bluuebunny/crossref_metadata_2025_split huggingface dataset:
Critical Gas-Flow Ratio for a Cluster of Wells Over Bottom Water
Authors: van Domselaar H.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.

Abstract
Critical gas production rates of interfering wells over bottom water have been calculated for three different well patterns. The calculations are based on the generalized Girinskii potential, which enables one to account for stratification and real gas flow, assuming Darcy's law to hold. This analysis is applicable when the well may be considered as fully perforated.
PVT data are used to establish empirical analytic relationships with respect to pressure. This makes it possible to calculate the generalized Girinskii potential for practical cases. A computer program has been developed which calculates critical rates for clusters of interfering wells in stratified horizontal formations of constant thickness. The program forms an Appendix to this paper.

Introduction
Many gas reservoirs contain bottom water. This imposes a restriction on the gas production from individual wells because above a certain critical rate, which may be different for each well, these wells cut water. The critical rate is defined as the steady-state gas production rate under a drawdown just small enough to prevent water production from bottom water. This critical rate is associated with the phenomenon of upconing bottom water. The form of the steady-state cone depends essentially on the perforation at the well and the reservoir parameters such as stratification.
The majority of the investigations concerned with the determination of critical rates are based on steady-state conditions and segregated flow of the fluids. Many of them, as here, deal with the case of fully perforated wells.
Lehner gives in the introduction to this paper a survey of the work published to date on the steady-state coning problem for compressible flow in stratified layers. The truly three-dimensional problem of free-surface flow in a stratified. problem of free-surface flow in a stratified. formation had already been treated by Girinskii. Girinskii, however, in his considerations applied the so-called 'Dupuit assumptions'.
Waterflooding Of The Olmos-Navarro Sand
Authors: Hester Carl T. , Sutton Gary B. 
Published: December 2007

Publication Rights Reserved
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
In South Central Texas, where many fields produce from the tight and shaly Olmos-Navarro sand, waterflooding is gaining momentum after indicated success of pilot operations begun in 1958. Although the nature of the sand and available water present problems, low viscosity oil and favorable water-oil relative permeability relations make waterflooding appear attractive. Currently nine projects are in operation and another is starting soon. Waterflooding in these 10 fields is expected to increase oil recovery by 111 percent of total calculated primary production. It is probable that all significant Olmos-Navarro fields will eventually benefit from this additional recovery technique.

Introduction
There are 45 fields producing from the Olmos-Navarro sand along a trend from Eagle Pass to San Antonio, Texas. (See Figure 1.) The 3439 wells currently producing from these fields average four barrels daily. This low productivity results from prevelant solution gas drive mechanism, reduced reservoir pressures, and the low permeability of the Olmos-Navarro sand. Efforts are under way to increase oil recovery by waterflooding; however, the sand has characteristics objectionable in waterflooding. It is tight, shaly, and highly stratified. Also, available water is undesirable. Regardless of the unfavorable sand conditions and water supply, successful waterflooding in the Olmos-Navarro is probable because of favorable oil-water viscosity ratios and relative permeabilities.

HISTORY OF WATERFLOOD DEVELOPMENTS
Successful waterflooding of the Olmos-Navarro sand was first started in 1958 in pilot operations at Charlotte and Big Foot. As a result, seven other waterflood projects have begun. Also, waterflooding was extended throughout nearly all the Charlotte field, the largest Olmos-Navarro field in the area. Flooding in the North Charlotte field is waiting only on equipment and negotiations between operators.
Table 1 shows waterflood statistics for these fields.
Fracture Orientation In A Gas Storage Reservoir In West Virginia
Authors: Kotb A.K. , Araktingi 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.

Abstract
Tests to increase knowledge concerning the orientation of hydraulic fracturing have been performed on an Oriskany gas field in West performed on an Oriskany gas field in West Virginia using production and pressure analysis data.
A possible pattern of induced fracture orientation has been determined in the gas field to be most likely in the northeast-south west direction.
To confirm the possible fracture orientation, the system of zones of joint surrounding the storage field was studied; a rose diagram of the system of joints shows that the major trend of joints in this area is orientated between the range of 30 deg. to 35 deg. east.

Introduction
Hydraulic fracturing of petroleum reservoirs is an important stimulation method to improve flow capacity of hydrocarbons.
The initiation, orientation and extension of hydraulically induced fractures has received considerable attention in the technical literature. The quantitative physical factors involved in hydraulic fracturing appear to be fairly well understood; however, field results differ sometimes from theoretical models depending on the approximations made in the analysis.
The fracture orientation and its physical appearance was determined using an instrumental approach. However, results obtained by this method can be used to determine the orientation of the induced hydraulic fracture more accurately at the vicinity of the wellbore.
Recently the U. S. Bureau of Mines has initiated explanatory research to detect surface expressed fracture patterns over large areas of the Appalachian Plateaus Province, by radar imagery. It is believed that the majority of these lineaments manifest structurally controlled fracture zone. All lineaments checked by U.S. Bureau of Mines were found to be joint zones, rather than faults.
Large Scale Waterflood Performance Sprayberry Field, West Texas
Authors: Elkins Lincoln F. , Skov Arlie M. 
Published: December 2007

Abstract
First response to large scale water flood in the fractured milli-darcy Spraberry sand has led to a new unique cyclic operation. Capacity waterinjection is used to restore reservoir pressure. This is followed by a few months production without water injection and the cycle repeated. Expansion of the oil, rock and water during pressure decline expels part of the fluids but capillary forces hold much of the injected water in the rock. Field performance has proved this cyclic operation is capable of producing oil from the matrix rock at least fifty per cent faster and with lower water percentage than is imbibition of water at stable reservoir pressure.

Introduction
The Spraberry Field of West Texas presents unusual problems for both primary production and water flooding. Extensive interconnected vertical fractures in the fractional-millidarcy sandstone permitted recovery of oil on 160-acre well spacing, but they made capillary end effects dominant; primary recovery by solution gas drive is less than 10 per cent of oil in place. The concept of displacement of oil from the sand matrix by capillary imbibition of water has led to field techniques which promise greatly increased oil recovery. Free exchange of laboratory research, reservoir information and results of field pilot tests among the various companies has been very important in development of this technology.
Four units covering a total of 125,500 acres have been formed for waterflooding and eleven other areas covering an additional 220,000 acres are in various stages of unitization. Part of the Driver Unit reaching fill up first has demonstrated very unusual water flood behavior and indicated numerous operating problems that will develop within and among the various units.
A Simulation Model For Undersaturated Oil Reservoirs
Authors: Hopkinson J.L. , Natanson S.G. 
Published: December 2007

Publication Rights Reserved
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 mathematical simulation model for undersaturated oil reservoirs has been designed, which, from an analysis of past performance, provides predictions of the future pressure decline in individual wells or in localized areas of a field; such a field may include a number of reservoirs producing from a common aquifer.
The selection of field production rate and the distribution of production between wells are treated in & number of ways which lead to a quantitative mapping of the field's response to different modes of operation.
The model consists of an assemblage of computer programs which are linked and controlled by & master program. The reservoir system is characterized by a matrix. The elements of the matrix which describe the response of the reservoir to unit production at discrete locations are derived from numerical solutions of finite difference equations describing flow in a porous medium.
The use of the model in production and development planning is illustrated by a number of examples selected from an application to an existing reservoir.

Introduction
The development of certain large undersaturated reservoirs in the Middle East gave prominence to the usual problems concerning the number of wells to be drilled, their location, and their future production schedules. On an operational level, advice was sought on a systematic method of specifying current well production rates when the demand from the field could be expected to vary widely at short intervals.
The first requirement in answering such questions is the provision of the necessary technical information. The reservoir engineer should provide this by mapping in a systematic manner as wide a range of production strategies as possible. This paper describes a specific mathematical model which has been designed for this purpose and illustrates its use for a particular reservoir.

OUTLINE OF MODEL
The basic feature of the model is the use of a matrix to represent the response of an undersaturated reservoir to production. This can be extended, as required, to a number of such reservoirs with a common aquifer. The bulk of the model consists of the system of computer programs which were written to construct and handle this matrix.
Improvement Of Reservoir Studies Through Use Of Two-Dimensional Mathematical Analysis
Authors: Sheffield M. , Brinkman F.H. 
Published: December 2007

Publication Rights Reserved
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
This paper illustrates the many types of reservoir predictions which can be made using two-dimensional analyses. These advanced techniques will enable engineers to improve reservoir predictions; and more accurate predictions will, of course, provide a better basis for management decisions.
Specifically, the two-dimensional techniques have proved valuable in predicting the following types of reservoir behavior:Irregular advance of gas or water and its arrival time at specific reservoir locations.Gas overriding or water underrunning oil.Cross flow between reservoir layers and water imbibition into tight layers and lenses or from a fracture into a matrixblock.The coning tendencies of a single well.The saturation distribution behind a front.
Examples of these types of behavior presented in this paper are: a detailed study of a large gas injection project; pattern waterflood studies of both 5-spot and modified 9-spot patterns; and a study of oil recovery by imbibition from a fracture matrix system. These studies were made using a two-dimensional, two-phase, immiscible fluid-flow analysis that considers viscous, gravitational, and capillary forces.
Also shown is a recent comparison of the observed and mathematically predicted behavior of a laboratory model. This provides additional verification of the mathematical techniques.

Introduction
Most reservoir studies are made to compare various methods of reservoir depletion and to aid management in determining optimum development or operation of an oil field.
California Oil's Past, Present and Future: Coastal District
Authors: Richardson Robert L. 
Published: December 2007

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
Oil and gas exploration and development in the California Coastal District starts with the first well drilled in southern California in 1865 and progresses from an early period of exploration adjacent to surface oil seeps, through a 50 year period of giant oil field discoveries and up to present day offshore exploration in 1,300 feet of water from floating vessels. Exploration of the major geologic structures onshore has been extensive by not exhaustive, while many major structures offshore await penetration by the bit.
There are 130 designated oil and gas fields in the District with a total estimated ultimate recovery of 3.260 billion barrels of oil, of which 2.659 billion barrels have been produced, leaving an estimated future recoverable oil of 600.3 million barrels using present known techniques. An estimated 17.3 billion barrels of oil in place are yet to be discovered.
The District is just a few years into an active era of secondary recovery by waterflooding which is expected to grow in number of floods and secondary oil recovery in the near future. Steaming is an active contributor to the present District production, particularly in the San Ardo oil field. Tertiary particularly in the San Ardo oil field. Tertiary recovery processes do not look promising, at least not until the heterogeneity of the thick reservoir sands can be controlled.
Past exploration and discoveries indicate Past exploration and discoveries indicate that the future discoveries onshore are going to result from deep exploration of known structures and in the deeper parts of the basins. The final disposition of the Ventura-Santa Barbara Basin offshore area will bear heavily on the future of the oil industry in the District. Industry has spent large sums of money and made impressive strides in overcoming the deficiencies criticized at the time of the Dos Cuadros blowout. The development of oil spill containment devices and techniques and the proposed ocean floor completion systems answer the major objections to opening the Channel to further exploration and development.

Introduction
The California Coastal District extends from the western portion of Los Angeles County into San Mateo County just south of San Francisco and encompasses all of the coastal counties along this stretch of the Pacific Coast.
California Oil's Past, Present and Future: San Joaquin Valley and Sacramento Valley
Authors: Matthews John F. 
Published: December 2007

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
The Great Valley of California is one of the major geographic provinces of the state. It is divided into two basins, the San Joaquin Valley and the Sacramento Valley. Numerous productive oil traps in the San Joaquin Valley are located along the major trends and many dry gas accumulations are found in the Sacramento Valley.
The most favorable areas to be explored for new reserves are in the deeper zones, in areas of probable lenticular sands, and in extensions of present producing trends, although the best record is compiled by those who drill edge wells on the perimeters of the present producing fields. The future of present producing fields. The future of California development will change rapidly if the price of energy sources rises and if and when the exploration attitude of oil operators, small and large alike, reverts to the more positive attitudes of the past.

Introduction
The Great Valley of California is one of the major geomorphic provinces of the state (figure 1). It extends northwesterly some 400 miles from the San Emigdio and Tehachapi Mountains to the Klamath Mountains, and its 50-mile width is bounded on the west by the Coast Ranges and on the east by the Sierra Nevada. The surface of the valley is a relatively flat alluvial plain, although there are some surface expressions of subsurface anticlinal structures.
The Stockton Arch, for purposes of this report, will be considered the dividing line between the San Joaquin Valley to the south and the Sacramento Valley to the north, although there is no definitive separation point and the subject is open to controversy. point and the subject is open to controversy. The arch is actually a fault zone which runs in a northeast direction. It consists of one or more reverse faults which are upthrown on the south side, and there are several gas accumulations on this side.
There are some 35,000 wells capable of producing in the San Joaquin Valley. To producing in the San Joaquin Valley. To date some 6.5 billion of the state's 19.1 billion total barrels of oil has been produced from these wells which have been produced from these wells which have been completed from 110 fields.
There are 100 dry gas fields in the Sacramento Valley and some 1,200 productive wells. The wells have produced 5.2 × 10(9) Mcf. of gas. This is eighty percent of the total dry gas produced to date, although the state total, for both dry and that produced with oil, is in excess of 25 × 10(9) Mcf.
California Oils Past, Present and Future: Los Angeles Basin
Authors: McFarland Lee C. , Greutert Raymond H. 
Published: December 2007

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
The Los Angeles Basin could be classified as a mature petroleum province, from the standpoint of the explorationist, the development engineer and the production department. Most of the large fields are in advanced stages of depletion and secondary recovery procedures have been in effect for a number of years in the more prolific reservoirs.
Nevertheless, it is likely that 1 to 3 billion barrels of additional oil will be found in this basin from new fields, if and when the current Problems of compatibility can be solved and when the price of the product can justify the added costs which product can justify the added costs which the special conditions dictate.
Likewise, it seems apparent that production engineers will be able to add production engineers will be able to add significantly to remaining reserves within proven reservoirs by means of secondary and proven reservoirs by means of secondary and tertiary recovery techniques. This increase will also be dependent upon the price-cost structure as well as the ability of cur industry to come to workable terms with ecological and environmental forces active in this most highly urbanized producing province. province

Introduction
The Los Angeles Basin has been alternately extolled and castigated by Majors, Independents, and Consultants, as being:(a)The most prolific oil producing province for its geographic size in the world.(b)Over-explored, over-developed and depleted.(c)A good place to live while pursuing our profession.(d)One of the pursuing our profession.(d)One of the most difficult areas in the world for any Oil Company to make a buck, due to high costs of exploration and production, low product prices in relation to market needs product prices in relation to market needs and environmental pressures, reasoned and unreasoned.
The location and geology of the Los Angeles Basin are well-known to you, we feel sure, and we refer you to the many excellent papers which have been written on the geology and the oilfields in the area, excerpts from some of which have been included herein as Table 1 and as Figures #1 thru 5:
Table 1: A statistical summary of L.A. Basin production and reserves.
Figure 1: An updated Index Map showing oilfields and distribution of exposed basement rocks.