bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reservoir Management in the B-6/9, SVS-82, Lake Maracaibo, Venezuela - New Exploitation Policy for Maximizing Profit
Authors: de Carvajal G. , Banerjee S. , Carrizales R. , Garrido M. , Lozada T. 
Published: December 2007

Abstract
B-6/9, SVS-82 reservoir is located in Blocks IX and X in Maraven's concession area in Lake Maracaibo Basin in Western Venezuela. The field has been on production for more than 30 years and the recovery to date has been 45% of the OOIP (930 MMSTB). Its remaining reserves are confined between a gas front formed by the re-injection of the produced gas and a water front created by a strong aquifer in a relatively small area towards the top of a monoclinal structure. Though the reservoir is fairly well depleted, a prudent and comprehensive reservoir management program implemented during the past three years has substantially improved the production from this reservoir and consequently, the reserves have increased. This was accomplished by using new and existing technologies, such as, integrated reservoir characterization, 3-D Seismic, non-conventional simulation techniques, well workovers highly deviated wells and infill drilling. Prompt implementation of the exploitation policy has increased the reservoir production from 6 MSTB/D to 22 MSTB/D.
An integrated reservoir characterization study covering 3-D seismic, geology and geophysics, sedimentology, petrophysics and engineering has helped delineate the new reservoir limits and identified additional reserves and drilling prospects. A finely layered 3-D, 3-Phase reservoir simulation model was developed for a partial area of the field where most of the remaining reserves were confined between the advancing water and gas fronts. The Enumeration technique of reservoir initialization allowed a quick start of the forecast cases to investigate the productivity of the high angle wells and various combinations of infill drilling scenarios. The optimum number of infill wells — 20, was determined by economic factors.

Introduction
B-6/9, SVS-82 is one of Maraven's largest light oil reservoirs, located in blocks IX and X in Maracaibo Lake, Venezuela (Fig. 1). Production started in 1965 and in 1974, a gas injection project was initiated mainly for the purposes for storage and conservation. After 31 years of production, 45% of the OOIP (417 MMSTB) has been produced. The drainage strategy implemented in this reservoir has caused the remaining reserves (80 MMSTB) to be confined updip between the advancing gas and water fronts in a relatively small area towards the northern part of the reservoir.
In 1993, the Ministry of Energy and Mines (M.E.M) restricted the production from the reservoir. High GOR wells &gt;2500 SCF/B) had to be closed thereby reducing the reservoir oil rate to 6 MSTB/D. Production of high volumes of gas did not conform with the current reservoir drainage strategy (gas injection). Since it would be difficult to achieve the expected ultimate recovery for this reservoir under these conditions, a complete re-engineering of the project was initiated. Figure 2 shows a schematic of the reservoir management program that has been underway since 1993.
An Analysis Of Volumetric Balance Equation For Calculation Of Oil-In-Place And Water Influx
Authors: Tehrani D.H. 
Published: December 2007

Abstract
When fluids are withdrawn from a petroleum reservoir, the space left behind is filled partly by the expansion of the remaining fluids and rock and partly by the influx of water from a contiguous aquifer, if it exists. The Volumetric Balance Equation (VBE) is an expression Of this same statement. Its simplified form is:
Z = Ax + BY (1)
where;
Z = Total Fluid Withdrawals in MMRB
A = Original Active Oil-in-Place in MMRB
X = Unit Expansion
B = Water Influx Constant
Y = Water Influx Function
When sufficient historical data on X and Z are available, various functions for Y can be tried, and by the technique of least squares a set of values can be calculated for A and B.
It has been convenient to write the equation in the following form:
Z/X = A + B (Y/X) (5)
The advantage of this form is that firstly, it has only two variables, and least square calculations are easier for it; and secondly, the values of Y/X and Z/X can be graphically plotted, so that a linear trend can be visually examined. The disadvantage is that the equation has a low resolving power, and can produce erroneous answers. Nevertheless, in a literature survey carried out it was found that most authors used this form of Eq(5).
Application of Radioisotopes to Sub-Surface Surveys
Authors: Alberts A.A. , Cocanower R.D. , Bundrant C.O. 
Published: December 2007

Abstract
Recent advances in the technology of the use of radioisotopes has enabled the development of new techniques for oil and gas well surveys. Almost without limit, these surveys can be designed to answer questions regarding down-the-hole well conditions. They have been found to be reliable and relatively inexpensive. Early experiments used radium. Its use is objectionable because of its long half life. As other isotopes became available, this objection was overcome, so that today radioisotopes are revealing accurate subsurface information — the key to maximum production.
Application of the radiotracer technique requires the running of a reference log of the formation prior to addition of the radioactive material; the adding of the radioactive material to a fluid and pumping it into the well through perforations or into the open hole; the plating out, or filter cake build-up, of the radiotracer on the formation; and, subsequently, running several logs to determine the location of the tracer.
By comparison of these several logs, each to the other and to the base log, an interpretation can be made. It is possible, therefore, to locate permeable zones, to detect faulty cement at the casing shoe, to locate fractured zones, to locate communication between perforations, to assure correct location of a blocking agent, and to locate the cement top.
Operational hazards in handling radioactive materials cannot be minimized. However, they can be readily controlled, with little danger to personnel or of contamination of equipment, by the use of Atomic Energy Commission approved procedures.
This paper describes a few of the many possible applications of the plating-out technique in an effort to illustrate the potentiality of this new tool.
The isotope used in this work was received on allocation from the United States Atomic Energy Commission.

Introduction
Radioactive isotopes are being increasingly accepted as the key to accurate sub-surface information — the key to maximum oil and gas production. All of us are aware that the rate of flow of oil into the well-bore depends to a great extent upon the permeability of the producing formation. When these voids become plugged, oil production falls off. By a properly designed treatment, production may be restored.
Correlations for Design of Gas Transmission Lines
Authors: Walton Thomas A. 
Published: December 2007

This paper was prepared for presentation at the 47th Annual Fall Meeting of the Society of Petroleum Engineers held in San Antonio, Tex., Oct. 8–11, 1972. 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 who the paper is presented. Publication elsewhere after publication in the JOURNAL 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. 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.
When simulating a physical process, an engineer or a mathematician process, an engineer or a mathematician may choose to ignore some of the many influencing factors. In most cases, these factors are ignored because their effects are negligible. In some cases they are ignored because it makes the problem easier to solve. In the case of the general flow equation for steady state flow in pipelines, the flowing temperature pipelines, the flowing temperature has fallen victim to both of these reasons. Temperature effects are assumed to have little effect on pressure drop and even some of the pressure drop and even some of the more advanced simulations assume isothermal flow.
The general flow equation may be written in the form:
(1)
(2)
(3)
Ignoring elevations, this may be written:
(4)
(5)
However,
(6)
Temperature Logging In Injection Wells
Authors: Witterholt E.J. , Tixier M.R. 
Published: December 2007

This paper was prepared for presentation at the 47th Annual Fall Meeting of the Society of Petroleum Engineers held in San Antonio, Tex., Oct. 8–11, 1972. 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 who the paper is presented. Publication elsewhere after publication in the JOURNAL 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. 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.
To further the scientific aspect of temperature logging procedures and interpretation methods, theoretical models describing the exchange of heat between injection fluid, borehole, surrounding formation, and injection zone have been used to study; the borehole-fluid temperature during injection, as determined by rate, depth, and duration of injection, the temperature along the axis of the cylindrical system as it recovers under shut-in conditions from the disturbance due to injection, and the establishment of the formation-temperature disturbance due to injection of fluid. Comprehension of the heat-exchange phenomena involved has been stressed, rather than detailed matching of specific logs. In general, it was sought to establish what information a temperature survey could reasonably be expected to yield under "ideal" and actual field conditions. The results provide specific information concerning: - a criterion for running an injection temperature survey as a source of flow-rate data, - the effects of vertical heat exchange on temperature distribution during injection and shut-in, - the relation between time of shut-in and ability to discern the radial extent of the formation-temperature anomaly, and - the relation between rate and duration of injection and the radial extent of the formation anomaly. A principal conclusion from this study is that a temperature survey alone should not always be expected to yield volumetric flow information. Rather, a combination of temperature and flowmeter or tracer surveys should be conducted. Further, when injection has been going on for a considerable length of time, heat exchange within the formation can cause an anomaly of greater vertical extent than the injection zone itself.
P. 1
Performance History on Use of Biopolymer in Springer Sand Waterflood in Southern Oklahoma
Authors: Perry Boyce 
Published: December 2007

Abstract
An area within the North Alma Penn Unit, operated by Samedan Oil Corporation, has been selected to evaluate the effects of injecting a biopolymer at various concentrations into the Sims Sands reservoirs beginning during the early stages of waterflooding. The polymer "slug", sized equivalent to fifteen polymer "slug", sized equivalent to fifteen percent (15%) of the effective pore volume based percent (15%) of the effective pore volume based on a concentration of 250 parts per million (ppm), was started after thirty-one percent (31%) of the reservoir voidage had been filled with straight brine. Approximately thirty-nine percent (30%) of the polymer poundage has percent (30%) of the polymer poundage has been injected at a concentration of 304 ppm and has caused no apparent damage to the reservoirs. Five (5) of nine (9) producing wells have responded to water injection, and three (3) of these have shown a recent reduction in water production. Further injection will be required to fully determine the total effectiveness of the polymer, but there are early indications that the polymer is influencing the water cut in some wells.

Introduction
The North Alma Penn Unit is located approximately three (3) miles northeast of the townsite of Velma, Oklahoma in Stephens County. The Unit was formed in February, 1970 for the purpose of waterflooding three (3) Deese Sands and three (3) Springer Sands. Water injection was begun in November, 1970, into the lower Deese Sand (Pickens) and the Springer Sands (First, Second and Third Sims); injection into the upper Deese Sands is to be phased in as the in-line Sims producing wells phased in as the in-line Sims producing wells water out. For purposes of this paper, discussion will be limited to the Sims Sands.
The Sims Sands comprise approximately seventy-six percent (76%) of the total acre-feet of the net oil volume. Major faults separate each Sims reservoir into four (4) distinct fault blocks, and the northernmost fault isolates the area herein referred to as the "North Fault Block". It is within the North Fault Block where the injection of biopolymer fluid was begun in August, 1971, and is still in progress.
Selection of the North Fault Block for polymer injection was based on the following: polymer injection was based on the following:
- Uniformity of zones
- Complete closure of reservoirs with aquifers controlling three
- sides and a major fault on the southside.
Laboratory Tests on Collapse Resistance of Cemented Casing
Authors: Evans George W. , Harriman Don W. 
Published: December 2007

Abstract
Laboratory tests on collapse resistance of cemented casing give an insight into the role cement sheath strength and integrity have on the collapse resistance of tubular goods. A full cement sheath can materially improve the collapse resistance of the tubular goods-cement sheath structure. The stronger full cement sheaths offered the greatest resistance to collapse pressure. Cement sheaths that contain voids above a certain size give very limited improvement in collapse resistance.

Introduction
The role of the cement sheath relative to tubular goods performance in oil and gas wells has long performance in oil and gas wells has long been a subject of discussion. The questions generally raised concern the thickness, strength and configuration of the sheath and the effects of these upon burst and collapse resistance of cemented tubular goods. This study was initiated for the purpose of investigating the properties of the cement sheath with properties of the cement sheath with respect to their effect on the collapse resistance of the tubular goods cement sheath structure.
Collapse resistance of dual strings of mechanical tubing cemented together with sheaths of cement of various strengths and configurations was investigated. The tests considered conditions where collapsing forces were imposed on a bare cement sheath as well as a cement sheath surrounded by tubing. The dual tubular string collapse resistance was determined by applying hydraulic and mechanical loads to the structure.

Hydraulic Collapse Tests
Tests were first run to determine the hydraulic collapse pressure of uncemented tubing. pressure of uncemented tubing.
An Instrument for Measuring the Density of Air Entrained Fluids
Authors: Nickles S.K. 
Published: December 2007

Abstract
A simple solution to a problem which has often caused problem which has often caused significant error in the density measurement of fluids has been achieved. Some fluids, e.g., viscous cement slurries and drilling fluids, tend to entrain or trap a considerable volume of air. An instrument which effectively compensates for this air entrainment has recently been developed. In the petroleum industry, this instrument can be utilized at the surface of a gas or oil well site, and yet give a good indication of the density of a fluid at subsurface or downhole conditions. The basic concepts and physical premises on which the instrument premises on which the instrument was designed are discussed and analyzed in this paper.

History
The measurement and control of the density of drilling fluids (muds) and cement slurries has long been an important factor in the drilling of oil and gas wells. If the density of the fluid being pumped into the well is too low and a pumped into the well is too low and a high pressure zone is encountered, a blowout may quickly develop. on the other hand, if the fluid density is too high and a low pressure or "thief" zone is encountered, large quantities of expensive fluid can be lost to the formation which can also result in a blowout.
A variety of devices are used in determining the density of a fluid, with the conventional mud balance being the present recognized petroleum industry standard. The standard mud balance consists of a base and graduated arm with cup, lid, knife edge-type pivot point, sliding weight, bubble pivot point, sliding weight, bubble level and counterweight.
Electrical Conductivities in Shaly Sands - I. The Relation Between Hydrocarbon Saturation and Resistivity Index; II. The Temperature Coefficient of Electrical Conductivity
Authors: Waxman Monroe H. , Thomas E.C. 
Published: December 2007

Abstract
A simple physical model describing shaly sand conductivity was previously described by Waxman and Smits. The electrical conductivity of a water-saturated shaly sand was expressed as a function of a geometry factor, the brine conductivity, an effective concentration of clay exchange cations, and their equivalent ionic conductance. Experimental data support this relation. The model was extended to cases where the sands were oil-bearing. An expression was obtained relating the resistivity index to water saturation, brine conductivity, and the clay parameters mentioned above.
The assumptions involved in the model for oil-bearing sands have now been confirmed by additional laboratory conductivity measurements. We conclude that the effective concentration of clay exchange cations is increased by a quantity proportional to the decrease in water saturation. Twelve different rock samples from seven fields were utilized in these studies, incorporating a wide range of brine conductivities, oil saturations, and cation exchange capacities.
Further, the temperature coefficients of electrical conductivity were measured for a set of shaly sands equilibrated with salt solutions covering a wide range of concentrations. When compared at the same electrolyte concentration, these temperature coefficients increased systematically with increasing clay content of the sands.
Experiments on Effect of Water Injection Rate on Imbibition Rate in Fractured Reservoirs
Authors: Mannon Robert W. , Chilingar George V. 
Published: December 2007

Abstract
A relationship has been established in the laboratory between rate of water injection into a simulated fracture-matrix type reservoir model and rate of imbibition. In a series of experiments involving linear countercurrent flow, it was discovered that the higher the water injection rate, the higher the imbibition rate and the greater the indicated ultimate oil recovery.
The model consists of a horizontal slab of Berea sandstone having approximate dimensions of 6 in. × 6 in. × 112 in. sealed on all sides except for opposite 6 in. × 11 in. ends. Plates were placed across the exposed ends with a 0.001-in. to 0.002-in. clearance. Water was injected into the simulated fractures between the plates and the exposed sand faces.
Repeated runs, made using one side of the matrix block and then the opposite side, indicate that the water injection rate (same time duration):imbibition rate correlation is well defined. Two additional factors that dictate the nature of the injection rate-imbibition response are temperature and the condition of the sand face exposed to imbibition.
The results of the experimental work suggest that, under proper conditions, increased water injection rates may lead to higher production rates and oil recoveries in production rates and oil recoveries in reservoirs having fracture-matrix type porosity.

Introduction
Production of oil and gas from fractured reservoirs is common. Such reservoirs occur in various parts of the world. The host rock may be sandstone, siltstone, shale, limestone, or dolomite. Many of the reservoirs exhibit low values for permeability within the formation blocks themselves (called matrix permeability) and yield oil and gas at commercial rates due primarily to the existence of an elaborate primarily to the existence of an elaborate fracture system in the producing zone. Wells completed in low-permeability fractured reservoirs may flow initially at fairly high rates as the oil originally residing in the fractures moves rapidly to the wellbores. The movement of the oil from the matrix blocks to the fractures does not keep pace with the flow of oil from the fracture system to the wells, however, and the wells experience sharp decline in production rate. Early in the life of the pool, the wells may settle down at very low rates as the slow process of oil migration from the matrix blocks process of oil migration from the matrix blocks to the fractures and then eventually to the wells begins. The ultimate recovery from reservoirs of this type when subjected to solution gas drive is also very low.