bluuebunny/crossref_metadata_2025_split huggingface dataset:
Comparing Single-Point Pressure Buildup Data With Reservoir Simulator Results
Authors: Earlougher Robert C. 
Published: December 2007

Matching simulator results with historical reservoir data is an important part of a numerical reservoir simulation study. A good match is generally interpreted as indicating the validity of reservoir data used in the simulation and as justification for predictions of reservoir performance. One common matching technique is to compare simulator-calculated pressures with observed pressure data. Ideally, pressure data from observation wells (never produced or injected into) would be used for such matching. Unfortunately, such data are rarely available. Generally, most reservoir pressure data come from relatively short-term pressure data come from relatively short-term pressure buildup tests. Occasionally, only one pressure is pressure buildup tests. Occasionally, only one pressure is reported, even though the well may have been shut in for days or weeks. This note presents a method for comparing this kind of pressure data with simulator calculations. To keep simulation costs reasonable, reservoir simulation studies usually use 30- to 90-day time steps. Since pressure buildup tests normally last only a few days, it generally is not practical to include them in simulation runs. Thus, simulator results do not directly provide pressures for comparison with buildup-test pressure. Van Poollen et al. present a method for comparing observed pressure buildup data with simulator-calculated node pressure (not simulator calculated well pressure) for the time step during which the buildup test was run. This node pressure should agree with observed buildup pressure at a buildup time of
...........(1)
where
= buildup time at which buildup pressureshould be compared with nodepressure, hours= porosity, fraction= total system compressibility, psi= grid size, ft= total system mobility near the well, md/cp.
Total compressibility, ct, and total mobility (k/u)t, are defined by Matthews and Russell." Eq.1 applies to a well in the center of a square node and assumes that the semilog buildup plot (shut-in pressure, Pws, vs log of shut-in time, log t) is linear at t*. If this semilog plot is not linear at t*, the linear portion of the plot should be extrapolated to t*. The pressure att*, taken from the semilog straight line (extrapolated if necessary) should be compared with simulator-calculated node pressure. If the complete buildup curve is not available for instance, if only one pressure is observed - Eq. 1 cannot be used. In this situation, however, we can calculate a pressure to compare with simulator-calculated node pressure.
.............(2)
P. 711
The Pumpability of Clay-Water Drilling Fluids
Authors: Havenaar I. 
Published: December 2007

Abstract
Various methods have been proposed in the literature to calculate the pressure losses in drill-pipe and bit-nozzles, i.e., those parts of the mud-circuit where the largest pressure-losses occur. Very few data, however, are available to check the validity of these proposals.
Presented in this paper are the results of pumping experiments with clay-water drilling fluids of different specific gravities and different laminar flow-properties (differential viscosity and Bingham yield value), using pipes of different diameters. In addition, a series of measurements on bit-nozzles is discussed.
Two main conclusions may be drawn from this work for the flow through pipes.In the laminar flow region pressure losses can be calculated from the differential viscosity and Bingham yield value of the mud.In the turbulent flow region pressure losses can be calculated with good approximation from a viscosity term which is determined by the volume fraction of the dispersed phase.
Calculations making use of laminar flow properties may lead to erroneous results. The effect of temperature on the pressure losses in the case of turbulent flow can be calculated from the change in viscosity of the dispersing medium, i.e., water.
The main conclusions determined for the flow through bit-nozzles are that for flow conditions prevailing in the field, the pressure-drops in bit-nozzles are independent of the laminar flow properties of the mud. They are solely determined by the density of the mud and the geometry of the nozzle.

Introduction
The last decades have witnessed a steady increase in the depth of oil wells. This is illustrated by the increase in the drilling depth record in the USA from 8,046 ft in 1927 to 21,482 ft in 1953. This increasing depth, together with the experience that high rates of mud circulation and high fluid velocities in the bit-nozzles enhance the rate of drilling, has emphasized the importance of selecting suitable mud-pumps when starting the drilling of a deep borehole.
For such a selection it is necessary to be able to calculate the pumping pressures necessary to obtain the required circulation rates. The main part of the pressure-losses in the mud circuit occur in the drill pipe and the bit-nozzles. Various methods have been proposed in the literature to calculate the pressurelosses in the drill pipe. These methods do not all lead to the same results, and at the time this investigation was started insufficient basic data were available to check their validity. Moreover, to our knowledge, no data are available at all on the effect, if any, of the flow-properties of the mud on the pressure-losses in bitnozzles.
Bridging the Information Gap Between Operations and Engineering
Authors: Dunham C.L. 
Published: December 2007

Advances in computer and communications technology have often been cited to justify greater consolidation of staff functions. This consolidation, however, tends to widen the information gap between Operations and Engineering. That trend must be reversed, and the gap can be bridged by applying the latest developments in the very technology that caused the problem to begin with. problem to begin with. The Information Gap What Is It?
The information gap between Operations and Engineering is a communications gap. It is a failure of Operations to gather and communicate pertinent, timely information to Engineering. It is a failure of Engineering to formulate and communicate relevant, timely designs and operating guidelines to Operations. It is a failure of each group to define clearly its information needs to the other. It is a failure of each to understand fully the information needs of the other.

Why Does It Exist?
The old saying, "Out of sight, out of mind," describes one reason why the gap exists. Following are some other reasons:
1. The time lag before information reaches the field or central office makes the information outdated.
2. The operator's priorities often allow him little time to worry about the content or the accuracy of the information.
3. The engineer's priorities often involve him in other projects for extended periods during which he ignores the field.
4. The volume of data generated by the fields can overwhelm central clerical staffs.
5. A lack of adequate feedback causes engineering recommendations to seem irrelevant; as a result they are ignored by personnel in the field.

Why Should It Be Bridged?
All of the causes of the information gap can be surmounted - and occasionally they are, when special problems arise-by personal visits or telephone calls. problems arise-by personal visits or telephone calls. However, efficient operations require continual, routine solutions to the information problem. When information is required, either in the field or in the central office, it must be available. So long as the gap exists, there is much important information that is never transmitted, hence never used; this can lead to a continuing spiral of poor decisions and inefficient operation.
A Model for Events Occurring at Random Points in Time and an Example Application to Casing Failures in Cedar Creek Anticline Wells
Authors: Chesnut Dwayne A. , Goldberg Bernard 
Published: December 2007

Abstract
A familiar example of the "Poisson Pure Death Process" is the phenomenon of radioactive decay. It contains a single parameter, λ, which assumes specific values for each distinct unstable nucleus. Rather surprisingly, data on casing failures caused by salt-flow loading in Cedar Creek Anticline wells are also consistent with this model. This analysis is presented in the hope that other complex failure processes, such as breakdown of sand consolidation treatments, might also exhibit the same statistical behavior. In that case, this model could provide a useful tool for evaluating the economic consequences of such failures.
Data for one homogeneous group of wells are used to test the model and to determine λ for the group. The fit is quite good, and the data analysis techniques illustrated should prove useful to anyone attempting to apply the model under the usual condition of small sample size. An analysis and example show how the model provides a basis for deciding when to exercise preventive maintenance and which remedial alternative is most economical.

Introduction
Many types of complex physical phenomena are described quite accurately by a probability model known to mathematical statisticians as the "Poisson Pure Death Process." A familiar example is the phenomenon of radioactive decay. One cannot predict the precise moment that a given atom of a radioactive element will disintegrate. However, the Poisson model does allow one to calculate the probability that disintegration will occur within any time period of arbitrary duration. This model contains a single parameter, λ, which may be regarded as the average number of disintegrations per unit time when a large number of individual atoms are observed. This parameter has a different value for each radioactive element. Thus, its value depends upon physical details such as the chemical species involved, but the mathematical form of the probability law is the same for all radioactive elements.
The model also applies to other problems in which events occur at random times, especially when the physical phenomenon depends on many variables. In this paper, the model is applied to part of the data available on casing failures in Cedar Creek Anticline wells. The failures show up as complete or partial collapse of casing within salt beds at depths of 5,000 to 6,000 ft in most of Shell Oil Co.’s Cedar Creek Anticline fields.
Field Processing, Gathering and Transporting Sour Natural Gas at High Pressures From Pine Creek, Alberta
Authors: Frye C.C. , Becker H.W. , Masuda A. , Deugau A.V. 
Published: December 2007

Abstract
Natural gas containing 25.65 per cent hydrogen sulfide and 4.75 per cent carbon dioxide is gathered from eight wells and transported 26 miles at a flow rate of 160 MMcf/D and at operating pressures of from 2,200 to 1,800 psig. Dry desiccant dehydrators at each wellsite maintain the dew point of the gas below 17F. Telemetering facilities permit control of field operations from a central instrument console. Corrosion control measures, design considerations and material specifications pertaining to these special conditions are discussed.

INTRODUCTION
Natural gas containing 25.65 per cent H2S and 4.75 per cent CO2 is produced from the Pine Creek field, Alta. It is dehydrated at wellheads, gathered at 2,200 psig and transported 26 miles to the Windfall field where it is delivered to the inlet of, injection compressors at 1,800 psig. The daily average volume of gas transported is 160 MMcf. The project is believed to be unique in its combination of percentage of hydrogen sulfide, operating pressure and transportation distance. This paper describes the project and presents details of some of the design features, corrosion control program and centralized automatic operational control.
The Pine Creek field project is one phase of a joint operation of two fields - the other being the Windfall field. The two fields lie about 30 miles north of Edson, Alta. and 20 miles west of Whitecourt, Alta., respectively, as shown on the map (Fig. 1). They are owned by the same interests and operated according to a plan for maximum economic recovery of products. The Windfall Leduc D-3 reservoir contains a rich condensate-bearing gas containing 15.5 per cent H2S. The gas from the Pine Creek field contains only very small quantities of butane and heavier products. The Windfall reservoir is being cycled to obtain maximum condensate recovery using gas from the Pine Creek field as the displacing fluid, while producing the residue sales gas for both fields from the Windfall field.
The Pine Creek field development and gas-gathering facilities are shown on the map (Fig. 2). The producing formation is the Leduc D-3 reef at a depth of 11,300 ft. The original reservoir pressure was 4,590 psia at 7,400 ft subsea and the temperature is 245F. Eight wells are equipped with dry desiccant dehydrators with the following capacity ratings: three at 35 MMcf/D; three at 20 MMcf/D; and two at 10 MMcf/D.

WELLHEAD EQUIPMENT
Dry desiccant dehydrators were designed to reduce the water content of the saturated wellhead stream to 2.5 lb of water/MMcf at 2,000 psig. This specification was necessary to prevent hydrates and corrosion forming in the pipeline which will operate at temperatures as low as 20F. A typical flow diagram is shown in Fig. 3, and Fig. 4 is a photograph of one of the wellhead installations. Some of the design details given below are subject to modification in the field.
Impressions of the Russian Oil Industry
Authors: Smith Noyes D. 
Published: December 2007

Abstract
In 1959 the USSR produced approximately 1 billion bbl of crude oil, which corresponds to U. S. production in 1929. In the Soviet seven-year plan, production of petroleum is scheduled to increase to 1.75 billion bbl. The exploration opportunities in the Soviet Union are roughly comparable to those in the U. S. in the late 1920's. With the techniques presently available to them, it appears certain that they will be able to accomplish the exploration objectives of their seven-year plan. In production, the Soviet industry is conservation-minded, maintains pressure by water injection and plans production of a reservoir on 4 per cent a year. Many of their current fields have multiple horizons which have not yet been exploited. Soviet refineries are difficult to compare to those in the U. S. because the interest is primarily in distillate production rather than in gasoline production. Their equipment is inferior to modern U. S. equipment but is satisfactory for their present demands. The Soviet Union is presently short of pipeline and storage facilities, but a special effort has been undertaken to supply these. The Russians expect to increase their exports of crude petroleum and products, and it is almost certain that they will accomplish their petroleum industry objectives in the seven-year plan. The author's impression was that the people of the Soviet Union are satisfied with their systems of government and economics and are proud of the progress they have made. The people are very poorly informed about the rest of the world, in particular the U. S. Their living standard currently is much below that in the U. S. and Western Europe, although it apparently has risen considerably since World War II.

Introduction
During the month of Aug., 1960, a group of eight oil men representing various aspects of the petroleum industry in the United States and two technical experts from the U. S. Government visited Russia and its petroleum industry. The delegation was selected by the American Petroleum Institute to represent the U. S. oil industry in an exchange of visits with Soviet petroleum representatives.
JPT
P. 621^
A Trapping Hele-Shaw Model for Miscible-Immiscible flooding Studies
Authors: Claridge E.L. 
Published: December 2007

It has been noted previously that Hele-Shaw (parallel-plate) models are better than other types of laboratory models to properly scale down miscible displacements from field size to laboratory size. In most miscible flooding processes, however, the miscible displacement is preceded or followed by an immiscible displacement in which oil or gas is trapped by water, or waterflood residual oil is reconnected by a miscible slug. This trapping and reconnection could not be simulated in a conventional parallel-plate model. parallel-plate model. Now, however, a new version of this type of model has been invented that simulates the trapping behavior of porous rock. Instead of trapping by capillary (surface tension) forces, the new model traps light fluids by density difference (Fig. 1). A model of this type can be used to simulate, for example, the tertiary recovery process in which a solvent slug (e.g., CO2) injected in a waterflooded oil field and then followed by another water drive. The particular model devised for this purpose was made of 3-in. thick, 14-in. square plates purpose was made of 3-in. thick, 14-in. square plates of Plexiglas. The top plate contained 596 pairs of 1/40-in.-diameter holes, 112 in. apart at the base, and meeting 3/4 in. deep in the plate. Vent holes 1/16in. in diameter were drilled from the other side of the plate to the junctions of these pairs. The 12- x 12-in. square perforated region was supplied with wells in a nine-spot pattern, and was sealed around the periphery by an O-ring in a rectangular groove. The plates were held a fixed distance apart by shims and bolts outside the O-ring. A typical plate spacing was 0.01 cm. After the model was filled with liquids and air was forced out of the trapping holes, the vent holes were plugged with rods.
P. 255
Displacement of Oil From Porous Media by Miscible Liquids
Authors: Offeringa J. , van der Poel C. 
Published: December 2007

Abstract
The report describes scaled model experiments on the recovery of oil from porous sands by the injection of miscible liquids [solvents] and the subsequent recovery of the solvents by water flooding. Special attention has been paid to the scaling problem.
Scaling rules are deduced and their correctness is checked by carrying out experiments in tubes of various sizes.
Data are submitted on the effect of the viscosity ratio oil-solvent on the efficiency of the displacement process, the viscosity ratio varying from 1.5 to 5,000.
Breakthrough recoveries obtained when flooding with kerosene as a solvent, are equal to those obtained in water flooding at the same viscosity ratio, indicating that the phenomenon of viscous fingering is decisive. After breakthrough, however, flooding with a miscible liquid becomes much more efficient than a water flood and this is more pronounced as the viscosity ratio oil-solvent is higher.
Although high oil recoveries are obtained and most of the solvent in the sand can be recovered by a subsequent waterdrive, a straight flood with miscible liquids does not appear economically attractive because of the large quantities of solvent required. Therefore, a circulation process is introduced, the features of which are described in this paper. Though by means of this circulation process the amount of solvent required can be drastically reduced, the process is not yet economic.

Scope of the Investigation
The recovery efficiency by water flood of oils of viscosities exceeding 50 cp is low. As interest in production of these highly viscous oils is growing at the moment, it was considered worthwhile to gain basic information on the feasibility of first flooding such oils with a low viscous miscible liquid [solvent] and subsequently producing the latter in a conventional way, e.g. by water flooding. The method has the obvious drawbacks that return on the investment is delayed until water flooding has begun and that it requires the investment of a more valuable product to produce a less valuable one. On the other hand, it may be expected that the displacement of one liquid by another is more efficient when the two liquids are miscible than when they are immiscible. As laboratory data on this point are scanty, the present investigation seemed justified.
The Economics of the International Petroleum Industry
Authors: Chapman A.H. , Duce James Terry 
Published: December 2007

Introduction
The petroleum industry's operations not only affect the lives of all of us here, but also play a major role in shaping the economy and influencing the political life of every nation in the world. We find ourselves today face-to-face with enormous responsibilities at home and abroad. In this paper the writers will review some of the dangers and pitfalls which the industry has overcome in the past, and, even more important, take a good look at the future - particularly the long term future of supply and demand, and the political factors which underlie them.
Thirty-five years ago we were gravely concerned over our vanishing oil resources. At that time one of the pundits of the economic world recommended to his friends that they sell their oil stocks for the reason that the industry would soon have no raw material with which to work. At the same time, a Kansas professor strongly advised against "senseless joy-riding," as he considered it a waste of precious natural resource which, in his opinion, should only be sold at a very high price as, of course, a measure of conservation. However, our Kansas professor felt also that the way to keep the price high was for the states to siphon-off the profits in high taxes, and he mentioned taxes of a dollar a barrel.
Our first and greatest concern then was the scarcity of the basic raw material upon which the industry lived. Eugene Stebinger, then chief geologist of the U. S. Geological Survey, had estimated the possible world reserves at under 30 billion bbl. MidContinent crude sold for over $31 bbl. Since that time we have consumed some 50 billion bbl and today our forward supply picture has never been more promising.
Dual Pumping With Five Strings of Tubing
Authors: Edwards F.C. 
Published: December 2007

Introduction
Dual pumping, and its accompanying problems, has been a subject of continuing interest to the oil industry. From an economic standpoint, a substantial savings in drilling and equipment costs can be realized by the use of dual completions.
The problems encountered in the design and installation of the dual pumping equipment in this particular field were no different from those likely to be met in any field where dual pumping might be considered. For successful installations in this field the objectives of the designers were:To utilize conventional hydraulic pumping equipment, thereby standardizing all pumping operations.To obtain high pumping efficiencies from both zones by completing the upper zone with no packer and venting the gas in the lower zone from beneath the picker to the surface.To pump each zone independently without communication between the two as required by the Oil and Gas Division of the Texas Railroad Commission.
These three objectives have been accomplished and all presently-installed dual pumps of the type to be discussed are operating successfully. This type of dual pumping completion eliminates many of the problems encountered with "down the hole" trigger mechanisms. Each zone may be pumped in a conventional manner and both zones can be pumped simultaneously or individually.

Well Completions
Dual pump installations have been installed in the Prentice field and the Prentice 6,700-ft field located in Yoakum and Terry Counties, Tex. The pay zone in the Prentice field is the Glorietta (limestone of Permian Age), at a total depth of approximately 6,000 ft. The pay zone in the Prentice 6,700-ft field is the Clearfork (limestone of Permian Age), at a total depth of 6,700 ft. Most wells in both the Glorietta and Clearfork underwells. Prior to installation of dual pumping equipment in wells in these fields, all wells were twinned, that is a single well was drilled to each pay zone.