bluuebunny/crossref_metadata_2025_split huggingface dataset:
A floating storage unit designed specifically for the severest environmental conditions
Authors: Bax J.D. , de Werk K.J.C. 
Published: December 2007

This paper was prepared for the SPE-European Spring Meeting 1974 of the Society of Petroleum Engineers of AIME, held in Amsterdam, the Netherlands, May 29–30, 1974. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Netherland Section of the Society of Petroleum Engineers, P. O. Box 228, The Hague, the Netherlands. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A description is given of an oil storage facility comprising a combination of a number of vertical cylinders, forming a complete unit. Anchored to the bottom of the sea yet movable to another location if required, the floating unit has been designated a storage spar. The paper deals with the behaviour of the unit in certain sea states and with those parameters which effect motions due to wind, parameters which effect motions due to wind, waves and current. The basic philosophy of the design is discussed. Some attention is also given to the structural aspects of anchoring, tanker mooring and oil handling.
The paper also goes into some detail on the fabrication of the unit, its upending after launching, and its final installation at site.

Introduction
A glance at the map of the North Sea shows the presence of a number of highly interesting oil and gas discoveries many of which are scheduled to come into production very soon. The discovery of these new sources of hydrocarbons, and their location, sparked off a great deal of research and development activity leading eventually to the designing of equipment able to stand up to the severe and hostile environmental conditions peculiar to this northernmost portion of the North Sea. Because of the excessive water depths involved, plus the severe weather conditions, most structures going into this area have to be large and have to be heavy.
And since we are only just on the brink of development, activity is bound to increase considerably into the future. This means that water up to 200 meters deep will have to be contended with.
A Review of Tertiary Recovery in Illinois
Authors: Lawry Thomas F. 
Published: December 2007

This paper was prepared for the Second Midwest Oil and Gas Industry Symposium of the Society of Petroleum Engineers of AIME, to be held in Indianapolis, Ind., March 28–29, 1974. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
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
Tertiary recovery work done in Illinois to date has included in situ combustion in two reservoirs containing oil too viscous to waterflood successfully; a few trials of steam in huff-and-puff applications; and an increasing number of small-scale pilot size to semi-field-scale size chemical floods.
The in situ combustion tests have proven that in situ combustion is capable of removing almost all of the oil from a porous reservoir, although as much as one-fourth of the oil may be consumed underground as fuel for the process.
Chemical floods, using sulfonated hydrocarbons either in microemulsions or in aqueous solution, have shown that additional oil can be removed from sandstone reservoirs that have already been subjected to waterflood recovery methods.
Partially hydrolyzed acrylamides have proven to be a very useful adjunct to the proven to be a very useful adjunct to the application of sulfonated hydrocarbons in chemical floods as a means of improving mobility control of injected fluids.
A brief review of two in situ combustion projects and eight chemical floods is given in projects and eight chemical floods is given in this paper. Data are from earlier published papers plus more recent communication with papers plus more recent communication with authorized company representatives.

Introduction
For the purpose of this paper, tertiary recovery is broadly spoken of as any process of oil recovery by chemical or thermal means beyond the secondary recovery methods of waterflooding, air-gas repressuring, or use of vacuum. This paper is a review of all known tertiary paper is a review of all known tertiary recovery projects that have been done in Illinois (Fig. 1).
Future Oilfield Equipment Availability
Authors: Mairs M. Bruce 
Published: December 2007

Good afternoon gentlemen. Thank you for this opportunity.
A major oil company the other day published what it called "musings of an oil published what it called "musings of an oil person…" Today, with your permission, I person…" Today, with your permission, I would like to publish some "musings of an oil tool person…"
We find ourselves today at a very curious point in time in our industry. Demand for point in time in our industry. Demand for everything is high. Supplies are low. Production schedules are supertight. Tempers are Production schedules are supertight. Tempers are short. So is oil. Prices are spooky. Congress is nervous, so are businessmen. And the consumer stands watching all this in stark disbelief.
How did we get in this marvelous mess? To answer, we must retreat in time to the 1960's — described by one historian as the Decade of Extremes. Ten years of irony, paradox, gross exaggeration, massive paradox, gross exaggeration, massive miscalculations and contradictions in which we all had the pleasure of participation.
It was the decade of one of the worst Bear markets and the hottest Bull market in Wall Street history. It gave us political and economic extremes, extreme rises in costs, labor contracts, inflation and deficits, extremes on the campuses and on city streets, and even in religion where we witnessed rise of the occult and the Jesus Freaks. The sixties were also called the decade of materialism - when demand for everything sky-rocketed to unprecedented levels. More money chased more goods than at any time in the history of mankind.
Extremes were also felt in our industry. Some of these led us to where we are today - in the midst of tough problems and great opportunities.
The sixties saw the cost of drilling, producing and marketing energy products climb, producing and marketing energy products climb, while government controls held down fair profits. profits. Government policies controlling the price of gas and oil drove American oil companies outside the United States' boundaries in search of cheaper sources of oil.
High Temperature Behavior of Rocks Associated with Geothermal Type Reservoirs
Authors: Somerton W.H. , El-Shaarani A.H. , Mobarak S.M. 
Published: December 2007

ABSTRACT
Measurements of sonic velocities, bulk and matrix compressibilities and thermal conductivities have been made on a group of outcrop sandstones and a group of siltstone cores obtained from wells drilled in the Imperial Valley, California. Results of these measurements, which were made at temperatures as high as 200 °C and pressures to 16,000 psi, are presented and discussed relative to their application in high temperature underground reservoir studies.
Sonic velocities were found to decrease with increased temperature and increase with increased pressure and with liquid saturation. If the effect of temperature on sonic velocities is ignored, overestimation of porosity from transit-time logs could result.
Both bulk and matrix compressibilities were found to increase with increased temperature. Application of these data to surface subsidence calculations showed that although subsidence would be small due to fluid pore pressure reduction in these particular rocks, the effects of temperature on compressibility could increase subsidence substantially.
Thermal conductivities were of the expected order of magnitude for sandstones and siltstones of the type tested. Vaporization-condensation reactions caused a more than two-fold increase in apparent thermal conductivity for the higher permeability sandstones but had essentially no effect on the conductivities of the low permeability siltstones.
From results of the present work it was concluded that the temperature effects observed were of sufficient importance to warrant additional work at higher temperatures and on a wider variety of samples typical of those which might be encountered in high temperature subsurface reservoirs.

INTRODUCTION
In the development of geothermal power, an understanding of the properties and behavior of rocks and rock-fluid systems at high temperatures and pressures may be needed for a variety of applications. These include, among others, the interpretation of well logs, prediction of subsidence upon pore pressure reduction, calculation of reservoir storage capacity, and fluid flow and heat flow calculations. Properties needed for these applications include sonic velocities, bulk and pore compressibilities, thermal conductivity, permeability and electrical resistivity factor. Capillary pressure and relative permeability data measured at subsurface temperature and pressure conditions may also be required in multi-phase fluid and heat flow calculations.
An Examination of Countercurrent Capillary Imbibition Recovery from Single Matrix Blocks and Recovery Predictions by Analytical Matrix/Fracture Transfer Functions
Authors: Cil Murat , Reis John C. , Miller Mark A. , Misra Debasmita 
Published: December 2007

Abstract
Countercurrent capillary imbibition is an important oil recovery mechanism in naturally fractured reservoirs. This paper presents a comprehensive study which examines 8 important characteristics of countercurrent imbibition as observed from experiments conducted with single matrix blocks. These characteristics are (1) types of imbibition and recovery trends, (2) flux and transition time, (3) imbibition front and average saturation, (4) effect of block sizes and shapes, (5) effect of temperature, (6) effect of initial water saturation, (7) reproducibility, and (8) long-term recovery.
Existence of two flow periods during countercurrent imbibition were verified. The transition time between the periods was identified as an excellent factor for scaling core size and temperature effects on countercurrent imbibition recovery. The advancement rate of the imbibition front was confirmed to be proportional to the square root of time for 1 D water imbibition into gas-saturated matrix blocks. Experiments showed that initial water saturations ranging from zero to near 20% had no significant effect on recovery behavior. Long term recovery from gas-saturated matrix blocks reached 100%.
Analytical matrix/fracture transfer functions are often used to predict imbibition recovery. Over 23 such functions have been identified from the literature. In this study, these functions are categorized as:diffusivity functions,scaling relations,empirical functions, andmaterial balance functions.
One critical finding has been that analytical functions can provide alternative solutions when modeling oil recovery from naturally fractured reservoirs. We have shown that better functions can easily be developed by simply following the examples of previous functions. In this regard, three new functions and their variations are presented and verified. The findings in this study should provide a powerful toolbox for reservoir engineers in modeling oil and gas recovery from dual porosity/permeability structures which include naturally fractured reservoirs.
P. 237
A Viscous Coupling Model for Relative Permeabilities in Fractures
Authors: Fourar M. , Lenormand R. 
Published: December 2007

Abstract
Two-phase flow properties are required for modeling fluid flows and pollutant transport through fractured media. Several laboratory experiments have been reported in the literature but so far there is no general model to predict the two-phase conductivity of a fracture for a given pair of flowing fluids. In this paper we propose a simple model based on viscous coupling between two fluids flowing simultaneously in a single fracture. This viscous coupling model leads to simple analytical relationships between the relative permeabilities (Kr) and either saturation or fluid velocities. This model also explains the dependence of the non-wetting fluid Kr on the viscosity ratio. Results obtained with this model were compared to several series of data available in the literature with air and water. The fit between predicted and measured Kr is good when the ratio of flow rates is used as variable (Lockhart-Martinelli parameter). For use in numerical simulations, the saturation can be derived from the flow rates using the same model. The proposed model can improve the relative permeability curves that are used in the numerical simulations.
P. 253
Stochastic Reservoir Simulation Using Neural Networks Trained on Outcrop Data
Authors: Caers Jef , Journel Andre G. 
Published: December 2007

Abstract
Extensive outcrop data or photographs of present day depositions or even simple drawings from expert geologists contain precious structural information about spatial continuity that is beyond the present tools of geostatistics essentially limited to two-point statistics (histograms and covariances). A neural net can be learned to collect multiple point statistics from various training images, these statistics are then used to generate stochastic models conditioned to actual data. In petroleum applications, the methodology developed can be a substitute for objects based-algorithms when facies geometry and reservoir continuity are too complex to be modeled by simple object such as channels. The performance of the neural net approach is illustrated using training images of increasing complexity, and attempts at explaining that performance is provided in each case. The neural net builds local probability distributions for the facies types (categorical case) or for petrophysical properties (continuous case). These local probabilities include multiple point statistics learned from training images and are sampled with a Metropolis-Hastings sampler which also ensures reproduction of statistics coming from the actual subsurface data such as locally varying facies proportions.
P. 321
An Integrated Approach to Project Management, Wainwright West Project
Authors: Zaver Mohamud 
Published: December 2007

Abstract
A fast tracking, integrated approach to project management was utilized to develop a new pool at Wainwright West, located 200 km east of Edmonton, Alberta, Canada. An integrated multi-disciplinary project team of about 20 people composed of geosciences, development, land, drilling, completions, production, facilities and marketing, managed by a project manager was formed. This integrated, fast tracking approach resulted in production on-stream two months ahead of the original schedule and 10% below costs. Successes, enhancements and improvements were realized in every area, which were captured at a lookback session and implemented for the next phase of the project.
How We Can Be More Efficient with Our Drilling Hydraulics
Authors: Sutko A.A. , Sifferman Thomas R. , Harden Elard L. , Wahl Harry A. 
Published: December 2007

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

Abstract
Present-day drilling hydraulics can be made more efficient. The methods discussed in this paper result in lower cost and better use of hydraulic energy. These findings are based on using two nozzles instead of three and, in some cases, lowering the annular velocity. New data is also presented on borehole wall erosion and on better hole bottom cleaning with extended nozzles, especially when the nozzle angle is increased.

Introduction
Hydraulics has long been recognized as an important factor in drilling but, because of the complexity of the system, it has received limited detailed study. Early drilling optimization programs assumed that the drilling hydraulics was adequate. In more recent programs, procedures have been developed for determining procedures have been developed for determining optimum drilling fluid properties, velocities, etc. However, the basic information on what occurs beneath the bit and in the annulus was not available. Recent publications on bit hydraulics and drill cutting transport provide new insight into drilling hydraulics. provide new insight into drilling hydraulics. This paper shows how to apply this information to improve your hydraulic efficiency. Procedures are given that can save time and money Procedures are given that can save time and money by increasing penetration rates and decreasing hole problems. In addition, the more effective application of hydraulic energy can improve drilling operation while reducing fuel requirements.

EXPERIMENTAL

Bit Hydraulics
The bit hydraulics results discussed in this paper are based primarily on laboratory testing with 6 1/2-inch bits. The flow system was composed of a pump, drill pipe, bit, simulated hole bottom, and annulus.
For the pressure distribution tests, a contoured plate with seven taps located along a radius provided the bottom-of-the-hole pressures, and a row of seven taps equally spaced at 1/2-inch intervals gave the pressures up the side of the hole. The pressure at each of the points was measured with respect to the pressure points was measured with respect to the pressure at a point farther downstream in the annulus.
A New Cementing Material for Deep Hot Holes
Authors: Fincher Arnold , Goode John M. 
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 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
This paper describes a new cementing composition which is designed to have both low fluid density and long thickening time characteristics at elevated temperatures.
The advantages of using such a slurry are demonstrated when weak zones are encountered in cementing long strings in deep holes; when it is desired to circulate cement to the surface or bring it up the annulus a considerable distances since the reduction in slurry density allows a longer cement column to be tolerated without having formation breakdown.
Laboratory data is presented demonstrating that the slurry has good compressive strength over a wide temperature range, can be retarded easily at high temperatures, has good flow characteristics and does not exhibit severe strength retrogression at high temperatures.
Case histories of jobs, where the composition has been used, are given with the results of the jobs.

Introduction
With the drilling of deeper wells, problems in cementing have become more and more complex. Higher bottom hole pressures have been encountered requiring heavier muds to control high pressure formations. Where weak formations exist up the hole, these heavy muds tend to break down these zones causing severe lost circulation problems. In order to protect these weak zones, problems. In order to protect these weak zones, the practice of setting intermediate strings of casing has been employed by several operators in southern United States. Many of these long strings are set in 10,000 to 13,000 feet of open hole below 2500 to 5000 feet of surface pipe. These strings of casing are usually cemented to the surface. This procedure often results in the problem of formation breakdown due to the long columns of cement utilized.
In many wells, severe corrosion zones exist above the production zones. In order to protect the casing from corrosion, the practice of employing long cement columns to cover these zones has been utilized. Here again, potential formation breakdown is a problem.
What was needed was a cementing composition of low density, but could withstand the high temperatures encountered in deep well cementing.
Improving Wellbore Position Accuracy of Horizontal Wells by Using A Continuous Inclination Measurement From A Near Bit Inclination MWD Sensor
Authors: Berger P. E. , Sele R. 
Published: December 2007

Abstract
Wellbore position calculations are typically performed by measuring Azimuth and Inclination at 10–30 meter intervals and using interpolation techniques to determine the borehole position between the survey stations. Input parameters are, Measured Depth (MD), Azimuth and Inclination, where the latter two parameters are measured with the MWD tool in a stationary mode (non-rotating). Output parameters are the geometric coordinates; True Vertical Depth (TVD), North and East. To maximize the exposure of a production well to the reservoir, horizontal wellbores are frequently being drilled. Furthermore, to maximize the production of hydrocarbons from these wells, their relative position within the reservoir is critical. Improving the accuracy of the Inclination measurement and thus reducing the uncertainty of the calculated TVD value will increase the confidence in wellbore position.
The NaviGator™* geosteering tool or the AutoTrak™* rotary steerable system are frequently used to optimize the position of horizontal wellbores within the reservoir. Both these geosteering tools use a Near Bit Inclination sensor (NBI) to help the directional driller perform directional changes smoothly and accurately. Unlike traditional directional sensors the NBI sensor is capable of accurately measuring inclination while being rotated. Consequently NBI measurements can be performed continuously during drilling. The measurements can be used to more accurately calculate the wellbore trajectory.
Results in the paper demonstrate that the NBI sensor is more accurately measuring inclination than other directional sensors in a horizontal well. Also, by continuously measuring the inclination during rotation, some error sources are reduced, resulting in improved TVD accuracy.