Recruitment strategies and HPV self-collection return rates for under-screened women for cervical cancer prevention

In the United States, medically underserved women carry a heavier burden of cancer incidence and mortality, yet are largely underrepresented in cancer prevention studies. My Body, My Test is a n observational cohort, multi-phase cervical cancer prevention study in North Carolina that recruited low-income women, aged 30–65 years and who had not undergone Pap testing in ≥ 4 years. Participants were offered home-based self-collection of cervico-vaginal samples for primary HPV testing. Here, we aimed to describe the recruitment strategies utilized by study staff, and the resulting recruitment and self-collection kit return rates for each specific recruitment strategy. Participants were recruited through different approaches: either direct (active, staff-effort intensive) or indirect (passive on the part of study staff). Of a total of 1,475 individuals screened for eligibility, 695 were eligible (47.1%) and 487 (70% of eligible) participants returned their self-collection kit. Small media recruitment resulted in the highest number of individuals found to be study eligible, with a relatively high self-collection kit return of 70%. In-clinic in-reach resulted in a lower number of study-eligible women, yet had the highest kit return rate (90%) among those sent kits. In contrast, 211 recruitment which resulted in the lowest kit return of 54%. Small media, word of mouth, and face-to-face outreach resulted in self-collection kit return rates ranging from 72 to 79%. The recruitment strategies undertaken by study staff support the continued study of reaching under-screened populations into cervical cancer prevention studies

ADAPT(tm) trocar use for laparoscopic procedures in equidea

O objetivo deste trabalho é descrever o uso do trocater modelo Adapt(tm) no acesso laparoscópico em animais da família dos equídeos. O procedimento cirúrgico foi realizado em 15 equídeos (quatro jumentas, seis cavalos e cinco éguas), com peso médio de 320kg (290kg e 450kg, pesos máximo e mínimo, respectivamente). Os pacientes foram mantidos em posição quadrupedal, sob sedação e bloqueio local. Primeiramente, realizou-se o preparo asséptico, e o acesso foi feito pelo flanco direito ou pelo esquerdo, dependendo da estrutura a ser visualizada. Em todos os procedimentos, foi utilizado o trocater modelo Seal AdaptTM Ports (Teleflex Medical Introduces TautTM, USA), com diâmetro de 12mm. Inicialmente se fez uma incisão de pele de aproximadamente 15mm para inserção da ponta do trocater. Este foi inserido na ferida cirúrgica, realizando-se movimentos de 180º em sentido horário e anti-horário, até atingir a cavidade abdominal. Após esta etapa, o obturador do trocater foi retirado, e a ótica inserida para confirmar o acesso à cavidade abdominal. A síntese das camadas superficiais da muscular foi realizada com fio nylon nº 0, em um padrão Sultan, e posteriormente a dermorrafia, também com nylon nº 0, no padrão de Wolf. O equipamento apresentou eficiência nos procedimentos de dissecação das camadas subcutânea, musculares e peritônio, não ocorrendo significativa hemorragia nessas camadas. Em um paciente muar, ocorreu afastamento do peritônio parietal, e em alguns casos (40%) ocorreu pequeno enfisema subcutâneo no pós-cirúrgico. Todos os pacientes apresentaram boa cicatrização da ferida cirúrgica. O trocater modelo AdaptTM mostrou-se eficiente na abordagem laparoscópica em equinos, apresentando segurança em se estabelecer o acesso e versatilidade no emprego de diversos instrumentais

Quantifying brain development in the HEALthy Brain and Child Development (HBCD) Study: The magnetic resonance imaging and spectroscopy protocol.

The HEALthy Brain and Child Development (HBCD) Study, a multi-site prospective longitudinal cohort study, will examine human brain, cognitive, behavioral, social, and emotional development beginning prenatally and planned through early childhood. The acquisition of multimodal magnetic resonance-based brain development data is central to the study's core protocol. However, application of Magnetic Resonance Imaging (MRI) methods in this population is complicated by technical challenges and difficulties of imaging in early life. Overcoming these challenges requires an innovative and harmonized approach, combining age-appropriate acquisition protocols together with specialized pediatric neuroimaging strategies. The HBCD MRI Working Group aimed to establish a core acquisition protocol for all 27 HBCD Study recruitment sites to measure brain structure, function, microstructure, and metabolites. Acquisition parameters of individual modalities have been matched across MRI scanner platforms for harmonized acquisitions and state-of-the-art technologies are employed to enable faster and motion-robust imaging. Here, we provide an overview of the HBCD MRI protocol, including decisions of individual modalities and preliminary data. The result will be an unparalleled resource for examining early neurodevelopment which enables the larger scientific community to assess normative trajectories from birth through childhood and to examine the genetic, biological, and environmental factors that help shape the developing brain

New Fracture-Acid Technique Provides Efficient Stimulation Of Massive Carbonate Sections

ABSTRACT A new stimulation technique has been developed and successfully applied todeep massive carbonate completions in several areas. This same technique shouldprove useful in similar massive carbonate sections in Canada. Basically, thenew technique provides deep fracture penetration into the reservoir withlow-cost fluids and good fracture conductivity by effectively etching thefracture faces with special acid formulations. It differs from conventional hydraulic fracturing treatment only in thatacid replaces conventional propping agents. The treatment is economical in thatit uses inexpensive frac fluids to create fracture area and penetration andreduce fluid leak-off. Much smaller quantities of acid may then be used to etchthe desired conductivity at the required depth of penetration in the reservoir.If acid alone were used, the volume required would be prohibitively expensive. The new technique also eliminates many of the hazards of conventionalfracturing and acidizing. As no propping agent is used, there is no danger ofscreen-outs. Corrosion is minimized, because the pad volume of frac fluid coolsthe well equipment prior to the injection of acid. The technique, thus, is particularly useful in deep, high- temperature reservoirs. INTRODUCTION MASSIVE low-porosity, low-permeability carbonate formations such as the Ellenburger, Devonian, Hunton, Edwards, Budda and Smackover in the United States, and the Mississippian in Canada, are known to contain substantial andattractive quantities of hydro-carbons. Many of these accumulations have notresponded sufficiently to conventional stimulation techniques to warrantfurther exploration. Although a two-to three-fold productivity improvement canfrequently mean the difference between a noncommercial and commercial well, conventional acidizing and/or fracturing treatments have not provided suchincreases for sustained periods. A new dual fracturing-acidizing stimulationtechnique is now showing promise of improving productivity from these massiveformations. Basically the new fracturing technique provides deep reservoir penetrationwith low-cost fluids and good conductivity by effectively etching the fracturefaces with acid. Thus, it utilizes the advantages of both fracturing andacidizing penetration of the reservoir by the hydraulic fluids and developmentof high conductivity by acid. This treating technique also minimizes theprincipal hazards of conventional fracturing and acidizing-screen-outs andcorrosion. The combination also provides a more effective and economicalapproach to stimulation with acid-based fracturing fluids. Massive carbonates are often characterized by their extreme thickness anddepth, with accompanying high pressure and temperature. They often have extremelow permeability, and porosity. The permeability that is present is often inthe form of a fine interlacing of natural fractures and, in some cases, vugularsystems. Very little, if any, true matrix permeability exists. These primarycharacteristics have led to the difficulty in efficient, and effectivetreatment for stimulation. The thickness of these formations may range as high as several hundred feet, with depths of up to 25,000 feet. Thus, the low porosity dictates that theentire vertical extent of the formation must produce if ultimate recovery is tobe commercially attractive. Low permeability dictates that desired conductivitymust penetrate deeply into the reservoir to obtain commercial recoveryrates. THE PAPER WAS PRESENTED: at the 19th Annual Technical Meeting of The Petroleum Society of CIM, Calgary, May, 1968. Technology, January-March, 1969, Montreal Canada </jats:sec

Engineered Guide for Planning Acidizing Treatments Based on Specific Reservoir Characteristics

Published in Petroleum Transactions, AIME, Volume 219, 1960, pages 16–23. Abstract Analysis of acidizing techniques, in correlation with reservoir data and a backlog of past treatments, has resulted in the development of a valuable engineering guide for planning acidizing treatments. Such treatments fall into three categories:acid injection into the pores of the matrix;acid injection into natural formation fractures at less than parting pressure; andcombination acidizing-fracturing treatments in which acid solutions (without propping agents) are injected at treating pressures sufficient to open and extend fractures through which the acid flows. Because the spending time of acid during a specific well treatment does not change appreciably, maximum penetration is attained when the first increment of injected acid is completely spent. Additional acid injection cannot be expected to further extend the benefits of the treatment. Depth of penetration will depend upon the reaction rate of the acid under treatment conditions, the injection rate of the acid into the matrix or fractures and the area-volume relationship existing in the flow channels. Based on Darcy's flow formula, extremely low injection rates must be used in order to keep bottom-hole injection pressures below formation fracturing pressure. As a result, only limited penetration of unspent acid will occur. Treatment records indicate that, in most acidizing treatments, formation parting pressures are exceeded, greatly extending acid penetration. Under these conditions, stimulation benefits are limited to the fracture area produced during the spending time of the first increment of acid injected into the formation. This area may be calculated from laboratory and well data to estimate depth of penetration. This, in turn, may be correlated with productivity data to assist in the selection of optimum treating techniques and materials. </jats:sec

Investigation of Various Refined Oils for Formation Fracturing

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 285–288. Abstract The properties of some of the common fracturing oils, such as sand-falling rate, fluid loss and viscosity, are a function of the three major constituents of the oil. These are: asphaltic material, paraffin waxes and a base oil. The base oil can be either high or low viscosity. Asphaltic material increases viscosity by thickening the oil, decreasing the rate of fall of sand through the oil, at temperatures up to 200° F. When large amounts of paraffin wax are present, much of the wax is not dissolved, but is present in the form of microscopic crystals. This, of course is limited to temperature below the melting points of waxes. As a result, paraffin waxes do not function primarily as thickeners, but rather as bulking materials. The function of wax, without asphaltic material, in a low viscosity base oil is uniquely unlike that of wax with asphalt coexistent in the oil. The resulting difference in wax crystal size governs the sand-falling rate to a large extent. An ideal type of fracturing oil is one containing neither asphalt nor waxes. In such cases, the viscosity and resulting low sand-falling rate are apparently due to soluble resinous hydrocarbons, which are compatible with formation oils. Introduction Since the introduction of hydraulic fracturing as a method of stimulating production from oil and gas wells, a variety of fluids have been employed to open the fractures and carry the propping agent. Such fluids include gels, emulsions, and oils. In the latter category, the use of refined oils has increased tremendously, and it is probably safe to assume that such oils represent more than one-half of the total fluid used in fracturing. </jats:sec

Methods of Sludge Control During Acid Stimulation Treatments

Abstract The formation of asphaltic sludge during acid stimulation has been a seriousproblem in many areas for several years. Such sludges have had adverse effectson the results of treatments in several Canadian reservoirs. Recent studieshave shown that sludge may also affect results in many areas where its effectshave not yet been recognized. These studies indicate that:Sludge is a precipitate of colloidal materials present in crude oils.The precipitates occur due to changes in the environmental conditions ofthe crude by the addition of materials such as acid.Once formed, sludge is insoluble in most treating chemicals.Sludge can be prevented or controlled by the use of stabilizing agents intreating fluid or by the use of certain solvents as the outer phase ofacid-in-oil emulsions. The purpose of this paper will be to show how and why sludge is formed andhow it can be prevented or controlled. Simple laboratory tests to determine theprobability of sludge formation prior to treatment are discussed. Actual fieldresults point out some of the problem areas in Canada and show that sludgecontrol during acidizing treatments can increase productivity in theseareas. Introduction The formation of sludge by crude oil on contact with acid has beenrecognized as a serious problem in isolated areas for some time. The problemwas apparently first observed in certain California wells. In these wells, itwas noted that following acidizing treatments the wells were very slow to cleanup, and often a great deal of asphalt-like material was returned with thetreating fluids. In some cases, complete or partial plugging of the wellresulted from the treatment. A study of this problem revealed that the crudeoils produced from these wells actually formed solid precipitates upon contactwith acid. An analysis of these sludge-like precipitates showed them to be madeup mainly of asphaltenes, resins, paraffin waxes and otherhigh-molecular-weight hydrocarbons. These materials were apparentlyprecipitated from the crude by the reduction in pH as a result of acidcontact. </jats:sec