , Griffin D. D. 
Published: December 2007

Summary
Microinduction sensors are used in the Oil-Based Mud Dipmeter Tool™ to measure formation conductivity through nonconductive mud or mudcake. The sensor consists of small transmitter and receiver coils mounted in a pad. An extensive research effort involving sensor response modeling, laboratory experiments, and signal processing contributed to the development of these new sensors.
Undersea Drilling and Production Sites for Petroleum
Authors: Austin Carl F. 
Published: December 2007

Large undersea installations with shirtsleeve environment have existed under the continental shelves for many decades, The technology now exists, using off-the-shelf petroleum and mining equipment, to establish permanent manned installations within the sea floor- that can be used for well drilling and initial petroleum fluid processing. The past and present permanent, in-the-sea-floor mining industry is reviewed and methods now practical for direct access to and from permanent in-the-sea-floor drilling and production sites are outlined. Drill sites beneath the sea floor are free of weather and floating ice hazards, and enable complete access to the wellhead area by technicians and laborers. A present estimate for such an operating site is approximately $50 million.

Introduction
The petroleum industry has become deeply and irrevocably involved in producing gas and oil from the continental shelves. Chief among the problems of offshore drilling today is the hazard presented by the air-water interface, i.e., the damage potential of serious storms and waves, an example of which is the recent destruction of a British petroleum platform, costing 11 lives. To overcome the problems of working at the unstable air-water interface. the present industrial trend is to go to the sea floor. The following statement is appropriate: "The consensus of oil companies is that by 1975, if technology is available, most stationary installations will be on the bottom of the sea, not on the surface."'
In addition to working on the bottom of the sea while keeping the drilling platform on the surface, there is another major potential solution to the problems of offshore drilling. This solution is literally to burrow into the sea floor, using the rock as the construction medium for drilling and production sites in which all activities are carried out in a normal one-atmosphere environment. Fig. 1 illustrates the practicality of this approach. This machine shop bay is part of a mining complex with approximately 7 1/2 sq miles of open, permanent floor space. The individual shop bay is some 500 ft long. The striking aspect is that this existing installation is located beneath 400 ft of water, some 2 1/2 miles off the shore of an island on the eastern coast of Canada. The installation is 1,500 ft below sea level. A series of openings such as the one illustrated, excavated in the sea floor, could obviously contain an extensive petroleum drilling and production installation and very extensive bulk storage and processing installations. This article discusses how the study program called Rock Site, conducted at the U.S. Naval Weapons Center, has led to the conclusion that petroleum production sites, as well as many other industrial operations, can be located within the bedrock beneath the sea floor, using only existing tools and technology.
JPT
P. 1309ˆ
Remaining-Oil Determination Using Nuclear Magnetism Logging
Authors: Freedman R. , Rouault G. F. 
Published: December 2007

Summary
The determination of the volume of remaining oil in a reservoir is a key ingredient in planning future oil recovery operations. Nuclear Magnetism Logging (NML™) is an openhole wireline logging method that can provide accurate estimates of remaining-oil volumes. The signal processing required to extract these estimates from the logging data and the NML logging procedures used in this application are the subjects of this paper.
The physics of the NML method and the wellsite log-inject-log procedures used for remaining-oil determination is reviewed. The latter procedures include the doping of the mud with magnetite to kill the borehole signal and the injection of paramagnetic ions into regions sensed by the NML measurement to kill the formation-water signal.
A new NML signal-processing algorithm for determining remaining oil is developed. The algorithm is an improvement over conventional envelope processing in low SNR environments. The algorithm explicitly accounts for the statistical properties of bandwidth-limited Gaussian thermal noise in extracting signal parameters from signal-plus-noise measurements. This is especially important for remaining oil determinations for which accurate estimates of both the fractional bulk volume of remaining oil, Vbro, and the uncertainties in these estimates are required.
The method is applied to residual-oil data from a Shell well. The data consist of repeat waveforms at 44 stations. The FFFs are mostly in the range from 1.0 to 4.0 porosity units (p.u.) and the signal decay times are less than 50 msec. Thus, the data represent an abnormally difficult signal-processing problem as a result of the low SNR's. The results of processing these data are compared with results obtained independently by Shell with their own processing methods, which are widely regarded in the industry as standards. The volumes of residual oil and standard deviations estimated with the new signal-processing method developed in this paper are in excellent agreement with the results of Shell's processing methods.
A Complex Reservoir Characterized By Three-Dimensional Seismic, Geostatistical Reservoir Description, and Sponge-Core Analysis
Authors: Carr L. A. , Benteau R. I. , Corrigan M. P. , Van Doorne G. G. 
Published: December 2007

Summary
This paper reports the characterization and reservoir description of the Rainbow Keg River "F" pool located in northwestern Alberta, Canada. Significant improvements in reservoir description were made through further delineation of geological structure with a three-dimensional (3D) seismic program, evaluations of residual oil with sponge-core analysis, and a geostatistical reservoir description that uses kriging. Increased accuracy in reservoir analysis was required for the evaluation of the remaining resources under a mature waterflood.
The characterization is examined by matching a cross-sectional reservoir model to production performance, including oil/water-contact (OWC) and gas/oil-contact (GOC) history as well as reservoir-pressure surveys. The result of the program is an increased accuracy in reservoir delineation, improvements to well completion strategy, and a monitor of waterflood performance.
Influence of Clay Distribution on Shaly Sand Conductivity
Authors: de Waal J. A. 
Published: December 2007

Summary
Membrane-potential measurements were carried out on original and remolded core samples to study the influence of sample crushing on the electrical conductivity of shaly sands. Results show that the distribution of clay minerals has a large influence on their contribution to the electrical conductivity. Consequently, clay conductivities derived from nondestructive membrane-potential measurements are much more accurate than those calculated from conductometric titration measurements.
Membrane-potential measurements were carried out in a new experimental setup that allows the use of unconsolidated and therefore highly permeable samples. In particular, the problem of maintaining a constant salinity contrast over the sample length during the measurement has been solved. With the new equipment, reliable membrane-potential measurements can be made in 20 to 30 minutes per sample.
Relationship Between the Archie Saturation Exponent and Wettability
Authors: Donaldson E. C. , Siddiqui T. K. 
Published: December 2007

Summary
The calculation of in-situ water saturations from resistivity well logs relies on the saturation exponent of Archie's equation, where n =2 for clean, consolidated, water-wet sandstones. The saturation exponent, however, is a function of the water/oil/rock wettability and was found to range from &lt;2 to 8. The relationship between wettability and the saturation exponent is linear, and the slopes of the lines at low and high temperature are identical for a given sandstone.
General Turbulent Pipe Flow Scale-Up Correlation for Rheologically Complex Fluids
Authors: Lord D.L. , Hulsey B.W. , Melton L.L. 
Published: December 2007

Abstract
A mathematical model d1.20?p/4L = A(8v)s derived from the Blasius equation is proposed to be applicable to turbulent flow through straight cylindrical pipe for time-independent fluids which produce a diameter family of straight parallel lines on a log (d?p/4L) vs log (8v/d) plot or stress-flow diagram. Such a correlation should permit scale-up with data taken from one pipe diameter for Newtonian, inelastic non-Newtonian and viscoelastic fluids, such as dilute polymer fracturing fluids, which produce considerable frictional pressure reductions.
The Newtonian diameter exponent value 1. 20 is shown to be empirically valid for turbulent non-Newtonian flow by application of numerical analysis methods. Multiple regression analysis is applied to a logarithmic linearization of the proposed model. An improved data fit results from further linearization achieved by taking linear terms from a generalized Taylor's series expansion about the multiple regression coefficients.
Extensive experimental data obtained in five pipe diameters with water, sodium carboxymethylcellulose solutions, guar gum solutions, bentonite clay suspensions and calcium carbonate slurries are presented. Except for calcium carbonate slurries, which were investigated rather than time-dependent cement slurries, the fluids studied contain drilling or fracturing fluid additives. The behavior exhibited by these fluids is considered typical of most fluids encountered in drilling, cementing and fracturing operations.

INTRODUCTION
Considerable difficulties have been encountered in predicting turbulent flow pressure drops produced by non-Newtonian fluids flowing through straight cylindrical pipe. Correlations previously presented require extensive experimental data which represent several pipe diameters and a wide flow rate range to estimate the necessary scale-up parameters.1-7 One must implement either elaborate experimental apparatus or spend considerable time and effort to gather the se data. Presented here is a correlation method which should minimize the experimental effort and data analysis normally required by utilizing flow data taken with only one pipe diameter.
Turbulent flow data (up-stream and dawn-stream pressure and volumetric flow rates) were collected for five pipe diameters through operation of a small pipeline system having an electronic data acquisition and digitizing system.
A mathematical model derived from the Blasius equation was utilized to describe the functional relationship between pressure drop and the two independent variables, diameter and average flow velocity. A correlation, which should produce a valid single-pipe scale-up, resulted from a computer-implemented statistical and numerical data analysis for several time-independent non-Newtonian fluids.
Differences in Fracture Characteristics and Related Production: Mesaverde Formation, Northwestern Colorado
Authors: Lorenz John C. , Finley Sharon J. 
Published: December 2007

Summary
Reservoirs in the Mesaverde formation in the Piceance Creek basin, northwestern Colorado, consist of naturally fractured, low-permeability sandstones. Permeability along the natural fractures is the primary mechanism of gas production. However, the characteristics of the natural fractures change within the formation at boundaries roughly coincident with changes in depositional environment, as seen in 4,200 ft [1280 m] of core from the U.S. DOE's Multiwell Experiment (MWX) wells. Depositional environment controlled the characteristics of the matrix rock and reservoir heterogeneity as well as the fracture permeability system. Therefore, natural gas production rates from the different zones in the formation can be correlated with the natural fracture characteristics from that zone. The fracture systems consist of unidirectional regional fractures that provide highly anisotropic reservoir permeability trends. Locally, secondary fractures were superimposed on the regional system, and higher production rates resulted. Production rates are low elsewhere, and little well-to-well communication across the fracture trend occurs. Moreover, stimulations of these reservoirs have often been unsuccessful because the hydraulic fractures propagate parallel to the natural fractures.
Water-Injection Profiles in Eola Field Determined by Changes in Thermal- Neutron-Capture Cross Section
Authors: Tesarek P. B. , Heysse D. R. 
Published: December 2007

Summary
In waterflood operations it is desirable to inject uniformly into the targeted hydrocarbon-bearing sections of a reservoir. Wireline injection profiles have traditionally been used to determine where fluid enters perforations. Profile logs are inadequate, however, where segregation of flow into long, multiple zones is accomplished through a single tubing string and tubing injection mandrels with packers separating the zones. A technique has been proposed and tested successfully for detecting through tubing which intervals are actually being invaded by injection fluids. Logging the cased well with the Thermal Multigate Decay™ (TMD) pulsed-neutron tool while successively injecting fresh water, salt water, and borated salt water delineated invasion through the resultant increase in the thermal- neutron-capture cross section in the flushed intervals. This technique allowed a qualitative foot-by-foot analysis of the injection profile despite the presence of tubing, packers, and flow regulators. It also provided the data needed to improve injection practices and to enhance the recovery of hydrocarbons.
Application of Hand-Held Computers in Gathering Field Data
Authors: Bettis T.A. , Shreve M.A. 
Published: December 2007

Summary
Recent developments in hand-held computer technology have made feasible the direct daily transfer of field data to a common, easily accessible data base. This low-cost improvement of field-data-reporting procedures benefits field operators, clerical workers, engineering staff, and management by making information available quickly while substantially reducing paperwork.

Introduction
Mitchell Energy Corp. (MEC) implemented a field-data-gathering system in which field personnel enter information into a hand-held computer. Information on 2,350 wells, 134 compressors, and several production facilities previously recorded by hand is collected with a hand-held computer. This information is transferred to a personal computer (PC) and then to the main computer. The main computer manipulates these data to generate daily, weekly, and monthly production reports used throughout the corporation. Daily field reports are received earlier and contain more information than the hand-written reports they replaced. When possible, existing PC's, modems, and communications software available within the company were used. This project was implemented at a capital cost of less than $15,000.

System Concept
Project designers sought a method to enter data into the company's computer system at the first possible entry level: the field. It was desired to use a computer in the field that would be compatible with the existing computer system.
Field management defined the necessary features of the proposed computer. The field computer should be compact and small enough to carry in one hand, leaving the other hand free to enter data. It should be durable enough to withstand the rough conditions of a field environment, and should have enough memory to store all the daily information normally recorded by a lease operator for every well on his route. The unit should be able to store up to 5 days of data for each well to accommodate holiday weekends. Continuous memory would be necessary to maintain the information stored even when the computer was turned off.
For communications purposes, the computer would have to be able to store data in American Standard Code for Information Interchange (ASCII) files and interface with standard data-communications hardware already in use by the company. Keeping cost minimal was desirable, so an "off-the-shelf" computer for which software could be developed in house was preferred.

Pilot Project
A hand-held computer satisfying the outlined criteria was found for which field-data-gathering software was developed. A pilot project was initiated involving three lease operators, each using his own hand-held computer to gather data on 42 tertiary recovery wells, 12 primary wells, and a production facility. A 4-month pilot period was successfully completed. Results were such that expansion of the hand-held-computer data-gathering system to the entire North Texas Region was authorized.