bluuebunny/crossref_metadata_2025_split huggingface dataset:
Modern treatment of patent ductus arteriosus – single center experience
Authors: Mesihović Dinarević Senka , Kadic Almira , Begić Zijo , Halimić Mirza , Vukas Emina 
Published: February 2015

Introduction: Transcatheter closure is a treatment choice for the most children with patent ductus arteriosus (PDA). The closure of the ductus is indicated in any child or adolescent with developed symptoms of significant L-R shunt. The aim of this article is to present our results in 5 years treatment of patients with PDA and their outcome. Methods: From 2009 to 2014, 30 patients underwent a transcatheter closure of PDA at Centre for Heart and Pediatric clinic of Clinical University Centre of Sarajevo. Aortic angiogram was performed to evaluate the size, position, and shape of the duct for selection of appropriate occluder device type and size. All procedures were performed by local team of cardiologists from the Department of Cardiology, Pediatric clinic, with invasive cardiologists team from Sweden and Austria. Echocardiography was repeated at intervals of 24 hours, then 1month, 3 months, and 1 year after the procedure to assess the outcome. Results: Thirty patients underwent transcatheter closure of PDA during the study period. PDA of ≤ 2.0 mm was present in 8 patients and they underwent PDA closure with coils, while 22 patients had PDA diameter ≥ 2 mm, and they were treated by Amplatzer duct occluder (ADO). Only in 2 (6.2%) patients complications have been observed. The length of hospital stay after the treatment was two to three days. Conclusion: Transcatheter closure of PDA is a modern, safe and efficient method that ensures a faster recovery of the patients, shortens the length of hospitalization.
Increasing Hospital Breastfeeding Rates Through Online Education for Staff Registered Nurses
Authors: Baker Ann , Weideman Yvonne , Facello Debra 
Published: February 2015

Background: The Baby-Friendly Hospital Initiative of 2010 recommends the proportion of mothers who breastfeed their babies in the early postpartum period should be at least 75% (Baby-Friendly USA, 2010). The exclusively breastfeeding rate at a community hospital located in the
Appalachian region is 44%, well below the proposed standard. Registered nurses who lack knowledge or exhibit a negative attitude toward breastfeeding, can impede the understanding and skills necessary to empower mothers to effectively breastfeed.Purpose: This performance improvement
project was designed to determine whether an online educational module was effective in increasing the knowledge and improving the attitudes of nurses working with breastfeeding mothers.Methods: A pre- and posttest design was used to evaluate nurse’s attitudes and knowledge of
breastfeeding.Results: The results of the paired-sample t-test indicated a significant increase in the Breastfeeding Initiation Practice scores pre- and posttest. The exclusive breastfeeding rate had a clinically significant change from 44% to 58%.Conclusion: An online
educational intervention was effective in increasing the knowledge of nurses working with breastfeeding mothers. This efficient and cost-effective intervention may be valuable to hospitals desiring to increase exclusive breastfeeding rates by increasing the knowledge and skill of staff.
Electrical Characterization and Mineralogical Differentiation of a Weathering Cover in the South Cameroon Humid Intertropical Zone using the Self-potential Method
Authors: Atangana Joseph Quentin Yene , Angue Monique Abossolo , Nyeck Brunot , Ndongue Constantin , Tchatat Jules Tchamdou 
Published: February 2015

The study presented herein highlights the existence of a diversity of spontaneous sources of electric potential in weathering cover within the inter-tropical humid zone of south Cameroon. The study site presents a spatial mineralogical heterogeneity, which reveals the dominance of gibbsite more generally upslope, transitioning to a residual kaolinite downslope. The spatial characterization of these weathering mantles at the site revealed a general negative correlation between self-potential (SP), elevation, and sand and silt contents, confirming the existence of a dominant SP electrokinetic source. The main electrokinetic source is attributed to the presence of gibbsite, an abundant mineral at well drained relief summits of intertropical landscapes, likely resulting from the intense alteration of kaolinite. The electrofiltration phenomena related to fluid flow in the gibbsitic summit, quite rich in sand and silt, might justify this origin. A separate SP survey carried out in the kaolinitic mantles 5 km away, which lacked gibbsite, but was richer in clay, revealed a positive correlation between SP, elevation, and clay content of the surface horizons. The difference in correlation is attributed to the electrochemical nature of the SP within the second site. Thus, the diversity of sources of SP gives way to formulation of hypotheses on mineralogical differentiation and spatial characterization of lateritic covers.
Ground-truthing Electrical Resistivity Methods in Support of Submarine Groundwater Discharge Studies: Examples from Hawaii, Washington, and California
Authors: Johnson Cordell D , Swarzenski Peter W , Richardson Christina M , Smith Chris G , Kroeger Kevin D , Ganguli Priya M 
Published: February 2015

Submarine groundwater discharge (SGD) is an important conduit that links terrestrial and marine environments. SGD conveys both water and water-borne constituents into coastal waters, where these inflows may impact near-shore ecosystem health and sustainability. Multichannel electrical resistivity techniques have proven to be a powerful tool to examine scales and dynamics of SGD and SGD forcings. However, there are uncertainties both in data aquisition and data processing that must be addressed to maximize the effectiveness of this tool in estuarine or marine environments. These issues most often relate to discerning subtle nuances in the flow of electricity through variably saturated media that can also be highly conductive (i.e., seawater). Three contrasting field sites were examined for this study to assess the effectiveness of electrical resistivity techniques in varying coastal settings by comparing resistivity data to direct salinity and resistivity observations, quantifying changes in lithology and beach geomorphology, and fine-tuning inversion protocols. The three study sites all have substantial (up to 85 cm day−1) submarine groundwater discharge rates, but the hydrologic, oceanographic, and geologic characteristics of the sites are all very different. At a site in Pelekane Bay on the Big Island of Hawaii, seasonal flooding introduces very high concentrations of fine to coarse sediment into the bay. Near-shore circulation is limited in Pelekane Bay, so this newly introduced sediment can become deposited in the bay where it accumulates over time. At a site in Hood Canal, a fjord within Puget Sound, Washington, SGD rates can be high because of the large tidal range, abundant recharge, and steep hydrologic gradients. At Younger Lagoon in northern California, the flow of groundwater towards the coast is much more parsimonious, but here marine processes, including recirculated seawater, are important in controlling the flow of material towards the coast. Rigorous ground-truthing at each field site showed that multi-channel electrcial resistivity techniques can reproduce the scales and dynamics of a seepage field when such data are correctly collected, and when the model inversions are tuned to field site characteristics. Such information can provide a unique perspective on the scales and dynamics of exchange processes within a coastal aquifer—information essential to scientists and resource managers alike.
Overview: Mature Field Revitalization (January 2005)
Authors: Lagerlef David 
Published: February 2015

Have you ever considered the foresight of the original designers of the mature fields where you have worked? It is often impressive. During the conceptual-design phase, considerations of functional flexibility vs. preinvesting were likely evaluated before deciding how to prepare the field for the future. Significant dividends are realized when this foresight can be incorporated into revitalization projects. Advanced planning for facilities, pipelines, and other infrastructures can reduce the need for significant modifications when implementing revitalization projects. For example, expansion piping runs, production losses, and footprint can be minimized.
It is difficult to eliminate all future obstacles; conflicting interests will inevitably arise. The best economic option is not always the optimal solution for one of the existing facilities or reservoirs, and compromises often have to be made. It is important in these situations to be able to make the most informed decision possible. Quality evaluation tools and data management are critical for determining the economic value of mutually exclusive alternatives. Reliable models and data-retrieval systems can assist present-day engineers in decision making to enable them to take advantage of unexpected revitalization opportunities in a mature field.
Situations can arise, even with the use of advanced planning and quality information, in which there seem to be insurmountable obstacles. The petroleum industry has a track record of meeting such challenges with little hesitation. Difficult deliberations on unanticipated opportunities for a mature field can stimulate impressive and innovative solutions. Our industry is capable of turning the seemingly impossible into reality, which can be crucial in revitalizing a mature field.
Additional Mature Field Revitalization Technical Papers
Available at the SPE eLibrary: www.spe.org
SPE 88604 - A Case Study of a Mature-Field Redevelopment Using Propped Hydraulic Fracturing
SPE 88769 - Maturing Field: A Case History Offshore Abu Dhabi
SPE 89469 - Revitalization of Pilar Field (Sergipe-Alagoas Basin, Brazil) Using Deviated Wells Along Fault Planes—A Successful Experience
SPE 91005 - Through-Tubing Rotary Drilling: A Cost-Effective Method for Sidetracking Wells in Mature Assets
Gas-Injection Pilot in the Hochleiten Field
Authors: Denney Dennis 
Published: February 2015

This article, written by Technology Editor Dennis Denney, contains highlights of paper SPE 89356, "Gas-Injection Pilot in the Hochleiten Field," by K. Potsch, SPE, R. Ramberger, SPE, J. Glantschnig, SPE, S. Baumgarthuber, SPE, and F. Gossnitzer, SPE, OMV A.G., prepared for the 2004 SPE/DOE Symposium on Improved Oil Recovery,Tulsa, 17-21 April.
The Hochleiten field, a marginal field north of Vienna, Austria, is highly com-partmentalized and contains very viscous oil. Waterflooding worked only in a part of the reservoir. Poor communication and large pressure differences were observed across the field. A CO2 injection was attempted in an area in which no waterflood had been tried. Use of CO2 improved the inflow capacity of the injector, but oil production from affected wells increased only slightly. To match the actual response of the reservoir, reservoir-model adjustments became necessary. To support the existing reservoir description, an N2-tracer test was initiated to determine the preferred communication paths.

Introduction
The Hochleiten field was discovered in 1973. Production began in 1974. The main reservoir is the Tertiary Lower Sarmatian at a depth between approximately 710 and 800 m subsea. The structure map in Fig. 1 shows that the reservoir is highly compartmentalized with two major, probably sealing, faults. The reservoir is oil bearing, with small gas caps in Sectors A and C.
Approximately 30 wells have been drilled. A waterflood, comprising two wells each in Sectors A and C, was initiated in 1991 with mixed success because of the high level of structural and stratigraphical heterogeneity. Sector B was not included in the waterflood program because the production history did not define fault locations of impermeable layers.
In 1997, a detailed and integrated reservoir study was initiated to understand reservoir behavior. On the basis of new 3D-seismic data, a team of geoscientists and engineers revised the structural and stratigraphic framework of the field, leading to a new reservoir model for dynamic simulation. Several recompletions and infill-drilling locations were identified.
It became evident that lateral-facies changes, as well as reservoir compartmentalization, led to early pressure decline or early water breakthrough. Combining a material-balance model with neural-net-work models in one sector of the reservoir showed that the connectivity between wells and layers generally is poor, and, in particular, water injection at downdip locations could not support the pressure sufficiently in the updip areas of the structure. It also was found that the dissolution of gas increased oil recovery more efficiently than waterdrive alone. Therefore, gas injection is expected to be more efficient than waterflooding to access bypassed oil.
Enhanced Oil Recovery by Steamflooding, Cruse 'E' Field, Trinidad
Authors: Denney Dennis 
Published: February 2015

This article, written by Technology Editor Dennis Denney, contains highlights of paper SPE 89411, "Enhanced Oil Recovery by Steamflooding in a Recent Steamflood Project, Cruse 'E' Field, Trinidad," by V. Ramlal, SPE, Petrotrin, prepared for the 2004 SPE/DOE Symposium on Improved Oil Recovery, Tulsa, 17-21 April.
On the basis of the success of the Cruse ‘E’ Pilot steamflood in Trinidad, Petrotrin decided to expand the thermal project. The project was commissioned in January 1996 when steam injection began. In November 1998, environmental concerns in a residential area near the steamflood required project shutdown. This paper discusses the performance of the steamflood during steam injection and during the shutdown period, the operational and economic aspects of the project, and the environmental upgrade conducted to restart the project.

Introduction
The Cruse ‘E’ steamflood is in the Parrylands area of southwestern Trinidad, 8 miles from the town of Point Fortin. It is one of several active thermal projects operated by Petrotrin and is the most recent steamflood developed by the company. The Cruse ‘E’ Expansion steamflood was undertaken following the success of the Cruse ‘E’ Pilot Project. With loan financing from the Inter-American Development Bank (IADB), 28 new patterns were formed by drilling 60 wells and incorporating 35 existing wells in the thermal area. Steam-generation and -distribution equipment and production facilities were installed during 1995, and steam injection began in January 1996. The shallow Cruse ‘E’ sands were ideal for steamflooding, and response was obtained in only 9 months. After 22 months, production reached 1,200 BOPD. For environmental reasons, the flood was shut down in November 1998, and approval was not obtained to restart until March 2002.
Factors that contribute to the success of this project include large reserves of shallow heavy oil (average gravity of 17°API); reliable, adequate supplies of fresh water for injection and natural gas for steam generation; good reservoir continuity within the project limits; 30 years’ accumulated company expertise in enhanced oil recovery; and the success of the pilot project.
Overview: Well Intervention and Control (January 2005)
Authors: Barnett David 
Published: February 2015

Advances in well-control theory and practical applications continue to be developed and refined. Some of the most significant advances, and those that often appear in the literature as case histories, are those developed by multidisciplinary teams.
Problems that have plagued the industry for years are being dealt with by teams comprising specialists with expertise in drilling, geology, flu-ids, cementing, and reservoir engineering, to name a few. These problems are not necessarily those that arise solely from deeper drilling, harsh environments, or extreme water depths. They are age-old problems such as shallow gas, sustained casing pressure, and primary well-control procedures (i.e., kick detection and circulation).
Because these problems have been with us so long, partial solutions have been developed that at least allow us to continue drilling and producing, even in notoriously problematic areas. However, the number of unrecognized and mishandled influxes, shallow-gas events, flows after cementing, and producing wells with sustained casing pressure is just an indication that better solutions are needed.
It is encouraging to see the continuing effort from both operators and service companies to improve the materials and methods used to mitigate some of the longstanding well-control problems. This effort is not the typically high-profile, cutting-edge work that garners much of the attention in the industry. It is the practical effort aimed at applying new technology or new solutions to recurring problems.
Additional Well-Intervention and -Control Technical Papers
Available at the SPE eLibrary: www.spe.org
SPE 86706 - Comparison of Quantitative Blowout-Risk-Assessment Approaches
SPE 91009 - Gas Solubility in Synthetic Fluids: A Well-Control Issue
SPE 90427 - Software Simulation and System Design of Dynamic Killing Technique
Microannulus Leaks Repaired With Pressure-Activated Sealant
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper SPE 91399, "Microannulus Leaks Repaired With Pressure-Activated Sealant," by David W. Rusch, SPE, Seal-Tite Intl.; Fred Sabins, SPE, Cementing Solutions Inc.; and John Aslakson, SPE, W&T Offshore Inc., prepared for the 2004 SPE Eastern Regional Meeting, Charleston, West Virginia, 15-17 September.
Sustained casing pressure (SCP) is a serious problem that is prevalent in most of the oil-producing regions of the world. Annular pressure can be a significant safety hazard and has resulted in blowouts on a number of occasions. SCP is the result of fluid migration in the annulus. The most common path for fluid migration is through channels in the annular cement. An injectable pressure-activated sealant was used to seal channels in the annular cement of several wells in the Gulf of Mexico (GOM).

Introduction
Fluid migration through the annuli of well-bores can result in a condition known as SCP. SCP is pressure that rebuilds in the annulus after being bled down. The integrity of all wellbores deteriorates with age. Cracks and fissures caused by factors related to cement composition, thermal stress, hydraulic stress, and compaction develop in the annular cement. The most significant cause of SCP in outer casing strings is a poor cement bond that results in cracks and annular channels. The cracks and microannulus channels provide a path for high-pressure fluids to migrate. A significant flow of high-pressure fluids can result in an underground blowout or failure of wellbore integrity.
Opening New Exploration Frontiers With the Microflux-Control Method for Well Design
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper OTC 16622, "Opening New Exploration Frontiers With the Micro-Flux-Control Method for Well Design," by H. Santos, SPE, C. Leuchtenberg, and P. Reid, SPE, Impact Solutions Group, and A. Lage, SPE, Petrobras, originally presented at the 2004 Offshore Technology Conference, Houston, 3-6 May.
The new Microflux-control (MFC) method introduces several features that reduce the risks of conventional drilling, allowing a revision of the current set of well-design criteria. The full-length paper describes these new criteria and shows their benefit in terms of risk reduction and increased operational limits. The MFC method introduces new well-control concepts and addresses pore-pressure uncertainties. This drilling method allows reserves located in challenging areas to be explored more safely and economically.

Introduction
Reserves decline in mature basins has led the oil industry to move into more-challenging environments with increased drilling costs and risks. New drilling techniques need to be developed and used to exploit these new reserves economically.
Because the industry is very conservative, a long time usually is required for changes to be accepted and used to full potential. In many situations where new and advanced techniques are used, a traditional well design still is used with old numbers and concepts. Sometimes, regulatory bodies do not allow use of more-aggressive thinking even when it is based on and supported by successful tests. In other situations, rig contractors may be reluctant to accept the risks on their rigs or there may be insurance restrictions. Ultimately, it is the operator who has to accept and understand the benefits of introducing new techniques so that wells can be drilled to total depth (TD). Having introduced the MFC method in previous publications, the authors concentrate in the full-length paper on the benefits the method can provide in various environments.
Gate-Valve Milling Operation Performed With Coiled Tubing
Authors: Bybee Karen 
Published: February 2015

This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper SPE 96685, "Pioneering ‘Gate Valve Milling’ Operation Performed With Coiled Tubing, Recovers an Important Oil Producer Offshore Brunei," by N.M. Al Araimi, SPE, Brunei Shell Petroleum; B. Gedge, SPE, and K. Burns, Weatherford; and M. Mahajan, SPE, BJ Services, prepared for the 2005 SPE Annual Technical Conference and Exhibition, Dallas, 9-12 October.
Brunei Shell Petroleum offshore Well A was shut in because the 3 1/8-in. master valve on the 5,000-psi monoblock tree was stuck in the closed position because of scale. Two options were considered for recovering the well with well intervention techniques rather than a complete workover and well-kill operation. Because the nearest gate-valve milling machine was in Europe, the valve was milled by use of a coiled-tubing (CT) unit that was on the platform performing a stimulation program on adjoining wells. This operation had been performed only once before, in the North Sea.

Summary
During routine wellhead maintenance, the lower master gate valve on Well A was found to be stuck in the closed position, most likely because of a broken stem related to scale buildup and attempts to open the valve. A number of attempts to free the seized valve by turning the wheel handle failed. The lost production caused by this well being offline was 1,260 BOPD, with a monetary loss of U.S. $1.9 million for every 30-day period.
Calcium carbonate scaling tendencies were identified as a likely cause of both the valve seizure and the progressive production decline observed since completion. A hydrochloric acid (HCl) soak treatment was performed, pumping 20 to 25 bbl acid into the wellbore. This treatment did not return the valve to operable service.
The HCl soak treatment was repeated. Because the gate valve was closed, this treatment consisted of a series of 1- to 1.5-bbl acid soak pills that were pumped and left to soak on top of the closed valve. After several hours, each spent pill was displaced through the flow wing outlet. This treatment also was not successful.
An alternative approach was required, and its timing was driven by a compliance need to access and test the subsurface safety valve (SSSV) that was beneath the gate valve. Milling would allow throughbore access to test the SSSV and set plugs to allow tree repair.

Considerations
Use of a gate-valve milling machine has proved to be successful in the past in a number of locations in the world, particularly in geothermal operations, where tree valve seizure is a common occurrence because of the often high scale production and cooling at surface, causing scale precipitation. The problem for this option was that the only unit available was in Europe. To mobilize the unit to Brunei would be expensive and time consuming, and additional equipment like blowout preventers (BOPs) also would have to be mobilized, making this a very expensive option, even if it was sound technically.