bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sonic Logging, A New Petrophysical Tool
Authors: Doh C.A. , Alger R.P. 
Published: February 2020

Joint Meeting of the Rocky Mountain Petroleum Sections of AIME, 3–4 March, Denver

Introduction
It has been recognized for many years that velocity measurements in the various formations provide useful information for both geologists and geophysicists. As early as 1934, patent applications were made for a two-receiver sonic logging device. However, in the past, the predominant application of velocity measurements has been in the field of geophysical problems -not in formation logging. The interpretation of seismic records is enhanced by accurate velocity data. Now, recent improvements in instrumentation have developed velocity measurements into an engineering tool which is helpful to both geologist and engineer in oil-well completion. The modern velocity, or sonic, logging tool will still provide the geophysicist with valuable velocity data, but its more important application will be in geological studies and reservoir evaluation.
Correlation problems, sometimes difficult with conventional electrical and radioactive logs, may be improved with sonic logs, however, the main advantage of sonic logs over, other logging devices appears to be the accurate detection and measurement of porosity.

Equipment Description
The sonic logging device described in this paper is based on a development by the Humble Oil and Refining Co. It features a two-receiver system and a short spacing (Fig. 1). The spacing used is generally 1 ft. A third receiver at an interval of 3 ft provides an alternate spacing, which can be utilized where more suitable to local geological conditions. Sound pulses are emitted by the transmitter at the rate of 10 or more per second, and the first arrival of energy at each receiver triggers the response system.
The two-receiver system eliminates some deficiencies of the single receiver used on several experimental and commercial tools. In the two-receiver system, the time consumed in the passage of the sound pulse from transmitter to wall of hole, and from wall of hole to receiver, is not added in the recording to the formation transit time. This hole effect is simply eliminated by recording the difference in arrival times at the two receivers. The influence of the mud character and hole size is, therefore, negligible in this system as long as the tool is held parallel to the wall of the hole. Centralizers are provided for this purpose.
Well Log Evaluations of Fractured Carbonates in the Wyoming Big Horn Basin
Authors: Jones Bob 
Published: February 2020

Joint Meeting of the Rocky Mountain Petroleum Sections of AIME, 3–4 March, Denver

Abstract
This paper illustrates the use of well logs in evaluation of Wyoming carbonate reservoirs, particularly the Phosphoria formation. The Phosphoria is a stratigraphic reservoir of Permian Age and includes primary and secondary porosity patterns. Procedures of calculating pore space water saturations are explained and illustrated. Log approaches to physical characteristics of the carbonate reservoirs are described, such as the presence of shale, formation fractures, relative permeability of intervals, etc.
The importance of high formation water resistivities in these reservoirs is well demonstrated. Calculations of recoverable reserves are demonstrated in one well and three fields.
Irreducible water saturations and "critical water saturations" as encountered in this formation are presented and discussed.
Methods and results, as reported herein, represent a practicable method of evaluating wildcat carbonate tests or carbonate fields in the Big Horn Basin.

Introduction
The author has applied standard log interpretation techniques to Wyoming Big Horn Basin carbonates [Fig. 1] with reasonable success since 1953. Experience has shown that the main stigma in analyzing carbonates and successfully completing them for production is the effect of fracturing systems which are very often present.
The Phosphoria dolomite is the most difficult producing Big Horn Basin reservoir in these respects and is therefore concentrated upon in this report. Known carbonate reservoirs present in this basin are shown in Fig. 2, the most important of which are Madison limestone end Phosphoria dolomite. Productive stature of Phosphoria can be easily compared by cumulative production to Jan.1, 1956. There is no intent to discount Madison lime and the deeper Big Horndolomite for they are excellent reservoirs. It is most likely, though, that oil accumulation in Phosphoria has been found in more areas because of the stratigraphic nature of its deposition.
Retorting Colorado Oil Shale by the Aspeco Process
Authors: Nevens Thomas D. , Culbertson William J. , Hobaugh John R. 
Published: February 2020

Joint Meeting of the Rocky Mountain Petroleum Sections of AIME, 3–4 March, Denver

Introduction
With the ever increasing costs of crude oil exploration and the increasing demand for petroleum in the U. S., it is apparent that in a few years secondary sources of fuels will be required. A survey of the possible sources of fuel oils leads one to conclude that the oil shale reserves will probably be the first fuel reserve to be exploited to supplement the supply of crude oil required for national security and consumer demand.
Of the various oil shale deposits in the U. S., the deposit of the Picane Creek Basin in northwestern Colorado is undoubtedly the first deposit which will be developed as it contains approximately 350 billion bbl of shale oil, a 1,000-year supply if recovered at the rate of a million B/D.
With these facts in mind, the Oil Shale Corp. acquired the Western Hemisphere patent rights to exploit the Swedish Aspeco process which appeared to hold promise as an economical method of retorting Colorado oil shale. Briefly, the Aspeco process involves an oil shale retorting step carried out by means of countercurrent flow of shale and heat carrying solids, and a combustion step wherein heat is recovered from the retorted shale and transferred to the heat carrying solids. Approximately two years ago the Oil Shale Corp. contracted with the Denver Research Institute, University of Denver, to conduct the necessary studies to examine the Aspeco Process in detail, and to construct and operate a 1 ton per hour pilot plant. Specifically, the objectives of the studies were:To investigate the technical characteristics of the Aspeco process of oil shale retorting in the laboratory, and to determine optimum operating conditions and engineering design;To construct and operate a one ton per hour pilot plant retort in order to secure engineering data as a basis for further process design and for a detailed economic evaluation of the process.
The F.I. Process...Theory and Practice
Authors: Gilbert Bruce 
Published: February 2020

Joint Meeting of the Rocky Mountain Petroleum Sections of AIME, 3–4 March, Denver
The F.I. process, recently developed by The Western Company of Midland, Tex., is the solution to a production problem as old as the fracturing process.
The F.I. or fracture initiation process creates a fracture in a subsurface formation at the exact depth and in the plane desired. This is accomplished in a two-step operation. First, the F.I. gun, shown in Fig. 1, is lowered to the desired depth and fired, creating six holes in opposing banks of three each. The specially designed jet perforators are housed in an expendable aluminum container. The gun is designed to withstand extreme conditions of pressure and temperature as well as field handling.
Upon firing, the portion of the gun extending below the necked-down mid-section is shattered while the massive section above, including the connecting thread, is retained in the firing sub and withdrawn from the well. If desired, the small amount of debris may be removed from the well with a sand pump, however, this is generally not objectionable and is left in the bottom of the hole.
The perforation pattern produced by the F.I. gun is shown in Fig. 2. Due to the tapering of jet perforations, the holes are converged slightly to maintain as nearly as possible a uniform ratio of hole diameter to web thickness. The reasons for this will be explained later. The diameter of the holes in 5 1/2in. casing is from 3/8 in. to 7/16 in. The holes are uniform and may be sealed with perforation ball sealers. No splitting of cemented casing has been experienced.
The second step in conducting an F.I. operation is that of hydraulic breakdown and extension of the fracture. The type of fluid used in the breakdown phase is important. We believe that pressurized fluid penetration into intrinsic fractures or planes of relative weakness could interfere with controlled breakdown. For this reason a non-penetrating type of fluid is recommended for the breakdown. The advantage gained by use of a non-penetrating fluid in fracture extension is generally understood.
Removal and Prevention of Scale in Producing Oil Wells
Authors: Featherston Aleck B. 
Published: February 2020

Evangeline Section Meeting on Drilling and Production Practices on the Gulf Coast, 24 April, Lafayette, Louisiana

Abstract
The deposition of scaling compounds from brines produced with oil has been a serious problem for many years. The use of inhibited muriatic acid to remove acid soluble scale has become commonplace, but the acid insoluble scales required mechanical removal.
Now calcium sulfate or "Gyp" scale, which is one of the most common of the acid insoluble scales, can be removed chemically.
The deposition of scales can be controlled over long periods of time by placement of complex dimetallic polyphosphates in the producing formation.

The Problem
The deposition of scaling compounds from brines produced with oil has been a serious problem for many years. Compounds such as calcium carbonate, calciumsulfate, barium sulfate, and others have been found in many wells. The effect that these scales have on the production of a well will depend largely on the location of the scale in the system. Since the scaling or precipitation takes place when the equilibrium of the brine is changed by pressure drop, temperature change, or mixing with other brines, it could cause trouble at any point in the production system. Scale deposits have been found in the production string, down hole equipment perforations, and in the formation itself. The formation of scales is an economic problem that affects the producing operator. The scale can plug fractures or formation channels, stop upper forations, plug tubing and pumps and stick rods. All of these will have adverse effect, if not in production decline, at least in economical operations.
Scales found in wells have been roughly divided into two groups through field operations. Based on their reaction with hydrochloric acid, they are either [1] acid soluble or [2] acid insoluble. This, of course, is a simplified division as some of the scales found in the wells are mixtures of scaling compounds, but it is adequate for most field applications.
New Design Concepts Developed in 1-3/8 in. Expendable Shaped Charge Perforator
Authors: Lebourg M.P. , Bell W.T. 
Published: February 2020

Evangeline Section Meeting on Drilling and Production Practices on the Gulf Coast, 24 April, Lafayette, Louisiana

Abstract
The two basic problems associated with the design of high performance, small diameter, fixed charge, expendable perforators have been resolved in a new 1-3/8-in. diameter gun for use through 1.5-in. production tubing.
A new method to control gun clearance and a new firing system which fully utilizes internal carrier space were developed and are described herein. This new combination, in a given gun design, is found to offer maximum and consistent performance on all shots irrespective of casing size.

Introduction
Developments in permanent-type completion operations within the past few years have resulted in multiple-string completions in which two or more sands are produced independently and simultaneously from the same well. Due to casing diameter restrictions, this technique has necessitated the use of small bore 1.5-in. production tubing which must be negotiated by the expendable shaped charge tool in order to perforate the well.
For a through-tubing tool to pass freely through this small bore tubing it must have a diameter not exceeding 1–3/8-in. Such a tool was introduced to the field during 1955 in the form of a swing tool. Mechanical difficulties with this gun, however, emphasized the need for a simpler, more reliable tool; one which would offer high charge performance in the common casing sizes in spite of small gun diameter restrictions. A gun was also needed to shoot small diameter liners below 1.5-in. tubing.

Basic Design Problems
Fixed charge guns of the capsule or tubular type are considerably more trouble free than swing guns. However, a preliminary study of conventional capsule and tubular gun designs in the 1–3/8-in. diameter immediately revealed two basic problems which greatly influenced gun performance:large gun to casing clearances andlack of internal carrier space for charge components.
Worldwide Exploration
Authors: Graves R. R. 
Published: February 2020

Abstract
It is a pleasure to be here with members of the Society of Petroleum Engineers and to share with you, and my distinguished co-panel ists, our thoughts on worldwide exploration.
Recognizing that worldwide exploration is a rather difficult topic to cover fully in 20 minutes, i will attempt to address a few of the more important aspects.
Foremost in any consideration of broad, regional exploration is an assessment of Future Potential for both oil and gas. In addition to showing the historical record of worldwide reserve estimation, current estimates as well as the broad geographic distribution of where the Future Potential is located, will be addressed.
A New Performance Measure to Test the Contribution of the Petroleum and Natural Gas Industry in an Expanding Economy
Authors: Barr Virgil L. 
Published: February 2020

Annual Meeting of the American Institute of Mining, Metallurgical, and Petroleum Engineers, 14–18 February, New York City
National income originating compared to physical production for an enterprise or an industry reflects its ability to strengthen the national economy. For a single industrial sector or for an industry this comparison can be useful to reflect changes that may occur in this ability to contribute because or changing supply demand-income-investment equilibria. A favorable relationship can be postulated by specified economic incentive, and the accompanying technologic input required can be shown.
The new index proposes the use of the Federal Reserve Board indexes of production divided by the constant dollar income originating in the petroleum industry which reflects increases or decreases in performance. When compared with other mineral industries and with total industry, an approximation of relative strength is evident.
By constructing three different hypothetical conditions for future petroleum imports, assuming a constant excess capacity requirement for domestic production, and providing an estimate for future domestic demand for petroleum, the impact on the performance index can be shown.
Thus, a strong position for the petroleum and natural gas industry can be stated. If this is done, it becomes evident that because of restrictions on cost-price relationships, a drilling program that would provide enough domestic oil to meet demand may not be practicable. By difference, the amount of improvement in methods of production and processing through technologic advancements can be stated explicitly.
Technology Tomorrow - JPT Article Series
Authors: _ _ 
Published: February 2020

Compilation of a series of articles published in the Journal of Petroleum Technology between February 2006 and April 2007.
The year-long Technology Tomorrow series was published in theJournal of Petroleum Technologybeginning in 2006. The SPER&D Advisory Committee created the series to spark discussion among the entireJPTreadership and include ideas that may not be in the current mainstream of thought. The seven articles included are:
Carbon, Hydrogen, and People by Vikram Rao, Vice President, Technology, Halliburton Energy Services
The Next Trillion: Anticipating and Enabling Game-Changing Recoveries by Nansen G. Saleri, SPE, Manager, Reservoir Management, Saudi Aramco
The Chemistry of Carbon Capture and Storage by Richard Pike, CEO, Royal Society of Chemistry
Reserves Growth: Torturous and Tortuous by Roy Long, E&P Program Technology Manager, National Energy Technology Laboratory, U.S. Dept. of Energy
Extracting the Benefits of Nanotechnology for the Oil Industry by Ramanan Krishnamoorti, University of Houston
Energy: The Next Biotechnology Challenge by Francesca de Ferra, Technical Manager, R&D Center, Eni Refining and Marketing Div. of San Donato Milanese
Technology for a Sustainable Tomorrow by Vik Rao, Senior Vice President and Chief Technology Officer, Halliburton
Effect of Network Parameters of Preformed Particle Gel on Structural Strength for Water Management
Authors: Salehi Mahsa Baghban , Moghadam Asefe Mousavi , Jarrahian Khosro 
Published: February 2020

Summary
Preformed particle gel (PPG) is an appropriate solution for conformance control and water management in low permeability reservoirs. In this paper, the network parameters of PPGs are evaluated through swelling tests and rheology and by determining their role in maintaining structural strength. Several PPG hydrogels were prepared by varying the concentrations of polyacrylamide and chromium triacetate [Cr(OAc)3] as copolymer and crosslinker, respectively, using a central composite design. The characterization of these hydrogels was performed using a scanning electron microscope (SEM), electron dispersion X-ray (EDX), and environmental scanning electron microscope (ESEM). The correlation between reaction conditions and the network parameters of polymer networks, such as the molecular weight of the polymer chain between two neighboring crosslinks (Mc¯), the crosslink density, and the size fraction, have been determined. In addition, swelling of the hydrogels took place through the Fickian diffusion mechanism. Structural states of Laponite dispersions strongly depend on concentration and ionic strength. Based on the rheological tests, the dynamic modulus of the PPG was strongly dependent on the initial concentration and resulting network parameters of the hydrogel. The results showed an effective interaction between Mc¯ and the elastic modulus of the gel network. Through the optimization of the network parameters, the appropriate composition was presented on the basis of the factors of strength (complex modulus of 4×104 Pa in the plateau region), the formation of a 3D network, and the preservation of the viscoelastic structure in the presence of Na+, Ca2+, and Mg2+, at a salt sensitivity of 0.5. In addition, the optimum sample structure was confirmed on the basis of microscopic images. Based on the coreflooding data, the optimal PPG showed a disproportionate permeability reduction (DPR) index of 17.01 and indicated the dual performance of these materials against water and oil. Also, the permeability diagrams of the core showed wettability of the oil-wet core could shift to more water-wet after PPG injection. To summarize this research, we present the determination and analyses of the network parameters as a novel technique for predicting the performance of hydrogels in porous media, and for investigating their strength under harsh reservoir conditions. In other words, determination of the network parameters can be used to ensure the success of the gel performance in porous media.
Application of Finite Difference Methods to Analogue Computational Techniques
Authors: Mullins Lynn D. 
Published: February 2020

Joint Rocky Mountain Meeting of the Society of Petroleum Engineers of AIME, 23–24 May, Billings, Montana

Abstract
The intent of this paper is two-fold - [1] to clarify the interpretation of analogue studies and [2] to stimulate interest in the use of finite difference approximations. Analogue methods, as applied to date to the problems of reservoir engineering, are reviewed briefly. Methods of interpreting results from detailed, two-dimensional analogue studies in light of finite difference methods are also discussed.
While the treatment in the paper is confined largely to undersaturated reservoir systems, the concepts of finite difference approximations apply equally well to the complex problems of gas evolution and relative permeability. In fact, the finite difference methods are among the very few capable of resolving the complex non-linear differential equations of interest to the reservoir engineer.

Introduction
Subsequent to Bruce's introduction of the electric analyzer many and varied application have been made of electric analogue methods practical reservoir behavior analyses. These analogue methods were designed primarily for gross reservoir behavior analyses, and for this purpose, the so called "single condenser", "multiple condenser" and "pool unit" studies have a great deal of merit.
The author has been concerned with problems associated with detailed [" Detailed" is used here and throughout the presentation to designate a minute representation of the reservoir and its behavior, and implies an abundance of detail rather than exhaustiveness in detail.] analyses of pressure distribution and fluid movements in under-saturated reservoir systems. Such problems have stimulated considerable interest in detailed analogue studies and the application of finite difference methods to them. This paper presents a method of extending the usefulness of analogue methods and introduces the concepts of finite difference approximations. However, the methods and concepts presented herein are, for the most part, extensions of previously published methods.
A New Cement-in-Oil Slurry
Authors: Crone B.L. , White G.L. 
Published: February 2020

Fall Meeting of the Southern California Petroleum Section of AIME, 17–18 October, Los Angeles, California

Abstract
A new cement-in-oil slurry has been developed which has proven itself in the field to be an efficient and valuable aid in helping to reduce or eliminate water production in oil and gas wells. The new slurry utilizes a viscous and thixotropic, kerosene-based carrying agent possessing a low fluid loss, which will suspend and carry the cement particles to maximum depths in the formation at comparatively low injection pressures. The carrying agent places a protective coating of viscous oil around the cement particles and retards the wetting of the cement until all of the slurry has had time to be placed in the formation. After a certain time interval, special chemicals contained in the slurry cause the viscous oil to be reverted to thin kerosene and also will permit the cement particles to become water wet and thereby set the cement. Any slurry entering the oil bearing portion of the formation and contacting no water will be recovered as thin kerosene and unset cement.

Introduction
Although no statistics are available, it is well known by engineers and other production personnel that present methods of squeeze cementing are not completely satisfactory. Unsatisfactory results have been the rule rather than the exception in many areas when squeezing becomes necessary. Problems that can arise are numerous: failure to displace the desired amount of slurry out of the tubing at an allowable pressure; difficulty in regaining oil production after squeezing; frequent reversion to the original water production when stimulation is necessary after squeezing.