bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reflex Human Papillomavirus Test Results as an Option for the Management of Korean Women With Atypical Squamous Cells Cannot Exclude High-Grade Squamous Intraepithelial Lesion
Authors: Ryu Ki-Jin , Lee Sanghoon , Min Kyung-Jin , Kim Jae Won , Hong Jin Hwa , Song Jae Yun , Lee Jae Kwan , Lee Nak Woo 
Published: May 2015

Abstract

Background.
Current guidelines recommend initial colposcopy with biopsy regardless of human papillomavirus (HPV) test results in women with atypical squamous cells, cannot exclude high-grade squamous intraepithelial lesion (ASC-H). The purpose of this study was to evaluate the value of HPV testing in women with ASC-H based on colposcopic pathology results.

Materials and Methods.
A multicenter cross-sectional study was carried out at three academic hospitals and involved 40,847 Korean women who underwent cervical cancer screening with cytology and HPV tests with or without subsequent colposcopic biopsies between January 2007 and December 2013.

Results.
ASC-H was diagnosed in 276 women (0.7%). Only 6 of 68 (8.8%) women with ASC-H who were HPV negative had cervical intraepithelial neoplasia grade ≥2 (CIN ≥2) lesions, whereas 47.4% of the women with ASC-H who were HPV positive had CIN ≥2 lesions. No cases of invasive cervical cancer were diagnosed among women with ASC-H who were HPV negative. Logistic regression analysis was performed using the group with normal Papanicolaou test results and HPV-negative status as the reference group. Women with ASC-H who were HPV positive had a significantly increased risk of CIN ≥2 lesions, whereas no significant increase was observed in patients with ASC-H and HPV-negative status.

Conclusion.
If the result of the HPV test was negative, the risk of CIN ≥2 lesions in Korean women with ASC-H cytology was low. Reflex HPV testing should be an option for the management of women with cytology showing ASC-H to decrease unnecessary colposcopic biopsies, which are expensive and invasive.

Implications for Practice:
Current American Society for Colposcopy and Cervical Pathology guidelines recommend universal colposcopy for the management of women with atypical squamous cells, cannot exclude high-grade squamous intraepithelial lesion (ASC-H) on cytology, regardless of human papillomavirus (HPV) test results. The present study suggested that HPV cotesting in patients with ASC-H cytology can provide more detailed and useful information regarding the risk of high-grade cervical intraepithelial neoplasia (CIN) lesions and the need for further treatment. When the result of the HPV test was negative, the risk of CIN lesions of grade ≥2 in women with ASC-H cytology was low. Consequently, reflex HPV testing, rather than immediately performance of invasive and expensive colposcopy with biopsy, should be an option for the management of women with ASC-H.
Clinical Activity of Ipilimumab in Acral Melanoma: A Retrospective Review
Authors: Johnson Douglas B. , Peng Chengwei , Abramson Richard G. , Ye Fei , Zhao Shilin , Wolchok Jedd D. , Sosman Jeffrey A. , Carvajal Richard D. , Ariyan Charlotte E. 
Published: May 2015

Abstract

Background.
Ipilimumab improves overall survival (OS) in advanced melanoma. Acral melanoma is an uncommon clinical subtype of this disease associated with poor prognosis. The clinical activity of ipilimumab has not been well-defined in advanced acral melanoma.

Methods.
We retrospectively reviewed the demographics, treatment history, and clinical outcomes for all patients with acral melanoma treated with ipilimumab from two academic centers between February 2006 and June 2013. Using Cox proportional hazards models, we assessed for factors that correlated with OS.

Results.
A total of 35 patients with acral melanoma received ipilimumab. Melanomas arose on volar surfaces (n = 28) and subungual sites (n = 7); stage M1c disease was present in 54%, and 45% had elevated serum lactate dehydrogenase (LDH). Best response by RECIST 1.1 criteria was complete response in 1 patient, partial response in 3, and stable disease (SD) in 4 for an objective response rate (ORR) of 11.4% and a clinical benefit rate (ORR + SD) at 24 weeks of 22.9%. Median progression-free survival was 2.5 months (95% confidence interval [CI]: 2.3–2.7 months); median OS was 16.7 months (95% CI: 10.9–22.5 months). Normal LDH and absolute lymphocyte count ≥1,000 at 7 weeks predicted longer OS. Immune-related adverse events (irAEs) were noted in 16 patients including 7 with grade 3/4 irAEs (20%).

Conclusion.
Ipilimumab is clinically active in acral melanoma with similar ORR and OS compared with unselected melanoma populations. Ipilimumab remains a viable therapeutic option for patients with advanced acral melanoma.

Implications for Practice:
Ipilimumab is a commonly used immune therapy that improves survival in metastatic melanoma. The clinical activity of ipilimumab in certain rare melanoma subtypes, such as uveal or mucosal melanomas, is suboptimal. Acral melanoma is another unusual subtype of this disease that arises on the palms, soles, and nailbeds. In this study of 35 patients with acral melanoma from 2 centers, ipilimumab was found to have activity that appears equivalent to unselected melanoma (response rate of 11.4%, median overall survival of 16.7 months). Ipilimumab remains a viable treatment option for this melanoma subpopulation.
Characterization of the Driving Unit of Linear Submerged Double Acting Pumping System
Authors: Moreira André Pimentel , Lepikson Herman Augusto , Schnitman Leizer , Ramalho Geraldo Luis , Matos Francisco Frederico 
Published: May 2015

Abstract
This paper present the characterization of the driving unit of a rodless mechanical pumping device, named linear Mechanical Submerged Pumping of double effect (MSP) which is the subject of a recent patent application at the National Institute of Intellectual Property (BR 2013 10 7033422). This rodless pumping device consists of an alternative hydraulic piston adapted to operate partially or totally submerged in oil production wells. The device is also a viable alternative for pumping water from deep aquifers. The goal of this work is to characterize and identify the main components used in the MSP concept, using the operating parameters and dimensions of conventional artificial lift wells, available in the Laboratory of Artificial Elevation of the Federal University of Bahia (LEA/UFBA). Our results allow estimating the characteristics of the components required to meet the requeriments for production considering the operating parameters of MSP. This new method of artificial lift and the alternative method of pumping fluid of linear wells or with deviation, justify investment in the production of specific components as well as producing the prototype, testing and validating the apparatus using trading components.
Numerical Simulations of 3D Single-Phase Flow in a Stage of a Centrifugal Pump of ESP Systems
Authors: P. Maitelli C. W. , F. Bezerra V. M. 
Published: May 2015

Abstract
In the present work a mathematical model was developed to obtain numerical simulations to describe the 3D single-phase fluid flow within one stage of a centrifugal pump used in the Electrical Submersible Pumping (ESP) systems. Simulations were performed with ANSYS® CFX® software and the results for pressure fields and velocity profiles were analyzed and compared to pump manufacturer curves. Three non-structured meshes were evaluated and two turbulence models were implemented to verify convergence and the model precision.
Reuse Selection Criteria for Progressive Cavity Pumps Based on the Mean Time between Failure and Reliability Function for Each Pump Type in the Cira Infantas Field
Authors: Labrador Laura , Celis Jonathan , Martin José Luis , Rubiano Edward , Gutierrez Jahir , Monroy Manuel , Prada Jesus , Obregon Cristian 
Published: May 2015

AbstractLa Cira-Infantas (LCI) is Colombia's oldest oil field whose production started on April 18th, 1918. Since it is a mature field and is undergoing secondary recovery most of its wells have low flow rates (&lt; 1000 BFPD). The wells require an artificial lifting system with low-cost installation and maintenance. For low flow and gassy wells in sandstone reservoirs, the Progressive Cavity Pump (PCP) system has been used since 2006.It has been observed that the smallest percentage of PCP failures is due to the pump. When a pump fails, it is necessary to determine if a component should be reused. Currently, when any work is performed on a well, the pump is inspected with a borescope. When the results show that the pump efficiency is 50% or higher, it is considered reusable. In addition, corrosion, scale formation, wear and abrasion from reservoir fluids should be identified to determine if the pump can be reused.A database was constructed of the history of the PCP in LCI. Each well had its run life, type of installed pump and the cause for any intervention. Thus, every pump model was classified, identifying all the interventions as pump failure or no-failure using failure codes. This data was used to obtain the Mean Time Between Failure (MTBF) calculation and its corresponding probability of survival, obtaining the initial criteria to reuse the pumps according to what was calculated and the experience and knowledge of the conditions in the field. This history, combined with the test bench efficiency analysis, assisted in determining if the pump was in good condition and a candidate for reinstallation.Today, when a pump is pulled out and successfully passes testing, its information is compared against every pump in the database. This enables a prediction of how much longer the PCP will last. After the estimate of reliability is calculated, the decision is made whether to reuse it or to reject it.
Failure Index Reduction Strategy for Artificial Lift Systems in Cira Infantas Field
Authors: Monroy Manuel , Gutierrez Jahir , Prada Jesus , Martin Jose Luis , Rubiano Edward , Labrador Soraya , Celis Jonathan , Sales Paola de 
Published: May 2015

Abstract
The Cira Infantas Field is located in the Middle Magdalena Valley Basin. It was discovered in 1918, the first oil producing field in Colombia, reaching a peak production of 53,000 BOPD in 1939. The field has been subject to different methods of secondary recovery, gas injection and waterflooding since then. In 2006, a waterflooding redevelopment with injection-production system optimization was started. In the first year, oil production increased from 4,500 BOPD to 9,800 BOPD and injection increased from 12,000 BWIPD to 36,000 BWIPD.
After an increase of the Failure Index in 2012, the artificial lift team developed a strategy to reduce this performance indicator based on process improvements including supply chain, design, storage, installation procedures, well start up and well surveillance.
As of December 2014, the field has 1000 producing wells and 408 injectors. The most common artificial lift system (ALS) is Beam Pump (BP) with 760 wells; followed by Progressive Cavity Pump (PCP) with 135 wells; Electrical Submersible Pump (ESP) with 99 wells and Electrical Submersible Progressive Cavity Pump (ESPCP) with 6 wells. The main failure causes are associated with sand, corrosion (CO2 is present), poor monitoring and operation procedures among others.
The application of the Root Cause Failure Analysis, RCFA was the first step to identify the artificial lift problems to be solved. One of the first conclusions showed the necessity to redefine the production range for the different ALS. This is an example that the problems are not always associated to the reservoir fluids, leading the team to define a strategy that covers all stages where ALS's are involved. The new implemented strategy yield a reduction in the ALS failure index from 0.67 to 0.47 in just 24 months. The savings enabled the operation to carry out additional well work (Workover & Well service) without additional funding.
New Approach for Reservoir Management Through the Implementation of Slim ESP With Bypass System for Production Logging in a Field With Rod Pumping Systems
Authors: Azancot A.. , Saavedra P.. , Romero J.. , Navas E.. , Pabon M.. , Agudelo O.. , Hernandez D.. , Reyes J.. 
Published: May 2015

Abstract
Casabe has been under waterflooding for more than 30 years. The heterogenities of the reservoir and the commigled injection implemented at the beginning of the waterflooding, resulted in early break through times. In 2007, selective injection was implemented allowing to inject separately in each layer and, therefore, to have injection distribution through Injection Logging Tools (ILT). However, producer wells are completed in commigled and with PCP or SRP systems, making difficult access the well to have any information about production distribution. At the current phase of the field development, the production distribution is key information for reservoir management to make decisions about short to medium plans to optimize production.
By pass systems has been used in 9 5/8” casings with enough room to set an ESP and a by pass system (Y-tool). In Casabe field, producer wells are completed with smaller casing diameter representing a real challenge due to the lack of space to accommodate an ESP with a bypass system.
This paper presents the sucessfull application of Slim ESP with by pass system installed in high water cut wells with 7” and 29 #/ft casing, to run conventional production logging tools to determine production distribution and to identify swept and damage zones, PI per layer, crossflow between layers and not producing zones. The challenge of production logging in this environment was not only related to the type of completion in Casabe field (completions with rods and smaller diameter), but also to the multilayer characteristics and high water cut which needed an especific set of tools and sensors to have the best accuracy in the oil and water distribution per layer. A Production Logging Tool of 1-11/16” and a set of 8 probes for bubble counting was a must to achieve the objectives, so the Slim ESP with bypass system was selected based on this condition. After reviewing several combinations, a Slim ESP 319 series and a bypass system with a drift of 2.087” was selected as unique solution. Producction logging has been perform for the first time in Casabe field with a conventional PLT, with no operational problems and with clear results related to oil and water production distribution allowing making short term decisions such as isolating swept zones, stimulating damaged zones or optimizing injection in delpeted zones, but also allowing to understand the real behavoir of the wells and reservoir with the current completion strategy which help to make medium term decisions about reservoir management and field development.
Production Optimization using Insert Progressing Cavity Pumps (I-PCP) and Hydraulic Equipment for Heavy Oilfields in Mexico
Authors: Carreno L. Jimenez , Barbosa C. Yudiche , Ramirez B. Villalobos 
Published: May 2015

Abstract
Implementation of compatible production technologies for extraction of heavy oil using progressing cavity pump (PCP) systems in three different oilfields: Altamira, Ebano, Panuco & Cacalilao; located in Northeastern Mexico. The optimization process was accomplished thru implementation of Insert Progressing Cavity Pumps (I-PCP) and hydraulic driveheads, in areas without electric power network, and high restrictions of well service rigs.
The project started with conventional PCP, and a second phase achieved an important operational improvement thru I-PCP and surface systems with smaller internal combustion engines in response to the operator's request for less fuel consumption. In 2008 January a conventional PCP was installed in the Franco Española-66 well (60 BFD & 1000 m lifting capacity), successfully operating for 2 years. Subsequently between 2008 and 2009, 32 additional PCP were installed, but the operator company had serious restrictions for optimization programs because of unavailability of well intervention rigs.
In response for January 2010, an I-PCP was installed in the Altamira-1022 well (189 BFD & 1500 m lifting capacity), for extraction of heavy oil (10-13 °API); the favorable results led to installation of over 200 additional PCP systems in shallow wells (&lt;450 m). At the same time, 80 power generators as surface equipment were installed in Ebano field; this due to the absence of electricity in the area. Those generators used 4.3 and 5.7 liter internal combustion engines. Those wells had low gas-oil ratio (GOR), therefore the use of natural gas obtained from annulus (casing-tubing) was not an option, so an outsourcing of Liquefied Petroleum Gas (LPG) was required. Considerable financial costs for high daily gas consumption were caused by this situation.
Facing this condition, the first hydraulic surface equipment with smaller capacity (3.0 L) was installed for January 2012, showing a decrease in gas consumption and lower costs. Likewise, the new application was focused on shallow wells, during next two years, in which all of the initial engines were replaced.
This PCP optimization process showed several positive economic impacts: Decrease of intervention rig frequency regarding former PCP systems installed, which demanded pulling of production tubing string.Saving in time and cost in front of PCP failures due to lower operating time using flush-by units, in comparison with bigger intervention rigs; i.e., workover or maintenance rigs.Lower deferred production levels were obtained.Additional cost saving associated to the consumption of LPG.
Implementation of this PCP process as artificial lift system for heavy oil wells achieved important improvements regarding operational performance and well productivity.
Three-Dimensional Model for Rod String Stress and Fatigue Calculations in Progressing Cavity Pumping Wells
Authors: Assmann Benno 
Published: May 2015

Abstract
This paper presents a 3D vectorial approach model that is capable of calculating traction, bending, cutting effort and torsion stress which are combined through Von Mises’ theory and applied to Goodman fatigue stress analysis and contact load distribution for guide distribution.
Geometry is described by a 3D model that determines tangent, normal and binormal vectors. This model allows calculating Cartesian coordinates and curvature from wellbore drilling data: measured depth, inclination and direction. Using geometry and curvature it is possible to calculate alternating bending effort that adds and subtracts from traction, besides other orthogonal shearing stresses, like cutting effort stress generated by contact load and friction that is added to torsion. These types of stresses are combined and applied through the applicattion of Von Mises’ Theory and Goodman's Analysis in order to verify rod string sizing.
A three-dimensional model is applied to develop an algorithm to perform stress calculations and analysis in a deviated geometry well and this algorithm is included in design software that makes all the possible combinations of rod strings, pumps, tubings, driveheads and prime movers, selecting the best suited combination by the fuzzy logic method. Some well designs are presented and stress analysis results are compared with commercial software results and the differences are highlighted and analysed. These designs include geometry, curvature and stress components, torque, load, fraction of rod strenght, contact loads and guide distribution along well profile. The algorithm includes contact load calculations and optmized rod guide distribution. Applying this model, rod string performance and MTTF can be improved in deviated wells by taking into account stresses that appear in this type of well and they are frequently not considered.
This model combines additional existing stresses in a deviated well like: bending, cutting shear, contatc friction stresses and compose weight and curvature contact loads resultant in inclined plane curve, in a more accurate approach. The fuzzy logic method, which automatically selects the best equipment combination, is another novelty.
Electric Submersible Pumping, First Application in a Mature Field in Mexico, Using the Unconventional Technology With Synchronous Permanent Magnet Motor (PMM) + “Power Save” Pump
Authors: Garcia Edgar Lopez , Gonzalez Jaime Sanchez , Torales Felipe L. , Campos Israel Molina , Gonzalez Fernando J. , Gonzalez Jose R. , Hernandez Edsel J. , Tapia Ramon 
Published: May 2015

Abstract
To share and divulge lessons learned using ESP system first application in a mature field operated by Petrofac Mexico, using cutting-edge technology and an Electric Submersible Pump (ESP) system with synchronous permanent magnet motor (PMM) + Power Save pump in Santuario 132 well, operated by Petrofac Mexico at the service of Petroleos Mexicanos (Pemex), for 384 days.
In this technical work the ALS selecting process is explained in detail, as well as new technology implementation in ESP systems with synchronous permanent magnet motor (PMM) + Power Save pump with staged vortex type semi-compressors, in the Santuario 132 well, operated by Petrofac Mexico for Pemex, is presenting the recommendations and good practices carried out mainly in the phases : Conceptual (design, specifications and manufacturing), Installation (assembly and commissioning), Operation (operational reliability and optimization), Out of Operation / Fail (methodology for analyzing the fault); phase Removal (analysis and inspection system) and last phase learning (change in design or procedures).
Modeling and Automatic Control in Artificial Lift using Smart Fields Technologies
Authors: Torres L. H. , Souza L. d. , Schnitman L.. , Lepikson H. A. 
Published: May 2015

Abstract
The production and operations in oil and gas fields are getting more complex, with more and more demanding restrictions for safety, energy efficiency, environment, which sets new technical challenges for automation and control. On the other hand, modeling and system identification tools and advanced control systems can be an important key to enhance stability and cost effectiveness and support the personnel (operators, engineers, etc.). This article will illustrate some results obtained with the application of modeling and advanced control systems for artificial lift using smart field technologies.
Determination of Downhole Dynamometer Cards for Deviated Wells
Authors: Araújo A. P. , Maitelli A. L. , Maitelli C. W. , Dos Santos D. P. , Costa R. O. 
Published: May 2015

Abstract
This paper proposes a numerical solution for the calculation of the downhole dynamometer card for deviated wells equipped with sucker-rod pumping. The solution shown is based in the model developed for the project of sucker-rod pumping systems considering three-dimensional trajectories. The results shown indicate that the incorporation of the three-dimensional model to the algorithm allows the adequate calculation of downhole dynamometer cards for vertical and deviated wells. The model enables the estimation of important productive parameters for any sucker-rod pumping system, such as flow rate and intake pressure, besides calculating significant data for deviated systems, such as lateral load acting throughout the rod string.