bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of Minimum Cost Drilling Programs
Authors: Cole Frank W. 
Published: December 2007

Abstract
Minimum cost drilling programs have been available for about 10 years, but only recently have they been utilized to any extent. One of the principal disadvantages of most programs is that they assume rig operating costs are independent of bit weights and rotary speeds. Although the use of minimum cost drilling programs is relatively new, their proper use programs is relatively new, their proper use can effect substantial savings in the drilling operation.
The principal uses of a minimum cost drilling program are in (1) planning the entire well, (2) selecting the proper bit, (3) optimum time to pull a bit, (4) proper weight and speed to meet special conditions, such as extending bit life in order to save a round trip, reducing bit life as a result of changing formations, critical rotary speeds and crooked hole conditions, (5) revising optimum bit weights, rotary speeds, and bit footages on an instantaneous basis during drilling and (6) studying special problems such as the influence of rig costs on optimum drilling conditions.
Minimum cost drilling programs can be economically used with a time-share computer and a teletype terminal. The terminal can be located at the rig or in the office.
Most minimum cost drilling programs in use today are more complex than they need to be. A relatively simple program should be used initially; then, as more experience is gained, the programs can be made more complex.

Introduction
Since the late 1950's, as evidenced by the published petroleum literature, there has been published petroleum literature, there has been a strong interest in developing mathematical relationships which would describe and, therefore, permit some type of optimization of the drilling operation. Beilstein and Cannon made an important contribution to understanding the interrelationships of some of the more important variables affecting the economics of drilling. Speer later published valuable data which largely supported the observations of Beilstein and Cannon. Within a short period of time a number of analytical methods for describing the drilling operation were published. All of these methods were developed published. All of these methods were developed primarily to study the effects of varying bit primarily to study the effects of varying bit weights and rotary speeds on penetration rates and drilling costs. These analytical methods are now commonly referred to as minimum cost drilling or optimized drilling methods. A true minimum cost drilling program must include all variables influencing the drilling operation. Some of the most important of these variables are (1) drilling rig, (2) crew efficiency, (3) hydraulics programs, (4) type of mud, (5 bit selection (6) bit weight and (7) rotary speed.
Driller's Challenge: The 28,000 Foot Hunton
Authors: Muscovalley J.N. 
Published: December 2007

Abstract
The deep Anadarko Basin is expected to become a major gas producing province within the next decade. The Hunton formation, sometimes occurring as deep as 28,000 feet, is the primary objective of today's gas exploration in the Basin.
The drilling industry faces the challenge of providing the equipment, and technology, to drill wells of this depth on a continuous and economical basis.
Because of the many wells drilled below 20,000 feet in the past five years, the industry today has the experience and the technical ability to successfully meet this challenge.

Introduction
The Petroleum Industry must find new gas reserves. The Anadarko Basin, long one of this nation's major gas producing provinces, now is being explored to it's deepest extent for this gas. This nation's continuing need for energy has made what once seemed uneconomical and impractical, a necessity.
Today, the Hunton formation of Devonian age is one of the primary targets for this deep gas exploration. There are presently several wells drilling to the Hunton, which may occur as deep as 28,000 feet.
A few years ago, a 28,000 foot well would have been totally uneconomical. Deep drilling, at that time, had not become the routine matter that it is today, and the demand for gas had not reached the point where gas transmission companies were point where gas transmission companies were willing to bid for the gas before the well was spudded. The combination of these two facts, the improvement in drilling and the improvement in the supply and demand for gas, has made the 28, 000 foot well a reality.
However, a well of this depth still represents a tremendous challenge to the industry. Well costs in excess of 2 million dollars, well depths deeper by 2, 000 to 3, 000 feet than any ever drilled, unknown geological problems, and finally the risk of wildcatting at any depth, makes this one of the most dramatic challenges the drilling industry has ever faced.
Geological Elements Involved in the Exploitation of Deep Reservoirs
Authors: Moore Carl A. 
Published: December 2007

Abstract
A knowledge of the geometry of the rocks in the increasingly deeper basin areas may provide significant geological elements which can affect drilling and completion procedures.
In the Mid-Continent "hard rock" country, porosity variations at depth do not follow the pattern that is recognized in the soft Gulf Coast sediments. Porosities in sandstones may vary with the presence of shale beds which are subject to compaction by overburden presence of shale beds which are subject to compaction by overburden pressures; and by factors of re-arrangement of grains accomplished pressures; and by factors of re-arrangement of grains accomplished through crushing and re-cementation. Grain size distribution and initial porosities will be factors to be evaluated. Fairly coarse, non-shaly, beach sands can be expected to porosity at depths, than deposited in deep water, are shaly. These latter poor porosity because of overburden pressures, as re-arrangement factors.
Limestone porosities averaging over 12% are being reported from Hunton (Devonian - Silurian age) limestone reservoirs below exhibit greater those sands which were below wave base, that types will exhibit compaction due to well as the 20,000 feet. Because of the rigid rock fabric, porosity in limestones is not expected to be a function of depth of burial. Rather, the environment of deposition will affect the primary porosity. The geologic history, of the record of periods of deposition, uplift, and mountain building movements in the area, will be the most significant factor in the development of secondary prorosity from which giant gas production is being proved.
The degree of dolomitization of limestones is another factor in the development of porosity. There is usually a straight line relationship between the increase in dolomite content of a limestone and its increasing porosity. Evidently dolomitization is an early phenomena, controlled by the depositional environment of the limestone and the diagenetic changes which are imposed upon the new rock. Any petroleum that is generated in a basin may move into the porous limestone reservoir rock from an adjacent shale source rock.
Increased fluid pressures at depth may initiate micro-movements along minute fracture planes, and thus add a factor to the drillability of a given rock, and may influence the migration of fluids.
How to Select the Correct Sand Control System for Your Well
Authors: Coulter A.W. , Gurley D.G. 
Published: December 2007

Abstract
There has long been a need for a guide to the selection of the sand control system needed for a particular well. There are four types of systems in use today:
(1) screens, gravel packing,
(2) sand consolidation and
(3) a resin-coated particulate such as sand.
Although universal agreement may not be possible at this time, there are certain guidelines that are followed. The factors involved include formation permeability, clay and silt content of formation, interval length, number of zones, homogeneity, well history, type completion, depth, expense of rig time and others. This paper will consider these factors and their influence on the selection of sand control systems.

Introduction
The problem of controlling sand production in oil and gas wells has increased significantly in importance in the past few decades as new offshore oil provinces have been discovered and developed. The oil produced in many fields, particularly in south Louisiana, offshore Louisiana and California could not be economically produced if effective means of sand control were not available. Many papers have been published over the years describing the various sand control systems available to the industry. Much has also been written concerning the proper techniques for applying the various systems. There is no doubt that much progress has been made in solving the problem of sand control. There remains, however, a great degree of controversy and much divergence of opinion as to which method of sand control should be applied in any particular situation. Admittedly, this is a controversial problem, but the authors feel that certain guidelines can be established on the basis of experience with the various systems in use. The purpose of this paper is to review the four main methods of sand control that are in widespread use and to discuss those factors which are most important in the selection of the method best suited for a particular well.
Taber South - Canada's First Polymer Flood
Authors: Martin Ian , Lozanski Wally 
Published: December 2007

Abstract
Three years of actual performance of the Taber South Mannville B pool polymer flood has resulted in sufficient data to review the initial decision to implement this type of secondary recovery scheme. Comparison of performance to the original forecasts to a performance to the original forecasts to a critical re-examination of those forecasts and to performance of conventional waterfloods in pools with similar characteristics has been pools with similar characteristics has been made. Operating costs and capital costs caused by polymer injection have been studied. Consideration of ultimate polymer slug size and operational procedures has been undertaken to provide a guide for optimum future performance. provide a guide for optimum future performance. The conclusion has been reached that polymer flooding has been economically successful and appears to have been significantly more profitable than a conventional waterflood.

Introduction
Canada's first polymer flood was initiated in Feb., 1967, in the Taber South Mannville B oil pool, located approximately 35 miles southeast of Lethbridge, Alta. (Fig. 1).
The Taber South Mannville B pool was discovered in March, 1963, with the drilling of the CPOG Taber S 2-29-7-16 well. A total of 23 oil wells and 11 dry holes drilled on a 40-acre spacing pattern, to an average depth of 3,230 ft, defined a reservoir containing an estimated 40,010,000 STB of oil.
Long Stroke Pumping Unit
Authors: Ewing Roy D. 
Published: December 2007

The success of the sucker-rod system for pumping oil wells is due, primarily, to the pumping oil wells is due, primarily, to the simplicity of the surface, as well as the subsurface equipment. In the early life of the industry the wells were shallow and could be adequately pumped with beam-type surface equipment. As wells were drilled to greater depths and larger volumes had to be pumped, consideration was given to other types of surface equipment to actuate the sucker-rod system.
Some of the advantages of long-stroke pumping are (1) fewer stress reversing cycles pumping are (1) fewer stress reversing cycles resulting in longer sucker-rod life, (2) more net plunger travel as related to polished rod travel, (3) longer subsurface pump life due to reduced number of pumping cycles and increased area of wearing surfaces in the pump, (4) less tubing and sucker-rod coupling wear in crooked or slant holes and (5) less frequent servicing of subsurface equipment.
The long-stroke pumping unit covered by this paper has the following advantages in addition to those listed above:
(1) increased production due to uniform polished rod velocity production due to uniform polished rod velocity (this is highly important in pumping viscous liquids),
(2) less reducer torque due to short torque arm and
(3) more horsepower developed by a given reducer due to higher rotating speed of the drum shaft.
There may be some question as to what constitutes long-stroke pumping of an oil well. Twenty years ago a beam-type n unit with a 100-in. stroke was considered to have a "long stroke". As the requirement for pumping more liquid from greater depths developed, beam-type units were made larger and with longer strokes to satisfy this demand. There is now one beam-type pumping unit available with a maximum stroke length of 300 in. It is difficult to say what the limit will be on length of stroke for a beam unit. It will probably be determined by the degree of success of some other type unit, such as the one to be discussed.
A number of long-stroke pumping units have been built with varying degrees of success. They were generally limited by mechanical design problems or adverse effects on other components problems or adverse effects on other components in the pumping system.
Influenced by the old adage, "If at first you don't succeed, try, try again", another design* of a long-stroke pumping unit was conceived and the advantages of long-stroke pumping have been achieved to a very high degree. pumping have been achieved to a very high degree. The key to the success of this unit is a contoured drum for spooling wire rope assemblies to actuate the sucker-rod string and suspend the counterbalance. Fig. 1 shows an installation of the long-stroke pumping unit. The stroke length is 34 ft and the polished rod-load capacity is 35,000 lb. Two geared speed reducers have been built with ratings of 310,000- and 420,000-in. lb peak torque capacity. Maximum recommended input hp to these reducers is 75 and 100, respectively.
The Interdependence Of Free World Nations On Their Petroleum Supply
Authors: O&apos;Brien Jerome J. 
Published: December 2007

UNITED STATES DEPARTMENT of the INTERIOR * * * * * * * * * * * * * * * * * ** * * * news release
For Release to PM's, FEBRUARY 19, 1962
It is with greet pride that I have the privilege of addressing you today the Society of Petroleum Engineers of the A.I.M.E. This occasion is serving at wofold purpose for me; en opportunity to fraternize with many of my old friends and colleagues, end the honor of addressing en organization of which I am a card-carrying member. It is always a pleasure to meet with an engineering group because, in my opinion, there are more men of genius, pluck and determination to win, engaged in engineering then in any other profession.
The word "interdependence" has perhaps been too widely used recently, but whether we like it or not, the problems of oil are entwined with broader problems everywhere.
The petroleum industry of the Free World today is deeply influenced by two dominant sets of factors that give rise to severe stresses within the industry's structure and create major uncertainties as to the future direction of its development.
The first of these elements is the worldwide excess in the capacity to produce, to refine, and to transport oil. This progressive imbalance between world consumption of petroleum products and ability to produce is generating intensive, and sometimes disruptive, competition in oil marketing. It is creating instability in the entire world petroleum price structure.
The second cause of stress is far more complex. It is a reflection of the new trend in world affairs characterized by the fading of the colonial system end the emergence of a succession of new, inexperienced, end sometimes unstable political units. Radical changes are occurring in many areas where established social end economic patterns are being put aside or are under attack.

RESERVES OF CRUDE OIL AND NATURAL GAS LIQUIDS
Some of the fundamental problems relating to petroleum are revealed by examination of the contrast between the location of the major consuming area send the location of the major oil reserves of the Free World. The consumption of oil, of course, is concentrated in the industrially developed areas such as the United States and Europe, whereas most known reserves are located in less developed areas such as the Middle East.
The Case for Oil Spill Dispersants
Authors: Canevari Gerard P. 
Published: December 2007

Abstract
The subject of oil spill handling represents a new area of technology that is unique in that it encompasses chemical, mechanical and biological disciplines. Within this subject the use of chemical dispersants represents a solution that can provide the most applicable approach under certain conditions.
This paper defines the overall problem of oil spills and then derives the basis for the use of dispersants, as well as the conditions that justify their use. Chemical dispersants are not a panacea for the cleanup of oil spills. However, there are situations where dispersants should be used for the benefit of our natural resources; and there are also instances where they should not be used.
An appreciation of the dispersing mechanism and the influence of environmental factors is necessary in order to assess the appropriate role for dispersants in the handling of oil spills.

Introduction
It is important at the outset of any discussion regarding oil spill dispersants to review the subject of oil spills in general in order to consider the use of dispersants in the correct perspective. The subject of oil spill handling is complex as it encompasses several engineering disciplines, as well as biological, conservationist and political interests.
This paper will derive the specific area of application for dispersants and will review the pros and cons regarding their usage. At the outset, it should be outlined that the role of oil spill dispersants is one of a last resort nature since prevention of oil spills is the first consideration. In the industrial and governmental communities, the major effort has been directed toward this area. There is extensive ongoing research, for example, ranging from operational areas, e.g., collision avoidance techniques and training, to more novel approaches such as gellation of crude oil cargo to prevent release from a damaged compartment, oil-water separation devices, flocculating agents, etc.
However, after a spill has occurred, physical containment and removal is the physical containment and removal is the recommended approach. This is the most complete solution to the problem. Unfortunately, the present state of the art limits the effective present state of the art limits the effective application of oil containment booms to rather quiescent conditions and they are not suitable in general for open sea conditions. As concisely summarized by Dewling, there are at least 37 different approaches to corralling and holding oil spills. Spill boom systems are available in prices ranging from $5 to $45 per foot and represent an important tool under those sea, weather and geographical conditions that permit effective deployment. There is extensive research currently underway in this area, principally funded by the U.S. Coast Guard, to principally funded by the U.S. Coast Guard, to extend the capability of spill booms.
Application Of Leaky Aquifer Theory To Testing Of Aquifer Gas Storage Prospects
Authors: Witherspoon P.A. , Neuman S.P. 
Published: December 2007

Abstract
A much more complete theory of transient flow in leaky aquifers has recently been developed and can be applied to the problem of investigating the hydraulic properties of caprock layers over potential gas storage reservoirs. During a pumping test, the transient behavior of a multiple-aquifer system depends on the properties of the aquifer being pumped as well as the degree of communication that can develop across the pumped as well as the degree of communication that can develop across the caprock to unpumped aquifers. However, at sufficiently small values of time defined by tD less than 1.6 Beta /(r/B), the effects of the unpumped aquifer can be ignored and the caprock can be treated as though it were semi-infinite.
The application of this new theory to the problem of testing aquifer gas storage prospects is reviewed, and it is shown that the theory provides a better understanding of earlier concepts on slightly leaky caprocks. The general applicability of the method is demonstrated by analyzing data from field tests on two different aquifers with very leaky caprocks. The results are in excellent agreement with core analyses of the caprocks.
Shell's Experiences on the Cedar Creek Anticline, Montana, with Blended HCL Acid-Unibead* Mixtures to Continuously Divert and Stimulate Carbonate Reservoirs
Authors: Hayden Brian R. 
Published: December 2007

Abstract
This paper presents Shell Oil Company's experiences in stimulating producing, water injection, and water source wells on the Cedar Creek Anticline In Montana, using a blended HCL acid-Unibead* continuous diversion and stimulation technique. Wells not amenable to effective stimulation using conventional methods of zone isolation and acid placement because of problems in well mechanics are currently being stimulated using the continuous diversion and stimulation technique with favorable results. The use of surface blended mixtures of HCL acid and Unibeads to stimulate problem wells is considered to be more effective than the more widely used "slug-plug" diversion and stimulation technique, and to have wider application, especially for treating wells on the Cedar Creek Anticline.
The results of 30 treatments on producing, injection, and water source wells performed to date using the continuous diversion and stimulation technique are presented, along with the reasons for the use of this technique, observations made, conclusions reached, and recommendations for future use.

Introduction
Shell Oil Company began using a continuous HCL acid-Unibead* stimulation technique during December 1969 to acid treat impaired wells on the Cedar Creek Anticline in Montana completed in as many as 16 porous Silurian-Ordovician and 4 Mississippian carbonate intervals. Because of well mechanics, many of these wells were not amenable to effective stimulation using conventional methods of zone isolation and acid placement (such as a retrievable bridge plug and packer arrangement).
The Real Story of Cement Expansion
Authors: Root R.L. , Calvert D.G. 
Published: December 2007

Abstract
One of the most serious problems encountered when cementing casing in a well is the failure of the cement casing and cement formation bond. The failure of the cement bonding is a major problem from the standpoint of allowing problem from the standpoint of allowing migration of fluids from one zone to another. Also, poor bonding can result in large losses of reservoir fluids, premature reservoir depletion, and unsatisfactory stimulation operations. With these factors in mind, it has long been recognized that superior cementing operations could be achieved if expansion could be induced in oil well cements. Expansion currently is induced in oil well cements by two methods, addition of salts (salt cements), or addition of an expanding component (chemically compensated cement).
The purpose of this paper is to compare the expansion characteristics of these types of cements. Additional characteristics such as pumping time, compressive strength, and bonding pumping time, compressive strength, and bonding are also compared.

Introduction
Good bonding of the cement to pipe and cement to formation is essential for effective zone isolation. This problem is evident in oil, gas, and gas storage wells. Secondly, poor bonding may limit the desired production and stimulation techniques of the well in question. The introduction of expansion in a well cementing system has long been recognized as a possible means of improving the primary cement job. At present, these are four basic methods that may be used to accomplish better bonding.