bluuebunny/crossref_metadata_2025_split huggingface dataset:
Massive Hydraulic Fracturing of High-Temperature Wells with Stable Frac Foams
Authors: Wendorff C. L. , Ainley B. R. 
Published: December 2007

ABSTRACT
Recent studies under downhole conditions show the relationship between foam texture, i.e., bubble size and foam rheology. They also show that under the low shear conditions that exist in a fracture during treatment, foams behave as power law fluids. Dynamic fluid-loss testing indicates stabilized foams are some of the more efficient fracturing fluids available. Formation damage results help explain why foam-fractured wells clean up so well.
As a result of our better understanding of the properties of foam under downhole conditions, we have developed new, highly stable foam systems. These systems are 100 to 1000 times more stable than conventional foams and, therefore, greatly broaden the downhole conditions under which foams can be used.
Field results demonstrate the successful placement of large amounts of proppants with stable foams in both oil and gas wells at temperatures up to 300°F. In addition, foam-fractured wells clean up better and, therefore, pay out faster than wells fraced with conventional fluids.
Layer Definition and Pressure Buildup Case Histories in a Carbonate Reservoir
Authors: Vadgama Usman N. , Arifi Nagmeddin A. 
Published: December 2007

ABSTRACT
Pressure buildup analysis theory becomes complicated in a multi-layer reservoir where several layers are communicating through the well bore only. This paper presents case histories of pressure buildup analysis in a layered carbonate reservoir where an unusual amount of information on the characteristics of the layers is available. The productive formation consists of several dolomite and limestone layers separated by thin tight streaks. Lack of pressure communication between layers has been determined by pressure measurements in the individual layers using the Repeat Formation Tester (RFT). The field results give an example of the use of the Repeat Formation Tester to define reservoir layering in a carbonate reservoir. Results of the two-dimensional radial model simulated pressure buildup performance are compared to the actual measured pressure buildup data.
Pulse Testing in the Statfjord Field
Authors: Rathbone Monroe Jackson , Unneberg Arild , Cull Geoffrey W. L. 
Published: December 2007

ABSTRACT
Pulse testing in a major oil reservoir in the North Sea has proven useful in determining inter-layer communication for reservoir modeling and gas breakthrough prediction. In order to predict the results of the high pressure gas flood in the Statfjord Field, it was critical to determine if the shale layers formed continuous vertical-flow barriers. Therefore, two pulse tests were performed in the Statfjord reservoir in April 1980, These tests were designed to confirm interwell communication between the gas injector and the oil producers and to provide data for calculating reservoir gas injection capacity.
Design calculations using average reservoir parameters estimated the pulse response to be about 0.2 psi per 10,000 STB/d of pulse rate. This small pressure response was a significant feature of these tests; however, high resolution pressure gauges proved adequate for monitoring the pulse response. Interpretation was complicated not only by the small pressure responses but also by the cyclical pressure effects caused by lunar and solar gravitational forces on the fluids in the reservoir. This effect, noticed on all the data, was "filtered-out" by three methods of analysis.
The first test responded as predicted from the design calculations, and the results gave conclusive evidence of communication. It also verified that the estimated average reservoir parameters were reasonable. The second test possibly showed a small response, but the results were inconclusive.
This paper presents a case history using pulse testing as a reservoir evaluation tool. The methods of design, the analysis of the raw data, and the interpretation of the results are detailed.
Taking an Oil and Gas Company Public
Authors: Wesneski Lawrence Edward 
Published: December 2007

Abstract
The increasing capital requirements in the energy industry have led a number of private, independent oil and gas companies to turn to the public market as a source for funding future growth. The principal asset of many of these companies, and often the primary determinant of value in the public market, is the firm's oil and gas reserves. Estimates of hydrocarbon reserves are usually based on studies and reports prepared by independent petroleum engineers. Although they play a key role in taking a company public, petroleum engineers usually do not get exposed to the entire process. The purpose of this paper is to provide an overview of the process of taking a company public and to clarify the petroleum engineer's role in the process.
Exchange Offer for Drilling Fund Partnerships Source for New Exploration and Production Companies of the Future
Authors: Ouzts Johnie M. 
Published: December 2007

ABSTRACT
The exchange of stock for interests in limited partnerships is a promising new way to create an "instant" oil company. Several relatively small exchanges were successfully accomplished during the past two years; a company has now been created that has producing and exploration properties valued at well over $600 million.
Rigorous Computer Simulation of CO2 Dehydration Facilities
Authors: Best Jim W. 
Published: December 2007

ABSTRACT
The possible development of the Bravo Dome Carbon Dioxide (CO2) Gas Field located in northeastern New Mexico has led to a detailed study of CO2 dehydration design using computer simulation. Two commercially available computer programs from the ChemShare® Corporation were used to simulate actual CO2 dehydration test results. Amoco is currently in the process of using these programs to aid in preliminary design of a full-scale dehydration facility.
A Dual Porosity CNL Logging System
Authors: Davis R. R. , Hall J. E. , Boutemy Y. L. , Flaum C. 
Published: December 2007

ABSTRACT
The two-detector CNL neutron porosity logging system has been commercially available for about 10 years. It provides an accurate log when the amount of elements with high thermal neutron capture cross section (Σ) in the formation is small. Corrections are required to the measured porosity when this is not the case. In order to take advantage of the better measurement statistics obtainable with thermal neutron detectors and the insensitivity of epithermal neutron detectors to the presence of elements with large Σ, a new CNL logging tool incorporating two thermal and two epithermal neutron detectors has been designed.
Two separate porosity measurements are thus obtained—one from each pair of detectors. In "clean" formations the measured porosity values agree. However, in formations containing high Σ elements (such as shales), the porosity measured by the epithermal detectors will read lower and agree more closely with the density-derived porosity. The epithermal measurement thus provides better gas detection in shaly gas sands. A comparison of the two porosity measurements can provide an indication of the clay content of the formation.
A data processing technique, utilizing the individual detector counting rates rather than their ratios, is used to derive the porosity values. This technique provides considerable improvement with regard to correction for borehole effects. An adaptive filtering scheme has been used to minimize the statistical uncertainty of the porosity measurement. This filter allows quick response to borehole environment changes while reducing statistical variation in slowly varying zones.
Log examples are shown which illustrate the shale effects on both the thermal and epithermal porosity measurements. Also presented is an example showing the improvements due to the use of the new data processing technique. The advantage of the epithermal measurement for gas detection can be seen in a representative example.
Comparison of Methods for Measurement of Oil Saturation
Authors: Donaldson Erle C. , Staub Harrison L. 
Published: December 2007

ABSTRACT
The City of Long Beach, California, in cooperation with the Department of Energy, conducted a program to obtain oil saturation data in the HXa unconsolidated sand of the Wilmington Field, after initiation of a mi cellar-polymer project. A core analysis program was coupled with open-hole and cased-hole logging, and the single-well tracer test to obtain a comparative analysis of current commercial methods that are available for the determination of oil saturation.
Five wells were redrilled from the surface and five were milled out adjacent to the HXa sand giving a total of ten wells completed in the zone on which the comparative analysis was conducted. Cased-hole logs were also run as follows: dual-spacing thermal neutron decay time log, dual-detector neutron lifetime log, and carbon-oxygen log. The single-well tracer test was performed in one well using ethyl acetate.
The measurements of oil saturation show considerable disagreement between methods. Core analysis was impaired by loss of fluids and expansion. Comparison of the vertical profile of log analysis exhibits differences due to limitations of the individual methods; combined analysis of several logs is considered more reliable. The best average formation saturation was obtained from the single-well partition tracer test.
Results of Hydraulic Fracturing Treatment BHP Analysis in Peru
Authors: Erdle J. C. , Bennaceur K. , Bell J. , Bezier C. 
Published: December 2007

ABSTRACT
Eight fracture treatments conducted without packers were monitored in Peru. Horizontal and vertical fractures were detected. The fracture geometry model characterizing the bottomhole pressure behavior of the vertically fractured zones depended on depth. Khristianovic behavior (BHP decrease with time) was exhibited between 1500 and 2000 feet. Perkins and Kern behavior (BHP increases with time) occurred at depths greater than 2000 feet. The horizontal fractures were created at depths less than 1500 feet.
Measured tubing friction gradients for both crosslinked and non-crosslinked guar gum based frac fluids correlated well with published pipe loop data. Calculated gradients based on power law coefficients determined from Farm experiments were extremely high. The experiments indicated a critical need for an appropriate rheological model and laboratory test apparatus for gelled fluids.
Fracture parameters derived from Nolte's pressure decline analysis technique were reasonable, providing valuable insight to treatment diagnosis and design. The refinement of equations for perforation and fracture friction pressure drop (or fluid rheology) is needed to increase confidence in quantitative analysis results.
Steamflooding As an Alternative EOR Process for Light Oil Reservoirs
Authors: Hanzlik Edward J. 
Published: December 2007

ABSTRACT
Past laboratory work and published field test results have shown that oil distillation during steamflooding of light crude oils can be a very efficient recovery mechanism. Increases in oil price and revised tax laws have prompted a renewed interest in steamflooding light-oil reservoirs. This paper seeks to stimulate consideration of steamflooding as a viable alternative to chemical enhanced recovery techniques in shallow, light-oil reservoirs.
Use of Well Logs to Provide Formation Design Values for Hydraulic Fracture Treatments
Authors: Ameri S. , Rieke H. H. 
Published: December 2007

ABSTRACT
Considerable emphasis is being placed upon the use of hydraulic fracturing to stimulate hydrocarbon bearing formations, especially those with low permeability. Unfortunately, the optimization of these fracture stimulations in open and cased holes is impaired due to the lack of information on design parameter values.
This study presents wireline tool usage in providing proper design parameter values for hydraulic fracture treatments and in evaluating the success of such a treatment. Examples of logging suites are provided and methods are presented for converting log measurements into design values. Techniques are discussed and a matrix chart has been developed for relating tool capabilities with design requirements. Recent developments of new logging tools, advances in upgrading existing wireline tool capabilities and digital methods of interpretation have provided industry with a better means of obtaining these design values.
Basic input data required for hydraulic fracture treatment design include information on formation thickness, lithology of the host rocks and candidate treatment zone, permeability, pore volume, temperature, identification of existing fractures, fracture gradients, elastic moduli, perforation verification in cased holes, type and saturation of fluids in the pore space, influx of fluids, cement bonding in cased wells, casing integrity and fracture closure pressure. Assessment of the effectiveness of the fracturing operation can be obtained by determining fluid influx and fracture height,
Oil Production in Shallow Reservoirs By Carbon Dioxide Injection
Authors: Klins Mark A. , Farouq Ali S. M. 
Published: December 2007

ABSTRACT
Currently there is a great deal of interest in carbon dioxide for the recovery of both heavy and light oils. This paper deals with the efficiency of gaseous carbon dioxide as a recovery agent for moderately viscous oils. The paper gives model results, and compares and contrasts the findings with laboratory and field test observations, pointing out the range of conditions over which carbon dioxide is likely to be effective. Also, the current status of carbon dioxide for light oils is considered.
It was found that over the viscosity range of 1 to 1000 centipoises, carbon dioxide was superior to nitrogen injection, natural depletion, or waterflooding for oil viscosities above 70 cp. The gain over waterflooding was as much as 9 percentiles in oil recovery, being greater for the more viscous crudes. Oil saturation was an important variable as oil recovery decreased rapidly with a decrease in saturation. Another significant factor affecting ultimate oil recovery was the critical gas saturation. Viscous oils showed a 27% increase in recovery as the critical gas saturation varied from 0 to 10%. The blowdown recovery upon curtailment of carbon dioxide injection was about 1%; field values are as high as 4%. Reasons for this discrepancy are outlined. The amount of carbon dioxide left in the reservoir was used as a measure of the efficiency of the process; it was high for low oil saturations, especially for the more viscous oils.
An economic analysis of the carbon dioxide injection process showed that the economics are tenuous; a variety of factors in addition to the oil price would determine the economic viability of the process.
Exploration Drilling In Remote Areas
Authors: Whitley W R 
Published: December 2007

Abstract
In 1967, Woodside Petroleum Development Pty. Ltd., then Burmah Oil Company of Australia Ltd., drilled its first well on the North West Shelf, Ashmore Reef No. 1
Within the oil industry, Australia was considered logistically a remote area of the World, and the North West Shelf, one of the most remote areas of Australia.
A description of the problems overcome to achieve the commencement of oil exploration in North West Shelf waters, with a main operations base in Perth, 2000 Km distance from the well location and a forward supply base at Broome, 400 Km from Ashmore Reef, up to offshore drilling in the 1980's is presented in the following six topics: Construction of offshore refuelling installations for helicopters.Commissioning of temporary forward bases as drilling permit areas decreed.Setting up of communication network from Perth to Broome and drilling rigs.Logistic problems with air, land and sea distances from Perth to drilling areas.Drilling in waters under threat of tropical cyclone activity.Present day operations.
An update of current operations in North West waters will be given at conference time and will not be included in the published paper due to the time element involved.
Status of Oil Exploration in Australia
Authors: Fetters R T 
Published: December 2007

Abstract
Exploration activity in Australia has increased steadily since the mid-1970s following the downturn seen at the beginning of the decade. Almost four million square kilometres is now held under permit, and competition is strong for the available acreage.
Seismic activity has reflected this upturn in interest, with 63,000 kilometres of data acquired in 1980 and almost as much again in 1981. It is intended that the number of seismic crews operating in Australia, both on and offshore, will be substantially increased by the end of 1981, allowing further enlargement of the industry's seismic data acquisition capabilities.
Drilling has increased similarly since the mid-1970s following the unsuccessful activities of the previous few years. Approximately 140 wells are to be completed in 1981, and with the arrival of several new rigs in the country it is anticipated that the number of wells drilled in the coming years will steadily increase.
Up until the present, virtually all exploration wells have been drilled in areas of known hydrocarbon occurrence, such as the Cooper, Surat and Gippsland Basins. Few wells have been truly wildcat despite the fact that many of Australia's sedimentary basins have not yet been explored by modern methods. The scope for exploration in new areas is extremely wide, and the chances of an economically significant discovery must therefore be quite high.
Expenditure on exploration has increased at an even greater rate than activity, and this trend is expected to continue in the coming years. This overall increase in industry activity points to a very optimistic future for both oil exploration in Australia and for the country's self-sufficiency in energy.
Oil Muds in South East Asia
Authors: McNaughton Peter J. 
Published: December 2007

Abstract
Where severe drilling conditions exist, especially the combination of water-sensitive sloughing shales, abnormal formation pressures and high bottom-hole temperatures, several operators in South East Asia regularly use "invert emulsion" oil muds to drill and complete trouble-free gauge holes.
This paper will review oil mud operations in the South-East Asian region, and a case history will be presented to illustrate the succesful use of oil mud in the development of a major Indonesian gas field.
Some misconceptions still surround the use of oil muds. Modem oil muds are stable, practical and relatively simple drilling fluids which may be scientifically formulated to match the most severe drilling conditions. This paper will attempt to clarify some of the misunderstandings commonly associated with oil muds.
The range of application and advantages of an oil mud will be demonstrated, and the physical and chemical properties of a typical invert emulsion oil mud will be discussed.
Finally, the key to an efficient oil mud program lies in the planning stage. Using examples from one Indonesian operator's extensive experience, the various economic and logistic factors to be considered when using oil mud will be discussed.
Prospects and Constraints of Oil Exploration in Bangladesh
Authors: Lietz Juergen K. , Kabir Jahangir 
Published: December 2007

Abstract
Within the last three years large efforts have been undertaken to explore the oil potential in Bangladesh. Prospecting for oil in an already well known gas province appears to be a challenge which is presently met by intensive seismic surveys, stratigraphical and geochemkal investigations and exploration drilling.
Seismostratigraphic correlations nearly all-over Bangladesh appear to change some concepts held so far on the stratigraphic age of different sedimentary sequences. The results from seismic stratigraphy are partly in contradiction to the conventional stratigraphic framework and recent palynoiogical results. Nevertheless they are presented in this paper as a further approach to discuss still open questions on the hydrocarbon inventory of the Bengal Basin. The results of setsmo-stratigraphy shed a different light on different structural parts of Bangladesh regarding their oil potential.
Safety Principles for Design of Offshore Units
Authors: Roeren E. M. Q. 
Published: December 2007

Abstract
The concept of "defence tines" may be used to illustrate the safety barriers for mobile units.
Defence line 1 is characterized by the structural concept, the stress level, the number and properties of stress concentrations, the material properties, the fabrication standard, supervision during fabrication etc In other words, the inherent standard or quality of the as-built and delivered unit.
Defence line 2 is characterized by the quality of in-service inspection and control, as well as the general up-keep of the structure and its equipment.
Defence line 3 is characterized by the capability of the unit to withstand credible failures of vital stractural elements, whether due to internal causes (eg. fatigue cracks progressing too far) or external causes (eg. damage due to accidental loads).
Defence line 4 is characterized by the capability of the unit to provide survival possibilities to the personnel on board when a grave accident has taken place, this is primarily a matter of giving ample time for rescue of people.
The paper will discuss these defence lines with particular reference to semisubmersibles and, moreover, provide information on items of particular importance for such mobile units.
As it turns out, dramatic changes in current designs are not involved, but rather that of filling some important "holes" in the established practice of design and in-service routines and tasks.
Statistical data for the period 1970–80 will be given for all types of mobile units.
Advances In Tubing Connection Testing
Authors: Pyle C. L. 
Published: December 2007

Abstract
Producing hot, high rate, high pressure wells can subject tubing threads to compression and tensile forces that exceed the scope of current published data and specifications.
Mobil Oil Indonesia, contractor to Pertamina, Indonesia's National Oil Company initiated the development of test apparatus and test procedures to simulate actual downhole stresses on tubulars. Mobil's intention was to fill the gap in the published data and to determine the cause of thread leaks in Aran wells. It was postulated that the leaks were the result of extreme compression and tensile forces acting on the tubing threads. Weils completed in the Arun Limestone are capable of producing 250 MMSCFD at well-head pressures and temperatures of 4000 psi and 347° F. Forces on the tubing string varying from 350,000 lbs compression to nearly 500.000 lbs tension during pressure and temperature reversals between conditions of shut-in, producing and stimulating.
The test apparatus and procedure can detect thread leaks while subjecting test specimens to: 7500 psi internal pressureCompression and tensile loads up to 500,000 lbs.Temperatures up to 350° F.Quenching of internal pin surface such that the temperature is reduced from 350° F to 150° in
Application of the equipment and test procedures confirmed the failure mechanism and helped evaluate other thread designs for use in the harsh Aran wellhore environment.