bluuebunny/crossref_metadata_2025_split huggingface dataset:
Water Flooding Pays Off on Prolific Dora Roberts Lease
Authors: Walters J.D. 
Published: June 2009

Introduction
Waterflood operations were commenced on Sunray Mid-Continent Oil Company'ssolely owned Dora Roberts lease, located in the Howard Glassock field, Howard county, Texas, with the injection of water into a Yates sand 90 acre cooperative pilot water flood on Feb. 10, 1952. Production was boosted from 330to 3,281 bbl a day within 16 months after initial water injection. One year later the project attained a second peak production of 3,834 bbl a day. This represents a 1,062 per cent increase in production relative to the normal primary rate of production.
Today, after more than four years of operation, the production is still six times what it would have been under continuation of primary conditions. Cumulative totals indicate that up to July, 1956, 3,485,000 bbl of oil have been recovered through waterflood measures. One barrel of oil has been produced for every 3.78 bbl of water injected into the Yates sand. To date the waterflood operations have recovered an amount of oil equal to that obtained over the preceding 24-year primary period.
Total oil recovery from waterflood operations is expected to surpass 12,500bbl per acre.

Primary Development and Production History
The Yates Sand oil production from the Dora Roberts project, comprising 480leased acres, was obtained in March, 1928. Of 38 wells completed for production from the Yates sand found at about 1,400 ft, the same number of wells were still producing at the time water injection was commenced. Initial production of the wells ranged from 11 to 500 B/D natural.
Production has been obtained from three other formations all underlying the Yates sand formation. In addition to the Yates wells, a total of 49 wells were drilled and completed in the Seven Rivers sand reservoir found at about 1,800ft, the San Andres Lime reservoir found at about 2,600 ft, and the Clear Fork Lime reservoir found at about 3,000 ft.
Water Injection Well Fracture Treatments Benton Field Franklin County, Illinois
Authors: Parkison H.R. 
Published: June 2009

Abstract
Maintenance of desirable water, injection rates has been a problem at Bentonand is a problem to many waterflooding projects. Inability to maintain desirable injection rates is generally the result of plugging by precipitates in the injected water, skin effects incurred during completion, and limited reservoir capacity; Several methods have been used to alleviate this problem in the Benton field and one of the most successful has been hydraulic fracture treating.
Data from 29 fracture treatments of 26 injection wells at Benton show that water injection rates have been substantially increased. Although the behavior of other injection wells mask the effects of increased injection rates in treated wells, total liquid production has been increased in surrounding producing wells without adversely affecting produced water-oil ratios.
Fracture treatments have been varied, but an optimum treatment has not been conclusively indicated. However, results of water-base treating liquids compare favorably with the results obtained from the use of more expensive acid-base and/or oil-base liquids.
The physical nature of the fractures has been investigated by several different injection profiling methods. Pronounced profile changes have not been observed. It appears that existing zones of weakness in the formation have been extended and that a single vertical or horizontal fracture plane has not occurred.

Introduction
Maintenance of desirable water injection rates has been a problem at Benton since the initiation of waterflood operations in November, 1949. The Benton water flood is not unique in this respect, since the problem of maintaining water injection rates is common to many waterflood operations. Considerable effort has been expended in an effort to solve this problem because of its importance to the success of any waterflood project. Inadequate water injection rates create unbalanced flood conditions which reduce flood efficiency, and cause flood life to be extended.
Engineering Analysis of Water Flood Prospects
Authors: Wilson Wallace W. 
Published: June 2009

Introduction
The rapid growth of water flooding during the last few years has stimulated the industry to exploit this method of operation to the maximum advantage. Many operators who formerly paid little attention to the secondary recovery possibilities of their properties now realize the importance of evaluating every prospect in their holdings. The impact of this growth of interest in water flooding is easy to see. Well completion practices often are planned for less expensive conversion to secondary operations at a later date; the number of consulting engineers in this field is increasing, as is their backlog of work; and it is increasingly difficult to purchase primary production without some consideration of the potential secondary reserves.
To the average producer, this situation creates some interesting problems. He hears of many successful floods, but of few of the failures. No one, it seems, wishes to announce publicly that his water flood was more productive of experience than oil, and the literature on unsuccessful floods is both meager and carefully clothed with anonymity. All too often, then, the impression is gained that the risks are small, with the rewards stupendous. Such, unfortunately, is often not the case. One also might gain the impression that water flooding is a simple business which involves merely putting an uncertain amount of water down a few of the poorest wells on the lease, with oil certain to appear at others, all of which is accomplished at nominal cost. The basic idea is partially true, but unfortunately, this practice is rewarding only indirect relationship to careful planning or to the bounty of nature in the absence of good engineering.
Success in waterflooding operations begins with the selection of properties to flood which have reasonable chances for profitable operation. A screening process should be used to select only those properties for flooding which have favorable reservoir conditions and the development of those selected should be based on a thorough engineering analysis to seek out any indications of future operating problems in advance of their sudden appearance.
Income Secondary Tax Aspects of Recovery Projects
Authors: Aikman A.E. 
Published: June 2009

Introduction
No one need tell you gentlemen that secondary recovery projects and operations are becoming more numerous and important in the oil and gas industry. We all know that unless such projects and operations are undertaken a substantial amount of reserves will be unrecoverable and lost at least as far as our generation is concerned and perhaps to all future generations.
Of course, lawyers especially are cognizant of the fact that the development and changes in the law lag behind the development and changes in business operations and procedures which are necessitated by our dynamic economy. And as so often happens the laws, whether statutory or case law, do not give a great deal of assurance as to the ultimate legal consequences stemming from a particular operation, transaction, or contract. Consequently, lawyers frequently have to draw heavily upon their imagination tempered with judgment and forecast what the courts will probably hold in a particular situation.
What has been said applies in, the field of federal taxation to a greater degree than in other fields of law. The reason is perhaps simple since the field of income taxation is relatively new as fields of law go, and it is an extremely dynamic field which varies in many respects from year to year, all of which may explain why the field of tax law lends itself to more specialization than other fields might.
Contrasting Development, Operation, and Results of Three Waterfloods in Eastern Kansas
Authors: Lollar R.F. 
Published: June 2009

Abstract
The Bush City Shoestring comprising approximately 1,500 productive acres, lies generally in an east-west direction in Anderson county, Kansas. The sand involved is 760 ft deep and is composed of sand and shale layers, resembling in many ways the characteristics of Bradford third sand in Pennsylvania.
According to one published paper and other available data, this reservoir is expected to yield a recovery from water flooding of 2,400 bbl/acre over a period of 10 or more years. The Maracaibo Oil Exploration Corp. has developed and operated an 80-acre tract within this reservoir. We will, attempt to show the difference in application of development and operating practices of Maracaibo's Starit lease vs adjacent property and will show that 3,700 bbl/acre have been recovered in 3.2 years.
A more recent Maracaibo development is illustrated in brief. This area of 31acres, located on the Paola Shoestring, Miami County, Kansas, and referred to as Maracaibo's Phillips-Chandler lease, is an excellent example of good waterflooding practices vs results. It is unique as a test area from a viewpoint of selective shooting, use of Triton X-100, injection of fuel oil prior to water injection, and use of fully automatic pumping wells.
An attempt has been made to design the papers to provide the full story and to show in the final analysis the results of economics involved on the basis of dollars expended vs dollars returned vs time.

Introduction
The following study, relating to our experience with sandstone reservoirs in Eastern Kansas, is submitted in two parts:
Part 1 - Illustrates the planning, development, operation-and net results of Maracaibo's Starit 80-acre lease in contrast to the available data of a 370-acre development adjacent to and on either end of the Starit acreage.
Part 2 - Illustrates, in brief, the characteristics of operations and results of a more recent development, Maracaibo's Phillips-Chandler lease, which has responded splendidly to the employment of good waterflooding procedures and represents some unusual methods of development and operation.
A Resume of the Factors Governing Interpretation of Waterflood Performance
Authors: Calhoun John C. 
Published: June 2009

The performance of a water flood is a composite of many separate effects, which fall into a variety of categories. Nature gives many variables through the character of the reservoir rock and fluids and the manner in which they interact. Man imposes additional variables through the wells which are drilled and the manner in which they are completed and operated. In spite of this complexity, we assume at least in principle, that we can resolve all the factors that contribute to a water flood and dissect the entire operation into a series of causes and effects. This is perhaps a brash assumption. Although it may be easy to synthesize a complex situation, the analysis of one can be difficult. To draw an analogy, one may watch a cook and, having noted all the actions taken and the ingredients added, predict to a degree whether or not the cake will be successful. However, it is quite different to taste the finished cake and be able to trace a specific characteristic to a particular cause during the operation of mixing and baking. We say, in effect, that the baking of a cake is an art, not a science.
So it is, to a degree at least, with the water flood. We may plan and watch the operation and predict results in a limited way. Yet, it is quite difficult to trace a given result unequivocally to a specific cause. Generally, there are several equally plausible causes. The fact is that water flooding is also an art, not a science. Of course, it is our hope, as engineers and scientists, that we may be progressing to the place where water flooding operations will be governed entirely by science. In one sense, my remarks are intended to indicate how far we may be along this road. We are probably not even so far along as the cook, for she can bake her cake with some idea of the total factors involved and the role played by each. We do not yet know for sure, so it seems to me, that we have enumerated all the factors that are important to the waterflooding process.
Fresh Water Fracturing in Oil Reservoirs
Authors: Hurst R.E. , Rollins J.T. , Stewart H.A. 
Published: June 2009

The use of fresh water as a fracturing fluid in oil reservoirs became widespread in the Permian Basin in 1956,following its earlier introduction in the San Juan Basin. Although water was first used because of its economy, it soon became apparent that water often gave better production increases than oil-base fracturing fluids. Investigations showed that these improved results were caused by the action of fresh water in dissolving and removing salt from treated formations.
Salt occurs in reservoir rocks as matrix material, pore-filling material, fracture-filling material and as fall-out or precipitate from crude oils or brines. The salt content of a core sample can be determined by petrographic study or by chemical tests. Examinations of thin sections of cores show not only how much halite [salt] is present, but also whether the halite is in the form of cementing material, individual crystals, or secondary deposition in pores, channels, or natural fractures.
Fig. 1 is a photomicrograph [X300] of a halitic sandstone thin section from an upper Permian formation. Halite is the cementing material binding together chert and quartz grains. At the upper left hand corner, marked "C", is a chertgrain. The grains marked "Q" are quartz, and the black grains at upper right are magnetite or ilmenite. The arrows point to characteristic cubic openings in the halite. Others are between the arrows and below them. The opening at the right arrow contains a gas bubble. Although many more such openings are in the sample, they cannot be brought into focus at such high magnification.
Fig. 2 is a photomicrograph [x69] of loose quartz sand grains from the same core sample after the cementing halite was removed. This is the effect that can be expected when fresh water is used in treating such a formation.
The presence of halite as individual crystals in the formation is shown in Fig. 3, a photomicrograph [X300] in which both halite and quartz grains are prominent. It is apparent that halite grains may be as large as or larger than quartz grains. Dissolving and removing many such halite grains during a fracturing treatment using fresh water will substantially increase formation permeability.
Drawdown Exploration Reservoir Limit, Well and Formation Evaluation
Authors: Jones Park 
Published: June 2009

Abstract
Drawdown Exploration is the name of a technique that enables the operator to determine from a single drawdown well test the following:ability of the rock to transmit a fluid,darcy-feet of pay connected with the well,well completion efficiency,drainage radius,distance to the productive limit, andbarrels of oil or Mcf of gas connected with the well.
The technique will detect in place hydrocarbons at the rate of 100,000 to about 1,000,000 BOPD or 1,000,000 to about 10,000,000 Mcf of gas per day. If the well will flow for six hours or more and the hazard of sticking the drill pipe is negligible, the test may be run in an open hole before casing is set. A flowing water well may be tested in order to determine whether oil or gas is present at some distance away from the well.
A 1-mile radius explores about 2,000 acres. A 2-mile radius explores about 8,000 acres. The instrumental limitation on the radius of exploration needs further study in the field with a differential pressure bomb. The need for study on the electric analyzer of nonsteady-state flow is also emphasized.
The use of Drawdown Exploration for determining in place oil or gas, water contact, impermeable boundary and well completion efficiency is illustrated by six field examples.
By virtue of discovery, the phrase "Drawdown Exploration" is claimed for exclusive use by Park Jones.

Field Examples
Fig. 1 is for a Texas gas well that averaged 16 bbl of condensate per MMcf of reservoir gas. The curve labelled [P,t] shows the bottom-hole flowing pressure plotted against the logarithm of time, t, in days. The vertical logarithmic scale, Y, on the left side represents the daily rate of P decrease divided by the producing rate in reservoir B/D. The ability of a reservoir rock to transmit a fluid is measured in psi/reservoir B/D and is called the Darcy constant.
A Laboratory Study of Oil Recovery by Solvent Flooding After Water Flooding
Authors: Talash A.W. , Crawford Paul B. 
Published: June 2009

Abstract
Laboratory studies have been made to determine the quantity of oil that may be recovered by application of a solvent flood after water flooding. It was found that substantially all of the oil remaining after water flooding could be recovered by subsequent flooding with a petroleum solvent.
By fractionation and recirculation of the produced effluent it may be possible to reduce the solvent requirements by a factor of two or three.

Introduction
Previous studies have indicated that the oil recovery from porous media may be substantially increased by the injection of miscible fluids. Everett, Goochand Calhoun have suggested that a high recovery could be obtained by displacing reservoir crude with miscible liquids. Results of the study made by Kennedy indicate that the production of oil from depleted oil reservoirs may be substantially increased by the injection of liquefied petroleum gas. Kennedy'slaboratory tests were made using a sand-filled oxygen bottle to simulate a reservoir. The sand was saturated with oil and then flooded with propane. Some of the recoveries obtained by this method were as high as 98per cent indicating that most all of the oil may be obtained by L.P.G. injection.
Offering a and Van der Poel have presented information on the oil to be recovered by circulation of kerosene as a solvent through porous media. They conducted scale model experiments. The study included viscosity ratios of the crude oil to the kerosene from near 1.5 to 5,000. It was found that the oil recovery at breakthrough when flooding with kerosene as a solvent, was equal to those obtained in water flooding at the same viscosity ratio. However, after breakthrough occurred it was found that by flooding with the kerosene [a miscible liquid] the flood becomes much more efficient than the water flood and as a result considerably more oil could be recovered by using the solvent flood than by using the water flood.
Graves Hyperthyroidism After Stopping Immunosuppressive Therapy in Type 1 Diabetic Islet Cell Recipients With Pretransplant TPO Autoantibodies
Authors: Gillard Pieter , Huurman Volkert , Van der Auwera Bart , Decallonne Brigitte , Poppe Kris , Roep Bart O. , Gorus Frans , Mathieu Chantal , Pipeleers Daniel , Keymeulen Bart 
Published: June 2009

OBJECTIVE
After an initially successful islet cell transplantation, a number of patients return to C-peptide negativity, and therefore immunosuppressive therapy is discontinued. Some are then found to have developed Graves disease. We examined the risk of Graves disease after immunosuppression.

RESEARCH DESIGN AND METHODS
Immunosuppressive therapy was stopped in 13 type 1 diabetic islet cell recipients who had received one course of antithymocyte globulin and maintenance doses of mycophenolate mofetil and a calcineurin inhibitor. None had a history of thyroid disease.

RESULTS
In four patients, clinical Graves hyperthyroidism was observed within 21 months after discontinuation and 30–71 months after the start of immunosuppressive therapy. All four patients exhibited a pretransplant positivity for thyroid peroxidase (TPO) autoantibodies, while the nine others were TPO negative pre- and posttransplantation.

CONCLUSIONS
Type 1 diabetic recipients of islet cell grafts with pretransplant TPO autoantibody positivity exhibit a high risk for developing Graves hyperthyroidism after immunosuppressive therapy is discontinued for a failing graft.
The Association Between A1C and Subclinical Cardiovascular Disease
Authors: McNeely Marguerite J. , McClelland Robyn L. , Bild Diane E. , Jacobs David R. , Tracy Russell P. , Cushman Mary , Goff David C. , Astor Brad C. , Shea Steven , Siscovick David S. 
Published: June 2009

OBJECTIVE
To test the hypothesis that A1C is associated with subclinical cardiovascular disease (CVD) in a population without evident diabetes, after adjusting for traditional CVD risk factors and BMI.

RESEARCH DESIGN AND METHODS
This was a cross-sectional study of 5,121 participants without clinically evident CVD or diabetes (fasting glucose ≥7.0 mmol/l or use of diabetes medication), aged 47–86 years, enrolled in the Multi-Ethnic Study of Atherosclerosis (MESA). Measurements included carotid intimal-medial wall thickness (CIMT) and coronary artery calcification (CAC). Results were adjusted for age, sex, ethnicity, smoking, systolic blood pressure, LDL cholesterol, HDL cholesterol, antihypertensive medication use, lipid-lowering medication use, and BMI.

RESULTS
Compared with those in the lowest quartile for A1C ([mean ± SD] 5.0 ± 0.2%), participants in the highest quartile (6.0 ± 0.3%) had higher adjusted mean values for common CIMT (0.85 vs. 0.87 mm, P = 0.003) and internal CIMT (1.01 vs. 1.08 mm, P = 0.003). A1C quartile was not associated with prevalence of CAC in the entire cohort (P = 0.27); however, the association was statistically significant in women (adjusted prevalence of CAC in lowest and highest A1C quartiles 37.5 vs. 43.0%, P = 0.01). Among those with some CAC, higher A1C quartile tended to be associated with higher CAC score, but the results were not statistically significant (adjusted P = 0.11).

CONCLUSIONS
In this multiethnic cohort, there were small, positive associations between A1C, common CIMT, and internal CIMT in the absence of clinically evident diabetes. An association between higher A1C and CAC prevalence was evident only in women.
Inflammatory, Hemostatic, and Other Novel Biomarkers for Diabetic Retinopathy
Authors: Nguyen Thanh T. , Alibrahim Ekaterina , Islam F.M. Amirul , Klein Ronald , Klein Barbara E.K. , Cotch Mary Frances , Shea Steven , Wong Tien Y. 
Published: June 2009

OBJECTIVE
There are conflicting data regarding relationships of systemic biomarkers of inflammation, hemostasis, and homocysteine with diabetic retinopathy. We examined these relationships in the Multi-Ethnic Study of Atherosclerosis.

RESEARCH DESIGN AND METHODS
A total of 921 participants with diabetes were included. Diabetic retinopathy was graded from retinal photographs. We defined two outcomes: any diabetic retinopathy and vision-threatening diabetic retinopathy (severe nonproliferative diabetic retinopathy or worse). Systemic markers analyzed were C-reactive protein, homocysteine, fibrinogen, plasmin-α2-antiplasmin complex (PAP), interleukin-6, d-dimer, factor VIII, serum creatinine, and urinary albumin-to-creatinine (UAC) ratio.

RESULTS
Prevalence of diabetic retinopathy was 33.2% and vision-threatening diabetic retinopathy 7.1%. After adjusting for established risk factors (diabetes duration, A1C, systolic blood pressure, waist-to-hip ratio, and use of diabetes medications), fibrinogen (odds ratio 1.14 [95% CI 1.01–1.32], P = 0.05) and PAP (1.25 [1.05–1.50], P = 0.01) were associated with any diabetic retinopathy, while PAP (1.54 [1.13–2.11], P = 0.007) and homocysteine (1.57 [1.16–2.11], P = 0.003) were associated with vision-threatening diabetic retinopathy. Only PAP remained significant after additional adjustment for serum creatinine and UAC ratio. Area under receiver-operator characteristic curve (AUROC) for diabetic retinopathy was constructed for established and novel risk factors. Established risk factors accounted for a 39.2% increase of the AUROC, whereas novel markers (fibrinogen, PAP, homocysteine, serum creatinine, and UAC ratio) only accounted for an additional 2.2%.

CONCLUSIONS
There were few associations of novel markers of inflammation, hemostasis, and homocysteine with diabetic retinopathy after controlling for established risk factors. These data suggest that there is limited clinical use of these biomarkers for prediction of diabetic retinopathy.