bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Potential Of Enhanced Oil Recovery Processes
Authors: Sharp James M. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
The results of three successive surveys of industrial and cooperative federal/industry field testing of Enhanced Oil Recovery methods are summarized. Included are industry's forecasts of potential domestic EOR production and reserves and of the relative production and reserves and of the relative potential of the various major EOR potential of the various major EOR processes. processes.

OVERVIEW OF EOR POTENTIAL
Any discussion of the "Potential of Enhanced Oil Recovery (EOR) Processes" must emphasize the word "Potential". The dictionary definition of "potential" is: "possible, but not yet realized; or, capable of being, but not yet in existence". This definition accurately describes the status of EOR processes at this time. While there is little disagreement that EOR processes promise to be an important factor in crude oil production, there is equally little production, there is equally little disagreement that this has yet to be demonstrated.
EOR technology is not yet developed to the point of permitting accurate prediction of performance and risk prediction of performance and risk assessment. Therefore, it is not ready for production-scale application. For this reason, any projection of the Ultimate Recovery or of the time frame for a given level of Annual Production to be realized from EOR processes must be based solely on informed engineering opinion. It follows, then, that projections of production costs for EOR projections of production costs for EOR crude oil cannot be made except as very approximate ranges of cost for hypothetical successful operations. Finally, a prediction of the production vs time profile and of the incremental increase profile and of the incremental increase in recovery for a specific EOR process as applied to a specific reservoir in advance of large scale field test completion may be even more suspect than projections of total domestic projections of total domestic production, since statistical averages do not production, since statistical averages do not apply.
There is, then, considerable uncertainty regarding both the technical and the economic feasibility of EOR, especially as applied to a specific reservoir.
Spontaneous Emulsification-A Possible Mechanism for Enhanced Oil Recovery
Authors: Cash R.L. , Cayias J.L. , Hayes Michael , MacAllister D.J. , Schares T. , Schechter R.S. , Wade W.H. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Introduction
Spontaneous emulsification will occur between a hydrocarbon phase and an aqueous solution of petroleum sulfonates if the sulfonate preferentially partitions into the oil phase. The displacement of residual oil, in phase. The displacement of residual oil, in laboratory core floods, at a small capillary number is significantly improved when spontaneous emulsification occurs; with the displacement efficiency being favored by high emulsion coalescence rates. The mechanism of oil mobilization in these displacements may distinct from those of miscible and immiscible processes. processes.

MECHANISMS OF SPONTANEOUS EMULSIFICATION
If a layer of toluene is carefully poured on top of an aqueous phase containing 3 weight-percent of a petroleum sulfonate and 1 weight-percent NaCl, the system initially consisting of two relatively clear, distinct phases is at first quiescent. After about 15 minutes, a mist of fine drops can be seen at the interface: the surface beings to twitch sporadically and an emulsion of growing proportions is observed to form. This spontaneously formed emulsion is not, however, thermodynamically stable and so it cannot be attributable to "negative" interfacial tensions. Indeed, in a matter of days, coalescence of the emulsion can be detected. Eventually, the emulsion will coalesce entirely and the two clear phases are then stable, but of different composition.
The example of spontaneous emulsification/ breaking cited above is not an isolated one; many other similar systems will be defined in this paper. What makes the above process fascinating and certainly worthy of further study is that it represents a possible mechanism for tertiary oil recovery - one that appears to have been largely overlooked: one which is distinctly different from the low tension processes. It is the purpose of this paper to explore this possibility. The paper to explore this possibility. The conclusion is that residual oil can be mobilized by spontaneous emulsification. One possible mechanism is that the small oil droplets thereby mobilized may subsequently coalesce with other ganglia of residual oil, creating a local region of enhanced oil saturation. Other mechanisms of increasing the local saturation pre, however, possible. Once the local oil pre, however, possible. Once the local oil saturation is increased sufficiently the oil will be mobilized. Further coalescence can take place, and an oil bank can be formed. This place, and an oil bank can be formed. This process has been tested and the results are process has been tested and the results are reported here.
Fireflooding Shallow Tar Sands - A Case History
Authors: Terwilliger P.L. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Summary
A field pilot test of forward combustion utilizing fracturing techniques was conducted in a shallow tar sand deposit in central Kentucky. The tar sand at a depth of 100 ft had an average porosity of 22%, an oil saturation of 64% (6.4% porosity of 22%, an oil saturation of 64% (6.4% tar by weight) and a permeability of about 2000 md. The tar had an API gravity of 10.6 deg. and a viscosity of 150,000 cps at a reservoir temperature of 56 deg. F. The pilot area was a small inverted five-spot which was 107 ft on a side. Horizontal fractures were created in the four producing wells by breaking down the formation producing wells by breaking down the formation with air pressure, and the fractures extended and propped to a calculated radius of 25 ft by propped to a calculated radius of 25 ft by injecting water-base, gel carrying 4–8 mesh sand. A pneumatic fracture was created in the central injection well which was held open by the continued injection of air. A down-hole burner was used to initiate the combustion zone. Oil production responded to the movement of the production responded to the movement of the combustion zone ten days after the fireflood was started. The average oil production was 24 barrels per day for the four months required to complete the test. The total oil production of 3100 barrels was 54% of 5700 barrels originally in place in the pattern area. The injected place in the pattern area. The injected air-produced oil ratio was 42,000 cu ft/bbl. The produced oil was upgraded to 14.5 API and 2000 cps at 60 deg. F compared to 10.6 deg. API and 100,000 cps for the original tar at the same temperature. The major problems encountered were the lack of complete oxygen consumption, the unsymmetrical advance of the fireflood and the tendency of the combustion zone to move toward the top of the reservoir.

Introduction
During 1959 and 1960, Gulf Research and Development Co. conducted a fireflood field pilot test in a shallow tar sand deposit lying about halfway between the towns of Brownsville and Leitchfield, Kentucky, which had been leased from the Kentucky Rock Asphalt Co., hence the name KYROCK. The fireflooding or forward combustion method has been adequately described elsewhere and the modification tested at the Kyrock site was the utilization of both pneumatically and mechanically propped fractures. pneumatically and mechanically propped fractures. Earlier reverse combustion experiments in the sand tar sand deposit had indicated that horizontal fractures could be extended at constant depth over considerable distances and that a forward combustion reaction zone could be maintained using these fractures for a major part of the fluid flow. part of the fluid flow.
Steam Mobility in Porous Media
Authors: Trimble A.E. , Menzie D.E. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
An experimental investigation was made to study the steam displacement process. This paper presents the process. This paper presents the results of those experiments designed to show the role of steam mobility in the process. Calculations of steam phase relative permeabilities as phase relative permeabilities as functions of steam quality and liquid phase water saturation are also shown phase water saturation are also shown as an extension of the use of this type of data.
Mobility experiments were made in the absence and in the presence of a light oil. The oil was selected such as to minimize viscosity reduction and eliminate distillation. The role of steam mobility can then be seen in relation to the basic displacement efficiency of steam.
Results of the study indicate that steam mobility (in the absence of residual oil) decreases with steam quality for both high and low permeability cores. Where steam mobility permeability cores. Where steam mobility was measured in the presence of residual oil saturation, the effect of residual oil saturation became less pronounced with a decrease in steam pronounced with a decrease in steam quality and an increase in core permeability. permeability

Introduction
The principal mechanisms for the additional oil recovery from a steamflood over that of a waterflood were reported by Willman et all to be 1) thermal expansion of oil, 2) oil viscosity reduction, and 3) steam distillation of the oil. These three factors are present to various degrees in any field thermal operation and are of vital importance in trying to predict a steamflood performance. predict a steamflood performance. Shutler, using a thermal model to investigate the steamflood process, noted that oil recovery was obtained which could not be explained by temperature or steam distillation alone. He suggested a "condensing drive" mechanism was responsible.
Considerations in Financing the Development of Petroleum Resources
Authors: Matthews Thomas K. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
I have great empathy for those of you who are daily engaged in the valuation process. It hasn't been long since our process. It hasn't been long since our principal concern, aside from the reserve principal concern, aside from the reserve estimates, was the MER and predicting the allowable days for Texas and Louisiana. Crude prices were easy, for we all expected prices would ultimately increase. In prices would ultimately increase. In addition, financial institutions were eager to lend their money for reasonably long terms at exhorbitant fixed rates of 5 1/2 % to 6 %. Certainly the Rip Van Winkle engineer of the sixties arriving on today's scene would be more than a little confused.
While theoretically the financing of estimated reserves has improved substantially, along with the computer programs and hardware, the specter of controlled prices, rollbacks, FPC expansion or prices, rollbacks, FPC expansion or contraction, inflation, taxation, tight money, and OPEC, tends to fog the crystal balls of the heretofore competent prognosticators. I am sure that many of you have become as proficient in hedging your evaluations as proficient in hedging your evaluations as economists propounding future economic events.
Regardless of today's uncertainties, oil and gas will be the dominant energy sources for some time to come, and national priorties require an economic framework which encourages accelerated development of oil and gas reserves. The current outlook indicates that the sustained investment required to develop new reserves will substantially exceed the internally generated cash flow of the industry. Increased debt will be required to fund a good portion of the shortfall. We will unquestionably be called upon with more frequency to provide economic projections related to financial requirements.
The type of financing you are most likely to be concerned with is project financing, where the funds are borrowed for development of a specific project, and repayment is based solely on revenues resulting from the completed project. Project financing has come into much wider use in the past few years for several reasons, not the least of which is the favorable balance sheet treatment it affords.
The Relative Cost of Major Project Delay
Authors: Gaffney P.D. , Cox T.F. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
This paper discusses the interplay of the more important factors which determine an optimum development plan. Practical considerations may dictate an early commitment to field development, particularly in an offshore environment but such decisions must rely on a precise balancing of the relative advantages and disadvantages incurred by any delay.
Early commitment involves heavy reliance on relatively sparse reservoir data and it is therefore necessary to reconcile this drawback with the benefits of earlier cash flow. This assessment takes account of two additional factors, namely the effect of changes in oil price and the rate of inflation applicable during the investment period. The application of a lower initial period. The application of a lower initial investment exposure in a development plan within a high-risk reservoir environment shows that while this approach may not result in the most profitable field venture in the longterm, it frequently makes possible the initiation of a field project which would otherwise remain dormant.
Flow Closing Coefficients from Water Flow Tests for Subsurface Controlled Safety Valves (API-SSCSV's)
Authors: Pierce Phillip E. , McLemore Ethel Ward 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Flow closing coefficients and a function for prediction of orifice size, given the pressure drop and flow rate, were derived from pressure drop and flow rate, were derived from an analysis of water flow tests made on subsurface controlled safety valves. A pressure-drop function, the mass flux function, and four pressure-drop function, the mass flux function, and four Buckingham pi-number functions, were investigated, using the test data, as possible equivalents to the Bernoulli flow equation. The Euler function gave the highest probability of minimum error in prediction of the flow closing coefficients and orifice size.

Introduction
Subsurface controlled safety valves (SSCSV) are installed down hole in the tubing by wireline. They are frequently referred to as velocity closing valves or Storm Chokes. When they are installed in oil or gas wells, their purpose is to shut the well in when a disaster purpose is to shut the well in when a disaster occurs at the surface causing the wellhead to be partially or completely removed. The sudden partially or completely removed. The sudden increase in production rate resulting from such an event causes the safety valves to close because of an increased pressure drop across the bean or choke. This increased pressure drop acting against a differential area formed by the bean diameter and a sealing element diameter produces a force that overcomes a spring force produces a force that overcomes a spring force acting to keep the valve open during normal production. production. Fig. 1 shows a common type of SSCSV usually referred to as a "poppet type". The valve is shown in both open and closed positions. It is in the open position during normal production and is closed immediately after a disaster production rate occurs. production rate occurs. Fig. 2 shows a ball-type SSCSV in both the open and closed position, and Fig. 3 illustrates a third type called a "flapper valve" in both positions. The operating principle is the same positions. The operating principle is the same for all three valves; that is, a pressure drop acting against a differential area causes a force greater than a preset spring force tending to keep the valve open, therefore the valve closes.
Fig. 4 shows the derivation of the force-balance equation. This is a general derivation and is assumed to apply to all types of safety valves although a ball type is shown in the schematic.
Fig. 5 shows the position of the pressure taps used to measure the effective or valve-closing pressure drop across the valve.
Oilwell Paraffin Prevention Chemicals (September 1975)
Authors: Fulford Richard S. 
Published: December 2007

Abstract
Factors that influence paraffin deposition were investigated in laboratory experiments. An apparatus was built that measures the pressure and flow rate changes caused by pressure and flow rate changes caused by paraffin deposition from crude oil in one-half inch paraffin deposition from crude oil in one-half inch diameter steel pipe. Experiments were done with and without commercial paraffin prevention chemicals to determine the effectiveness of the chemicals. Several additives altered the flow properties of the waxy crude oil and thus properties of the waxy crude oil and thus prevented paraffin deposition at cold temperatures. prevented paraffin deposition at cold temperatures. The chemicals investigated include polyethylene, ethylene co-polymers, xylene, naphthylene as well as various surfactants sold or paraffin prevention. prevention. Temperature is the most important factor in paraffin deposition, but since crude oils with high wax contents are viscoelastic the flow rate and pressure are also important. As the flow rate decreases high wax crude oils become more viscous.

Introduction
Paraffin deposition in oil fields is an expensive and time consuming problem. It has been estimated that paraffin control in the domestic production industry costs in excess of five million dollars annually. These are direct costs and do not include production losses, increased horsepower requirements, damage or increased wear to equipment and manpower attention. This estimate was made in 1969 and inflation since that time may easily have doubled this figure.
Paraffin deposits are normally attributed to cold temperatures, but evaporation of light ends and gases can also cause solids to deposit from the crude oil. Since high-wax crude oils are viscoelastic the flow rate and pressure are also important.

EXPERIMENTAL

Identification of Oilfield Paraffins
The paraffins were dissolved in heptane and separated into saturate, asphaltene ad aromatic fractures by a procedure reported by Graves and Tuggle.

Paraffin-Crude Oil Flow Experiments Paraffin-Crude Oil Flow Experiments Experimental Materials
Crude oil from two different Oklahoma fields were used.
An Environmental Research Program for Drilling in the Canadian Beaufort Sea
Authors: Hnatiuk John 
Published: December 2007

Abstract
A multi-million dollar environmental research program consisting of thirty-three wildlife, biological, oceanographic, meteorological, sea ice and oil clean-up studies related to the southern Beaufort Sea is described. The studies are designed to provide ecological baselines, a better understanding of the physical environment, knowledge related to the consequences of a possible oil spill and means of oil clean-up in ice-infested waters Seasonal offshore drilling in Canadian Beaufort Sea from a floating vessel has been approved in principle and is scheduled to be undertaken during the open water period of 1976. The results of the studies discussed will be used to set operating constraints to safeguard the environment and minimize any adverse impact.
A unique feature of the program is its joint government-industry nature. The studies were specified by the Canadian Federal Government but the majority of the direct funding is by the oil industry. Government agencies co-ordinate the program with considerable management and scientific input from oil industry personnel. The two-year program will be completed by the end of 1975. The hostile environment is briefly described and problems arising during one of the worst ice seasons on record are discussed. The scope of the studies research methods and progress to date in individual studies are outlined and, where possible, results are provided. An important phase of the program is public interface to inform northern natives, government, those with environmental concerns and others about the program and the study results.

Introduction
The search for hydrocarbons in Canada's North has been extended to the geologically attractive but environmentally hostile southern Beaufort Sea. During the period, 1963 to 1969, offshore permits to explore for oil and gas were issued for the majority of the continental shelf which extends some 75 to 100 miles from shore, to water depths of approximately 600 feet, shown on the location map, Figure 1.
Technical Data File and Machinery Index Aboard Offshore Drilling Rigs
Authors: Buttery L.M. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Offshore drilling rigs are large, complex and expensive. The amount of technical data (in the form of manuals and engineering drawings) required for rig operation is quite massive and compilation and maintenance of such data is quite difficult. This paper discusses and illustrates how the use of "keyword indexing," magnetic tape typewriters and microfilm were used to produce a technical data system that produce a technical data system that is compact and easy to use, maintain and extend to other rigs.

Introduction
Experience shows that libraries of printed manuals and drawings have a printed manuals and drawings have a short useful life aboard offshore drilling rigs and, further, that required information is oftentimes unavailable by the time a critical need for it arises.
When equipment breaks down, for example, repair instructions and spare parts lists become critically needed parts lists become critically needed information. At such a time, nevertheless, it is not uncommon to find that such information is not available aboard the rig. The result is needless delay in repair — or worse, faulty repairs — and, ultimately, additional operating/maintenance costs.
Even if the basic information source is located, documents within it are likely to be damaged from previous use or part of the material may be missing. Even if the document, itself, is located, the particular bit of data required at a given time may be difficult to find because of inadequate indexing. And even if the data required is found, the volumes containing it are usually bulky and difficult to handle at point of use. Ordinarily, no means is available for copying needed pages. As a consequence, pages are removed from loose-leaf binders for use at the job site. The likelihood of replacement for these pages is not very great. On the other hand, the probability that such pages will be probability that such pages will be damaged is fairly high. With each successive use of technical data, the chance of its availability, when next required, becomes significantly smaller.