bluuebunny/crossref_metadata_2025_split huggingface dataset:
Water Injection, Arab-D Member, Abqaiq Field, Saudi Arabia
Authors: Malinowski R. 
Published: December 2007

PUBLICATION RIGHTS RESERVED
This paper is to be presented at the 36th Annual Fall Meeting of the Society of Petroleum Engineers of AIME in Dallas, October 8–11, 1961, and is considered the property of the Society of Petroleum Engineers. Permission to publish is hereby restricted to an abstract of not more than 300 words, with no illustrations, unless the paper is specifically released to the press by the Editor of JOURNAL OF PETROLEUM TECHNOLOGY or the Executive Secretary. Such abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in JOURNAL OF PETROLEUM TECHNOLOGY or SOCIETY OF PETROLEUM ENGINEERS JOURNAL is granted on request, providing proper credit is given that publication and the original presentation of the paper.
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 considered for publication in one of the two SPE magazines with the paper.

Abstract
A peripheral water injection system was begun in the Abqaiq Field of Saudi Arabia in 1956. The initial system consisted of gravity injection into three nose wells. Following the completion of the flank installations and electrification in 1958, injection rates were increased to the present rate of 30 to 40 MBD per well. The field water injection rate is approximately 300 MBD. The volumetric effectiveness of injected water is 50 per cent and is expected to increase to 70–80 per cent.
The water supply source, the Wasia formation, is a prolific aquifer containing non-potable water of 8,000 ppm total dissolved solids. The water is corrosive, however, corrosion is controlled by inhibitor injection. The Wasia water injection system is a closed pressure system.
A temporary sea water injection system was installed to evaluate the problems of a sea water injection project. The results of this project are presented.

FIELD HISTORY
The Abqaiq field was discovered in 1940, but full-scale development did not begin until 1946.
Figure 1 is a structure contour map of the Abqaiq field. For analytical purposes the field has been divided into two areas designated A and B as shown on the map.
At present there are 61 producible wells in the field. They are drilled on a contour pattern and the average spacing is about 5,000 feet.
Initial pressure at -6,500 feet datum was 3,395 psig and the bubble point of the reservoir fluid is 2,545 psig. The reservoir was undersaturated at discovery.
Average solution gas-oil ratio is 850 scf/STB. There has been essentially no change in producing gas-oil ratio. Separation is done at centralized separator plants of which there are three: one, in Area B and two in Area A. The crude goes through separation stages of 500, 250, 50 and 2 psig.
Evaluation Of The Slope Of Oil/Water Interface And Its Changes With Time
Authors: Hilmi Samara 
Published: December 2007

1961 Middle East Regional Meeting; Dhahran, March 27–29, 1961

SUMMARY:
The slope of the oil/water interface in edge water drive reservoirs is investigated. Equations of motion of the interface and their boundary conditions are presented, with possible computational techniques to solve these equations numerically. These equations are solved in some detail, especial emphasis being placed on the change of the angle of tilt with time, in two special cases: the first assuming no cross flow perpendicular to the bedding plane, the second assuming that there is maximum cross flow in that direction.

INTRODUCTION:
Theoretical analysis, laboratory investigation, and field observation all show that the advance of edge water in a water drive reservoir tends to distort the oil water interface. Pressure gradients caused by oil production and subsequent pressure drop in the producing area vary along the oil/water interface, thus causing the water to move with varying speeds in the different parts of the reservoir. This results in the distortion of the oil water interface.
Distortion of the interface as a result of oil production can be divided broadly into two categories local and field wide. These correspond to the pressure drawdowns in the reservoir, which can also be divided into bottom hole pressure differentials limited to the vicinity of the producing well, and to an overall pressure decline in the reservoir. We can picture the overall pressure decline at any time as a smooth curve varying from point to point in the reservoir. The bottom hole pressure differentials can be thought of as localized 'sinks' superimposed on this curve.
The Effect of Nitrogen on the Phase Behavior and Physical Properties of Reservoir Fluids
Authors: Vogel John L. , Yarborough Lyman 
Published: December 2007

Abstract
Nitrogen can be produced from air separation plants at considerably less cost than the value of an equal volume of natural gas. For this reason, nitrogen has been considered for pressure maintenance operations in gas condensate and oil reservoirs. However, the possibility that significant changes in phase equilibria and physical properties could occur in the reservoir fluid has hindered its acceptance as an injection gas.
Experimental laboratory tests were conducted in which gas condensate and black oil reservoir fluids were contacted by nitrogen at reservoir conditions. The results showed that the dew point pressures of gas condensates would significantly increase and retrograde liquid could condense where the nitrogen mixes with the reservoir gas. Additional contact by nitrogen revaporized a significant amount of the condensed retrograde liquid.
The results also showed that the oil formation volume factor and solution gas-oil ratio decreased, and the oil density and viscosity increased when a black-type oil was contacted by nitrogen.
The experimental tests were simulated using a modified Redlich-Kwong equation of state. The results showed that this equation of state can be tuned to reliably predict the effects of nitrogen on phase equilibria and physical properties of reservoir fluids. This equation of state could subsequently be used in compositional reservoir simulators to predict overall effects of nitrogen injection on reservoir performance.
A Report on the Old Luling (Edwards Limestone) Field, Caldwell and Guadalupe Counties, Texas
Authors: Davis Phillip , Goode O.N. 
Published: December 2007

Abstract
The history of the Old Luling (Edwards Limestone) field, Caldwell and Guadalupe counties, Tex., is briefly reviewed from the date of discovery through the year 1946.
In the year 1946, the field was in an advanced state of depletion. The operator of a majority of the field undertook an intensive work over, drilling-deeper, new well, and modernization program extending through the year 1955. This program, which involved the use of diamond coring, radioactive and electric logs, the application of cementing techniques new to the Luling field, correlation of underground zones of porosity in the Edwards Limestone, and the disposition of large volumes of salt water, is reviewed in detail. Oil productions which had reached a low of 1.5 million bbl/year in 1946, was increased to 2.5 million bbl/year by the end of 1955, and during the year 1956 showed the first decline after the program was started. Replacement of equipment in use for 25 years in a sour crude field is discussed. A better understanding of the geology and the nature of the accumulation and how it is affected by faulting was obtained by the program. In several instances, virgin or undrained reservoirs were developed.

Introduction
The Old Luling field is located in Caldwell and Guadalupe counties, Tex. It is approximately 5 miles northwest of the city of Luling and 1.1 miles southeast of the town of Prairie Lea, Tex. The specific geographical location is shown in Fig. 1.
Some time after the discovery of the Luling field, the name was changed to the Luling-Branyon field.
Alternate Slugs of Gas and Dilute Surfactant for Mobility Control During Chemical Flooding
Authors: Lawson Jimmie B. , Reisberg Joseph 
Published: December 2007

Abstract
Studied was a novel technique for mobility control during chemical flooding, namely, the injection of alternate slugs of inert gas and surfactant solution. This method of reducing mobility offers a possible alternative to polymer thickened water.
Performance was investigated in consolidated sandstone and carbonate. Sandstone included cores, and large slabs of rock oriented so as to maximize gravity segregation of gas.
Reported data suggest that, for mobility control in laboratory rocks, performance of alternate slugs of gas and dilute surfactant compares favorably with water soluble polymers, without the many disadvantages of the latter.
During experiments in large sandstone slabs, excessive foam drainage, and gravity segregation of gas, did not occur.
A Progressive Approach to Marginal Field Development in S.E. Asia
Authors: Milton Alan 
Published: December 2007

Abstract
No operator will knowingly decide to develop a marginal field uniess for research and development purposes.
Having said this, it is obvious, from the amount of publicity given to marginal discoveries, that there are such things as marginal fields.
This paper seeks to establish a definition of a marginal field, and the factors resulting in that definition.
Methods of improving the financial viability of such fields are described, using the particular qualities of flexible flowlines, floating production and storage facilities, and subsea completion or "tieback" technology.
The concept outlined is called progressive for the simple reason that the equipment used, because it is designed on a modular basis, allows the development of the field to progress from the initial testing or early production phase through to the final system, without significant interruption, irrespective of what the final system is.
An Assessment Of Grouting Materials, Placement Methods, Monitoring Equipment, And Flotation Equipment For Offshore Structures
Authors: Knox L. Carter , Sutton David L. , Callis Cliff 
Published: December 2007

Abstract
Current grouting technology is reviewed emphasizing some of the latest developments. Main topics covered are grouting materials, grouting methods, grout monitoring techniques, recent grouting related improvements, and structure flotation equipment.
Grouting materials to promote faster and higher strengths, help prevent self-desiccation, and offer increased expansions are discussed. Grouts are classified according to use and typical examples are given.
A new type of lightweight admixture has been developed which can be used to formulate low density (12.5 lb/gal, 1.5kg/dm3) grouts with final strength approaching that of normal (15.6 lb/gal, 1.87 kg/ dm3) density grout. Because of the vastly improved strength of this grout as compared to other low density grout, the use of such low density grouts to facilitate placement procedures warrants reevaluation.
Discussion of grouting methods covers five different techniques and their application. Several of these methods involve the use of new generation high pressure packers and flow control valves. With this new equipment, packer inflation/ grouting manifolds can be devised which enable multiple packer inflation through a single line and grout placement into multiple ports through a single line.
Improved leg plugs, conductor pipe plugs, and j-tube plugs have made structure flotation a simpler, more trouble-free operation. The plugs offer unprecedented economy and dependability. The leg plugs and conductor pipe plugs are mechanically set, retrievable, and reusable.
Power-Law Flow And Hydrodynamic Behaviour Of Biopolymer Solutions In Porous Media
Authors: Teeuw Dirk , Hesselink F. Theodore 
Published: December 2007

ABSTRACT
Aqueous biopolymer solutions have been investigated for their flow behaviour in porous media. A flow equation for these power-law fluids has been derived taking into account the effect of tortuosity on both shear stress and shear rate. A comparison has been made with previous equations (Christopher et al, Bird et al).
The equation was applied in flow experiments in Bentheim sandstone rock. Approximately the same flow behaviour exponent n was observed in core flow as in measurements with a rotation viscometer. It was found, however, that the flow coefficient K in core flow is about a factor of 2 lower than observed in a viscometer. This observation is given a plausible theoretical explanation on the basis of a model of a porous medium, consisting of a system of dilatations and constrictions.
In the derivation of flow equations it is usually presumed that the diameter of the dissolved particles in the flowing medium is negligible compared to the diameter of the flow channels. This presumption is not valid for polymer solutions. Consequently, the velocity profile of the polymer particles differs from that of the associated brine molecules, so the polymer tends to lead the brine. This hydrodynamic phenomenon provides a more satisfactory explanation for the so-called inaccessible pore volume effect than the concept that water flooding polymers do not occupy all of the connected pores. This has been illustrated in core flooding experiments in the absence and presence of oil. It also complicates the determination of adsorption/retention characteristics of polymer on rock in dynamic experiments.
Hydrocarbon Gels Of Alumino Alkyl Acid Orthophosphates
Authors: McKenzie Lee F. 
Published: December 2007

ABSTRACT
Partial aluminum salts of alkyl orthophosphates (AAAO) are effective gelling agents for hydrocarbons. The simplified chemical model of AAAO gel presented in this paper is used to describe mechanisms for breaking AAAO gels in oil field applications. The preferred method of breaking is with acid. By selecting an appropriate acid system, delayed action breaking with a predetermined amount of viscosity reduction can be obtained.
Application of Low Solids Mud in Cotton Valley Drilling
Authors: Miller James D. 
Published: December 2007

Abstract
This article discusses the practical application of low solids non-dispersed drilling fluid related to Cotton Valley drilling operations. A low solids system is briefly defined and proper solids control equipment and maintenance techniques are discussed. In conclusion the paper discusses mud related Cotton Valley drilling problems and presents examples of field data showing the favorable results achieved with a low solids mud system in several Cotton Valley wells.
Inflation in the Oil Industry in the 1970 - 1980 Decade, and its Significance
Authors: Garde-Hansen Hans 
Published: December 2007

ABSTRACT
The oil industry has seen inflation on both sides of the balance sheet well above that experienced by the general consumer, not only in increased costs, but in the difficulty of finding new reserves, and arbitrary government imposed tariffs. Figures presented will show that the high profits reported by many oil companies are misleading and still do not leave adequate funds for reserve replacement costs. Conclusions are drawn that governments must leave adequate and more funds with companies for future development.
Automatic Pump-Off Control for the Variable Speed Submergible Pump
Authors: Divine David L. 
Published: December 2007

Abstract
The Variable Speed Submergible Pump has been used for several years to match a submergible pump's characteristics to a well's production capability. Past applications have included those where a bottom hole pressure measuring device was used to control the pump speed and therefore the pump intake pressure. The automatic pump-off controller, discussed in this paper, allows an operator to maintain minimum pump intake pressure without a bottom hole pressure sensor. The controller also uses special speed variation techniques to prevent or possibly break a gas lock condition.
This paper will discuss the development of the controller and the physical principles which it is based on. Operational tests will be described along with the problems encountered. Finally, the future use of this controller in new applications, such as with wells which produce sand, will be presented.
The Use of Horizontal Drainholes in the Empire Abo Unit
Authors: Stramp Ryan L. 
Published: December 2007

ABSTRACT
ARCO Oil and Gas Company has drilled two horizontal drainhole wells in the Empire Abo Unit – A horizontal drainhole well is one in which the wellbore is turned from vertical to horizontal in a short radius and the horizontal hole is then drilled out some distance into the formation. These wells were drilled to evaluate the mechanical feasibility of the drilling process and to examine the effect producing through the drainholes would have on the well's tendencies to form gas cones. Although several problems were encountered while drilling the drainholes, the drilling technique used does seem to be mechanically sound. The wells have not been on production long enough to fully evaluate their gas coning performance as compared to conventionally completed wells.
This paper will briefly examine the gas coning problem in the Empire Abo Unit, discuss some of the techniques used to limit gas coning in the Unit, and review ARCO's experience with horizontal drainholes.
North Sea And Netherlands Gas Reserves And Their Impact On Free World Energy
Authors: Wright M.A. , Priestman G.D. 
Published: December 2007

Introduction
It is a pleasure to be with you here in Dallas this afternoon to discuss a subject that has caught the imagination not only of oil men but of the general public as well.
The spark that ignited this interest was the gas discovery in the Groningen province of Holland in 1959. Subsequent exploration has indicated it to be one of the largest gas fields in the world. What has quickened and held public interest, of course, is its potential significance to free Europe's energy supply.
With the aid of a few figures, I should like to do four things this afternoon:
First, comment on the European energy picture and outline the pattern that this new source of energy will be fitting into.
Second, describe the Groningen field and the way it is being developed.
Third, give you some idea of exploration problems in the North Sea area.
And fourth, speculate briefly on the impact which discoveries in these areas could have on European energy consumption.
Obviously, each of these topics deserves more attention than I will have time to give it, but I will touch on the essential points of each.

EUROPEAN ENERGY PICTURE
Fig. 1 compares free European energy consumption during 1964 with that of the United States and the Free World, in terms of oil equivalent. First this chart shows the energy consumption in Europe was some 16 million B/D. This is two-thirds of the U. S. consumption of 24 million B/D, and 30 per cent of the Free World total of 52 million B/D.
Fig. 1 also illustrated the considerable differences in the types of energy used in Europe and the U. S. For example, coal supplies 44 per cent of Europe's energy, twice that of the U. S. (22 per cent), while natural gas supplies less than 2 per cent of European energy as opposed to 29 per cent in this country. You will note that in both areas oil has a similar share of the energy market — some 45 per cent.
Another significant factor in the European energy pattern is that 42 per cent of the requirements are imported, as compared to 8 per cent in the U. S. Although everyone knows that most of Europe's petroleum must be imported, it is of interest to note that nearly 10 per cent of the coal consumed is also imported.
Finally, the over-all growth rate of energy consumption in Europe in the past 10 years has been 4.3 per cent a year, and is predicted to be 4.0 per cent a year in the foreseeable future. These figures are significantly higher than growth rates in the U. S.
Europe's rapid growth in energy demand and dependence upon imports offers many problems involving security of supply, balance of payments, etc.
P. 13^
Making The Organization Plan Work
Authors: Watson Douglas 
Published: December 2007

Introduction
Six to eight months ago, when Ernie Miller first talked to me about meeting with you this afternoon, he mentioned that the Management and General Interest Committee was concerned with the problems of organization. As a result of these discussions and my substantial interest in the subject, I found myself agreeing to be here today. Little did I think that simple conversation with Ernie would cause so much introspection on my part.
I determined early in the game that just another talk or discussion on the principles of organization would be redundant to most of you and not very helpful in this complex world in which we live. Accordingly, I took the license of retitling my discussion today, "Making the Organization Plan Work", and it is to this portion of the topic that I would like to address myself.

A SUCCESS STORY
Let me draw a picture for you that indicates why I feel it is important that we consider this aspect of the organizational problem.
Recently, a large transportation company with which I am familiar attracted substantial headlines in that, for the first time in several years, it recorded an attractive operating profit. Indeed, it went to its customers and proposed a rate reduction. This is something almost unheard of in this day of rising prices. And yet, this is a company that for the last 10 or so years has seen an increasingly difficult operating circumstance accompanied by unattractive return on its substantial investment.
What is the secret ingredient of this success? The turning point here is in the personality of the new chief executive. This chief executive, with a small corps of devoted subordinates, literally single-handedly turned this large organization around. True, there was a sense of crisis, but the important thing here was that there was felt a sense of desire, a real motivation.
The Role of Step-Rate Injectivity Testing in Liquid Dominated, Highly Fractured Geothermal Reservoirs
Authors: Allen Terry S. , Baza John R. 
Published: December 2007

ABSTRACT
A step-rate injectivity testing program was designed to obtain additional operating parameters and reservoir data of the Roosevelt Known Geothermal Resource Area (KGRA), Beaver County, Utah. The testing program consisted of injecting fresh water at rates varying between one half (0.5) BPM and sixty (60) BPM into four producers and one injector. The rates, wellhead pressures and subsurface pressure data collected was used to size injection equipment for future field development, verify the highly fractured reservoir and cross check previous permeability calculations by using the multiple rate transient technique.1
Field Evaluation of Method to Control Gas Flow Following Cementing
Authors: Watters Larry T. , Sabins Fred L. 
Published: December 2007

ABSTRACT
Gas flow following cementing has hindered the completion of wells for a number of years. Research of this problem has indicated many solutions which have been either partially successful or unsuccessful in controlling gas flow following actual cementing operations.
A theory describing the cause of this problem and a novel solution to the problem were presented in SPE 8257.1 This paper summarized the results obtained during a fifteen-month field application of the control method. Results of 250 cement jobs performed world-wide are summarized and specific examples are discussed in detail.