bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Reservoir Model For Hillsboro Gas Storage Field Management
Authors: Udegbunam Emmanuel O. , Kemppainen Curt , Morgan Jim 
Published: December 2007

Abstract
A three-dimensional (3-D) reservoir model, developed from stratigraphic and petrophysical data, was used to understand the past behavior of the Hillsboro Gas Storage Field and to investigate the field’s performance under various future development. Twenty-two years of the gas storage reservoir history, comprising the initial gas bubble development and seasonal gas injection and production cycles, were examined with a full-field, gas-water, reservoir simulation model. Key issues in storage developments examined after successful history matches of the past gas storage performance included (1) the maximum possible total gas-in-place volume without gas loss and (2) the optimum base load volume that permits the achievement of the peak-day rate requirements.
The results from various simulated development strategies suggest that the gas-water front is already in the vicinity of the west observation well and that increasing the field’s total gas-in-place volume would cause gas to migrate beyond the east, north and west observation wells. They also suggest that storage enlargement through gas injection into the lower layers may not prevent gas migration. Concerning gas deliverability, simulated results suggest that a peak day rate of about 150 Mmscf/D can be achieved with up to 80% of the working gas produced before the peak day and that the peak day rate would fall below 125 Mmscf/D when 85% or more of the working gas is produced before the peak day. Furthermore, the results suggest that. the addition of strategically-located new wells would boost the simulated gas deliverabilities.
Gas-Condensate Production and Allocation Prediction Program
Authors: Gates Charles W. , Hughes Don L. 
Published: December 2007

Abstract
A procedure has been adapted and a computer program prepared to predict the depletion of a predict the depletion of a gas-condensate field, or a system of several fields, and allocate the desired total production between fields and reservoirs. Well capacities at declining reservoir pressures are used to calculate a pressures are used to calculate a reservoir's and a field's capability at any given time. Gas rates are determined quarterly on a wet, separator, and plant sales volume basis. Condensate and NGL production are also calculated. A dummy field option allows the prediction of the Additional reserves needed to sustain a selected sales rate, together with the timing at which they must be added. Additions, deletions, and recompletions of wells may be performed, and additions or deletions performed, and additions or deletions of reservoirs can be handled.
The program provides a tool to (1) determine the future performance of a property for operational purposes, (2) aid in evaluating purposes, (2) aid in evaluating alternate gas producing proposals, and (3) provide faster and more accurate data for economic evaluations.
The basic unit of prediction is the reservoir, with reservoir groupings forming a field, and field groupings forming a complete system. Both full pressure depletion and partial pressure depletion reservoirs can be pressure depletion reservoirs can be handled. The input consists of well deliverability data, reservoir and reserve information, and a forecast of contract demand.
Improvement in the Characterization of the Acid Wormholing by "In Situ" X-Ray CT Visualizations
Authors: Bazin B. , Bieber M.T. , Roque C. , Bouteca M. 
Published: December 2007

Introduction
Acidizing of carbonate reservoirs is a widely used process to improve reservoir production. Acid dissolves portions of the rock, making channels; the result is an increase in permeability. Two different stimulation processes deal with acids: matrix acidizing and fracture acidizing While in matrix acidizing deep, highly ramified channels are desirable around the wellbore in fracture acidizing, compact patterns are preferable since they limit fluid loss through the fracture walls and thus increase acid efficiency. A large number of studies deals with acidizing patterns. Core observations after lab experiments consist in most cases in replica of the acid etched channels by filling the channels with resins or melting-point alloys and dissolving the surrounding rock material. Compact patterns, wormholes of limited size, highly branched wormholes, i.e. trees like patterns have been observed with this technique. Also, very pitted core faces have been mentioned. On another hand, modeling studies try to reproduce the pattern observed. Network models show tree like pattern. Capillary models put forward the dissolution mechanisms and the determinant effect of the acid filtration from the wormhole wall on the acid propagation. However, the way of formation of these facies and the different parameters influences on the pattern size are not clearly established.
Mechanisms involved in carbonate dissolution by acids depend on the nature of the chemical reaction and on the flowrate. For limestone, the dissolution is mass-transfer limited. For this material, the acid flowrate has a determinant effect on the acid propagation rate defined as the ratio of the core length to the acid breakthrough time. At low flow rate the dissolution is compact and no wormhole forms; at high flowrate, the dissolution is mass-transfer limited: it is the wormholing regime;
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Underbalance or Extreme Overbalance
Authors: Behrmann L. A. , McDonald B. 
Published: December 2007

Abstract
Application of an extreme overbalance, sufficient to fracture the reservoir formation, applied either during or after perforating was first presented as an alternate completion technique during the 1993 Fall SPE Conference1. During the ensuing two years, a number of jobs have been run by different operators in a variety of formations with varying applications. The primary question asked by an operator relates to the benefit of Extreme Overbalance (EOB) versus current perforation techniques of underbalance (UB) or modest overbalance for well control. Of course this question spawns a whole set of new questions about when and how to use and the benefits and risks of the EOB. EOB, as used in this paper, includes Extreme Overbalance Perforting (EOP) and Rapid Overpressured Perforation Extension (ROPE).
This paper compares and contrasts UB and EOB strengths and weaknesses and provides recommendations of when and why to use the different techniques. Field examples are provided of successful and unsuccessful application of EOB completions.
Formation Damage Removal Through the Application of Enzyme Breaker Technology
Authors: Moore W. R. , Beall B. B. , Ali Syed A. 
Published: December 2007

Abstract
This paper describes laboratory experiments demonstrating that the use of polymer linkage specific enzymes is effective in breaking the starch polymer constituent of sized salt fluid loss control materials (FLCMs). It is further demonstrated that the linkage specific enzymes are efficient in reducing the near-wellbore damage induced by the starch polymer that makes up roughly 75% of the FLCMs polymer content. As a result of the laboratory work presented here, it is shown that return permeabilities arc in the 8098% range without the use of acid systems.
Selection of Screen Slot Width to Prevent Plugging and Sand Production
Authors: Markestad P. , Christie O. , Espedal Aa. , Rørvik O. 
Published: December 2007

Abstract
A numerical model has been developed that addresses both plugging of, and sand production through single wrapped screens. The model was developed on the basis of a fractal model for the particle size distribution of reservoir sands. A database of sand types from the North Sea and Haltenbanken areas was established. Principal component analysis was used to reduce the number of significant variables in the database, and to provide a basis for a prediction model for critical slot widths. A series of laboratory experiments were performed, and four critical slot widths were identified for each sand type, defining a safe design interval for screen slot width. A mathematical model was developed that can be used to predict the critical slot widths for other sand types from the area.
Gravel Pack Procedures for Productivity and Longevity
Authors: Barrilleaux M. F. , Ratterman E. E. , Penberthy W. L. 
Published: December 2007

Abstract
The primary objectives of a gravel pack are preventing formation sand production, achieving high productivity, and providing completion longevity. For cased hole completions, inadequately filling the perforation tunnels with gravel is probably the main cause of formation damage which ultimately translates into a well that is completion limited since it produces below the capacity of the reservoir. Hence, performing prepacking operations that fill the perforations with undamaged gravel will usually enhance productivity. Aside from prepacking, effectively packing the casing-tubing annulus produces a stable, void-free gravel pack that will not settle or deteriorate with time.
Gravel pack procedures were developed in the mid-1970's and subsequently optimized to address the above concerns. They consisted of preacidizing (if required) the formation followed by a prepack performed with lightly-gelled water pumped at matrix rates that filled the casing with gravel to the top of the perforations. After washing the prepack gravel from the casing, the gravel pack assembly was run and an annular gravel pack was performed using water as the transport fluid. This procedure provided two opportunities for gravel to prepack the perforations. Acidizing was subsequently performed to achieve the desired productivity. Well test data show that over 70% of the wells tested had skin factors that were less than 10 and many were in the zero range. Gravel pack failures were rare and over 95% of these completions produced to depletion without requiring a workover.
More recently, enhanced prepacking has been performed by pumping at high rates and using water as the transport fluid. These treatments were designed to fracture the formation a distance of 5-10 ft from the well to bypass formation damage. The high rate prepacks have been performed with either the screen in place (single step) or prior to running the screen (two-step) in the well. In either case, the annular pack continued to be performed with water. The high rate completions have been performed at little or no incremental cost compared to those conducted at matrix rates since they were performed with platform-based, moderate horsepower equipment. The performance of these completions has been excellent. The need for postcompletion acidizing and associated flowback concerns has been virtually eliminated. Wells clean up more rapidly, consistently have higher productivities, and appear to have improved completion success as compared to those performed at matrix rates.
Evaluating Completion Damage in High Rate, Gravel Packed Wells
Authors: Burton R. C. , MacKinlay W. M. , Hodge R. M. , Landrum W. R. 
Published: December 2007

Abstract
Conoco has completed and tested a series of high rate, gravel-packed oil wells. Analysis of the well test data for the first completion indicated significant formation/completion damage had been caused during the gravel-packing process. Extensive laboratory testing designed to closely simulate the completion procedure was performed in conjunction with detailed completion pressure loss evaluation. The studies identified the LCM pill used during completion operations as the primary source of damage. A new. self-breaking, LCM composition was designed that provided fluid-loss control with minimum formation/completion damage. This LCM system and a number of other design improvements were then used in the field's remaining gravel-packed completions.
This paper describes the analysis of well test data and the application of this information to evaluate completion procedures for these high rate, cased-hole, gravel-packed completions. The analysis technique used is unique in that it uses a combination of laboratory, analytical, and operational data to quantify individual components of the total measured pressure drop across the completion. This approach provides a significantly better insight into completion performance than merely stating an overall completion pressure drop, skin value, or well flow efficiency.
This systematic analysis of pressure losses resulted in a better understanding of "formation damage" effects and the factors that influenced them during the completion process. This in turn allowed completion procedures to be modified to target specific areas for improvement.
Diversification In The Petroleum Industry: Pros And Cons
Authors: Kennedy Edwin L. 
Published: December 2007

1962 AIME Annual Meeting, Los Angeles, CA, October 7–10, 1962

Abstract
In recent years much has been written in the trade journals of oil about the upheaval that has beset this industry, its causes and its correction. And it is likely that considerable more has been written by stockholders in oil to corporate managements that has not been published, as these stockholders witnessed a progressive decline in the relative ranking of the industry's securities by investors during the past five years. Words dear and intriguing to the market letter writers, such as glamour, growth, compound rate of gain, new products, obsolescence arising from research, etc., have largely escaped application to the securities of this basic industry. Even the phrase "relatively attractive" has appeared infrequently and then usually only after a significant decline in prices of the industry's equities.

Producing Companies Disappear
We shall not pause to examine the causes of oil's decline from its previous place of esteem nor to prescribe remedial measures nor even to guess as to the future.
Use of a Viscoelastic Carrier Fluid in Frac-Pack Applications
Authors: Brown J. Ernest , King Lee R. , Nelson Erik B. , Ali Syed A. 
Published: December 2007

Abstract
The fluids commonly used in frac-pack treatments were initially designed for either fractruing low permeability formations or for conventional gravel pack operations. These fluids do not address the unique problems found when fracturing higher permeability formations. Conventional frac-pack fluids (borate crosslinked guars and HEC) undergo whole polymer leakoff, and create a deep invasion bank of concentrated polymer that is very difficult to break and can lead to high formation damage.
Viscoelastic surfactant (VES) fracturing fluids have been developed which exhibit excellent rheological properties and still maintain low formation damage characteristics even in high permeability formations. These fluids are completely polymer free and do not rely on internal chemical breakers to degrade the fluid viscosity.
This paper will detail the results of recent laboratory studies on viscoelasitic surfactant fracturing fluids, and will compare the rheological and formation damage properties to other conventional fracturing fluids. The laboratory findings will be substantiated by several field case studies.
The Correct Selection and Application Methods for Adsorption and Precipitation Scale Inhibitors for Squeeze Treatments in North Sea Oilfields
Authors: Jordan M. M. , Sorbie K. S. , Graham G. M. , Taylor K. , Hourston K. E. , Hennessey S. 
Published: December 2007

AbstractOver the past three years, the Oilfield Scale Research Group at Heriot-Watt has conducted a number field studies to evaluated scale inhibitors for both downhole squeeze application and topside continuous injection for a number of North Sea operating companies. This paper presents an approach for screening commercial sulphate and carbonate scale inhibitors for field application. The screening results, which include data from static/dynamic inhibitor efficiency, static adsorption, compatibility and thermal stability are used to rank the performance of commercial scale inhibitors. From this short list, a small number (1 to 3) candidate products are taken on to reservoir condition coreflooding. In the screening of topside scale inhibitors, no adsorption tests are conducted.Results from adsorption and precipitation type corefloods will be compared for polymer and phosphonate chemistries selected using these screening procedures. Such corefloods serve both to evaluate the squeeze lifetime performance and to assess the levels of formation damage caused by the scale inhibitor package. The strategy of deriving a dynamic isotherm which can be utilised in computer modelling of the coreflood data to produce a "Field Squeeze Strategy" will be outlined. This systematic approach provides a set of effective and economical methods for the chemical screening of scale inhibitors. This results in an improved field application strategy with longer squeeze lifetimes, while minimising formation damage potential.
Energy Supplies in the 1970's: Abundance vs Scarcity -- The Issue of Prices
Authors: Steele Henry 
Published: December 2007

Introduction
In the past, the energy consumer in the United States in peacetime has faced no genuinely inconveniencing shortages of energy supplies. On the contrary, fuels have generally been abundant. But recently there has been much concern expressed in regard to prospective shortages of major energy sources. Fears were earlier voiced concerning an impending shortage of natural gas, and there are many who foresee declining supplies in the future, which will leave an increasing deficit for gas needs in view of the rapidly rising trends being projected for demand. And although some excess projected for demand. And although some excess producing capacity exists currently for crude producing capacity exists currently for crude oil, the level is apparently declining and in any event when realistically estimated compares unfavorably with volumes of imported oil. Furthermore, proved reserves of oil have been declining for several years, and trends in new discoveries per unit of exploratory effort have remained at disappointingly low levels for over a decade. More recently, concern has been registered in regard to coal supply, as some buyers have experienced difficulties in meeting their requirements.
Until recently, concern over impending energy shortages was limited largely to those who were immediately affected by them. But the number so affected was increased sharply by the severing of the Aramco Tapline in May 1970, and the sudden major restriction of crude oil output ordered by Libya the following month. These two actions, which reduced oil availability by over a million barrels per day, brought to the attention of many energy consumers the degree of precariousness in the energy supply equilibrium currently established.

IMPLICATIONS ON ENERGY SUPPLY
These actions however, are only the most highly visible factors in a pattern of developing supply shortages, and serve primarily to throw into sharper focus the somewhat longer run implications for energy supplies of a combination of economic forces and administrative actions which have created latent scarcities of several important fuels.
Model Wellbore Evaluation of Diverter Effectiveness Confirmed by Field Results
Authors: Morgenthaler L. N. , Burnett D. B. , Kiel V. D. 
Published: December 2007

Abstract
Effective diversion is critical to successful stimulation of long-interval, high-rate wells. Once near-wellbore damage has been removed in one portion of the completion interval, steps must be taken to divert stimulation fluids to intervals that remain damaged. Viscous fluid diverters, such as gels, foams, and emulsions, have all been used with success in field applications. These three diverter types were compared in the Westport Technology Center wellbore model. Foams and emulsions were found to provide more effective diversion than gel.
Based on the laboratory results, foam diversion was used during stimulation of injection wells at Shell Offshore Inc.'s Bullwinkle platform. Comparison of diverted and undiverted treatments quantifies the benefits to be gained from effective diversion and demonstrates that wellbore model studies correlate well with field results.
Frac Packing Offers Development Advantages for Ewan Field in Nigeria
Authors: Onasanya A. , Tibbies R. J. , Moran J. H. , DeBruin R. J. 
Published: December 2007

Abstract
Prior to 1995, sand production from the non-gravel packed wells and low productivity from a gravel packed well were factors which impacted the potential development of the Ewan Field, offshore Nigeria. To make the field a more attractive development candidate, horizontal and frac-pack completions were recommended. This paper compares the results of the first frac-packed well, which was expected to improve both production rates and ultimate recovery, with the previous gravel pack completion. Pressure build-up and production data show the improved productivity obtained after frac-packing. The results from the first frac-pack were so encouraging that field development includes frac-pack completions for all non-horizontal wells.
The Effect of Surface and Interfacial Tensions on the Recovery of Oil by Waterflooding
Authors: Kennedy Harvey T. , Guerrero Erasmo T. 
Published: December 2007

Abstract
In this investigation, the effects of the surface tension of brine and the interfacial tension between oil and brine on the recovery of oil by waterflooding of Woodbine sand was studied. Variation of the surface forces was obtained by the addition of small amounts of commercially available chemicals, which did not appreciably change the surface tension of the oil.
Fourteen surface-active agents, which were found to be effective in lowering the surface and interfacial tensions were further investigated to determine the extent of their adsorption by the Woodbine sand cores. It was found that adsorption was sufficient in all cases to prevent any substantial concentration of chemical at the flood front. The flow system was, therefore, brought to equilibrium with definite concentrations in the flood water by circulation before each test. The data thus have no relation to the results obtainable by using the chemicals in full-scale waterfloods, but should be helpful in predicting the performance of surface-active chemicals which are not lost by adsorption, such can be found.
Flow tests were made on various concentrations of six chemicals selected from the fourteen investigated for surface activity and adsorption, with and without the presence of gas in the core.
What Price Deliverability?
Authors: Hanna L.E. 
Published: December 2007

One of the public questions of major concern confronting our nation today is the sufficiency of our energy supply. In recent months we have seen voltage reduction and partial blackouts of electric service in partial blackouts of electric service in several parts of the country; the development of tight supplies of coal and residual fuel oil, and, of course, the subject of which we are so intimately aware: the decline in new discoveries of natural gas. While it is not my purpose today to launch into the reasons and possible solutions, it is important to keep the entire national picture in focus as we look at one aspect of picture in focus as we look at one aspect of gas supply.
We all know that reserves don't have much meaning until they are translated into flowing gas. Deliverability on a daily basis is the key to our ability in the transmission business to meet our customer's needs. Our mission today is to examine what has been happening in two of the oldest and, at one time, most prolific sources of flowing gas; namely, the Hugoton and West Panhandle Fields. From time to time I shall make specific references to our own experience, although the conditions now apparent affect all pipeline buyers in these two fields.
Although gas had been discovered some years before, production in large volumes began in the Hugoton and West Panhandle Fields in the late twenties and Panhandle Fields in the late twenties and early thirties. Initial pressure was about 450 psig in both fields.
Panhandle Eastern and the other companies began tying in wells and building gathering systems as the needs of each company developed.