bluuebunny/crossref_metadata_2025_split huggingface dataset:
CT Studies of Surfactant-Induced CO2 Mobility Control
Authors: Wellington S. L. , Vinegar H. J. 
Published: December 2007

ABSTRACT
Foam mobility control for was studied by Computerized Tomography (CT) in tertiary first-contact miscible corefloods. The CT images show that injection of 0.05 wt% Neodol 25–12 Ethoxy Glycerol Sulfonate (NEGS 25–12S) in brine prevents gravity and viscous instabilities, and enables CO2 to displace all the oil from cores in a piston-like manner.
Surfactant screening tests, designed to test the debilitating effect of temperature, salinity, and crude oils on foam performance, are described. NEGS is both temperature and salinity tolerant: it forms stable foams with CO2 in the presence of oil to at least 76 deg C with hard brines containing at least 18 wt% TDS.
CT studies revealed a combination of factors contributing to effective CO2 mobility control. These include both increases in apparent CO2 viscosity and capillary pressure changes which produce a high-saturation brine bank insitu. This brine bank separating the CO2 and oil banks further reduces CO2 mobility through relative permeability effects but does not impair oil recovery efficiency by brine-shielding mechanisms.
The Application of a 2-D Compositional, Radial Model To Predict Single-Well Performance in a Rich Gas Condensate Reservoir
Authors: Clark T. J. 
Published: December 2007

ABSTRACT
This paper illustrates the use of a two dimensional (2-D), compositional, radial model to simulate a producing well in the Nugget reservoir of the Anschutz Ranch East Unit. The single well model used an eleven layer vertically heterogeneous reservoir description (kv &gt; 0) with a nine component fluid characterization to predict producing well behavior and condensate saturation development both before and after the breakthrough of injection gas (used for reservoir pressure maintenance). The simulation effort showed that there would be no detrimental effect on condensate recovery or well performance caused by removing the Unit imposed 3,500 psi (24 132 kPa) bottom hole pressure drawdown limit. The simulation work also indicated that the extreme gas productivity increase experienced after breakthrough was the result of lower gas viscosity and higher gas relative permeability in the breakthrough layers, and that a single layer could be responsible for the majority of the gas productivity increase.
A PDC Solution to Drilling Sticky Formations With Noninhibited Water-Base Drilling Fluid: Experience in the Provincia Field in Colombia
Authors: Koskie E. T. , Appen H. E. 
Published: December 2007

ABSTRACT
This case history documents the successful drilling of sticky clays, clay-stones and shales with non-inhibited, water base drilling fluid using a Polycrystalline Diamond Compact (PDC) bit designed specifically for this application. In the Provincia field of Colombia, where sticky clays, claystones and shales present just this sort of problem, a fishtail-style PDC bit has been found to be the best solution to date to drill these formations. It's use has resulted in a reduction in drilling time per well in this field of about 30%, i.e. a savings of from five to seven days per well.
Damage Ratio from With Variable Drill-Stem Tests Back Pressure
Authors: Kazemi Hossein 
Published: December 2007

Abstract
The drill-stem test [DST] is a temporary completion designed to sample the reservoir fluid and to establish the possibility of commercial production. It also yields values for the permeability capacity of the formation, for wellbore damage and for static reservoir pressure. The conventional interpretation is based on the assumption that the production rate is constant during the flow period.
In fact, flow is not constant because the fluid column rising in the drill pipe exerts a time-variable back pressure on the face of the formation exposed in the wellbore. The effect of the resulting variable flow rate on damage ratio obtained from conventional DST analysis is studied in this paper. For the case of high fluid productivity, conventional analysis yields a higher formation capacity and a lower damage ratio than the true values. The error in the damage ratio is particularly large. The method of Odeh and Selig1 will improve the flow capacity calculation considerably. However, they do not calculate the formation damage. A method for calculating the damage ratio is suggested here.

INTRODUCTION
The drill-stem test [DST] is a production test carried out through a temporary completion; it is designed to sample the reservoir fluid and to determine the possibility of commercial production. The test is carried out by attaching a fluid sampler to the drill collar and lowering the sampler to the zone to be tested. One or more packers, which are part of the tool, are set to isolate the formation from the mud column in the wellbore; then the formation fluid is directed into the sampler and subsequently into the drill pipe. A clock-driven recording gauge records the pressure variations. After a short period of production, the valve between the drill string and the sampler is closed; the recording of the bottom-hole pressure continues and corresponds to a short buildup test. The plot of this pressure on a linear scale vs [T+ ?]/? on a logarithmic scale is a curve, an analysis of which yields values for formation capacity [kh], wellbore damage, and static reservoir pressure.2
U.S. Natural Gas Regulation and Markets: Changing the Rules To Fit the Game
Authors: Jimison J. W. 
Published: December 2007

ABSTRACT
Order 436 is the Federal Energy Regulatory Commission's bid to convert the natural gas pipeline industry, traditionally regulated as a natural monopoly, into a semi-competitive and more efficient transportation industry. This paper analyzes the market environment into which Order 436 was introduced, reviews the background and provisions of the landmark action, and assesses its effects, particularly on the pipeline industry. The paper concludes that the Order puts many pipelines into an untenable position given the current market context and has not fully anticipated further market changes.
The Role of Commercial and Strategic Inventories
Authors: Krapels E. N. 
Published: December 2007

ABSTRACT
Petroleum inventories have commercial and strategic implications. In the commercial sphere, the level of petroleum inventories is an indicator of the direction of oil prices in the short term, and a force directly influencing oil prices. As a direct force, the importance of inventories on oil prices has increased since 1978. This increase is due in the first place to the very large size of the storage sector of the oil industry. The system's capacity makes it possible for large volumes to go into and out of the storage system. The size of the flows has become larger since 1978 as a result of the increased uncertainty about the security of supply (1979-81), the decline in demand (1982-1985), and changes in the relations between exporting country governments and oil companies. In the strategic sphere, the increase in government-owned emergency stocks has changed the balance of power in future efforts by oil exporters to impose embargoes or sharp price increases.
Energy Policy and Tax Reform
Authors: Cummings J. R. 
Published: December 2007

ABSTRACT
This paper discusses the history of energy tax reform, as well as the outlook for future changes. Particular emphasis is placed on an explanation of the tax provisions granted to the industry over the years to search for and produce domestic oil and gas and the gradual reduction in those provisions. The paper goes on to discuss the future of energy tax reform, including the impact of a possible import fee.
The Politics of Energy Policy: The Corporate Perspective
Authors: Scott J. N. 
Published: December 2007

Abstract
The energy industry has long been the target for governmental taxation and control. Examples abound, dating back to the early days of this century when the oil and gas industry was developing and coming right down to the second session of this 99th congress. As early as 1906, the Hepburn Act provided for regulations of oil pipelines. A committee chaired by Senator LaFollette in the '20's investigated the petroleum industry with some legislators at that time attempting to set the stage for regulation. Questioning was fierce! During many of these early years the debate over depletion allowance was an annual occurrence. During the 1930's, under the National Industrial Recovery Act, controls were placed on the oil industry though not others. Then, in 1954, came the landmark Phillips case on which the Supreme Court ruled that natural gas prices could be controlled at the wellhead. After 32 years, we are still trying to correct that mistake.
The decade of the '70's was a particularly difficult period for the industry from a political standpoint. Twice, events outside the United States caused supply disruptions and fears that the country was running out of fuel supplies. For some, the oil and gas industry became the scapegoat. There were rumors that loaded tankers were waiting offshore and that gas wells were shut in to force prices higher. There were divestiture bills, windfall profits taxes, and other negative legislative actions. To some extent, the political mood was punitive.
When the hysteria subsided and common sense began to prevail, there seemed to be a basic realization that the oil industry didn't cause the problem (although some, even today, may find it difficult to admit), but that we must have a strong industry with adequate incentive to develop our country's energy resources. There seemed to be a near consensus that the United States should strive for energy independence. There was legislation to encourage leasing of promising offshore areas, to develop alternate energy sources, to encourage conservation, and, to some extent, develop new supplies of natural gas.
Case History Study of Fracture Height Containment in East Texas
Authors: Arp M. E. , Hilton R. E. 
Published: December 2007

ABSTRACT
A discussion of the problems associated with fracture height containment in several producing horizons in East Texas is presented along with a field-proven solution. Fracture height containment has plagued operators in East Texas for years. Fracturing of producing intervals, such as the Georgetown, Buda, Woodbine, Travis Peak and Pettit Lime, has in many cases resulted in unsatisfactory production. The poor production can in many cases be attributed to fracturing out of zone. A technique has been developed to minimize fracture height growth. This patented technique incorporates non-reactive diverting agents to bridge above and below the pay zone. This results in a planned screenout in the vertical directions thus forcing the fracturing fluid to propagate the fracture in the horizontal direction.
Several case histories are presented to show the effectiveness of the technique.
Financial Institution Borrowing Guidelines for Reserve Base Borrowing and Documentation
Authors: Richter T. H. 
Published: December 2007

ABSTRACT
The independent operator has relied on various sources of revenue for decades. The financial institution has been providing assistance for over 50 years. The secured oil and gas reserve loan may be the most common type of financing sought by the independent. Due to possible tax legislation, the investor marketplace is questionable, thus there is increased pressure on financial institutions borrowing to necessitate the fundings for drilling acquisitions and normal operating capital.
Traditional lending institutions now face problems involving energy and energy related loans. The review efforts by these institutions and regulatory agencies have increased loan process analysis to the point that all areas of the financial situation of the operator must be addressed. The rewards of this research can benefit the independent in several areas. Having gathered all data, evaluated it, prepared the presentation and submitting it in a knowledgeable fashion will enable the financial institution to properly and expeditiously reply to the independent operator's loan request.
In order for the independent to achieve this goal, he must be knowledgeable of the information required, the format in which the information should be presented, the relative values the institution places on each item of the package and what it tells the institution. With this information at hand, the independent operator can present a well researched loan proposal and achieve his objective – the loan!
Mechanical Performance of Fiberglass Laminates for Sucker Rod Applications
Authors: Gauchel J. V. 
Published: December 2007

ABSTRACT
This paper will present the results of a program designed to evaluate the tensile, shear, and tensile/tensile fatigue performance versus temperature of typical FRP pultruded laminates used in sucker rods. The predictability of performance and its sensitivity to process conditions will also be discussed.
Roller Rock Bit Hydraulic Program
Authors: Skalle P. 
Published: December 2007

ABSTRACT
In the past the hydraulic program of rock bits with exchangeable nozzles has been determined by optimizing bit hydraulics, i.e. jet impact force, bit hydraulic horsepower etc. Bit hydraulics, however, is alone insufficient as criteria. This paper applied instead rate of penetration as criteria which is a more general and fundamental approach to determine the hydraulic program. The only factors in the rate of penetration equation which are of importance are the hydraulic functions, i.e. functions of pump flow rate and bit nozzle size. It is shown that the only hydraulic functions which have an influence on rate of penetration are bit hydraulics, and the difference between dynamic mud pressure and pore pressure at the bottom of the well. To be able to estimate the hydraulic program, unknown constants must be determined. Therefore, previously known and new empirical constants of the hydraulic functions have been estimated. The optimal solution has been worked into a general computer program, and typical sample calculations show clearly that this new approach has a distinguished effect on existing hydraulic programs.
The Use of a Drilling Model in Simulation, Optimization, and Formation Description
Authors: Malguarnera S. C. 
Published: December 2007

ABSTRACT
A system of equations constituting a drilling model has been developed with the capability to handle all bit, mud and formation types. This model has been used in three application programs:
DRLSIM. A bit run time simulation DRLOPT. An optimization program which predicts termination mechanisms and cost per foot for a range of operating conditions. FORMDES. Foot-by-foot drilling data is used to produce drilling resistance, pore pressure and fracture gradient logs.
Identification, Evaluation, and Treatment of Formation Damage, Offshore Louisiana
Authors: Schaible D. F. , Akpan B. , Ayoub J. A. 
Published: December 2007

ABSTRACT
A field case is presented for an offshore Louisiana oil well on which severe formation damage was identified, evaluated, and successfully treated. The emphasis of the paper is directed towards the techniques employed to identify the presence of the formation damage, evaluate its possible sources, and formulate an acid system which would effectively treat the formation damage.
A comprehensive study of transient pressure test data, nodal1 analysis curves, and production logs was performed to identify the presence of formation damage. After the existence of the formation damage was confirmed, extensive sidewall core studies were undertaken in an attempt to isolate possible causes of the damage. The results of these studies provided information which was used to formulate an acid system which would effectively remove the formation damage from the affected well.
In conclusion, post treatment transient pressure test results and nodal analysis plots are presented to illustrate the success of the acid stimulation performed on the well.
Remedial Methods for Bacterial Formation Damage by Application of Oxidizers
Authors: Ghalambor A. , Hayatdavoudi A. , Beladi K. , Mathemeier P. F. 
Published: December 2007

ABSTRACT
One of the known causes of formation damage in producing wells is through the plugging of the formation by microorganisms. The result of the formation plugging will be a reduction in permeability. There is no effective means to date that can effectively deal with this type of formation damage, which can occur during drilling, completion, or secondary recovery operations. The biocide treatment used in waterflood operations is only effective in killing the microorganisms that are in the water prior to pumping it down the hole, but it will not be effective as far as the future growth of the microorganisms is concerned in the formation. A series of experiments were conducted using cores of Berea sandstone. The permeabilities of the cores were determined after preparation. The cores were then injected with micrococcus luteus bacteria at several different pressures. The permeabilities of the cores were determined again by the same technique under the same conditions. A 50% to 75% decrease in permeability was resulted from bacterial injection (depending on whether the core was cut horizontally or vertically along the formation bedding plane). The cores were examined with a scanning electron microscope (SEM). The SEM study showed that the pore sizes ranging from 0.4 to 10 microns were seriously plugged by the microorganisms. The damage was minimal for the pores larger than 50 microns. The cores were then injected with various volumes of a 2% concentration of oxidizers at several different pressures. The two oxidizers used were sodium hypochlorite and potassium hypochlorite. The results of flushing the cores with an oxidizer was partial restoration of the original permeability. Depending on the core sample, the permeability of the damaged cores was improved by 3% to 25% for the rate of treatment in the study. In the last phase of the study, corrosion tests were conducted. The results of the corrosion test showed that for the same time of exposure of corrosion coupons to the oxidizers, the amount of corrosion was found to be higher than the amount of corrosion for a drilling or some packer fluids. The exposure time of an oxidizer in a field application will be much less than the exposure time of drilling or packer fluids, and therefore, the corrosion for the oxidizer can be considered as insignificant.
Well Return Analysis Causes Re-Evaluation of HCl Theories
Authors: Gdanski R. D. , Peavy M. A. 
Published: December 2007

ABSTRACT
Twenty-five acid return samples taken extensively throughout the post-treatment flow from an offshore Louisiana well showed almost complete consumption of excess hydrochloric acid (HCl) by the HF acidizing chemical process. The high HCl consumption was not due to dissolution of carbonate minerals. This observation appears to run counter to the oil industry belief of several decades that HCl was not significantly consumed in the process of stimulation with HF acid apart from calcite dissolution. Acid returns analysis also revealed an efficient ion exchange acid spending process, almost complete reprecipitation of silicon with an associated dissolution of aluminum, and good surface tension reduction for most of the acid returns.
Formation Damage Tests of High-Density Brine Completion Fluids
Authors: Morgenthaler L. N. 
Published: December 2007

ABSTRACT
Laboratory core flow tests were conducted to assess the formation damage potential of brines with densities between 13.4 and 19.2 pounds per gallon (ppg). Unfavorable fluid/rock interactions are not evident. Recovery of oil permeability is slow but complete, in agreement with established displacement theories. Observed damage effects are the result of instability of the brine or incompatibility with water in the cores. The effectiveness of ZnBr2 in preventing impairment suggests acid soluble impairing materials.
Heavyweight Brines and Corrosion Inhibitors Commonly Used in Brines Affect Various Types of Packer Elements
Authors: Hudson T. E. 
Published: December 2007

ABSTRACT
The use of brines in oil and gas wells as a completion fluid, workover fluid and packer fluid is a common practice. Salts commonly used to make these brines are KCl, NaCl, CaCl2, CaBr2 and ZnBr2.
Under certain conditions these brines are corrosive, and corrosion inhibitors are usually added to reduce their corrosivity on the tubing, casing and downhole tools used in the well. Brines also come into contact with the elastomers (packer elements) used on the downhole tools. Failure of the packer element either by hardening or softening can significantly reduce the time interval between workover operations.
This study encompassed the testing of various types of commonly used packer elements at 250°F (121°C) and 350°F (177°C). These elastomers were tested for 7 and 70 days. The physical properties of packer elements observed throughout the test periods were hardness, tensile strength and elongation.
Brines selected for use in these tests were 14.5 lb/gal (1.74 g/cc) and 16.5 lb/gal (1.98 g/cc) which used CaCl2, CaBr2 and ZnBr2 as weighting agents. Corrosion inhibitors tested were (1) a film-forming amine and (2) a low-molecular-weight organic product which contained sulfur.
The types of rubber elements used in this study were 80-durometer chlorinated polyethylene (CPE), 70-durometer nitrile and 90-durometer nitrile elastomers.
Sand Control Techniques in Shengli Oilfield
Authors: Chen Detan , Zhou Boqi , Liu Zhengze 
Published: December 2007

ABSTRACT
Shengli Oilfield has been developed for more than twenty years. The problem of sand production has existed since its development. About one third of the total oil wells in Shengli have sand problems. This paper describes the techniques of sand control in Shengli Oilfield. Three sections are presented: —Chemical sand control;—*Sand control in steam soaking wells;—Mechanicals and control.
In the past twenty years, twenty-six fields have been put into production in Shengli. The amount of cumulative oil production has reached 240 million tons.
The geological structure of Shengli Oilfieldis very complicated, oil fields are located in many depression basins. The reservoir rocks are Tertiary sandstones of younger geological age, very unconsolidated and produced with different degrees of sand production troubles.
There are sand problems in 2/3 of the reservoir and 1/3 of the producing wells in Shengli Oil Field. Some of these wells have been plugged by sand to a height of 98 — 271 meters. Some of the flowing wells produce oil with a sand content as high as 40% from the start of the production. Due to the severe sand problems some wells cannot even be tested for reservoir parameters in some new exploration areas. For example, in Gudao Field the averaged cumulative sand production per well reached 25 cu. m. and the total cumulative amount of sand produced reached 20000 cu. m. during six years of production: i.e. 11 cu. m. sand per 10,000 t. of oil. Under such circumstances, the research work on sand control techniques and its generalized application have great significance in maintaining peak oil production in Shengli Oilfield.
Shengli Oilfield has a history of 20 years of sand control. Because of the very complicated geological conditions such as multiple faults, great differences in their vertical and horizontal distribution and the wide range of formation permeabilities and oil viscosities existing in various oil pools and very different bottom conditions occurring in the sand producing wells, various sand control techniques are needed for effective treatment. These techniques in Shengli Oilfield are characterized by simplicity, effectiveness and economy. Two types and 8 techniques are mainly used and 3,965 operations had been conducted by the end of 1984.
The sand control techniques of Shengli Oilfield are described in following three sections: —Chemical sand control;—Thermal well sand control;—Mechanical sand control.