bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Framework for Exploration and Production in Developing Countries
Authors: Ait-Laoussine Nordine , Miller Norman W. , Parra Francisco R. 
Published: December 2007

ABSTRACT
Developing countries outside the OPEC Area are faced today with an urgent need to develop their indigenous energy resources and, in particular, their hydrocarbons. These are of key importance to net oil importers and small net exporters alike if their economic development is to continue at a satisfactory pace. In the past, governments have concentrated on structuring their exploration and production agreements in such a way as to secure for themselves most of the economic rent or windfall profits that result from large oil discoveries, and this has meant that exploration for the smaller fields has been seriously inhibited. There is a need now to structure E+P agreements so that they combine the governments' goal of capturing the economic rent on large discoveries with encouragement to explore for and develop the smaller fields which, in many countries, would make a significant contribution to the energy economy. The present paper puts forward a new framework agreement to accomplish these twin goals in a practical manner. It recognizes and builds into the agreement the fundamental distinction between the exploratory and development phases, and ties the contractors' reward to the financial rather than the physical performance of the field.
The HEP (Hydraulic, Electronic, Pneumatic) Pumping Unit: Performance Characteristics, Potential Applications, and Field Trial Results
Authors: Jesperson Paul J. , Laidlaw Robert N. , Scott Richard J. 
Published: December 2007

ABSTRACT
The HEP pumping unit which is the result of a five year development program by Canadian Foremost Ltd., constitutes an alternative to the familiar beam pumping unit as a means of transferring energy from the prime mover to the sucker rod string of a pumping well. This paper addresses some basic concepts which are part of the HEP system design and will describe some of the resultant unit performance characteristics. The potential for enhancement of pumping well operations utilizing the high degree of control over rod string motion attainable with the HEP system, is discussed together with the results of a number of field trials in the Lloydminster area and some plans for further unit evaluation and development. A lift capacity comparison with conventional beam pumping units is also included.
Recovery of Retrograde Condensed Liquid by Gravity Drainage
Authors: Castelijns J. H. P. 
Published: December 2007

ABSTRACT
A compositional model has been developed for calculating the recovery of retrograde condensate by means of gravity drainage. The model is an extension of the one-dimensional gas-oil gravity drainage theory in that it includes the effects of retrograde condensation and revaporisation. The model has been applied for the condensate-rich gas cap of the Afam F5.00 reservoir in Nigeria. It has been found that a substantial amount of condensate will accumulate at the gas/oil contact: over 5% of the gas cap's hydrocarbon pore volume after 10 years of production, increasing to almost 10% after 20 years. At the end of the reservoir's productive life, the average condensate saturation left behind in the gas cap will be some 3%. Hence, any pressure maintenance requirements in the reservoir will be dictated by oil shrinkage considerations rather than by the need to reduce liquid losses in the gas cap.
Steam Flooding: Treatment And Control Of Injection Fluids
Authors: Woods G.A. 
Published: December 2007

Publication Rights Reserved
This paper is to be presented at the California Regional Meeting in Los Angeles, Calif., Nov. 5–6, 1964, and is considered the property of the Society of Petroleum Engineers. Permission to publish is hereby restricted to an abstract of not more than 300 words, with no illustrations, unless the paper is specifically released to the press by the Editor of the JOURNAL OF PETROLEUM TECHNOLOGY or SOCIETY OF PETROLEUM ENGINEERS JOURNAL is granted on request, providing proper credit is given that publication and the original presentation of the paper.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and considered for publication in one of the two SPE magazines with the paper.

Abstract
With the constant increase in demand for oil products and decrease in domestic reserves, the need to develop secondary methods of oil recovery in existing fields becomes increasingly important. Many depleted or partially depleted fields have been brought back into production by such methods as water flooding, steam or hot water flooding, and in-situ combustion or fire flooding. Though once considered relatively exotic and new in concept, these techniques have accounted for a great increase in oil recovery from fields once considered exhausted.
The average recovery expected with cold water flooding is considered to be about 20% of the oil in place after primary production, whereas a recovery of 60% or more can be expected from a well operated steam flood.
As with other oil production methods certain problems are involved. Of paramount importance is the proper treatment and control of injection fluids to minimize equipment and formation damage.
It is generally true that water in oil recovery areas is not of the best quality and thus when steam or hot water flooding is employed as a secondary method of oil recovery, treatment of the water can be of significant importance. Such treatment must be engineered for each flood so as to assure freedom from scale and corrosion problems in the steam or hot water generators and piping, as well as plugging in the flood. Boilers employed in this type of operation are frequently of high heat exchange design, requiring high quality feedwater.
Various approaches of Water treatment are discussed including external as well as internal conditioning.
An Interactive Production Forecasting And Economic Evaluation System
Authors: Hennigan H. W. , Canon M. W. , Ziara B. A. 
Published: December 2007

ABSTRACT
This paper describes an interactive, conversational model for production forecasting and economic evaluation. The system is designed to provide ‘Menu Selection’ at each branching point to allow the project analyst a choice of procedures for the program under study. The production forecasting capabilities range from the use of existing batch mode programs which employ reservoir engineering techniques applicable to various reservoir producing mechanisms to the use of decline curve procedures, curve fits of historical data plus extrapolation using an appropriate decline curve method or extrapolations of historical data based on the user's engineering judgment.
The system includes prompting, data preparation aids, and HELP commands for detailed explanations of data requirements and calculation procedures. Access to temporary and permanent data bases, or input of selected data and ability to examine intermediate results between discrete steps in the calculation sequence are provided. Optional depreciation and tax procedures include those needed for U.S., U.K., Norway, Indonesia, etc. Also available are escalation methods, sensitivity analysis, composite and difference cases, optional formats for result summaries and case detail, graphical video display and/or hard copy of selected output. Access to the data bases for storage of input data and results can be controlled with optional levels of security.
All procedures meet internal standards with respect to computational methods for reservoir engineering and accounting methods for tax and finanical basis economics evaluation. Results include all of the parameters normally used in economics analyses.
Selection of Artificial Lift Method
Authors: Neely Buford , Gipson Fred , Clegg Joe , Capps Bill , Wilson Phil 
Published: December 2007

ABSTRACT
This paper summarizes the opening remarks of the panel members on a panel discussion of "Selection of Artificial Lift Method". This is not a co-authored paper in the normal sense. It is a paper with five sections, each section independently authored by a panel ember.
Investment Selection Under Uncertainty For Producing Operations
Authors: Sellers David H.A. 
Published: December 2007

Publication Rights Reserved
This paper is to be presented at the Eastern Regional Meeting to be held in Pittsburgh, Pa., on Nov. 5–6, 1964, and is considered the property of the Society of Petroleum Engineers. Permission to publish is hereby restricted to an abstract of not more than 300 words, with no illustrations, unless the paper is specifically released to the press by the Editor of the JOURNAL OF PETROLEUM TECHNOLOGY or the Executive Secretary. Such abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in JOURNAL OF PETROLEUM TECHNOLOGY or SOCIETY OF PETROLEUM ENGINEERS JOURNAL is granted on request, providing proper credit is given that publication and the original presentation of the paper.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and considered for publication in one of the two SPE magazines with the paper.
One of the notable features of the modern oil industry is the constant pressure for increased efficiency to meet the challenge of growing costs and increased competition. With increasingly large capital outlays for producing operations, it has become critical that investment be made as effective as possible. For this reason, considerable attention has been given to techniques for insuring maximum benefits from dollar expenditures. It is to our industry's credit that many quantitative methods for dealing with the myriad of assumptions and variable factors of producing operations have received wide acceptance.
One of the most serious and challenging decisions facing a producing company executive is that of selecting from the investment opportunities available the combination which will provide the highest returns. Since budget funds are usually limited, this selection must be made on the basis of economic and operational merit. The degree of merit can be determined only from the information available to the executive and from his experience.
The treatment of risk in capital budgeting Is critical since its measurement is largely subjective in evaluation assumptions and managers' preference for it is variable. Procedures for considering risk range from the simple discounting of expected values of investment returns, to the more complex determination of the utility of the investment. The main disadvantages in existing procedures are the suppression of information and the computational complexity. In brief, uncertainty is a fact of life in producing. We must live with it, and make financial plans accordingly. In dealing with risk, it is the results that should be considered. We must rule out unnecessary risks, but still aim for the high returns.

THE INVESTMENT OPPORTUNITY
Let us restrict the investment opportunities facing a company to producing operations.
Gas Condensate Evaluation in Multi-Layered Systems by Production Logging Tools
Authors: Sarabian A. B. 
Published: December 2007

Abstract
Generally speaking, Gas Condensate Reservoirs may refer to those reservoirs that are producing fluid with the oil gravity of higher than 45°API and the gas-oil ratios of between 5,000 to 100,000 scf/bbl. These types of reservoirs are often found in the deep wells (below 10,000 ft), and the gas that condenses to liquid at the surface temperature and pressure is light color or colorless. Sometimes gas-condensate is called wet gas; the term "wet" does not necessarily mean that gas contains water, it refers to heavier hydrocarbons in the gas mixture.
Table 1. shows the comparison of gas-condesate compositions with the dry gas compositions; as it is seen in this table, the percentage of heptanesplus in gas-condensate fluid is greater than it is in dry gas fluid. This results in higher gas-oil ratio for dry gas fluid at the surface.
In order to understand the behavior of Gas-Condensate Reservoir, the PT phase diagram is presented in Figure 1.
Application of Log-Inject-Log in Granny's Creek Oil Field
Authors: Ahmad Mian Munir , Ovies Sharon Loraine 
Published: December 2007

ABSTRACT
The purpose of this study was to apply principles of the Log-Inject-Log technique through utilization of the Thermal Neutron Decay Time Log (TDT) to ascertain reservoir parameters necessary for an evaluation of a perspective secondary/tertiary flood. This technique provides insitu measurements for determination of residual oil saturation and estimates of bulk volume movable oil and gas saturation. To achieve this purpose log-inject-log was employed in conjunction with open hole log data in a heterogeneous, pressure depleted Big Injun sandstone reservoir. This study represents the first application of the log-inject-log method in the Appalachian Basin.
The log-inject-log process required multiple TDT logging runs following alternate injections of low and high salinity waters. Well site procedures for acquisition of the necessary raw data are presented with a description of the interpretation model. A computer analysis of the data used open hole log measurements as a data base for reservoir characteristics needed to obtain residual oil saturation from the log-inject-log data.
The Effect of Anisotropy and Vertical Fracture Penetration on Production Decline Curves for Low Permeability Gas Wells
Authors: Smith Richard K. , Sawyer Walter K. , Esposito Patrick R. 
Published: December 2007

ABSTRACT
In most reservoir engineering studies, the vertical fracture height and the formation height are assumed to be equal, which may or may not be true. This study investigates the effect of vertical fracture penetration and horizontal anisotropy in the development of production decline curves for a low permeability gas reservoir.
This study shows that the productivity for a given vertical fracture decreases as the fracture position departs from the center of the formation interval. Horizontal anisotropy significantly impacts production decline curves. Up to approximately 70 percent of cumulative recovery is affected significantly regardless of the fracture penetration ratio.
Physicochemical Mechanics of the Propagation of the Stabilized Oil Bank Formed During Dilute Surfactant Flooding
Authors: King Gregory R. , Ertekin Turgay , Stahl C. Drew , Jones J. H. , Nagarajan R. , Yarzumbeck A. J. 
Published: December 2007

ABSTRACT
Recent displacement tests have indicated that under certain conditions the stabilized oil bank formed during dilute surfactant flooding may be composed of as many as three distinct oil banks. These secondary oil banks are characterized by the arrival of high oil cuts, high sulfonate concentrations, and low interfacial tensions in the effluent stream. The mechanisms governing the formation of these three banks, although different for each bank, are related to the interactions between the oil, rock, surfactant solution, and mobility buffer.
To determine the mechanisms governing the formation of these banks, a series of core floods was designed to isolate and study each bank separately. The experimental results, including the production histories and effluent analysis of these tests are presented and discussed.
The results of these tests indicate that two of the banks are formed by the chromatographic separation of high and low equivalent weight sulfonates, while the third is formed by the desorption of sulfonate during the injection of low saline fluids (mobility buffers). Also discussed are the means to alter the production profiles of displacement tests by manipulation of these mechanisms.
Technical and Economic Potential of Enhanced Oil Recovery in Appalachia
Authors: Kuuskraa V. A. , Hammershaimb E. C. , Morra Frank , Wicks Donald 
Published: December 2007

ABSTRACT
This paper examines the future conventional and enhanced oil recovery potential of the Appalachian Basin. It concludes that the cost of finding and producing a new barrel of reserves through exploration is $36. Further, even at prices up to $60 per barrel, conventional oil reserve additions from the Appalachian Basin are only projected at 500 to 700 million barrels.
The other main prospect for increasing recovery is to apply enhanced recovery methods to the 16 billion barrels of oil remaining in-place after primary and secondary recovery. Appalachia's shallow reservoirs, with relatively low pressure, porosity, and permeability, tend to have relatively high residual oil saturation at conclusion of primary and secondary recovery operation. Many of the same reservoirs properties, however, present engineering and economic problems that have limited the region's enhanced oil recovery applications to date. By examining the potential of eight reservoirs from the four largest oil producing Appalachian states, the paper concludes that the three EOR methods most amenable are carbon dioxide, surfactant flooding, and steam drive.
Reservoir and Production Characteristics of Composite Coal/Sandstone Gas Reservoirs
Authors: Rieke H. H. , Galliers F. 
Published: December 2007

ABSTRACT
Exploration for deep Atoka gas reservoirs during the past 10 years in the Arkoma basin of Oklahoma has provided opportunities to obtain reservoir and production data from shallow. Pennsylvanian age, Hartshorne composite coal/sandstone gas reservoirs. The Hartshorne formation by itself is not normally considered to be a potential secondary target if gas shows are evident and the deeper zone is non-productive. Independent operators, however, have been completing shallow wells (&lt;2000 feet) in the Hartshorne formation for over sixty-five years.
Four hydraulically stimulated wells, each having eight years of Hartshorne production history, were chosen to be analyzed. All four of the gas wells are situated on the northern flank of the Kiowa syncline, Pittsburg County, Oklahoma and are located within three miles of each other. The range in depth for the producing Hartshorne intervals in these wells is from about 3000 feet to 4200 feet.
Geophysical well logs, seismic data, sample cutting and core descriptions, gas composition data, well test information and production decline curve analyses were used to characterize the reservoir geology and to estimate the reserves and recovery of these composite reservoirs.
Reserve estimates ranged from .04 BCF to 0.5 BCF per well. Well data suggests that in-fill drilling between these four wells has the potential of recovering more gas. Analysis of the reservoir geology indicates a deltaic-fluvial depositional environment that has several lateral discontinuities in the gaseous Hartshorne coalbed. The geologic data shows that the coalbed can split into as many as three identifiable seams in some parts of the syncline.
Application of Nitrogen Fracturing in the Ohio Shale
Authors: Abel James C. 
Published: December 2007

ABSTRACT
When pumped at sufficient rates and pressures, gaseous nitrogen alone has been successfully used as a fracturing fluid in the Ohio Shale Formation of the Devonian shale trend. Enhanced production results have proved that use of nitrogen, even without a propping agent, has outperformed other stimulation systems employed in this lithological area of Ohio and West Virginia. Job design and procedures for nitrogen fracturing are presented in this paper as are production results of five treatments performed in the Ohio Shale Formation.
Special Purpose Components of Drilling Fluids, the Relevance of Laboratory Tests to Their Actual Use
Authors: Ford D. H. 
Published: December 2007

Abstract
Certain laboratory test work on mud products can be accepted as being relevant to, and correlating with, the conditions met with in actual use. Firstly I want to look at three examples where this is true.
The first example concerns two methods now used for comparing the performance of lubricants in drilling fluids, the Falex test and the core test. The original method used by the industry involved testers producing a metal to metal scar with the dimensions of the scar being taken as a pointer to lubricant performance. In the field the downhole torque is generated by loading between two surfaces and, for the steel upon steel situation, i.e. rotating pipe in casing, the Falex tester gives very good simulation. Figures 1 and 2 show the Falex tester and its mode of operation. The pin is rotated at constant speed and the torque required to do this is measured as the jaw loading on the pin is altered. Figure 3 shows typical results of jaw load and torque when three different products are compared with each other and the base mud. Figure 4 gives the same results in graphical form. From this evidence a judgement as to the likely relative performance of these products in the field can be made with comparative confidence.
Nevertheless even here there can be a real danger of oversimplifying the procedures in order to find a single measurement for evaluation purposes. Time spent at each loading level is important and can significantly alter results, as different products have very different 'skin' durabilities under sustained load. Temperature is also very important and checks need to be made to confirm that alteration for these parameters does not materially alter the conclusions for the case in question. The load at break down is the one usually reported but the load at transition pressure is often more applicable as this is the point of incipient seizure as marked by the acceleration of torque increase. Figure 4 gives a good example of this.
Directional Surveying Using Inertial Techniques - Field Experience in the Northern North Sea
Authors: van Nispen Johan , Howe N A 
Published: December 2007

ABSTRACT
Two FINDS Tools, operated by Eastman Whipstock on behalf of Ferranti Eastman Survey have been on contract to Shell UK Exploration and Production and have completed 63 surveys in a two year period. They have maintained their accuracy specifications with a high reliability which combine to give measurable economic benefits.
Comparisons of results from conventional magnetic single shots, MWD surveys and gyroscopic multiple shot surveys demonstrate that large errors can go unrecognised. The 'Systematic Error Model' of Wolff and De Wardt for instruments of this type is shown to have substantial validity.
New Technology in Underwater Inspection
Authors: Gardner W. E. , Wheeler W. J. 
Published: December 2007

Abstract
The importance of a high standard of inspection and maintenance of offshore structures is evident from considerations of safety of personnel, prevention of loss of production due to shutdowns, or pollution of the sea due to oil discharges. These factors are highlighted by the occasional disaster, involving loss of life or the significant release of oil.
Governments and certifying authorities have the responsibility for issuing and enforcing guidelines and regulations for inspection, but these obviously have to be based upon what is technically possible and, in many cases, the technology just does not exist to ensure the desired inspection standard.
The commercial market for inspection in the North Sea alone is expected to grow to approaching £100 million by the mid-1980's, with a figure at least three times as high for the total world market.