bluuebunny/crossref_metadata_2025_split huggingface dataset:
Modelling Faulted and Fluvial Reservoirs
Authors: Smith P. J. , Morgan D. T. K. 
Published: December 2007

Abstract
In this paper methods are presented for calculating:
– the reduction in permeability across faulted reservoir sections, and – the recovery factor in fluvial reservoirs.
Conceptual and stochastic modelling methods are used to determine: the effective permeability of a faulted reservoir sequence,the effective recovery factor from a fluvial reservoir,the uncertainty in predictions implicit in using these values.
An example of a gas field is given using these methods together with a convential reservoir simulator.
Geological Modelling of the Frigg Field with Special Emphasis on Shale Mapping
Authors: Skaug M. , Gundescø R. 
Published: December 2007

ABSTRACT
This paper describes a detailed geological modelling of the Frigg field. The Frigg field is a major North Sea gas reservoir composed of turbiditic sands. It has been in production since 1976. Gas-liquid contact movements, RFT pressure data and petrophysical evaluations have confirmed that the reservoir contains many barriers to vertical flow. A detailed geological mapping incorporating these barriers (shales) was required to simulate the complex field behaviour.
For that purpose, a geological model containing sand lobes and intercalating shales has been defined from the seismic and well data. Altogether ten geological units have been interpreted.
An extensive shale mapping study has been incorporated into the model. Shales have been classified into two types. The deterministic shales have been defined and mapped along reservoir layer boundaries and have been implemented in the model as horizontal flow barriers. The more discontinuous shales within reservoir layers have been modelled using statistical methods.
Geological Characteristics in Cook Inlet Area, Alaska
Authors: Kelly Thomas E. 
Published: December 2007

This paper was prepared for the 41st Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Dallas, Tex., Oct. 2–5, 1966. 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.
The Cook Inlet basin is a narrow, elongate trough of Mesozoic and Tertiary sediments located north of latitude 59 degrees in south-central Alaska (Fig. 1). The basin covers approximately 11,000 square miles of the northern part of the Matanuska geosyncline and is bounded by the Kenai and Chugach Mountains on the east, the Talkeetna Mountains and the Copper River on the northeast, the Susitna basin on the north, the Chigmit Mountains and the Alaska Range on the west, and the Shelikof Strait on the south. In less than ten years the basin has achieved such a degree of prominence as a petroleum province that it ranks with off-shore areas in California and the Gulf Coast as the most promising future source of large domestic reserves. Oil and gas exploration in the basin has rapidly increased in the past few years and is currently at its highest level in history. Although the general characteristics of the basin are fairly well known, new informations as it is made available will cause many revisions of the stratigraphic and structural fabric before a complete geological picture is possible. This report revises and refines certain concepts of the basin which were discussed in an earlier work (Kelly, 1963). In certain aspects it may be considered a progress report that will require periodic updating as new information is made available.

PREVIOUS WORK
A list of references includes many published reports written chiefly by members of the U. S. Geological Survey who investigated the mineral resources of the Cook Inlet basin. The first indications of petroleum in the basin and the early attempts to find production were documented by Martin (1905). Mather (1925), further described the petroleum potential of the southwestern part of the basin in the Kamishak Bay area.
The Use of Pour-Point Depressant Additive in the Beatrice Field
Authors: Fielder M. , Johnson R. W. 
Published: December 2007

Abstract
This paper reviews the selection of PPD as the most effective solution to overcome potential transportation problems identified with the waxy nature of Beatrice crude oil.
Field operating experience led to PPD treatment being reduced to 20% of the original laboratory recommendation. More recently, field trials have enabled operation without PPD to be achieved.
Trapping Configurations for Cambrian Rose Run Production in Ohio
Authors: Coogan A. H. , Maki M. U. 
Published: December 2007

Abstract
Oil and gas are produced from the Rose Run Sandstone reservoirs and three other units of the Cambrian Knox Dolomite Super-group in Ohio where these rocks subcrop at or close to the Knox unconformity surface and where sufficient porosity is developed.
The Rose Run Sandstone unit, the lowest of the. Beekmantown part of the Knox Dolomite Supergroup, is a reservoir for gas in a narrow, sublinear belt near the western limit of the Rose Run subcrop below the Knox unconformity surface. Other lower formations also produce, such as the Upper Copper Ridge Dolomite which is the reservoir in the well known Cambrian oil fields of Morrow County, Ohio. Small pools have been discovered in the so-called "B" Zone, a glauconitic, sandy formation in northern Ohio. Finally, the Lower Copper Ridge Dolomite is a reservoir for gas in Wayne and Seneca counties, Ohio.
A Procedure for Optimal Hydraulic Fracturing Treatment Design
Authors: Poulsen D. K. , Soliman M. Y. 
Published: December 2007

Abstract
A numerical procedure for determining proppant schedules for hydraulic fracturing treatments has been devised. This procedure uses previously developed fracture conductivity distribution curves1 to minimize the amount of proppant used in a treatment. Coupling this procedure to a fractured-well simulator and a fracturing treatment economics model allows the optimization of different aspects of a fracturing treatment.
A Patchy-Charge Model for the Surface Conductivity of Clays
Authors: Cohen R. R. , Radke C. J. 
Published: December 2007

Abstract
To provide a critical assessment of electrical resistivity logging measurements in shaly sands, a theoretical, patchy-charge model is derived to quantify the surface conductivity of clay minerals. The proposed model instills a molecular rigor into the general framework of the widely-used, semi-theoretical approach of Waxman and Smits. The most significant contribution of the patchy-charge model is its physical explanation for the characteristic convex curvature observed from experimental measurements on the change of the effective conductivity of water-saturated shaly sands with the change of the conductivity of the equilibrating brine. We attribute the major portion of the extra conductivity to two-dimensional translation of counterions along the inner Helmholtz plane (IHP). By representing isomorphic substitution within the clay lattice as patches of periodically varying charge, an electrical activation barrier to migration along the IHP is identified. It is the variation of this electrical barrier to surface diffusion with changing ionic strength which gives rise to the curvature seen in the experiments. The patchy-charge model predictions for overall reservoir formation conductivities yield excellent agreement with experimental data on water-saturated shaly sands over a bulk conductivity range from 0.1 S/m to 10 S/m with the benefit of only one adjustable parameter. Model calculations are readily extended to predict oil saturations for measured resistivity ratios of shaly reservoir formations.
Fifth Comparative Solution Project: Evaluation of Miscible Flood Simulators
Authors: Killough J. E. , Kossack C. A. 
Published: December 2007

ABSTRACT
This paper presents the results of comparisons between both four-component miscible flood simulators and fully compositional reservoir simulation models from seven different participants for a series of three test cases. These cases varied from scenarios dominated by immiscible conditions to scenarios in which minimum miscibility pressure was maintained or exceeded throughout the simulations. In general, agreement between the models was good.
For a test case in which reservoir pressure was maintained above the minimum miscibility pressure, agreement between four-component simulators, with the assumption of complete mixing of solvent and oil, and compositional simulators was excellent based on cumulative oil production as a function of cumulative water injection. For cases in which immiscible conditions dominated, the four-component models tended to be pessimistic compared to fully compositional models because condensible liquids were not considered to be carried in the gaseous phase in the four-component simulations. Relative permeability treatment, especially near the injection well, tended to dominate the timing of recovery and injectant breakthrough.
Application of a Multiple Porosity/Permeability Simulator in Fractured Reservoir Simulation
Authors: Lee B. Y. Q. , Tan T. B. S. 
Published: December 2007

Abstract
This paper presents the modelling of naturally fractured reservoirs using a multi-porosity multi-permeability thermal simulator. An iterative solution technique that allows connection between any pair of blocks is used.
Dual-porosity and triple-porosity systems are simulated. Results follow those of the analytical methods. Simulation of a thermal recovery scheme using a horizontal steam injector and a horizontal producer in a naturally fractured heavy oil reservoir is presented as an example.
A More Flexible Approach of Dynamic Local Grid Refinement for Reservoir Modeling
Authors: Han D. K. , Han D. L. , Yan C. Z. , Peng L. T. 
Published: December 2007

ABSTRACT
This paper describes a new and more flexible approach of dynamic local grid refinement, which can also be used to subdivide the grid block fixedly in any desired parts of reservoir. The amount of fundamental blocks and subblocks can be minimized by using a step-by-step scheme of subdivision almost without any restriction.
Moreover, it is shown that the specially developed system of ordering scheme and data management of this method is very simple and effective. Especially in dynamic grid refinement, no inactive grid block is produced in the process of ordering, and just a little of additional running time is needed to execute this system in computer.
This paper reports that the results produced by using the dynamic grid refinement is very close to those obtained with the conventional fine grid system, and the running time are much lower.
Explosive Technology A New Tool In Offshore Operations
Authors: De Frank Pete , Robinson Reginald L. , White Bill E. 
Published: December 2007

This paper was prepared for the 41st Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Dallas, Tex., Oct. 2–5, 1966. 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
Hurricanes Carla (1961) Hilda (1964), and Betsy (1965) played havoc with the offshore oil industry. Physical damage has been estimated over $200 million, excluding loss of production estimated at 10 million barrels resulting from Hurricane Betsy alone. Resulting navigation hazards also necessitate temporary and later permanent salvage or removal of thousands of tons of debris from drilling and production facilities.
In many areas use of conventional methods to repair damage or clear away debris was not feasible due to safety precautions or physical condition of the structures. Technological advances in the use of explosives have permitted their successful use for restoration of wells and salvage of equipment in underwater operations.
This paper covers development and field applications of new explosive devices and techniques which resulted in a safe, time reducing, and economical method of remedial well applications and debris removal. Details of operations covering the successful control of blowing wells are presented. Also discussed are applications and procedures using explosive devices to remove conductor strings and platform pilings for abandonment remove hurricane damaged structures, and salvage underwater pipelines.
The potential of explosive devices in other offshore and underwater operations is covered, emphasizing the variety of applications of underwater explosive technology as a safe, economical, and useful tool in offshore operations.

Introduction
Offshore petroleum activities have prompted development of radically new equipment, tools, and operating procedures. This development has been accelerated with worldwide offshore activities now being conducted in over 60 countries. Occasionally some unforeseen and dramatic event occurs which acts as a catalyst in the development tools and equipment.
Application of Parallel (MIMD) Computers to Reservoir Simulation
Authors: Scott S. L. , Wainwright R. L. , Raghavan R. , Demuth H. 
Published: December 2007

ABSTRACT
The application of parallel computers to reservoir simulation is studied with the aid of two recently introduced Multiple Instruction, Multiple Data (MIMD) computers. The problems posed by reservoir simulators are shown to be particularly well suited for such parallel computers* Fundamental parallel programming techniques using Fortran are presented for the Hetrogeneous Element Processor (HEP) produced by Denelcor and the iPSC Hypercube produced by Intel. These techniques are then applied to two of the most time consuming tasks in reservoir simulation: forming the matrix coefficients and producing a sparse matrix solution. The problem of parallel formation of sparse matrix coefficients is addressed for the single and multiphase cases using both black oil and compositional fluid models. Parallel sparse matrix solution is addressed by considering D4 ordered Gaussian elimination, and the multigrid, conjugate gradient, and Successive Over-Relaxation (SOR) methods. Three parallel algorithms based on SOR are developed to illustrate the possible diversity of parallel algorithms. The red-black and multicolored SOR methods which are often used on vector machines are shown to be easily adaptable to parallel MIMD machine. Matrix partitioning and a new method of iteration pipelining are also presented as parallel SOR methods. The various SOR algorithms, in parallel form, are mapped onto the HEP to illustrate the speedups currently possible on an MIMD machine. Projections are made on the future importance of these types of machines to reservoir simulation.
Pressure Decay Measurement
Authors: Rudd Neilson 
Published: December 2007

This paper was prepared for the 41st Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Dallas, Tex., Oct. 2–5, 1966. 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
Measurements of permeability in core samples of inhomogeneous rock are susceptible to errors resulting from inadequate sample size and defects inherent in the existing techniques.
This paper presents an experimental method of radial permeability determination which permits rapid measurements on whole core samples with minimum bias from sampling and measuring procedures.
The technique is analogous in many respects to permeability calculations from pressure buildup data. Pressure in the sample cell is increased abruptly and the time required for gas in the pore space to reach pressure equilibrium with the chamber pressure is measured by electronically monitoring the decaying cell pressure. This time is proportional to permeability. In addition to permeability data, the configuration of the pressure decay curve may yield insight into such useful core characteristics as pore size distribution.

Introduction
Geological formations are not normally homogeneous with regard to lithology and structure. Since, in the past, we have dealt largely with oil and gas production, most of which is derived from the least variable lithologies, we are not well equipped to deal with the more inhomogeneous formations now becoming important in gas storage, waste disposal, and lower grade oil and gas reservoirs.
Part of our problem is the immense computational complexity which arises from the addition of more independent variables to our reservoir performance equations. This, however, is susceptible to solution by use of the modern high speed computer.
The real "bottleneck" is in the acquisition of enough reliable data upon which to base our more sophisticated approach to reservoir studies.
The subject of the present paper is not a major "breakthrough" but serves, we hope, as an example of the kind of review and refinement of techniques which is required from those of us who are concerned with data gathering to support the efforts of those of you who are involved in the prediction and control of reservoir performance.
The Petroleum Industry A Look Backward....And Forward
Authors: Hill Kenneth E. , Coqueron Fred G. 
Published: December 2007

In early 1956 the Petroleum Department of The Chase Manhattan Bank published a lengthy study entitled "Future Growth and Financial Requirements of the World Petroleum Industry. "This report was the result of a year's work by a group of petroleum experts working under the guidance of Joseph E. Pogue, distinguished petroleum economist. Its aim was stated succinctly in the first paragraph as follows:
"The purpose of this report is threefold:
To measure the tremendous growth that lies ahead for the world petroleum industry; To determine in broad terms the changing patterns of supply which will be necessary to satisfy the anticipated needs; and To express the growth in terms of capital required and examine the ways in which the capital funds may be generated."
So far as is known this was the first published long-range report which estimated the probable growth in demand for a full decade ahead, then postulated the pattern of supply for these needs and determined the capital requirements. Doubtless some large petroleum companies were making such studies for their private use at that time, but none were published. But now we have a multitude of forecasts, for every large company has an economics and planning department which makes forward estimates each year, and a summary of expected demand growth for five or ten years is included in most annual reports.
In 1955 The Chase Petroleum Department became quite interested in the longer range outlook because it appeared the growth in petroleum consumption might continue upward at the same dynamic rate experienced since World War II— nearly 6% in the United States and twice that abroad. Furthermore, tremendous new low-cost discoveries of crude oil in the Middle East, Canada and Venezuela had been brought into production and were seeking a market not only in Europe, but in the United States. And at about this time most large oil companies were recognizing the rapidly increasing- finding costs in the United States and the inadequate return on such investments. Because of the need to meet the voracious product requirements of the first post-war decade, the money requirements for capital
Characterization of Polyacrylamine-Cr+6 Gels Used for Reducing Water/Oil Ratio
Authors: Nanda S. K. , Kumar R. , Sindhwani K. L. , Goyal K. L. 
Published: December 2007

Abstract
Polyacrylamide-Cr+6 gels are being used for reducing water-oil ratio with varied success. Out of many factors affecting the process of water control, chemical characterization of the gels plays an important role. Present paper describes the phenomenon of gelation with special reference to its characterization which is carried out through following laboratory studies:
Yield optimization Thermogravimetric studies Elemental analysis I.R. studies X-ray differaotion studies Stability of gels and Solubility of gels
The present studies reveal that gelation process of polyacrylamide with chromium ions takes place through co-ordination bonding with nitrogen. The optimization studies have indicated that better results are expected in the following concentration ranges of the reactants:
Polymer = 2.0 – 3.0 g/L Reducer = 1.5 – 2.0 g/L Oxidiser = 1.5 – 2.0 g/L
In addition, the gels formed at neutral pH, have been observed to be comparatively stable and sustain the reservoir temperature for 50 days. Solubility in chemicals like HCl, mud acid, hydrogen peroxide indicates that these chemicals can be used as breakers.
Effect of Salt Composition on Clay Release in Berea Sandstones
Authors: Kia S. F. , Fogler H. S. , Reed M. G. 
Published: December 2007

Abstract
The effect of salt composition of fluid injected into clay-bearing Berea sandstones on the water sensitivity phenomenon has been studied. Experiments were carried out with solutions of sodium and/or calcium ions which are the type of ions commonly found in formation environment. The fresh water flooding of sandstones previously exposed to sodium salt solutions results in the release of clay particles and a drastic reduction in the permeability. However, the permeability reduction is reduced when calcium ions are also present in the salt solution. Formation damage is virtually eliminated when the solution composition is adjusted to give calcium surface coverages of greater than a critical value of 75%. The effect of the fluid composition on the damage process is explained by the double-layer interactions between the surface of the clay particles and the pore walls.
The Development and Application of a Detectable Polymeric Scale Inhibitor To Control Sulfate Scales by Squeeze Applications
Authors: Burr B. J. , Howe T. M. , Goulding J. 
Published: December 2007

Abstract
A new labelled polycarboxylic acid scale inhibitor has been used successfully to control deposition of mixed sulphate scale in North Sea Oilfield reservoirs and downhole tubulars. The concentration of this new inhibitor in produced water has been monitored successfully under field conditions, allowing mass balance calculations to be carried out.