bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reservoir and Production Characteristics of the Clinton Sand, East Canton Oilfield
Authors: Watts Royal J. , Schrider Leo A. , Craig Jerry G. 
Published: December 2007

Abstract
Geophysical well logs, petrographic thin section core analyses, and production- and pressure-decline curve analyses were used to pressure-decline curve analyses were used to characterize the geology and to estimate the reserves, recovery, and well life of the East Canton oilfield, northeastern Ohio. Clean sand sections of the Clinton were found to contain an average of 95 percent quartz and less than 4 percent clay. These sections correlated with the 80-percent-sand line determined by gamma ray logs and with core permeabilities averaging more than 0.1 permeabilities averaging more than 0.1 millidarcy. Production was found to be more closely related to thickness of 80 percent sand than any other reservoir characteristic. Economic life and output of the wells studied are predicted to be approximately 10 years and about 30,000 to 40,000 barrels per well. A primary recovery factor of 9 to 12 percent is indicated. Primary reserves of the 60,000-acre field are a minimum of 51 million barrels. Approximately 500 additional wells will have to be drilled to complete development of the field. With such a low primary oil-recovery factor, much oil will remain for secondary recovery possibilities.

Introduction
The East Canton oilfield is one of the largest in the Appalachian Basin (Fig. 1) and contains important primary and secondary oil reserves. The reservoir has low porosity and permeability, and hydraulic fracturing is permeability, and hydraulic fracturing is needed to stimulate wells to economic production. More than 60,000 acres of proved production. More than 60,000 acres of proved production are available with more than 1,000 production are available with more than 1,000 wells, and there are infill locations for at least 500 more. Over 14 million barrels of oil have been extracted from the field, and current production is 10,000 to 11,000 barrels per day. The Bureau of Mines undertook these per day. The Bureau of Mines undertook these studies to obtain information for possible secondary recovery considerations in this field.
Reservoir and production characteristics of this field have never been clearly understood, however, and such information is essential to productivity predictions and maximum recovery. productivity predictions and maximum recovery. Geological and reservoir studies were made in an effort to obtain this information. Techniques and methods utilized included pressure buildup tests, PVT bottom-hole sample test, production decline and pressure decline production decline and pressure decline analyses, and correlation of geophysical well log data with oil production data from over 100 wells.
Performance Predictions on Low Permeability Gas Wells
Authors: Mullins J.R. 
Published: December 2007

Abstract
Frequently it becomes necessary for the reservoir engineer to predict the stabilized deliverability of a gas well with a minimum predict the stabilized deliverability of a gas well with a minimum of test and production data. Usually this must be done with limited test data obtained by venting the gas to the atmosphere. The pipeline may not be available, since the purpose of the test and the production forecast may be to justify the installation of the pipeline. Although venting does not degrade the quality of the test, it does frequently reduce the quantity of test data obtained. Since sizeable expenditures for pipeline installation and development drilling, or conversely, the abandonment of a structure, may be influenced by the well's predicted performance, it is essential the most accurate prediction possible be made with the data available. However, when conditions permit, the more desirable test, a prolonged drawdown into the pipeline followed by a pressure buildup test, should be conducted.
It will be shown that the typical short term one-point flow test taken on a well completed in a tight reservoir will indicate deliverabilities which are greatly exaggerated. Many wells in the Mid-Continent Area give indications of requiring several months to stabilize or reach simi-steady state flow conditions. A test of such duration is usually impractical. Frequently, time in addition to the cost preclude such a test. It, therefore, becomes necessary to obtain a reasonably accurate forecast in the absence of extensive field test data. It is the purpose of this paper to present a practical method of obtaining a reliable forecast.
Energy and the U. S. Economy
Authors: Cleary William B. 
Published: December 2007

We've heard a great deal lately about the energy gap and the forthcoming energy crisis. Such a crisis is simply inconceivable to most of us who have lived all our lives with abundant supplies of cheap energy, but time has a way of rendering many established concepts obsolete. Imagine what our reaction would have been had the President of the United States said in 1956, one year prior to Sputnik, "We are going to place a man on the moon in the next decade." We would hurriedly have checked the Vice President's health. Yet in 1960, only three years after Sputnik, our President made such a statement and although President made such a statement and although it was received skeptically at the time, it was in fact fulfilled within the decade.
How could we possibly have an energy crisis? A few days ago I saw regular gasoline being advertised at 24.9 cents at a local station and remembered that I had paid more for it twenty five years ago. If we're short of oil, why doesn't gasoline cost more?, -bottled drinking water in New York City is considerably more expensive. I read recently that the Potential Gas Committee says we have well over 11 hundred trillion cubic feet of potential gas reserves in this country, we only use 22 trillion a year,-so how could we possibly have a shortage of natural gas? If we are supposedly short of crude, why did the state of Texas reduce its daily allowable this fall apparently allowing its wells to produce only 64% of the time. These are all logical questions and they are asked frequently by consumers of natural gas and oil.
The sad fact is that we do have an energy gap and we are approaching an energy crisis of major proportions. It's perhaps the most serious crisis that this nation has yet faced. Can we solve it?, - I think we can and I plan to outline for you a few of the steps that this nation must take to protect and insure adequate energy for its future. One of the most difficult parts of this solution will not be concerned with the technical or political problems but rather with the communications problem, -the elimination of the credibility gap.
In order to come up with reasonable solutions, let's look first at the problem. It would appear that the energy gap we are facing in the United States is the direct result of having no national energy policy. The problem has been aggravated by sex and by affluence. The part that sex plays of course, has to do with the population growth. Fifty years ago there were 100 million people in this country. Now there are over 200 million. By 1980, and reproduction is expected to boost us to over 240 million. Where does affluence come in? In 1950, each of our inhabitants used an amount of energy equal to 39 barrels of oil per year.
Understanding Foamy Oil Mechanisms for Heavy Oil Reservoirs During Primary Production
Authors: Huerta M. , Otero C. , Rico A. , Jimenez I. , de Mirabal M. , Rojas G. 
Published: December 2007

Abstract
A set of experiments in porous media was performed to determine oil recovery factor during natural depletion for a heavy oil reservoir. Results on "critical or mobile" gas saturation, produced fluid characterization, residual oil saturation, production profile and effective viscosity versus pressure are presented.
In order to characterize the ability of the heavy oil to trap the released gas, conventional and non conventional PVT tests were carried out.
By comparing the experimental results during differential liberation tests, a gas trapping factor for the oil was obtained. It accounts for the amount of solution gas that has been thermodynamically released but does not form instantaneously a free gas cap.
The so called pseudo-bubble pressure was obtained. In this work the hypothesis involved in the "Low Viscosity Model" was also tested.

Introduction
During the last years it has been a very large discussion about different production mechanisms to explain the production behavior observed in some heavy crude oil reservoirs specially in the Orinoco Belt in Venezuela and Lloydminster in Canada.
It has been characterized by high production rates and/or high primary oil recovery, besides a good pressure maintenance.
In the past, we have evaluated other drive mechanisms such as compaction, water drive and thermal process.
A considerable amount of laboratory and field work has been done to evaluate compaction effects in the area of our interest.
The results obtained from that study showed no evidence of subsidence or compaction, therefore it is not likely to be a major production mechanism. On the other hand, no active aquifer has been found either.
According to field (well head samples) and laboratory evidence, the heavy and extra heavy Hamaca oil exhibits "foaminess" when produced under solution gas drive. P. 671
Technical Advances Applied to Downhole DST Equipment Efficiently Solve Difficult Testing Problems (Pumping Wells, HPHT Wells, etc...)
Authors: Bouroumeau P. , Parra L. , Petel P. 
Published: December 2007

Abstract
The paper presents two technical advances applied to downhole DST equipment: Surface Read Out (SRO) with Wireless Transmited Data (WTD) where pressure/temperature measurements are received in real-time, using electro-magnetic transmission through the formation.High temperature DST string and memory gauges.
A test program was carried out with WTD in the Middle-East, where it was important to get pressure data in real-time during the test. Due to the presence of an ESP to flow the well, the selected solution was a real-time pressure/temperature electro-magnetic transmission tool which gave very positive results for: monitoring the complete operation.obtaining accurate data in real-time.optimizing the test program and the duration of the test.
The second part of the paper describes technical advances applied to components of the DST string and to the memory gauges.
Liquid Loading along the Completed Section of Horizontal and Inclined Wells may govern Inflow Performance
Authors: Asheim Harald , Oudeman Piet 
Published: December 2007

Abstract
For single phase flow, it is commonly accepted that wall friction along the completed wellbore may reduce inflow performance. For two-phase flow, interface friction and resulting liquid loading are usually more important than wall friction and may govern inflow performance. The paper provides quantitative understanding of how liquid loading along the wellbore affects inflow performance. It shows that liquid loading can be reduced and inflow performance improved by proper completion design.

Introduction
Pressure drop due along the completed section of the wellbore may have significant impact on the overall inflow performance. Methods to predict and counteract detrimental effects of such pressure drop have been proposed by different authors. They all assume single phase flow.
In multi-phase flow, heavier and more viscous fluids tend to flow at lower velocity than lighter fluids. This causes interface friction and relative accumulation, loading, of the heavier fluid, which contributes to pressure drops along the completed wellbore. Where the flow velocity in the wellbore is low, as towards the well bottom, liquid loading may govern the pressure drop. It may therefore be suspected that the production of a second fluid will result in quite different inflow performance than predicted by single phase flow models. Laboratory experiments by Ihara and others did not identify principal differences. However, this may be due to their design of equipment and choice of experimental conditions.
The current paper considers analytic and numerical modelling of two-phase, steady-state inflow performance, accounting for pressure drop along the completed section of the wellbore. The problem can be quantified by combination of concepts already used for modelling of inflow to wellbores and tubular two-phase flow. However, liquid loading in the wellbore leads to unusual boundary conditions, that require special solution methods.
The solution method developed in the paper enables fast and mathematically accurate prediction of two phase inflow performance. This also shows that liquid loading along the completed section may govern inflow performance. However, proper well design reduces liquid loading and improves the effective inflow performance.

The Model
For notational convenience, a gas reservoir with associated liquid is considered below. However, the model may with minor modifications be applied to other immiscible fluids such as oil and water, or to fluid with solids.

Basic Assumptions and Relations
The inflow to the wellbore is assumed proportional to pressure drawdown. Thus, the gas inflow rate per unit length of completed wellbore is expressed as
(1)
The reservoir pressure, is assumed to be in static equilibrium.
P. 395
A method for using the naturally-occurring negative geoskin in the description of fluvial reservoirs
Authors: Corbett Patrick W.M. , Mesmari Abdallah , Stewart George 
Published: December 2007

Abstract
In well testing, an important corroboration of the interpretation can be made from integrated analysis of core and geological information. The kh product, skin, and flow regimes from the pressure data should all be consistent with the petrophysical data and the geological interpretation.
It has been observed that certain types of reservoirs show negative skin despite the absence of any natural or induced fractures. This skin has been interpreted as due to the presence of thin high (with respect to the matrix) permeability channels. These channels have the well testing signature normally associated with fractures and are termed "Pseudo-fracture channels" (PFC). The skin (negative) due to the limited extent of these features around the well bore, results from purely geological phenomena and is termed "geoskin". Modelling studies have mapped out the relationship between thickness, radius, number and location of PFCs, the permeability contrast with the matrix, and the quantity of negative geoskin. With some understanding of the external limits of the reservoir the lateral extent of these phenomena can be estimated.
We show the application of the model in a braided fluvial reservoir. The well test in two wells are solely the response to different architectural organisation of the same matrix and channel permeabilities. The model shows that the two wells lie at the extremes of a continuum in which the scale of channels is the only varying parameter. This knowledge is useful in the understanding of reservoir performance and allows the well test data to be used more effectively in the reservoir model.
This study also shows that the interpretation of the skin can be an important measure of the near well bore properties and should be expected in braided fluvial systems (i.e., high net: gross) where high permeability, small scale (relative to the tested volume) channels can be present. Other high net:gross reservoirs were there are high permeability contrasts may also show such phenomena.

Introduction
Braided fluvial reservoirs are important hydrocarbon reservoirs worldwide that are characteristically highly heterogeneous as a result of the sedimentary processes. In these systems, permeability is largely controlled by the primary textural parameters of the sediment. The variability in permeability is a function of sedimentary architecture and this determines the characteristics of the well performance as shown by, the well test response. P. 87
Plugging Potential Of Gravel Carrier Fluids, Contaminated By Satellite Particles Originating From Gravels
Authors: Reijnen P.H.F. , Trompert R.A. , Samuel A.J. 
Published: December 2007

Abstract
The fine materials present in the gravels used in gravel packing represent a largely unrecognised source of impairment. They form filter cakes on/in the perforation wall resulting in direct impairment and cause declining injectivity while placing gravel in perforations. This may cause poor perforation filling with gravel, which in turn leads to pack invasion on production and further impairment.
This study has revealed substantial levels of permeability impairment caused by injection of suspensions containing fine debris from originating gravels (clay, silt and satellite particles). This occurs for natural gravels that are well within the API specification limit of 1%w for silt and clay.
This work indicates that the API specification should be reduced to 0.005%w. In this case less than 10% of the fines, causing possible impairment in the completion phase, are originating from the gravel.
Washing of the gravels (if the gravel does not meet the proposed new specification) will reduce the fines content and is suggested for synthetic gravels; natural gravels require a more thorough washing step.

Introduction
Placement of gravel inside perforations relies on leak off of gravel carrier fluid into the formation. This process may however cause i) accumulation of fine solids present in the slurry at the perforation wall or within the formation, resulting in internal or external filter cake formation, and ii) reduced injectivity. The latter may cause incomplete filling of perforations with subsequent invasion of formation grains into the gravel or 'trapping' of fine solids by the gravel pack. In-house studies have proven that these two mechanisms and intermixed gravel with perforation debris are the major causes for internal gravel pack productivity impairment.
All gravels from natural sources and some synthetic materials are contaminated with fine materials viz. silt, clay and grain satellite particles. Even if good oil field practice is maintained (brine filtration, wellbore cleaning prior to gravel packing, minimal use of pipe dope etc.),the fines present in gravel slurries originating from the gravel itself,fines released by the crushing action of the pumps andfines released by the abrasive action of the flowing slurry remain sources of impairment.
Core flushing experiments have been carried out to evaluate the permeability impairment due to the fines present in several gravels. The results obtained are presented in this article.

EXPERIMENTAL PROCEDURES

Fluid preparation and analysis
Gravel slurries (479 g/l) were prepared using 0.45 m filtered 2% KCl brine for two minutes using a high speed (2000 rpm) propeller mixer. The gravel was removed by 80 mesh sieving, resulting in gravel carrier fluids contaminated with suspended fines from the gravel. These gravel carrier fluids were flushed at rates and volumes equivalent to oil field gravel packing practice in the core flushing tests.
P. 699
Meeting the Challenges of Deepwater Subsea Completion Design
Authors: Aldridge Don , Dodd Paul 
Published: December 2007

Abstract
Significant technological advances in methods and equipment have permitted increased drilling in deeper waters, often beyond continental shelves. Completion techniques have also advanced to allow efficient deepwater production. When designing a deepwater or subsea completion, traditional downhole challenges are complicated by subsea wellhead conditions that require advanced practices and equipment. This paper will acquaint the reader with characteristics unique to deepwater, subsea completions and present new completion accessories that maximize performance throughout the life of the well. Included will be a case study of a new use of electronics, dynamic seal assemblies and deepwater subsurface safety systems by an operator in deepwater Gulf of Mexico.

Introduction
When considering deepwater exploitation, not only are the issues of wellhead changed, but also downhole equipment must be modified due to surface and ocean floor conditions. In the design and installation phase of the completion and subsequent life of the well, the presence of certain design parameters and the ease of installation must be considered as well as how any future stimulation, intervention or workover will be accomplished and/or accommodated. This paper will put forth thought processes that must go into a subsea completion design and present a deepwater completion typical of those being used in the Gulf of Mexico.

Tubular design
Tubular design must address some unique aspects of a subsea completion. In addition to wellhead placement on the ocean floor, many wells are highly deviated to horizontal, with obvious impact on tubular and production string design.
Stimulation. The tubular design must address any future well intervention or stimulation modes. The stimulation mode differs in a subsea completion from that of a surface completion. Temperature versus depth, from the surface, increases in a linear fashion in most surface or shallow water completions (Fig 1).
The subsea completion temperature increase is not linear. As fluids are pumped from the surface, they are cooled by surrounding waters until the wellhead depth is reached, at which time the temperature versus depth begins to increase in a linear fashion (Fig 2).
P. 279
Hazardous Wastes In Petroleum Activities Issues on Spent Catalyst : A Case Study
Authors: Suwasono Djoko 
Published: December 2007

Abstract
On April 1994, The Government of Indonesia enacted the Government Regulation Number 19 concerning the Hazardous Waste Management which will be come into effect as from April 1, 1995. Despite all the efforts made, petroleum activities in their operations may use or explore hazardous materials which eventually will produce hazardous wastes. The material, among others are catalyst.
The Appendix of this Government Regulation had categorized the Spent Catalyst as hazardous waste, therefore the handling of this waste (material) should follow the process and procedures as indicated by the regulations.
The new oil refinery at Balongan, West Java, will utilize catalyst, thus produce spent catalyst in quite a big amount, amount, i.e. more than 30 tons per day.
The comparison of treating this bulk of wastes if categorized as hazardous waste ton non-hazardous are quite enormous, and the discussion in this paper will elaborate on the efforts made by Pertamina to appeal to the Government under the co-ordination of BAPEDAL (The Environmental Impact Management Agency), to exclude this specific Spent Catalyst from hazardous waste categories. This references are made to the definitions and criteria set up in this regulation as well as comparison studies with similar industries in other countries.
The exclusion of this Balongan refinery spent catalyst from the present status with categorized as hazardous waste to non-hazardous will eventually meet the requirements of sustainable development operation achievable in most efficient way.

Introduction

The Treatment of Spent Catalyst at PERTAMINA
In processing crude oil into fuel oil such as premium, diesel oil, LPG, etc. the following processes are employed : distillation, vacuum, cracking and reforming.
The cracking process is the breaking of long CH chain into a short chain generally employing a catalyst to accelerate the said chemical reaction. In addition, the catalyst is also employed at the Hydrogen Plant unit; to help accelerate the reaction between steam and gases from the unit passing through the tube reformer, catalyst of the zinc type is also utilized
In the cracking reaction, the catalyst employed is in the form of sand which mainly contains aluminum and magnesium silica; this catalyst is getting more and more saturated, so it needs to be degenerated or replaced with the new one when it does not function any more.
P. 391