bluuebunny/crossref_metadata_2025_split huggingface dataset:
Comparing Suture Strengths for Clinical Applications: A Novel In Vitro Study
Authors: Vasanthan Asvin , Satheesh Keerthana , Hoopes Wyeth , Lucaci Patrick , Williams Karen , Rapley John 
Published: March 2009

Background: The purpose of this study was to compare the tensile strengths of commonly used sutures over a 2‐week period under simulated oral conditions.Methods: Three suture materials (chromic gut [CG], polyglactin [PG], and polyglactin‐fast absorbing [PG‐FA]) were used in 4‐0 and 5‐0 gauges. After pretensioning, 252 suture samples (42 of each material and gauge) were used. A biologic simulation was created in vitro by mixing 9 ml sterile human saliva and human serum in a 1:1 ratio in a petri dish maintained at a pH of 7.4 to 8.1 at 37°C. All samples were tested preimmersion and 1 hour and 1, 3, 7, 10, and 14 days postimmersion. The tensile strength was assessed using a microtensile tester, and the maximum load required to cause suture breakage was determined. The point of breakage in the samples and the samples themselves were also assessed.Results: During the first 24 hours of immersion, all 4‐0 and 5‐0 samples of CG and PG maintained their initial level of tensile strength; PG‐FA 5‐0 decreased in strength, which was statistically significant (P = 0.001). Between days 1 and 3, the tensile strength of PG and PG‐FA decreased significantly, with PG‐FA 5‐0 showing a greater and more precipitous decrease than PG‐FA 4‐0; the tensile strength of CG changed little during this time. After 7 days of immersion, PG 4‐0 had significantly greater tensile strength than CG, and both were significantly greater than that of PG‐FA. By day 10, CG and PG had statistically greater strength (P = 0.01) than PG‐FA, and values were similar for the 4‐0 and 5‐0 gauge materials. All samples of PG‐FA 5‐0 and most samples of the PG‐FA 4‐0 exhibited 0.00 N strength (i.e., they had disintegrated) at the 10‐ and 14‐day periods of evaluation.Conclusions: 4‐0 sutures are stronger and have greater tensile strength than 5‐0 sutures. CG seems to sustain its strength better than PG and PG‐FA after 2 weeks. PG‐FA may not be a desirable suture if tensile strength is required after 10 days. Appropriately designed clinical studies are necessary to confirm this finding in an in vivo environment.
Circulating Interleukin‐6 and High‐Sensitivity C‐Reactive Protein Decrease After Periodontal Therapy in Otherwise Healthy Subjects
Authors: Marcaccini Andrea M. , Meschiari César A. , Sorgi Carlos A. , Saraiva Maria C.P. , de Souza Ana M. , Faccioli Lúcia H. , Tanus‐Santos José E. , Novaes Arthur B. , Gerlach Raquel F. 
Published: March 2009

Background: Periodontal disease has been associated with many chronic inflammatory systemic diseases, and a common chronic inflammation pathway has been suggested for these conditions. However, few studies have evaluated whether periodontal disease, in the absence of other known inflammatory conditions and smoking, affects circulating markers of chronic inflammation. This study compared chronic inflammation markers in control individuals and patients with periodontal disease and observed whether non‐surgical periodontal therapy affected inflammatory disease markers after 3 months.Methods: Plasma and serum of 20 controls and 25 patients with periodontal disease were obtained prior to and 3 months after non‐surgical periodontal therapy. All patients were non‐smokers, they did not use any medication, and they had no history or detectable signs and symptoms of systemic diseases. Periodontal and systemic parameters included probing depth, bleeding on probing, clinical attachment level, hematologic parameters, as well as the following inflammatory markers: interleukin (IL)‐6, high‐sensitivity C‐reactive protein (hs‐CRP), CD40 ligand, monocyte chemoattractant protein (MCP)‐1, soluble P‐selectin (sP‐selectin), soluble vascular adhesion molecule (sVCAM)‐1, and soluble intercellular adhesion molecule (sICAM)‐1.Results: There were no differences in the hematologic parameters of the patients in the control and periodontal disease groups. Among the tested inflammatory markers, IL‐6 concentrations were higher in the periodontal disease group at baseline compared to the controls (P = 0.006). Therapy was highly effective (P <0.001 for all the analyzed clinical parameters), and a decrease in circulating IL‐6 and hs‐CRP concentrations was observed 3 months after therapy (P = 0.001 and P = 0.006, respectively). Our results also suggest that the CD40 ligand marker may have been different in the control and periodontal disease groups prior to the therapy (P = 0.009).Conclusions: In apparently otherwise healthy patients, periodontal disease is associated with increased circulating concentrations of IL‐6 and hs‐CRP, which decreased 3 months after non‐surgical periodontal therapy. With regard to the CD40 ligand, MCP‐1, sP‐selectin, sVCAM‐1, and sICAM‐1, no changes were seen in the periodontal disease group between baseline and 3 months after therapy.
Working With Coiled Tubing in H2S and CO2 Wells: A Global Perspective
Authors: Hampson R. , Moir C. , Freeney T. 
Published: March 2009

Abstract
The use of coiled tubing (CT) in wells containing hydrogen sulfide gas (H2S) has associated problems because of the potential for sulfide stress cracking (SSC) of the CT material. Carbon dioxide (CO2) can also contribute to general corrosion or intensify any H2S-related corrosion because of chemical reactions resulting in acid. However, with the right precautions, equipment, and procedures, this type of operation can be carried out safely and successfully.
The various problems associated with working with CT in H2S and CO2 wells are discussed and a general best practice taken from locations working regularly with H2S and CO2 is presented. This paper shows the equipment, chemical inhibitor, quantity and method of inhibitor application, and other precautions taken to carry out the work safely and successfully. An alternative approach is also highlighted for some situations whereby any H2S is bullheaded into the well before coiled-tubing intervention. This alternative approach avoids any contact of H2S with CT to prevent corrosion. A number of case histories are shown for different H2S and/or CO2 locations around the world, which detail the type of operations, quantity of H2S and CO2, procedures used, frequency of operations, and the overall success of these methods in ongoing operations.
This paper presents a review of methods and equipment currently being used around the world to work in potentially corrosive and dangerous H2S and/or CO2 wells.
Corrosion Fatigue of Grade-90 Pipe in 15% and 28% Hydrochloric Acid With and Without Inhibitor
Authors: Ehtesham Asif , Freeney Timothy , Hampson Richard 
Published: March 2009

Abstract
Coiled tubing (CT) is routinely exposed to different concentrations of acid in stimulation and cleanout jobs. Routine maintenance measures are generally taken, such as the use of inhibitors and proper cleanup and storage practices. However, a large number of CT strings suffer from corrosion and corrosion-fatigue related damage. Though it is difficult to isolate string damage solely from corrosion fatigue, this paper addresses the effect of acid with and without inhibitors on corrosion-fatigue properties of the grade-90 pipe through experimental testing. The results of testing demonstrate that exposure to acid without an inhibitor and during fatigue had the most pronounced effect on fatigue life. The simultaneous action of corrosion and fatigue produced more pits and cracks than would have occurred by corrosion or fatigue separately.
CT exposure to acid before, during, and after bending can have different effects on fatigue life. This paper describes an experimental study that was conducted to observe these effects. A strip of metal, 1-in. wide and 6-in. long, was cut from a round 1.75-in. OD, 1.56-in. wall thickness of 90-ksi yield CT and underwent one-way, bent-beam fatigue testing. This paper will present S-N curves generated for samples in three environments: air, acid, and acid with inhibitor at deflection levels ranging from 0 to 40 mm. Finite element analysis (FEA) was used to correlate deflection to strain range levels of 0.5 to 4.0%.
Damaged Control Line Replacement Safety Valve System: Thru-Tubing
Authors: Bolding Jeff L. , Embrey Mark R. , Mondelli Max E. , Sanders Don L. 
Published: March 2009

Abstract
Description: A wireline insert, Surface Contror permission to publish this paper. A special thanks to BJ tools specialiolled Sub-Surface Safety Valve (SCSSV), has been successfully installed for an operator in the Gulf of Mexico, in a well, which had lost control line integrity. The new Control line was installed "thru-tubing", using capillary tubing and wireline disciplines.
Application: The Minerals Management Service (MMS) reluctantly grants variances to oil and gas operators who request permits to install storm chokes, on wells which have lost control line integrity. Storm chokes do not allow for surface control and are less safe than the mandated SCSSV's. The new system has been MMS approved and offers operators a safer alternative, which is less costly than a workover and more flexible than a strom choke or velocity valve.
Results, Observations, Conclusions: The new system was installed and the well is flowing trouble free whilst having complete surface control capability. Subsequently, the operator has had the flexibility to substantially increase the production rate avoiding the necessity of adjusting differential pressure settings as with a velocity type valve.
This system has an enormous impact on the environment and economics. The most reliable method of controlling a subsurface safety valve is with a direct hydraulic system. Preserving use of a direct control system has historically been a focus of operators and encouraged by governing bodies. Reconnecting direct control of the safety valve relieves operators and governing officials from having to make difficult decisions regarding a safety issue. Aside from the apparent safety advantage, the system presents economical advantages as well. Operators maintain the option for flowing at maximum rates and are relieved of frequent maintanence expenses associated with velocity type devices. Case in point, the operator has had the ability to adjust production rates from 1 mmcfd to 5.2 mmcfd.
Significance of Subject Matter: This system has an enormous impact on economics and the environment. Considering the single pod well, the operator now has the option to negate the bi-annual inspection of a storm choke or velocity valve, which would require a lift boat operation each time. Additionally, this API 14A product will prevent the necessity of a workover, avoiding costs which may render the remaining reserves, uneconomic.
Success Story of Regaining Full-Bore Access to Formation Following Failure of Attempted Cement Squeeze Using Thru Tubing Under Reaming Technology
Authors: Ghani Siti Alsyah Binti Abdul , Haner Kyle , Robinson Larry , Rossing Mike 
Published: March 2009

Abstract
A certain Field development is located offshore Malaysia in 60 meters of water. Well B-10 was drilled in 1991 with deviations up to 69° and was completed as a dual string producer from sands E-12/13 in the short string and E-14 in the long string via two strings of 2-7/8" tubing in 9-5/8" 40 lbs/ft casing. In 2008, the E-14 sand was no longer productive with a water cut of 95% and so a water shut-off initiative was performed using a coiled tubing cement squeeze. The job resulted in failure probably due to the less than expected rate of cement fluid loss into the formation resulting in its unintentionally plugging the casing and tubing and blocking access to the formation for reperforating.
To regain access to the casing and the E-14 sand, it was necessary to perform two procedures with coiled tubing (CT); to mill the cement in the tubing and to underream the 9-5/8" casing thru the 2-7/8" tubing. The extended reach required to clean the tubular down to the casing wall posed a major challenge with the possibility of getting the underreamer stuck in the tailpipe, being unable to retract it to re-enter the tubing or damaging the tubing and/or the completion equipment during retrieval. The milling and under-reaming job were successfully carried out despite the challenges, including milling cement in the 9-5/8" casing, high 69°deviation, high tool expansion requirement from 2-7/8" tubing to 9-5/8" casing and the use of nitrogen as a motor drive fluid.
In this paper the authors will review the history of the well and the problems that lead to the cement job being performed, the reasons for the subsequent problems and the consequences of failure. Subsequently, the paper will review in detail the risks involved in the proposed procedure and the new technology offered. The paper will also discuss the cleanout procedure which was performed successfully and re-established full bore access to the perforations.
New Performance-Tracking System Enhances Knowledge Management and Provides Valuable Assistance in Well Planning and Procedure Evaluation on a Global Basis
Authors: Rossing Mike , Hammond Blake Thomas , Green Steve 
Published: March 2009

Abstract
To this day the words "we tried that before and it didn't work then either" are too often heard when a procedural problem occurs. This is arguably because work records have historically been stored on a well by well basis in filing cabinets or on field service engineer's hard drives with no centralized, globally accessible capability to allow gathering and comparison of data pertaining to similar operations anywhere in the world. As a result a means of making cross reference to what happened on other wells when a given procedure or product application is being considered can be difficult, if not impossible. There is clearly a need for a different approach to procedural and product performance record keeping that will facilitate comparison with previous applications on a global basis and provide a means of evaluating the risk and the chances of success.
The adoption of the Internet by business provided the opportunity to create a single database from a multitude of desktop databases and spreadsheets. With this end in mind the Performance Tracking System (PTS) was conceived to provide a method of storing product utilization and performance data on a global basis that could provide instant access to the results obtained, allowing a means to evaluate and plan any given procedure based on historical performance. This in turn allows an evaluation to be made as to how the product or procedure could be expected to perform when used in a given set of parameters. This system, which has been in use now since 2002 and is now implemented company wide, provides a means of cataloging performance across a full spectrum of product lines and well conditions and as the body of accumulated data has grown so it can provide comparative analysis for any given worldwide operational area, regardless of end user, to the benefit of all operations. It utilizes the features of a simple "asset tracking system" while providing a means of resolving the myths and perceptions associated with the phrase. The PTS provides a means of answering thousands of independent questions but perhaps foremost among them, "has this been done this way before and how successful was the outcome" can be answered with certainty.
In this paper the authors will discuss the concept of the PTS, how it was designed and the methods used to implement the gathering and storage of data in an instantly recoverable manner. They will go on to provide examples of how the system has been used to assist in well planning, to resolve disagreements on procedural matters and to set up a position ahead of the curve in knowledge management to the benefit of working relationships between supplier and customer.
Applying Well-Remediation Techniques to Subsea Flowlines in Deepwater Gulf of Mexico
Authors: Hudson Lisa A. , Bowen Gregor J. , Breithaupt Truman A. 
Published: March 2009

Abstract
Flow assurance in subsea production flow lines is becoming more prevalent as deepwater well developments continue to grow. Coiled tubing (CT), though traditionally used in wellbore environments, can be utilized to address flow assurance.
Complications are possible when applying CT technology in a nonconventional environment. Connection tie-ins and available deck area are typically incompatible with intervention-type activities, and challenging issues such as weight limitations, nature of blockage, and weather sensitive environments lead to the need for elaborate planning with multiple contingencies to address the uncertainties. Our study investigated the operational planning and logistical requirements associated with the radiation of the flow assurance for the Serrano flowline.
The Serrano flowline is located in the Gulf of Mexico (GOM), in 3,500 ft of water and is tied back 6 miles to the Auger TLP. Three subsea wells have produced through the electrically heated Serrano flowline since 2001. In November 2006, there was an unplanned shutdown of the flowline and despite numerous attempts to restart, the wells had failed to flow.
In December 2007, after 6 months of intensive and complex planning, a standalone CT operation was successfully performed while drilling operations continued on the main rig. The operations consisted of utilizing a unique small footprint compensation frame to allow access to the flowline from a confined area. Then a 1-1/2-in CT string was deployed into the flowline to retrieve a sample of the blockage for diagnostic purposes. The analysis of the sample dictated the optimal cleanout strategy which was to combine a specialized rotary nozzle with pumping diesel and solvents to successfully clean out the flowline. The blockage was breached at a depth of 3,700 ft after cleaning almost 1,000 ft in less than 24 hours. The flowline was reinstated and gas production restored to &gt;2,000 bbl/d and 8 MMcf, thus preventing the client from losing the lease.
Wireline Tractor Milling Operations From a Riserless Light-Well Intervention Vessel at the High-Temperature Åsgard Field
Authors: Juel Henning , Ranum Håvard , Mjaaland Svein , Varne Terje , Solberg Dag Birger , Bjorndal Rune 
Published: March 2009

Abstract
Intervention with scale milling on subsea wells have traditionally been performed with semi submersible rigs and heavy intervention equipment as coiled tubing. Riserless Light Well Intervention (RLWI) with wireline has so far been a practical and cost efficient alternative in the subsea intervention marked. The on-going development of wireline tractor technology including milling bits has increased the scope of work for RLWI to include mechanical scale removal.
This paper describes a case history of first time use of wireline tractor scale milling technology in a well on the high temperature Åsgard field deployed from a RLWI vessel. The well had a history of calcium carbonate scale build in the production liner first seen in 2003. The well had been intervened using coiled tubing in 2003 without being able to remove all the scale bridges completely.
The objective of the intervention was to remove a 23 m calcium carbonate scale bridge to provide access for installation of a high pressure high temperature (HPHT) bridge plug and permit subsequent additional perforation work. An electric wireline conveyed tractor with a rotational assembly was chosen to perform the job.
A qualification test programme was performed to confirm that the selected wireline tractor and milling assembly could operate reliably in an environment up to 166 °C for extended periods without tool failures. The maximum well temperature was 152 °C. Following successful trials in the test facility the equipment was mobilized to the RLWI vessel.
The scale bridge of 23 m was milled in 3 runs with a 5.72" custom designed milling bit. Subsequent operations were successful with installation of a HPHT bridge plug and completion of four additional perforation runs.
The production results after the intervention was an oil increase from 468 Sm3/d to 1204 Sm3/d. The Gas Oil Ratio was decreased from 3500 Sm3/Sm3 to 2750 Sm3/Sm3. The successful operation by scale milling on the Smørbukk field has demonstrated that wireline tractor scale milling technology can be used on high temperature wells using the RLWI concept.
Subsea-Pipeline Intervention With Coiled Tubing From a Supply Vessel
Authors: Pepin Alexandre , Spadaro Angelo 
Published: March 2009

Abstract
Coiled tubing (CT) pipe has been successfully used in the past to clean and abandon in situ subsea pipelines in offshore areas where conventional industrial approaches (i.e., pigging, flushing or suction) were not feasible. The technique of using CT has been explored before and the subject has been covered in previous SPE papers1. The basis of the previous work relies on the CT pipe's strength to be pushed through long, horizontal lines and its ability to convey tools and fluids at once.
One of the main limitations, however, in using CT for pipeline interventions in offshore environments as opposed to the traditional methods is the amount of equipment required on board. In most cases, deck space, loading constraints and operational factors such us seabed, heave, or current direction, fixed have posed significant challenges. These challenges have been addressed in some specific cases for production platforms, jack-up boats, or dynamically positioned (DP) monohull vessels. However, traditional coiled tubing intervention will not always provide a feasible solution.
A particular operationally challenged subsea pipeline intervention exists in the Congo delta. The pipeline, which linked two production platforms, had been plugged with organic deposits and two pigs from an initial cleanup attempt in November 2004.
Subsequent conventional trials failed to break through these obstructions, so CT was proposed as a feasible alternative. The platform's deck space and crane load capacity, 4-knot sea currents rich in alluviums and products from the Congo river, and 46-ft seabed that used either jack-up boats or DP vessels not an option. This paper discusses the unique solution developed to address the operational and technical challenges of this difficult environment