bluuebunny/crossref_metadata_2025_split huggingface dataset:
Defining Oil And Water Entries In Producing Wells
Authors: Schaller Herman E. 
Published: December 2007

Abstract
"Production Logging" is gaining ever increasing importance as the petroleum industry continues its efforts to increase the badly needed recovery of known reserves.
To provide the optimum assisted recovery system for a reservoir it is highly desirable to know the dynamic flow characteristics of the reservoir, both for the injection wells and the producing wells. This information is also important during the producing life of a reservoir to not only provide routine producing life of a reservoir to not only provide routine monitoring data, but also when problems arise to furnish a factual basis on which to evaluate and hopefully correct such problems. This paper deals with the dynamic conditions existing in producing oil wells and the parameters involved. It describes the approach used in defining the intervals contributing oil and/or water and the quantities of each. Actual examples of surveys are presented, with reference to the use of this information where available.

Introduction
Subsurface analysis of fluid flow in producing oil wells is quite complex when compared to similar types of measurements in injection wells. Under injecting conditions, generally only one phase is present, usually water but also possibly hydrocarbons phase is present, usually water but also possibly hydrocarbons either in liquid or gaseous form. Under single-phase conditions it is relatively straightforward to measure the rate of fluid travel at any given depth, either by the use of an appropriate radioactive tracer or an electromechanical device such as the continuous spinner or packer flowmeter.
PRODUCING WELL FLOW CONDITIONS In dealing with producing wells (under normal producing conditions), generally two phases (water and oil) are present; and in addition, free gas may also exist in the wellbore. Assume a system where the flow stream is 4-in. diameter or larger and rates where the water may range up to 2000 BPD and oil to 500 BPD. Under these conditions and in oil cut not to exceed 50 per cent of the gross fluid, flow conditions will probably be that of two distinct and separate fluids (water and oil), each having its own flow characteristics. Water, being the heavier fluid, will be present as the continuous phase from the intake of the flow string present as the continuous phase from the intake of the flow string to the effective depth of the well, and any oil present will be as the dispersed phase. (It is likely that this condition will prevail where any substantial amount of water is being produced.)
Packer Snubbing Program Protects Elk Hills Wells Turnkey Contract Reduces Costs
Authors: Young S.A. , Burch W.H. , Muse J.F. 
Published: December 2007

Abstract
The Elk Hills Naval Petroleum Reserve No. 1 in the San Joaquin Valley of California, which was set aside in 1912 and developed in the mid 40's and early 50's through acts of Congress and employing the resources of the Standard Oil Company of California as operator, was completed within the technology of the period. The majority of the wells in the Stevens Zone which range in depth from 5,000 ft. to 7,400 ft. with bottom hole pressures of 3,000 psi, were completed without packers but with tubing in the hole.
As a result of a growing concern for the protection of this untouched prolific oil reserve and for more efficient operation should the need arise to produce the field, it was decided to install packers and sub-surface check valves in wells from the Stevens Zone. All operations were conducted by a supply-service company on a lump sum turnkey contract for the operator.
In order to minimize formation damage and because the economics were favorable and to preserve productivity, it was decided to snub out the tubing as opposed to killing the wells. Because of wellhead configurations, only 193 wells lent themselves to the snubbing operation, leaving 25 remaining wells to be killed. Conclusions:
- snubbing, although generally regarded as a last resort because of its presumed higher cost, not only proved to be less expensive than killing operations but considerably more desirable from a well productivity standpoint.
- Turnkey operations provided by a reliable service company on contract may permit substantial reduction in overall cost.

Introduction
The United States Naval Reserve No. 1 (Elk Hills) (Fig. 1) with an area of 38,072 acres and located in Kern County, California was set aside by an Executive Order issued by President Taft on September 2, 1912. This action was taken in response to a request from the Secretary of the Navy in cooperation with the Secretary of the Interior to secure the reservation for the Navy of oil bearing land in California sufficient to insure a supply of 500 million barrels of oil. There was appreciable acreage in the Reserve originally patented to the Southern Pacific Railroad title of which was subsequently passed to the Pacific Oil Company and later to Standard Oil Company of California.1,2
A New Concept in Pumping Unit Technology
Authors: Metters E.W. 
Published: December 2007

A number of years ago, my company realized that existing equipment considered adequate for producing oil wells at the time would not be capable of producing wells of the future. All forecasts indicated there would be a need for equipment to produce from deeper wells and produce higher volumes from the more shallow wells.
A research and development project was initiated with the assignment of determining the most efficient means of lifting fluid from the producing zone to the stock tanks. All known producing zone to the stock tanks. All known methods of lift were investigated. The results of the investigation showed each system under a certain set of conditions could be classified as the most economical, but not necessarily the most efficient. The department finally philosophized that the most efficient means philosophized that the most efficient means would eventually develop into the most economical.
One system stood out above all others in its ability to lift fluid with the least lost effort. This, as you would suspect, was the conventional sucker-rod lift system. Further study showed that, even though the sucker-rod system over-all was the most efficient, as the loads increased either by volumes lifted or by increase in depth or a combination of the two, the efficiency of the system became much less and the projected cost of operation became too expensive to be commercially feasible.
With volumes of data on hand regarding attempted production of heavy loads utilizing sucker rods, there was one method which was able to produce fluid with a much reduced down-hole cost and a comparative good down-hole efficiency. This was the long-stroke hydraulic pumping unit.
The use of hydraulic pumping units reached its peak during the early 1950's. Without a doubt the manufacturers and the operators did everything possible to make the hydraulic unit operational, but it was a very complex piece of equipment and, except for an isolated instance or two, all the thousands of units had to be retired. The cost of maintenance was too high and the reliability far too low to be considered as acceptable.
Much was learned during this period. Due to the long stroke, at a constant velocity more fluid could be produced with far fewer cycles; hence, much more fluid could be produced by the sucker rods during their life expectancy. Subsurface pump problems were dramatically decreased. This is easily understood when you consider the barrel wear is distributed over a much greater area, and the velocity of the fluid through the valves is much lower than would be encountered with conventional surface equipment.
The research and development department then concentrated its efforts on a machine that could generate a long-stroke alternative to a beam type, which is relatively efficient at lifting lighter loads but becomes progressively less efficient as the loads increase.
Planning For and Managing Industrial Environmental Problems at the Corporate Level
Authors: Lent Robert R. 
Published: December 2007

Abstract
The many problems related to industrial environmental pollution are identified and discussed. People, technology, earnings, capital requirements, legislation, politics, and planning are complicating elements of the total problem.
I wondered and pondered a long time, trying to come up with a good way to begin a discussion of this type.
Then I remembered from my school days that fables are an effective way to make a point and, through the moral, to emblazon it point and, through the moral, to emblazon it on the hearer's mind.
So let me start out with a fable. Let's see how well I can compete with Aesop. I'll call it a Fable for Our Time.
Once upon a time — all fables begin that way, don't they? — there was a small city in a remote area. It had no traffic problems because it had no traffic to speak of. The city was very isolated — from the world, even from the twentieth century.
When the automobile finally was introduced there, it presented no problems at first. Few people had a car, and those who had one didn't drive very much. Traffic laws, then, were unneeded and non-existent.
But over the years the city grew and grew, and the number of automobile owners grew and grew. And they drove more and more.
And what havoc that growth did reap!
The rush hour became utter chaos. Collisions were many and often. People were killed and maimed. Irritation and frustration abounded, to the tune of great cacophonies of honking horns and bending fenders. Something clearly had to be done.
The situation, of course, was very emotional. Politicians propounded and expounded, in search of a headline. Students demonstrated. Mothers marched. Militants bombed. Letters to the editor were many and bitter. Gloom descended. An untimely end for the human species was regularly predicted.
The government reacted.
Safety Equipment That Can Help Prevent Pollution
Authors: Wilder Odis 
Published: December 2007

Abstract
Due to recent happenings that have received wide publicity the oil industry is, out of necessity, becoming keenly aware of the need to look very closely at safety systems and equipment to meet requirements of regulatory agencies and, at the same time, provide the best possible protection for their wells.
This paper presents some of the equipment that is available to the industry. It deals with subsurface equipment and design as well as surface equipment and design. Operation of the equipment, in most cases, is explained in detail.

Introduction
Pollution has been a problem in the oil industry, almost from its beginning. There are numerous types of pollution that can be directly and indirectly tied to the oil industry, but it is our purpose in this discussion to deal primarily with prevention of pollution from the standpoint of oil spill, whether it be on offshore platforms land locations, or drilling locations.
When looking at this problem objectively, we know why there are oil spills. With this in mind, we proceed to find a solution. Often times these problems seem difficult to solve, but with advanced technology and engineering ability that is available to the oil industry today it is reasonable to assume that the answer will be found. In reality, the solution is fairly simple. It is a matter of knowing what is required, selecting the necessary equipment to do the job, using the proper design, enacting a strict safety maintenance program and make it work. You, the producer, program and make it work. You, the producer, have an investment to protect.

Downhole Design
Perhaps the most important phase of any oil or gas well is during the completion stage. It is at this point that a "Life of the Well Concept" should be considered. Considerable money has already been spent to drill and case the well. The downhole equipment required to complete the well is, in most cases, a small percentage of the costs to this stage.
Sub-Surface Disposal of Acidic Effluents
Authors: Ostroot G. Warren , Donaldson Arthur L. 
Published: December 2007

Abstract
A study has been made as to the effect of acidic type effluents for Deep Well disposal, on various cementing compositions as well as their effect on plastic pipe. Data will include laboratory test results on API Class A, C and H Cements, Pozzolan Cement, Resin Cement, Gypsum Cement with Resin Phase and a Resin Slurry using Sulfuric Acid, Nitric Acid, Hydrochloric Acid and Mixed Acids. A section is devoted to well design which includes optimum pipe to hole size ratios, recommendations for down hole equipment such as special packers, the use of plastic and stainless steel pipe and various techniques gained from field experience in cementing Acid Disposal Wells.

Introduction
It is only within the last decade that the magnitude of the damage wrought to our natural resources, surface as well as sub-surface, has become a major concern to individuals, sportsman groups, conservation, State and Federal Government Agencies. Viewpoints are many and varied as to the availability of sufficient fresh water supplies to take care of both human and industrial needs, however, the consensuses seem to be that supplies are available if they are not wasted through misuse or by pollution from industrial wastes. More stringent laws are in the making by both the State Governments and the Federal Government.
Most areas are concerned with the problem of pollution in one form or another, with the more serious situations developing in industrialized and metropolitan areas. In many of these areas, water pollution as pertains to lakes, rivers and streams as well as underground fresh water supplies is a very serious problem.
The primary methods used in the disposal of industrial wastes are surface and sub-surface. Many different means have been used in surface disposal operations depending upon the type of waste and the condition of the final waste at the receiving point. Generally the treatment for surface disposal is classified as chemical, physical, or biological; however, any physical, or biological; however, any combination of these three may be used. Where the final product is deposited back to an area for re-use, some of the more expensive methods of surface disposal include land fills, settling tanks, filtration systems, aeration, floatation, oxidation, chlorination, pH adjustment, etc. These are not the most effective methods of waste disposal as considerable damage can result from spillage, overflow from heavy rains, seepage, etc.
Environmental Protection At The Line Level
Authors: Honeycutt Baxter D. 
Published: December 2007

Abstract
Line level environmental programs are presented. These include regulated presented. These include regulated investment protection measures which also protect the environment, preparation of oil spill contingency plans and ecological programs. Cooperative ecological research can be initiated between producing districts and governmental agencies and universities. That base line ecological surveys are necessary for emergency planning and to measure industry and resort impact on marine areas near shorelines is emphasized. Specific measures that line level personnel can institute for environmental protection are outlined.

Introduction
Growing concern with the state of our environment has made mandatory inclusion of ecological protective measures into the first level supervision of oil and gas drilling and production. The highly publicized Torrey production. The highly publicized Torrey Canyon, Santa Barbara Channel and Main Pass Block 41 oil spills focused much criticism on offshore operations. As a result, naturalists, fishing interests, government agencies, and conservation groups such as the Sierra Club are closely examining our operations in coastal waters. A valid concern of theirs is that the bays and estuaries must be protected as they are the nurseries for the abundant marine life in the seas.

Regulated Protection Measures
A line supervisor answers this need for protection of the invaluable marine life protection of the invaluable marine life while serving to provide minerals which are also necessary to our society. This supervisor is the man responsible for coordinating activities between various operating sections such as drilling, producing and engineering. First he takes measures as a prudent operator to protect his investment, consequently protecting the environment. Examples of these protecting the environment. Examples of these are (1) engineered well drilling programs, (2) adequate blowout prevention equipment, (3) tubing flow controls, (4) vessel sizing, rating and venting, (5) high-low liquid and pressure controls, (6) flame and gas detectors, (7) sprinkler systems, and (8) corrosion preventive measures. Rules of State and Federal preventive measures. Rules of State and Federal regulatory agencies spell out these measures and they are strictly enforced, but the real responsibility lies with the supervisor.
Some Aspects of Simultaneous Horizontal Two-Phase Fluid Flow Through Pipelines
Authors: Schneider Frederick N. , White Philip D. , Huntington R.L. 
Published: December 2007

Introduction
During the past decade a number of pipelines have been laid through which oil and gas are flowed simultaneously. In certain areas such as swamps and offshore locations, this method of transportation has been favored. Whether the advantages gained from separate lines offset the additional cost of those as compared to a single line carrying both is still a moot question.
Another problem which is encountered in two-phase flow is the feasibility of injecting a liquid drying agent, such as diethylene glycol, into natural gas lines in an effort to reduce hydrate formation. In pipeline design the prediction of the increase in energy loss and liquid holdup are questions which plague the engineer and will remain unanswered until the mechanism of two-phase flow is better understood.
It is essential that lines carrying two phases be of sufficient diameter so that the pressure drops will not be too high and yet their size will be small enough so that the cost will not be excessive. It is well known that the energy losses experienced in two-phase flow are ordinarily higher than those for single-phase flow. This is due not only to the irreversible work done by the gas on the liquid as it is dragged along but also to the reduced flow areas resulting from the presence of two fluids. No completely satisfactory means has yet been found to calculate the pressure drop resulting under a given set of conditions. Also, the dependence of the various flow types upon flow rates and other physical properties is not well understood. As two-phase flow now is being used to a greater extent in industry, the need for additional experimental information has increased. It was with this thought in mind that the present investigation was undertaken.
Some of the early experimental work was reported in 1939 by Boelter and Kepner. They studied two-phase flow occurring in a fuel distributing system for heaters in California orchards, and their data cover flow in 1/2 and 3/4 inch metal pipe of 50 ft lengths. Although they presented no correlation, it was suggested that the pressure gradients were functions of various dimensionless groups.
In 1944 the first general correlation was developed by Martinelli, Boelter, Taylor, Thomson and Morrin. A further analysis was made by Martinelli and co-workers covering the viscous region in 1946. Their tests were made in tubes of two to 50 feet in length ranging in size from capillary tubing to one inch pipe.
Fatigue Of Threaded Sucker-Rod Couplings
Authors: Bellow D.G. , Faulkner M.G. 
Published: December 2007

Abstract
Accelerated laboratory tests on the fatigue characteristics of sucker-rod couplings were carried out on a closed-loop hydraulic testing system. The purpose was to evaluate a number of different thread designs currently being used in the manufacture of sucker-rod couplings. The thread forms tested included the simple cut, a keyhole, cut and burnished, cut and cold worked and fully cold worked.
The results show that the fatigue life increases as the degree of cold-working increases. It is also seen that the effects of accelerating the testing are insignificant.

Introduction
The failure of sucker-rod joints is of considerable interest to those involved in petroleum production. To eliminate or minimize such failures many attempts have been made both, to producing new rod and coupling designs, and to eliminating the coupling altogether. The literature shows a number of papers dealing with the subject of joint failures, specifically related to improving the pin connection. There is apparently very little written on the coupling itself yet there is a multitude of coupling designs commercially available for use in joining sucker rods. The question arises as to which of these designs is the best. Thus, to aid in the design and selection of a coupling, the purpose of this paper is to evaluate the fatigue life of a number of purpose of this paper is to evaluate the fatigue life of a number of different thread designs which are being used in the manufacture of sucker- rod couplings.
Coupling design has, for the most part, been consistent with the pin design to which it must mate. Thus, coupling design has evolved from the simple cut thread, to a keyhole, burnished, cut and cold-worked and recently, to the fully cold-worked or rolled thread. To the consumer the coupling represents but a part of the cost of a rod. However, to the manufacturer, not all couplings can be made with the same ease and hence, same cost.