bluuebunny/crossref_metadata_2025_split huggingface dataset:
Introductory Work in Scale Inhibitor Squeeze Performance: Core Tests and Field Results
Authors: King G. E. , Warden S. L. 
Published: December 2007

Abstract
The occurrence of calcium sulfate scale in wells has recently become a sporadic major problem in producing wells in some CO2 floods.1 The problem has also been observed in wells where a potential scaling factor exists and the produced water has more than a fraction of a percent of carbon dioxide gas. Where calcium ion and sulfate ion concentrations are sufficiently large, accelerated deposition of calcium sulfate has been seen in the CO2 floods. Deposition occurs most frequently on pumps and where outgassing of CO2 or turbulence is involved.2
This paper reports the results of a study to determine the cause of accelerated formation of calcium sulfate scale in CO2 environments and find scale inhibitors which can be used to prevent precipitation of calcium sulfate. An additional goal of the study was to gain a more complete understanding of factors affecting the inhibitor squeeze process, so that longer squeeze life could be obtained. The data reflects findings of research into factors affecting scale precipitation, scale inhibitor screening tests, and initial results on inhibitor placement and flowback in cores.
The Evaluation of Scale Inhibitors for High BaSO4 Scaling Potential Using a New Tube/Filter Blocking Apparatus
Authors: Schalge A. L. , Dormish F. L. 
Published: December 2007

ABSTRACT
A new and novel tube/filter blocking apparatus was used to evaluate scale inhibitors under dynamic flowing conditions. The apparatus gives reproducible results for high total dissolved solids (tds) brines which contain high barium and sulfate levels. This reproducibility is achieved by balancing the tds levels of the incompatible brines prior to mixing. Inhibitor efficiency as determined by the tube/filter blocking unit compliments those from the traditional static jar test for barium sulfate.
The ability of the inhibitors to prevent barium sulfate formation in the capillary tube and/or filter was measured at various formation water/seawater mixing ratios, inhibitor concentration levels, temperatures, pH values, and CO2 saturation levels.
The instrument is simple to use and requires a minimum amount of operator attention when in use.
Monitoring Sessile Bacteria Contamination and the Associated Corrosion in a West Texas Water Injection System
Authors: Kochelek J. T. , Stone P. J. 
Published: December 2007

ABSTRACT
This McElroy San Andres waterflood involves the commingle and injection of approximately 130,000 barrels per day of San Andres-Grayberg produced water and Hendrick Reef make-up water. After mixing, the water is skimmed and filtered before injection. Although the produced water contains relatively low levels of microbial contamination, the Hendrick Reef water is severely contaminated and causes contamination throughout the system downstream of the commingle tanks.
Monitoring of the planktonic microbial populations using culture media and ATP photometry had historically indicated levels of aerobes, anaerobes and SRB in the system as high a 1,000,000 bacteria per milliliter of water. However, this level of contamination did not seem to cause any operational problems. The filtration system operated smoothly and hydrogen sulfide was not a concern because of the high levels that naturally occur in the San Andres produced water in this area (700–1000 ppm). Any increase in hydrogen sulfide attributable to SRB activity would not be significant. Corrosion rates, as monitored by weight loss coupons and linear polarization probes, appeared acceptable and averaged somewhere less than 2.0 mils per year.
One problem that did exist within the injection system was an erratic and unexplained increase in total suspended solids in the water at the injection wells. The levels were occasionally considerably higher than in the water exiting the water plant. There were also injection difficulties in some of the wells. The solids that collected at the injection wells were most often identified as iron sulfide and paraffin with trace levels of calcium carbonate and calcium sulfate.
This paper will present information gathered regarding the use of probes designed to measure sessile microbial activity and the associated underdeposit corrosion. It will also address the analysis of wellhead deposits from the waterflood injection system and the effect of fluid velocities on deposition rates. A final discussion will involve some measures for possible control of the problem.
Phase Behavior and Solution Properties of Ethoxylated Anionic Surfactants
Authors: Skauge A. , Palmgren O. 
Published: December 2007

ABSTRACT
The surfactant class of ethoxylated anionics have been tested by measurements of solubility in brine and phase behavior in mixtures of NaCl brine and heptane at a WOR=2. The influence of changes in the lipophilic structure or degree of ethoxylation on the formation of multi-phase microemulsions is studied. In this paper we have studied alkyl- and alkylbenzene- ethoxy sulfonates with different chain length, branching and degree of ethoxylation. Nonylbenzene and dodecylbenzene surfactants are tested with both ethoxy sulfonate and ethoxy methylcarboxylate as the hydrophilic head group.
The solubility of the ethoxylated anionics in brine equivalent to seawater salinity, is characterized by the surfactant activity in solution at 22°C and for some surfactants also by the minimum cosolvent requirement. Phase behavior studies were conducted at 90°C. The optimal salinity and solubilization parameter at optimum was measured for all the 46 different surfactants at a given set of conditions.
The Role of the Engineer as a Citizen
Authors: Clewell D.H. 
Published: December 2007

American Institute of Mining, Metallurgical and Petroleum Engineers, Inc.
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Oct. 1–4, 1967. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract:
Opportunities for the engineer to exercise his responsibilities as a citizen are better than ever before. With the advent of the Industrial Revolution, the engineer became so influential that, rather than merely serving society, he found himself altering the course of society. He also found himself creating new problems in the course of solving existing ones. At the same time, the engineer has had to adapt to an enormous acceleration in the development and application of technology. For individuals and organizations this has meant that change has become a way of life. Today's engineer adapts to change and serves society better by solving problems through systems engineering. Systems may be industrial — transportation, for example, or geographic, such as a large urban complex. A new problem of the urban system is environmental pollution, and it is a problem susceptible of solution by a systems engineering approach. Pollution from the internal combustion engine, a significant part of the problem, may ultimately be eliminated through application of a systems approach involving both fuel and engine. A number of oil and automotive companies are involved in programs to accomplish this purpose. These programs are prime examples of opportunities for the engineer to practice good citizenship.
The Effectiveness of Acid Fractures and Their Production Behavior
Authors: Ben-Naceur K. , Economides Michael J. 
Published: December 2007

ABSTRACT
Acid fracturing has been a widely used stimulation technique for carbonate reservoirs. While the etching action of the acid would imply an open fracture (with infinite conductivity), the strength of the reservoir rock leads to a significant reduction of the apparent conductivity after closure. In addition, acid fractures are invariably shorter than propped fractures as a result of acid spending patterns and the creation of "wormholes". Consequently, acid fractures are not automatically indicated for all carbonate formations. Instead, a comparison of the production performance of both acid and propped fractures is always necessary.
This paper presents an outline of the propagation mechanism of acid fractures including reaction kinetics and fluid leakoff, and the resulting penetration. Upon closure, the impact of the effective stress upon fracture conductivity is shown using a compilation of published data. The time dependency of the effective stress around the fracture is quantified along with its influence on the production performance using a poroelastic model. Dimensionless cumulative production type curves are given for a range of fracture in-situ conductivities (for propped fractures), and the formation effective stress (for acidized fractures). A comparison of this performance leads to a correlation between propped fracture conductivity and formation effective stress to produce a desired cumulative production within the same time period.
For a given carbonate formation and a given effective stress, a comparison of expected performance leads to a relationship between fracture conductivity and the ratio of the lengths of a propped and an acid fracture. This allows the choice of the appropriate stimulation treatment. Additional effects, such as conductivity variation along the fracture resulting from nonhomogeneous etching profiles and wormhole development, are examined.
The Evaluation and Optimization of Hydraulic Fracturing Treatments for the Big Injun Formation in West Virginia
Authors: Aminian K. , Ameri S. , Bright D. , Yost A. B. 
Published: December 2007

ABSTRACT
Most gas wells which are completed in low permeability (tight) formations of the Appalachian Basin, such as Big Injun, require stimulation to achieve commercial production. The general responsiveness of these formations to a certain set of the stimulation treatments design parameters remains uncertain. Although the stimulation treatments have enhanced the production, the question that needs to be answered is whether the treatment designs are simply standard approaches based on past practices or they represent the optimum designs.
The stimulation and production data from a number of Big Injun wells in West Virginia have been collected and analyzed in order to develop the optimum design guidelines for successful applications. The production data were analyzed with the aid of production decline type curve to establish basic reservoir parameters. A commercial simulator and stimulation data were then utilized to match the production history in order to evaluate the formation characteristics. The results of history matching were then utilized to optimize the treatments on each well. Cost analyses were subsequently performed to select the most economic treatment. The results of this preliminary study indicated that the optimum treatment designs based on the reservoir parameters can further improve the economic production. The general guidelines have been established for more effective and economical fracturing treatment for the Big Injun Formation.
Gas Production Strategies for Devonian/Mississippian Clastics of the Appalachian Basin: A Case Study in the Plateau Region of Virginia
Authors: Kuuskraa V. A. , Kelafant J. R. 
Published: December 2007

ABSTRACT
The Devonian/Mississippian Age clastics continue to be a major source of natural gas production in the Appalachian Basin. However, the generally low productivity of these sands and shales calls for innovative development strategies, particularly during this period of low gas prices. This paper examines a series of such alternative development strategies, including drilling for deeper pay, using improved well logging to better identify productive net pay, and larger stimulation treatments.
The plateau region of Southwest Virginia was selected as a case study for three reasons. First, gas production in this area has increased four-fold over the past five years (4 Bcf in 1983 vs. 20 Bcf in 1987). Second, drilling activity was up 50% in 1986 counter to a sharp drop for the basin as a whole. Third, by multiply completing and properly stimulating wells in the full tight gas/Devonian shale sequence, this area offers the promise of attractive gas recoveries per well.
Average reservoir parameters were derived for the study area to enable simulations to be run. Past and current drilling, completion, and operating practices were then analyzed to determine average cumulative 20-year productions in the region. After representative reservoir properties and completion practices were established, the effects of larger stimulations and improved pay selection were simulated. The results indicate that current reserves per well can be almost doubled using improved pay selection, larger stimulations and multiple well completions.
Rheological Characterization of Borate Crosslinked Fracturing Fluids Employing a Simulated Field Procedure
Authors: Shah S. N. , Harris P. C. , Tan H. C. 
Published: December 2007

ABSTRACT
To design a successful hydraulic fracturing treatment employing borate crosslinked gels, accurate measurements of rheological properties of such fluids are required. Rheological characterization of borate crosslinked gels has been difficult with the rotational type viscometer. In this paper, we present the rheological properties of various borate crosslinked fluids employing a new procedure which simulates field pumping conditions, i.e. crosslinking the fluid on the fly, and fluid flow down tubing or casing and in the fracture.
The effects of fluid pH, gelling agent concentration, type of gelling agent, and temperature on the rheological properties of fluids have been measured. It was found that these parameters have significant effect on the final viscosity of gel in the fracture.
From the laboratory test data, correlations to estimate friction pressures in field size tubulars have been developed. It is also shown that in conjunction with field calibrations, these correlations can aid in accurate prediction of friction pressure of borate crosslinked fluids.
Factors Controlling Occurrence of Morrow and Cherokee Sands and Their Relation to Production in the Anadarko Basin
Authors: Forgotson James M. 
Published: December 2007

ABSTRACT
Stratigraphic and lithologic data from 1200 wells in the panhandle areas of Texas and Oklahoma and 600 wells in northwestern Oklahoma were recorded in a form suitable for computer processing. Maps were prepared for each of three subdivisions of the Morrow in the Panhandle area and for each of seven operational units selected to subdivided the lower Morrow in northwestern Oklahoma. These isopach and quantitative facies maps showing areal variation in thickness and rock types were used in combination with detailed stratigraphic relationships based on electric log correlations to interpret the depositional history and predict areas most favorable for development of porous sandstones.
In the panhandles of Texas and Oklahoma and in northwestern Oklahoma, the Morrow Formation is the basal transgressive predominantly clastic unit of the Pennsylvanian system, unconformably overlying the Mississippian. The upper boundary is delineated by the base of the "Thirteen-finger" limestone, an electric log marker, and the lower boundary by the Pennsylvanian-Mississippian contact. Lower Morrow and basal Cherokee sandstone accumulations correlate closely with the residual structure on the top of the Mississippian unconformity of topography or early Pennsylvanian structural movement on the deposition of these sandstones. Apparently significant structure existed before or developed during deposition of these units. Isopachous and structural data indicate continued activity of these structures throughout Morrow deposition.
Distribution of coarse terrigenous clastics within the predominantly fine terrigenous clastic Morrow Formation suggests one source of sand west of the Panhandle area and a second source on the northeast. The Wichita-Amarillo uplift south of the depositional basin began to supply coarse clastic material during deposition of the upper Morrow unit. In the Panhandle area, widespread sheet sandstone and sandstone beds at parallel trends of early Morrow shorelines are interpreted to be near shore marine sediments deposited as the early Morrow sea overlaps onto the shelf areas. The thin lenticular upper Morrow sandstone bodies are interpreted as having been deposited by a complex stream system flowing southeast toward the basin axis.
Valuation of Oil and Gas Reserves by the Comparative Method
Authors: Strevig William E. 
Published: December 2007

ABSTRACT
Valuations of oil and gas reserves are performed in different ways. The purpose, perspective and technique for the process is diverse. This paper will briefly review some concepts for oil and gas reserve valuations, including the advantages and disadvantages of two particular approaches to value, the income and comparative approach. Also included in this discussion are the market place for reserves, some "how to" ideas and conclusions for developing the best possible estimates of reserve values.
How Superconductor Applications will Affect Oil and Gas Demand - an Update
Authors: Starks L. A. 
Published: December 2007

ABSTRACT
Oil and gas companies should and do hedge their reliance on production of petroleum commodities. One hedge is an awareness of technologies that could affect the demand for energy. Thus, oil and gas companies should, at a minimum, monitor the developing applications in superconductivity. These applications have the potential to reduce oil demand an estimated 5% and gas demand an estimated 9% from the levels to which they would otherwise rise.
Fundamental Testing and Production Surveillance
Authors: Merryman C.J. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Oct. 1–4, 1967. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
With the changes of automation, increased job responsibilities, greater number of wells per man, and a steadily increasing number of wells under various stages of secondary recovery operations, proper production surveillance has become a major challenge. True, automatic equipment records well production accurately but well test equipment capacity and improvement appraisals still require trained personnel.
Engineering duties and, in many cases, reduced engineering manpower may leave an overall testing program foundering. Reservoir engineers continue to rely on reported field tests to guide future programs and expenditures. It is mandatory that tests not only reflect production but be accompanied with proper data to reflect true well capacity. To insure this level of operation the following program is suggested:
Continuous training and orientation. Complete test procedure. Adequate test facilities.
This program is explained with recommendations for necessary tools and practices.

Introduction
Well testing may be generally defined as a measurement of production during a given time interval, usually twenty-four hours. Tests are required for the many needs of production evaluation and for allowable proration by regulatory bodies. Actually, well tests are the pulse-beat of our industry, the indicator of change and the warning light defining future needs. Accurate tests represent equity at the unit bargaining table, permit efficient scheduling of work and are basic to sound budget estimates. Improved communications have made it possible to have current data available to everyone concerned and well test results play a greater part in decisions than ever before.
A New Concept of Continuous Flow Gas Lift By Multipoint Injection
Authors: Raggio Jerry 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Oct.1–4, 1967. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Continuous flow gas lift by single point injection is generally considered to be the most efficient method of lifting fluid from an oil well. However, for points of injection below 4000 feet, a homogeneous mixture of the gas and liquid from the point of injection to the surface is usually not realized in actual field operations. The liquid tends to separate from the gas causing turbulence and/or slippage which results in slug type lift.
This paper is a result of a detailed analysis of four (4) installations designed for continuous flow gas lift by multipoint injection plus three years of numerous field applications. In the absence of accurate flowing pressure surveys on three of the wells, it was necessary to use other means of determining points of injection. However, this was not difficult in most cases because several design changes were required on each well before continuous flow was achieved. Additionally, these were problem gas lift wells prior to the installation of the multipoint designs and the maximum points of injection were known.
The relative merits of multipoint versus single point injection for continuous flow gas lift can only be determined conclusively by extensive experimental work. Nevertheless, the results of the tests conducted thus far, though admittedly limited in scope, do indicate:A variance between flowing pressure gradient predictions based on published curves and actual gradients obtained by multipoint injection.That deeper points of injection and higher rates of production are possible by multipoint injection than was ever before attainable by continuous flow gas lift.