bluuebunny/crossref_metadata_2025_split huggingface dataset:
Wellhead Control Dispatched From One Control Center
Authors: Boggs R.E. 
Published: December 2007

Publication Rights Reserved
This paper is to be presented at the SPE Regional Meeting in Liberal, Kansas, November 18–19, 1965, 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 the 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.
Panhandle Eastern Pipe Line Company has long been aware of the advantages of being able to remotely control the flow of natural gas from various fields to meet sudden demand changes in our marketing areas. Transmission systems are designed and constructed to provide the required volume of gas demanded at any time, regardless of the weather or sudden changes therein, even though the peak domestic and industrial loads may occasionally be many times the average load. In order to meet peak demands the system makes use of its auxiliary facilities, such as storage fields that during the periods of slack demand have been filled with gas. High transmission line pressures also help to fulfill the peak demands, resulting from the high degree of compressibility of the gas itself. A sudden change in the weather in the marketing areas is not the only reason for a sudden need for additional gas volumes. The temporary loss of a compressor unit or a section of the pipeline can result in the sudden demand for more gas from another area. Unfortunately, the additional amounts of gas that can be obtained from these aforementioned facilities is limited and additional gas must be obtained from the producing areas if the peak demand persists. Under present operations when a gas well has to be turned on or shut-in, this must be done manually by a fieldman.
On a Convergence Criterion for Linear (Inner) Iterative Solvers for Reservoir Simulation
Authors: Diaz J. C. , Jines W. R. , Steihaug T. 
Published: December 2007

ABSTRACT
In reservoir simulation, the discretization of the fluid flow and energy equations generates systems of nonlinear algebraic equations. These equations are solved using Newton-Raphson iteration. This method works from an approximation, generating a linear sparse system of equations whose solution correct the current approximation. This process is repeated until a satisfactory solution of the nonlinear system is found. In practice, each linear system is solved with an iterative method. The overall efficiency of the simulator depends upon the stopping criteria for the linear (inner-) iteration and the termination rule for the nonlinear (outer-) iteration. In this article, stopping criteria for the inner-iteration in terms of the nonlinear requirements are discussed. The design of an optimal criterion includes knowledge of the approximate location of the regions of linear and quadratic rates of convergence for the nonlinear (outer-) iteration. A comparison of several stopping criteria is given. Their effect on CPU time, number of outer-iterations and time step selection is illustrated. Criteria using relaxed constraints in the linear convergence region are more efficient. The presentation is in the context of block-preconditioned iterative methods for thermal simulation.
Black Lake Field A Study In Conservation And Development Natchitoches Parish, Louisiana
Authors: Sawyer J.R. 
Published: December 2007

The Black Lake Field is located in Township 11 North, Range 6 West in Natchitoches Parish, Louisiana, on the southeastern flank of the Sabine uplift. Geographically the field is located between Black and Saline Lakes approximately 60 miles southeast of Shreveport and 15 miles northeast of the town of Natchitoches.
This is an area that had defied Operators for years. Prior to 1947 drilling had been restricted to shallow depths, but from 1947 to 1958 six (6) wells were drilled within a 7 mile radius of Black Lake to a depth of 8000 feet or deeper. The first of these deeper tests was the U. S. Forest Reservation #F-135, drilled by H. L. Hunt in January, 1947, in Section 35, T-11-N, R-5-W. Continental Oil Company then drilled three (3) wells, the Pardee #1, Section 30, T-12-N, R-6-W in July 1948; the Bank of Bastrop #1, Section 18, T-12-N, R-6-W in September, 1949; and the Edenborn #1, Section 27, T-12-N, R-6-W in November, 1949. Interest in the area died down until July, 1958, when F.R. Jackson drilled in Section 26, T-11-N, R-7-W the Franklin Realty #1. The Nebo Oil Company followed with the G. H. Monrose #1 drilled in Section 28, T-11-N, R-5-W in December, 1958. Although none of the wells were productive, the wells to the south and southeast had good development of Pettit porosity. This porosity development was not evident in the wells to the north, west, and northwest indicating the possibility of a stratigraphic trap for the accumulation of hydrocarbons.
Placid Oil Company began leasing in the area in the spring of 1963 and after obtaining sufficient acreage Geophysical crews were brought in to obtain seismic information. Based on a combination of seismic and subsurface data, Placid spudded the Edenborn #1 in Section 25, T-11-N, R-6-W on October 3, 1963. After drilling to a depth of 8359 feet the well was abandoned; however, because of the development of the Pettit porosity and the numerous oil shows in the cores, the Edenborn #2 was spudded February 13, 1964, three (3) miles north in Section 12, T-11-N, R-6-W.
The Edenborn #2 blew out while drilling into the Pettit and after spending nearly a month fishing, the well had to be abandoned due to mechanical difficulties in the hole. The rig was skidded 100 feet north and the Edenborn #2-A was completed May 25, 1964, flowing
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A General Purpose Single-Phase Naturally Fractured (Carbonate) Reservoir Simulator With Rigorous Treatment of Rock-Stress/Fluid-Pressure Interactions and Interporosity Flow
Authors: Leung W. F. 
Published: December 2007

ABSTRACT
A rigorous fully implicit numerical reservoir simulator has been developed to model single phase fluid flow in deformable naturally fractured or carbonate reservoirs. The present formulation represents a great improvement over existing simulators for fractured reservoirs in that many of the limiting assumptions have been removed. The interactions of rock stress, matrix pore pressure, and fracture pressure; bulk rock volumetric expansion effects; unsteady matrix-fracture flow; vug-matrix and vug-fracture flow; and the matrix and fracture anisotropic flow have been rigorously modelled. An interesting comparison in modeling fractured reservoirs is made between the present volume average approach and the deterministic approach where the matrix and fracture geometries are fixed. A parametric study reveals the new finding that the rock-stress interaction effects may modify significantly the compressibility of the fractured rock which would then affect the characteristic behavior of the pressure transients of a fractured reservoir. The stress sensitive permeability effect for the fractures is also determined to be important. It is shown through numerical examples that existing dual porosity models are inadequate to model a vuggy fractured reservoir where the solution vugs are intersected by the fracture network of the reservoir. A field example is used to demonstrate how a detailed geometrical description of the fractured blocks may be obtained by matching the simulated pressure transient behavior of the well test data.
Modelling the Effects of Shales on Reservoir Performance: Calculation of Effective Vertical Permeability
Authors: Begg S. H. , King P. R. 
Published: December 2007

ABSTRACT
In this paper we present four methods of estimating the effective vertical permeability of a reservoir containing stochastic shales in both two and three dimensions. The methods vary in their accuracy, speed and range of applicability. The first is based on numerical simulation, the second is an analytical method, the third and fourth are based on calculating approximate streamline lengths. The methods give consistent results for similar models and are used to show that the effective vertical permeability is strongly dependent on the shale dimensions, shale fraction and layer thickness. It is also shown that the results of the two-dimensional models are inappropriate even when the megascopic flow is unidirectional.
A Chemical Displacement Model for Alkaline Steamflooding in Linear Systems
Authors: Okoye C. U. , Kou-Jou C. , Tiab D. , Hayatdavoudi A. 
Published: December 2007

ABSTRACT
A chemical equilibrium flow model that incorporates conductive and convective heat transfer is presented for continuous alkaline steam flooding of acidic oils in linear systems. The chemical aspect of the model consists of the chemistry of acid hydrolysis at elevated temperatures, resulting in in-situ generation of surfactants and the interaction of the alkali with reservoir rock at high temperatures, leading to alkali consumption. The adsorption and desorption of active species at the interfaces are expressed as ionic processes using the Gouy-Chapman theory of diffuse double layers.
The model predicts that the surfactant slug generated in-situ in alkaline flooding increases with temperature and that, while adsorption of surfactant increases with temperature, there is a net increase in surfactant slug size to recover otherwise immobile oil, leading to higher oil recovery.
Drilling and Completion of Khuff Gas Wells, Saudi Arabia
Authors: Turki W. H. 
Published: December 2007

ABSTRACT
This paper will review the program for drilling and completing the primary well configurations for 4-1/2 in. (114.3 mm) and 7 in. (177.8 mm) Khuff gas completions in Saudi Arabia.
The drilling programs associated with these configurations and the typical drilling problems and geological considerations relevant to casing point selections will be outlined, as well as types, weights and grades of casings typically run. In addition, drilling fluids, cementing programs and wellhead equipment will be reviewed.
Finally, completion procedures will be discussed and drilling performance to date will be reviewed showing improvement since initial wells were drilled.
Environmental Factors Affecting the Movement and Dispersal of Oil Spills with Particular Reference to the Gulf
Authors: Lynagh N. 
Published: December 2007

ABSTRACT
Currents, tidal streams and winds all influence the movement and dispersal of oil spills. Examination of the surface circulation and wind climate of the Gulf highlights the coasts most likely to be at risk of pollution by spills from the major offshore production areas. Methods used in forecasting movement of spills are discussed.
Drilling Highly Deviated Wells in Umm Shaif Field: Problems and Solutions
Authors: Aggour S. B. , Rouatbi R. 
Published: December 2007

ABSTRACT
Three years ago, ADMA-OPCO, started mainly drilling highly deviated wells in Umm Shaif field for development and reservoir reasons. To achieve this objective and to overcome drilling difficulties, more refined techniques have been used, namely: –The use of hole cleaning and stiff 17 1/2″ bottom hole assemblies, in addition to non rotating sleeve stabilizers, which reduces lost time in 17 1/2″ phase.–Turbodrilling using hydraulic stratapax bits to enable setting 9 5/8″ casing in base of Thamama V.–Turbodrilling short section of the 8 1/2″ phase which eliminates the problems in this section and cuts short most of the completion and testing difficulties.
The application of the above techniques has led to ADMA-OPCO successfully drilling highly deviated wells with minimum time and low cost.
Data Gathering Comes Hard!
Authors: Ekola E.C. 
Published: December 2007

When El Paso Natural Gas Company first decided to gather some data from two or three outlying points and relay that information to a central location, there did not appear to be any great or insurmountable problems involved. We are still convinced of the veracity of the original conclusion, but we are also now aware of some of the myriads of small problems and able to give the reader a feel for our particular problems and their solutions.
As originally planned, there were some 41 quantities of analog information (15 second pulse duration) to be gathered from the locations of Phoenix, Tucson, and Casa Grande, Arizona. (See Figure 1). These quantities were to be relayed to a central Despatching location in El Paso, Texas. So far, how they were to be relayed, was open to good engineering practice, economics, and growth requirements.

ANALOG TELEMETER
The most straight forward method would be to relay the signals, or quantities, as they were, in analog form to the El Paso Dispatcher. Assuming that the Dispatcher could live with a time shared reading, three quantities could be displayed on a single recorder in the El Paso office. This would also necessitate 14 leased lines between El Paso and the outlying points. This requirement did not seem to fulfill our need of economics or future growth, to say nothing of good engineering. Just the array of recorders would eventually outgrow the wall space available.

USE OF INFORMATION
At this point it would be well to digress a moment and outline the use to which these particular readings will be used in order to clarify the following points.
The information to be gathered is natural gas pipeline static pressures and differential pressures obtained across orifice plate meters. The information is used to calculate instantaneous flow rates, accumulate gas volumes, figure line packs, to monitor pipeline conditions and to note trends.
The information was previously recorded on circular charts at the outlying locations and periodically the required information was phoned or teletyped to the Dispatcher in El Paso. The Dispatcher at the outlying point calculated all of the volumes and merely transmitted the end result.
Calculating In-Place and Recoverable Hydrocarbons: A Comparison of Alternative Methods
Authors: Smith P. J. , Buckee J. W. 
Published: December 2007

Abstract
An important component in the assessment of the economic risk of a prospect prior to development is the calculation of in-place and recoverable reserves and their associated uncertainty. This calculation requires the multiplication of the probability distributions of volume, porosity, net-pay to gross etc. to form the probability distribution of reserves. Two methods have been advocated for this calculation;
Parametric methods and Monte-Carlo methods
In (i) component distributions are combined analytically to give measures of average and confidence levels in reserves. whereas in (ii) the distribution of the components are randomly sampled to build-up the distribution of reserves. Although at present the Monte-Carlo approach has been widely advocated in the petroleum industry, due to their general applicability, the parametric methods have many adherents citing their ease and speed of use as principle reasons. However, there is a seeming lack of rigorous analysis in either method which would make the selection of the most appropriate method for a particular problem more objective. In this paper we address this area and show how the errors in both methods can. be reduced. Additionally, we suggest a new approach which combines the strengths of both methods into a flexible algorithm for reserves calculations.
In-Situ Stress State in the Mounds Test Well as Determined by the Anelastic Strain Recovery Method
Authors: Teufel L. W. 
Published: December 2007

ABSTRACTA method to determine in situ stress directions and magnitudes from anelastic strain recovery measurements of oriented core has been used to determine the principal horizontal in situ stresses in the mounds test well near Tulsa, Oklahoma. The mounds experiment was a shallow field experiment designed to evaluate and compare various methods of determining hydraulic fracture azimuth and geometry at depth. The azimuth and geometry of hydraulic fractures are controlled primarily by the orientation and magnitudes of the principal in situ stresses. In the mounds experiment the principal horizontal stress directions were determined directly from the principal horizontal strain recovery directions of oriented core. The principal horizontal stress magnitudes were calculated from the principal strain recovery magnitudes, effective overburden stress, and mechanical properties of the rock using a viscoelastic model. The in situ stress directions and hydraulic fracture azimuth determined from anelastic strain recovery measurements were within 10° of the fracture azimuth determined from a downhole television camera and a surface tiltmeter survey of a propagating hydraulic fracture. The minimum horizontal stress magnitude determined by the strain recovery method was within 2 MPa of an open-hole hydraulic fracture stress measurement.
Some Characteristic Properties Of Colorado Oil Shale Which May Influence In Situ Processing
Authors: Allred V. Dean 
Published: December 2007

Introduction
There are excellent reasons for trying to develop practical in situ techniques for processing oil shales. In conventional processing, as high as 80 percent of the material mined must also be disposed of as the inert inorganic portion of oil shale. This presents a costly materials handling problem. In addition, as much as 25 percent of the oil shale in place will be left behind as pillars in the mines. Another important consideration is that the rich, thick shale deposits are found under considerable overburden and not readily amenable to mining. There are unique problems and requirements that restrict the use of known in situ processes to oil shales. Among these considerations are such facts as: a. Oil shale does not contain oil, a- such, but is a marlstone of finely divided particles consolidated into rock with a solid insoluble organic matter called "kerogen."b. The only known technique for forming and liberating oily matter from shale is by first heating it until the solid organic matter decomposes into oil, gas, and a solid carbonaceous residue.c. Oil shale deposits in their natural state have little orno initial permeability to gases and liquids. The major problem is the lack of permeability and porosity. However, it should also be kept in mind that oil matter, as such, does not exist in shale.
Great Canadian Oil Sands Project
Authors: Moss A.E. 
Published: December 2007

One of the world's largest known reserves of petroleum is contained in the extensive bitumen-bearing sand deposits located in the Province of Alberta, Canada.
More than 175 years ago, one of the early explorers of Canada's Northwest recorded his observation of a black, sticky tar-like substance in the bedded sand banks of the Athabasca River. This material was used by Indians of the area for patching canoes and for other purposes where a water-proofing substance was required. The economic potential of these sands was recognized by geologists of the Geological Survey of Canada more than 75 years ago, even though the vastness of the reserves was not confirmed by core drilling until the 1940's.
The estimated reserves of recoverable oil contained in the tar sands of Northern Alberta are in excess of 300 billion barrels. The area underlain by these sands is at least 13,000 square miles, which is equivalent to approximately one-twentieth of the area of the Province of Alberta. Nearly 90 per cent of the reserves occur in an irregular area some 150 miles long and 50 miles wide known as the Athabasca Tar Sands deposit.
It is not the purpose of this paper to discuss in detail the many reasons why these deposits were not exploited at an earlier date. Suffice it to state that, in addition to two world wars, a major economic depression and the lack of available markets, there were a great many technological difficulties to solve. During the past several decades, many tens of millions of dollars have been spent on investigations by the Federal and Provincial governments, oil companies and other private investigators on drilling, sampling and research, including pilot plant tests, in an effort to determine an economic method of extraction.
Knowledge of the Alberta tar sands deposits has been accumulating rapidly in the past two decades. In this paper, I will describe the geology and characteristics of the tar sands, and the mining and processing project of Great Canadian Oil Sands Limited.
Wireline Operations in the Deep Delaware Basin
Authors: Cunningham J.D. , Fulkerson F.D. , Gollwitzer L.H. 
Published: December 2007

Abstract
Deep wells in the Delaware Basin, just as in other areas, complicate wireline operations. As compared with shallow well operations, increased depths, temperatures, and pressures place greater demands on equipment and operating techniques.
Temperature, although high in the deeper Basin wells, is less a problem than in other regions of large geothermal gradient. All modern logging equipment is designed and maintained to perform properly at temperatures as high as 340°F. Some instruments, such as the Gamma-Ray Neutron, operate at temperatures up to 500°F. Perforating, formerly a problem in high temperature wells, is now accomplished at temperatures up to 470°F through the use of special high temperature shaped charge components. Thus, although temperatures in deep Basin wells require careful preparation, they do not preclude effective logging and perforating operations.
Relatively light muds are used in the Delaware Basin to increase the efficiency of drilling operations. These low density muds create problems that are more or less unique to this area. First, all operations, both logging and perforating, are normally run using blowout preventers. A properly installed pressure control system enables efficient and safe logging operations. Second, the relatively light muds for such deep wells lead to high cable tension during wireline operations. Winch drums and cables must be engineered to operate safely under these unusually high tensions. A special powered sheave wheel has been introduced in the Delaware Basin to reduce cable tension at the drum and to further reduce possibilities of winch drum collapse, or of cable "cutting in" to lower layers on the drum.

Introduction
Deep wells in the Delaware Basin are not the easiest wells to log and perforate. In addition to the usual complications at extreme depths - such as elevated temperatures and pressures, and greater margin for error in depth measurements - these wells offer special problems.