bluuebunny/crossref_metadata_2025 huggingface dataset:
Funding Oncology Clinical Trials: Are Cooperative Group Trials Sustainable?
Authors: Seow Hsien-Yeang , Whelan Patrick , Levine Mark N. , Cowan Kathryn , Lysakowski Barbara , Kowaleski Brenda , Snider Anne , Xu Rebecca Y. , Arnold Andrew
Published: March 2012

Purpose

Many oncology clinical trials departments (CTDs) are in serious fiscal deficit and their sustainability is in jeopardy. This study investigates whether the payment models used to fund industry versus cooperative group trials contribute to the fiscal deficit of a CTD.

Methods

We examined the lifetime costs of all cooperative group and industry trials activated in the CTD of a cancer center between 2007 and 2011. A trial's lifetime is defined as being from the date the first patient was accrued until the last patient's actual or projected final follow-up visit. For each trial, we calculated the lifetime monthly net income, which was defined as monthly revenue minus monthly costs. Data sources included study protocols, trial budgets, and accrual data.

Results

Of the 97 trials analyzed, 64 (66%) were cooperative group trials. The pattern of lifetime net income for cooperative group trials has a positive peak during patient accrual followed by a negative trough during follow-up. In contrast, the pattern for industry trials resembled an “l” shape. The patterns reflect the differing payment models: upfront lump-sum payments (cooperative group) versus milestone payments (industry).

Conclusion

The negative trough in the lifetime net income of a cooperative group trial occurs because follow-up costs are typically not funded or are underfunded. CTDs accrue more patients in new trials to offset that deficit. The CTD uses revenue from accrual to existing trials to cross-subsidize past trials in follow-up. As the number of patients on follow-up increases, the fiscal deficit grows larger each year, perpetuating the cycle.
Marked, Homogeneous, and Early [18F]Fluorodeoxyglucose–Positron Emission Tomography Responses to Vemurafenib in BRAF-Mutant Advanced Melanoma
Authors: McArthur Grant A. , Puzanov Igor , Amaravadi Ravi , Ribas Antoni , Chapman Paul , Kim Kevin B. , Sosman Jeffrey A. , Lee Richard J. , Nolop Keith , Flaherty Keith T. , Callahan Jason , Hicks Rodney J.
Published: March 2012

Purpose

Imaging with [18F]fluorodeoxyglucose (FDG) –positron emission tomography (PET) allows early recognition of a response to agents that target key driver mutations in human cancer. We aimed to determine the metabolic response rate to vemurafenib in patients with advanced BRAF-mutant melanoma.

Patients and Methods

Baseline and day 15 FDG-PET was evaluated in 31 patients with advanced melanoma treated in a phase I study of dose escalation of vemurafenib (PLX06-02), which included four patients treated at subtherapeutic doses and 24 patients treated at 960 mg twice a day, which is the maximum-tolerated dose of vemurafenib.

Results

All 27 patients treated at potentially therapeutic levels had at least a partial metabolic response, and three patients achieved a complete metabolic response. In the 27 patients, there was an 80% ± 3% reduction in the maximum standardized uptake value (SUVmax) of target lesions and an 87% ± 3% decrease in the percentage of injected dose (%ID) in all identified disease sites. There was a positive correlation between %ID in all identified disease and target-lesion SUVmax (r2 = 0.66; P < .001) that indicated a significant homogeneity of the response between lesions in individual patients. Although no relationship was found between the reduction in target lesion SUVmax and best response according to RECIST (Response Evaluation Criteria in Solid Tumors), there was a trend for patients with greater reductions in uptake of FDG to have longer progression-free survival.

Conclusion

FDG-PET is a useful marker of an early biologic response to vemurafenib. Little variability in PET response was found between lesions in individual patients, which suggested minimal intrapatient molecular heterogeneity. FDG-PET is a useful tool for the evaluation of the biologic impact of inhibiting mutant BRAF and may allow for the more effective development of novel agents.
Impact of Age and Comorbidity on Non–Small-Cell Lung Cancer Treatment in Older Veterans
Authors: Wang Sunny , Wong Melisa L. , Hamilton Nathan , Davoren J. Ben , Jahan Thierry M. , Walter Louise C.
Published: March 2012

Purpose

Because comorbidity affects cancer treatment outcomes, guidelines recommend considering comorbidity when making treatment decisions in older patients with lung cancer. Yet, it is unclear whether treatment is targeted to healthier older adults who might reasonably benefit.

Patients and Methods

Receipt of first-line guideline-recommended treatment was assessed for 20,511 veterans age ≥ 65 years with non–small-cell lung cancer (NSCLC) in the Veterans Affairs (VA) Central Cancer Registry from 2003 to 2008. Patients were stratified by age (65 to 74, 75 to 84, ≥ 85 years), Charlson comorbidity index score (0, 1 to 3, ≥ 4), and American Joint Committee on Cancer stage (I to II, IIIA to IIIB, IIIB with malignant effusion to IV). Comorbidity and patient characteristics were obtained from VA claims and registry data. Multivariate analysis identified predictors of receipt of guideline-recommended treatment.

Results

In all, 51% of patients with local, 35% with regional, and 27% with metastatic disease received guideline-recommended treatment. Treatment rates decreased more with advancing age than with worsening comorbidity for all stages, such that older patients with no comorbidity had lower rates than younger patients with severe comorbidity. For example, 50% of patients with local disease age 75 to 84 years with no comorbidity received surgery compared with 57% of patients age 65 to 74 years with severe comorbidity (P < .001). In multivariate analysis, age and histology remained strong negative predictors of treatment for all stages, whereas comorbidity and nonclinical factors had a minor effect.

Conclusion

Advancing age is a much stronger negative predictor of treatment receipt among older veterans with NSCLC than comorbidity. Individualized decisions that go beyond age and include comorbidity are needed to better target NSCLC treatments to older patients who may reasonably benefit.
A GATA/homeodomain transcriptional code regulates axon guidance through the Unc-5 receptor
Authors: Zarin Aref Arzan , Daly Amanda C. , Hülsmeier Jörn , Asadzadeh Jamshid , Labrador Juan-Pablo
Published: March 2012

Transcription factor codes play an essential role in neuronal specification and axonal guidance in both vertebrate and invertebrate organisms. However, how transcription codes regulate axon pathfinding remains poorly understood. One such code defined by the homeodomain transcription factor Even-skipped (Eve) and by the GATA 2/3 homologue Grain (Grn) is specifically required for motor axon projection towards dorsal muscles in Drosophila. Using different mutant combinations, we present genetic evidence that both Grn and Eve are in the same pathway as Unc-5 in dorsal motoneurons (dMNs). In grn mutants, in which dMNs fail to reach their muscle targets, dMNs show significantly reduced levels of unc-5 mRNA expression and this phenotype can be partially rescued by the reintroduction of unc-5. We also show that both eve and grn are required independently to induce expression of unc-5 in dMNs. Reconstitution of the eve-grn transcriptional code of a dMN in dMP2 neurons, which do not project to lateral muscles in Drosophila, is able to reprogramme those cells accordingly; they robustly express unc-5 and project towards the muscle field as dMNs. Each transcription factor can independently induce unc-5 expression but unc-5 expression is more robust when both factors are expressed together. Furthermore, dMP2 exit is dependent on the level of unc-5 induced by eve and grn. Taken together, our data strongly suggests that the eve-grn transcriptional code controls axon guidance, in part, by regulating the level of unc-5 expression.
Both Sm-domain and C-terminal extension of Lsm1 are important for the RNA-binding activity of the Lsm1–7–Pat1 complex
Authors: Chowdhury Ashis , Raju Kalidindi K. , Kalurupalle Swathi , Tharun Sundaresan
Published: March 2012

Lsm proteins are a ubiquitous family of proteins characterized by the Sm-domain. They exist as hexa- or heptameric RNA-binding complexes and carry out RNA-related functions. The Sm-domain is thought to be sufficient for the RNA-binding activity of these proteins. The highly conserved eukaryotic Lsm1 through Lsm7 proteins are part of the cytoplasmic Lsm1–7–Pat1 complex, which is an activator of decapping in the conserved 5′–3′ mRNA decay pathway. This complex also protects mRNA 3′-ends from trimming in vivo. Purified Lsm1–7–Pat1 complex is able to bind RNA in vitro and exhibits a unique binding preference for oligoadenylated RNA (over polyadenylated and unadenylated RNA). Lsm1 is a key subunit that determines the RNA-binding properties of this complex. The normal RNA-binding activity of this complex is crucial for mRNA decay and 3′-end protection in vivo and requires the intact Sm-domain of Lsm1. Here, we show that though necessary, the Sm-domain of Lsm1 is not sufficient for the normal RNA-binding ability of the Lsm1–7–Pat1 complex. Deletion of the C-terminal domain (CTD) of Lsm1 (while keeping the Sm-domain intact) impairs mRNA decay in vivo and results in Lsm1–7–Pat1 complexes that are severely impaired in RNA binding in vitro. Interestingly, the mRNA decay and 3′-end protection defects of such CTD-truncatedlsm1mutants could be suppressed intransby overexpression of the CTD polypeptide. Thus, unlike most Sm-like proteins, Lsm1 uniquely requires both its Sm-domain and CTD for its normal RNA-binding function.
Epidemiology and Diagnosis of Health Care–Associated Infections in the NICU
Authors: Polin Richard A. , Denson Susan , Brady Michael T. ,   the COMMITTEE ON FETUS AND NEWBORN,   the COMMITTEE ON INFECTIOUS DISEASES, Papile Lu-Ann , Baley Jill E. , Carlo Waldemar A. , Cummings James J. , Kumar Praveen , Polin Richard A. , Tan Rosemarie C. , Watterberg Kristi L. , Byington Carrie L. , Davies H. Dele , Edwards Kathryn M. , Glode Mary P. , Jackson Mary Anne , Keyserling Harry L. , Maldonado Yvonne A. , Murray Dennis L. , Orenstein Walter A. , Schutze Gordon E. , Willoughby Rodney E. , Zaoutis Theoklis E.
Published: March 2012

This Technical Report was reaffirmed March 2023.

Health care−associated infections in the NICU are a major clinical problem resulting in increased morbidity and mortality, prolonged length of hospital stays, and increased medical costs. Neonates are at high risk for health care−associated infections because of impaired host defense mechanisms, limited amounts of protective endogenous flora on skin and mucosal surfaces at time of birth, reduced barrier function of neonatal skin, the use of invasive procedures and devices, and frequent exposure to broad-spectrum antibiotics. This statement will review the epidemiology and diagnosis of health care−associated infections in newborn infants.
Leukemia- and lymphoma-associated flow cytometric, cytogenetic, and molecular genetic aberrations in healthy individuals
Authors: Jakó János , Szerafin László
Published: March 2012

Most leukemia and lymphoma cases are characterized by specific flow cytometric, cytogenetic and molecular genetic aberrations, which can also be detected in healthy individuals in some cases. The authors review the literature concerning monoclonal B-cell lymphocytosis, and the occurrence of chromosomal translocations t(14;18) and t(11;14), NPM-ALK fusion gene, JAK2 V617F mutation, BCR-ABL1 fusion gene, ETV6-RUNX1(TEL-AML1), MLL-AF4 and PML-RARA fusion gene in healthy individuals. At present, we do not know the importance of these aberrations. From the authors review it is evident that this phenomenon has both theoretical and practical (diagnostic, prognostic, and therapeutic) significance. Orv. Hetil., 2012, 153, 531–540.
Dynamic nanoscale in situ TEM tribology
Authors: Lockwood A J , Anantheshwara K , Bobji M S , Inkson B J
Published: March 2012

Nanotribology, the study of friction, wear and lubrication at the nanoscale is an important area of research; however in practice due to the size scale, requires specifically designed tools to characterize nanoscale contacts. We have developed a TEM triboprobe incorporating an advanced nano-positioner with 3D programmable motion inside a transmission electron microscope (TEM) which allows us to selectively apply multiple reciprocating wear cycles to a nanoscale surface, and observe in real-time dynamical changes and the evolution of wear around a sliding nano-contact.

Nanoscale cyclic rubbing of an automotive aluminum-silicon alloy processed by focused ion beam (FIB) reveals dynamical surface fragmentation and the generation of nanoscale debris particles. The nanoparticles undergo complex motion as they interact with the sliding nano-contact. Over hundreds of reciprocating cycles, frictional heating leads to a phase separation of the Ga+ ions implanted by FIB forming liquid Ga nano-droplets and liquid bridges. The addition of nanoscale debris particles and liquid droplets dramatically changes the wear dynamics and transforms a 2-body sliding contact into a complex 4-body solid–liquid system exhibiting time-dependent, non-equilibrium kinetic behavior.

TEM nanotribology opens up new possibilities for the real-time quantification of cyclic friction, wear and dynamic solid–liquid nano-mechanics, which will have widespread applications in many areas of nano-science and nanotechnology.
Influence of Surface Segregation on the Mechanical Property of Metallic Alloy Nanowires
Authors: Datta Aditi , Duan Zhiyao , Wang Guofeng
Published: March 2012

The influence of surface segregation on the elastic properties of Pt-M (M = Ni, Co, or Fe) nanowires (NWs) are examined by comparing the predicted Young’s moduli of the segregated and non-segregated nanowires using density functional theory (DFT) calculations and the computed stress-strain curves under tensile loading using molecular dynamics (MD) simulation method. The moduli of the segregated NWs were found to be higher than that of the non-segregated ones. It is believed that the surface segregation increases the number of Pt-M bonds across the outermost and second surface layers, and thus enhances the Young’s modulus of the segregated Pt-M nanowires. MD results confirm our DFT results and it is found that onset of plastic deformation could be altered by the surface segregation process, as well.
Who are the low-risk patients that could benefit from watch-and-wait regarding the neck?
Authors: Kohler Hugo Fontan , Kowalski Luiz Paulo
Published: March 2012

CONTEXT AND OBJECTIVE: The management of clinically negative neck is controversial, with an ongoing debate on the indication criteria and prognostic impact of different types of therapy. The aim here was to compare the results from neck dissection and watch-and-wait, among oral cancer patients who, clinically, did not show any evidence of neck metastasis. DESIGN AND SETTING: Retrospective analysis in a tertiary cancer center hospital. METHODS: Patients with epidermoid oral carcinoma were assessed. The inclusion criteria were: primary tumor restricted to the oral/oropharyngeal cavity, no previous treatment, surgical treatment as the first option, clinical/radiological stage N0 and no distant metastasis. RESULTS: Two hundred and sixty-two patients were analyzed. The length of follow-up ranged from four to 369.6 months and, at the end, 118 patients were alive, 53 had died due to cancer, 84 had died from other causes and 7 had died after the operation. Among the patients who underwent neck dissection, lymphatic vascular embolization (P = 0.009) and tumor thickness (P = 0.002) were significant for regional recurrence, while for the watch-and-wait group, only tumor thickness was significant (P = 0.018). Through recursive partitioning, the patients without adverse prognostic factors and tumor thickness < 2 mm presented compatible results in the two groups. CONCLUSION: Elective neck dissection seems to be the best treatment option. Patients who are eligible for watch-and-wait constitute a small group that, ideally, is categorized according to the postoperative pathological findings
Upstream Situational Awareness - Comprehensive Events Based Surveillance Solution
Authors: LeBlanc M. , Rees D.
Published: March 2012

For thirty years the U.S. National Aeronautic Space Administration (NASA) has focused much of its efforts on real-time surveillance systems for real-time command and control of space flight, including the space shuttle program and the International Space Station (ISS). During the last several years a new paradigm shift to Commercial off the Shelf (COTS) technology by NASA has led to more rapid system improvements while greatly reducing costs.

COTS real-time surveillance systems architecture is being brought to the upstream oil and gas industry, by a team of technical collaborators instrumental in developing NASA's Mission Control Center in Houston, Texas. Working with major international operators, the team is developing and implementing COTS solutions for exploration and production Real-Time Operations Centers. By combining engineering and command and control systems integration expertise from the aerospace industry with reservoir, deepwater, drilling and production workflow skills and experience, cost effective smart solutions for situational awareness for the oil and gas industry can now be delivered.

Events in 2010 in the deepwater Gulf of Mexico cast a bright spotlight on the need for better understanding and monitoring of reservoir conditions, drilling and production activity, and decision making. Partly in response to these events, this unique integrated alliance team of vendors and proven applications has been formed to offer events-based surveillance, and complex events processing in real-time drilling and production environments.

Inadequate Situational Awareness (SA) has been identified as one of the primary factors in accidents attributed to human error, and is especially important in work domains where the information flow can be quite high and poor decisions may lead to serious consequences. Having complete, accurate and up-to-the-minute SA is essential where the burdens of technological and situational complexity on the human decision-maker are a concern.
Enhancing Production, Reservoir Monitoring, and Joint Venture Development Decisions with a Production Data Center Solution
Authors: Allen Mark , Smith David M
Published: March 2012

Tullow Oil is an independent E&P company with a portfolio of operated and non-operated assets predominantly located across sub-Saharan Africa. The Production and Reservoir Engineering team in Cape Town monitors non-operated production and evaluates Joint Venture (JV) development opportunities for these assets. In 2010 the team initiated a data consolidation project, the objectives of which were to quality control the incoming production data, provide engineering and management teams with easier access to current reservoir and field performance parameters, and reduce engineers' time spent on raw data manipulation. A Production Data Center (PDC) solution would improve the accuracy of data and information in reservoir and production models, thereby improving decision making and asset management.

The PDC solution, successfully implemented in February 2011, automates production data gathering from the JV daily and monthly production reports, assists with data validation, provides a standard data terminology and structure across the portfolio, and links with the corporate finance and reserves systems.
Using Digital Oilfield Principles to Enhance Safety
Authors: Heckbert Steve , Quick Melissa
Published: March 2012

Chevron has applied digital oilfield principles to enhance workforce safety in emergency situations. An older emergency management process was transformed into a centrally coordinated workflow to guide decisive action and timely evacuation during tropical cyclones.

The Chevron operated Gorgon Project will develop the Gorgon and Jansz-Io gas fields, located within the Greater Gorgon area, about 130 kilometres off the north-west coast of Western Australia. The Project is being constructed on Barrow Island, a Class A Nature Reserve located approximately 60 km off the north west coast of Australia. The environment on Barrow Island is unique. It is home to flora and fauna, some of which are not found anywhere else in the world. Chevron has operated Australia's largest onshore oilfield on the island for more than 40 years, demonstrating that industry and the environment can successfully coexist.

The Gorgon Project is driving significant activity on and around Barrow Island. The construction phase workforce has expanded to undertake offshore drilling and marine operations, plant site preparation, accommodation facilities and aviation support as well as continuing oilfield operations.

The northern coast of Australia, including Barrow Island, is prone to severe tropical storms each season, from November through April. The safety threat is real and unpredictable.

Growth in Chevron's workforce drove a requirement for a well-coordinated storm evacuation process, with unified accountability across the island and offshore vessels. This need was met by developing an i-field decision environment that unites all affected groups, tracks all personnel, coordinates critical data like storm projections and aircraft availability and conserves the safety margin through data-guided decisions, as a cyclone develops and moves.

This transformed evacuation process informs the decisive action that is needed, balancing the paramount need for safety with environmental responsibility and operational goals. This paper describes the results of improved efficiency in demanning safely during storm threats and remanning quickly once the storm threat passes.

(Note: i-field™, the short form of "integrated field", is Chevron's Digital Oilfield program.)
From Standard Operations via Re-manning and Remote Support to Automated Advisory Systems; a Stepwise Development Program for Remote Operations Over a Decade
Authors: Sæverhagen Erland , Thorsen Arve K. , Dagestad Jan Ove , Svensson Inge , Grøvik Lars Olav
Published: March 2012

For anyone involved in organizational changes, people development, optimization of work processes, and reduction in overall risk exposure at the rigsite, the ultimate goal is to develop automation where possible. Automation has been used for years in the car industry, and the oil industry is slowly adopting the potential of automated systems for the drilling environment, gradually integrating all associated processes or important downhole data in full range.

Baker Hughes, with strong support from Statoil, has since 1999 developed a remote operations model based on the Baker Expert Advisory Centre/Operations Network /BEACON) platform, starting with remote operations monitoring from an onshore operations centre. Subject matter experts were placed in the operations centre to process the data in real time, leading to significant changes in work processes both on- and offshore. New positions were developed and new shift plans were implemented. As new downhole tools were developed new service levels such as drilling optimization, ECD management and reservoir navigation services were introduced, all remotely from the operations centre requiring no additional personnel at rigsite, all made possible by rig connectivity, data transfer capabilities and proper work process delineation.

Tomorrow's solution will integrate all available surface and downhole data, and automated advisory systems will deliver advice based on a wider range of combined real-time data, as well as historical databases and best practice, empowering individual judgment and assumptions. This change will significantly contribute to improved operational performance as well as risk mitigation and reduced Health, safety and Environment (HS&E) exposure.

Drilling process automation is something the industry has been anticipating. This paper will discuss the automation potential with respect to remote operations ability, the required development of traditional field positions, collaboration models (e.g., operator/service provider/rig contractor), improved operational efficiency and expectations for operational cost reductions.
Skarv And Valhall Re-development A Journey To The Second Generation Of Digital Oilfields
Authors: Larsen Eldar , Hocking Paul
Published: March 2012

BP in Norway has been in the forefront of developing intelligent energy solutions since 1999 with the installation of their first fiber optical communications link to the Valhall and Ula fields in the North Sea. Throughout the past decade BP Norway has built up considerable experience with Field of the Future Technology ranging from the first advanced collaboration environments for both drilling and operations, the worlds first "Life of Field Seismic" array on the Valhall field as well as advanced remote monitoring tools.

In 2005 it was decided to go ahead with two major projects, one a new field center for the Valhall field and the second a green field development for the Skarv field based on an FPSO. This presented a fantastic opportunity to build on BP Norway's existing experience and create two truly second generation fields of the future. This paper will examine how this was achieved and how the project teams and contractors were engaged via a set of automation and remote performance blue prints to deliver this achievement.

As these fields are commissioned and come on stream they will present a major change in maintenance and operational mind set for the onshore support organization in adopting the extensive remote monitoring and optimization tools that are available to them. New advanced collaborative environments have been provided not only at the main office but also at the new support base and offshore. The Valhall design also includes on onshore control room with full remote control capability.

Clearly these two fields represent a sustainable approach to Intelligent Energy - a world leading example of delivering value retrofitting digital oilfield capabilities to existing assets, then incorporating all the experience and learning into a second phase of greenfield projects.
Connecting a Global Digital Oilfield Community Through a Collaboration Platform
Authors: Coppock Susie , Simonato Ana
Published: March 2012

Description

As large digital oilfield programs evolve, the need to effectively develop and share adoptable solutions across a global enterprise is essential to value realization and solution readiness. The most innovative solutions are typically defined by multi-faceted teams. Once prepared, they must be clearly comprehended by adopting locations. The challenge: How to facilitate the interactions of a geographically-dispersed and functionally-diverse network of petrotechnical, information technology and operations end users, subject matter experts, management teams and central facilitators striving to build a common understanding of new ways of working?

Application

This paper is based on Chevron's experience in leveraging a collaboration platform for the Upstream Workflow Transformation organization that facilitates the adoption of i-fieldSM solutions across upstream business units globally. While it is based on Microsoft® SharePoint® as the technology enabler, the emphasis in this paper will describe the types of global stakeholder interactions, team interactions and information-sharing requirements that can be facilitated through currently-available configurable technologies, and the planning considerations needed for delivering those to a diverse global workforce.

Results, Observations, and Conclusions

The paper will describe results and key insights through this implementation. It will illustrate how a shared virtual home can help facilitate stakeholders' understanding of scope and plans, enable the teamwork of global solutions teams, support design-related interactions, enhance knowledge-sharing across global groups and facilitate resource mobilization, strategies and visioning.

Significance of Subject Matter

Global programs that involve contributors from multiple locations and disciplines will benefit by a virtual location where stakeholders can leverage a shared view to designs, plans, progress and teams can define new solutions collaboratively. Connecting these groups effectively is essential to delivering a comprehensive program built on contributions by all.
A WITSML Enabled Workflow for Integrating Offset Well Drilling Risks and Events Into Well Planning and Execution
Authors: Deeks N. R. , Arevalo Y. I. , Fernandes A. J.
Published: March 2012

In recent years, our ability to record and share information about risks and events affecting rig operations has improved significantly. An important enabler in this has been the development, and broad adoption, of the risk object within the WITSML standard. However, the ability to effectively share data on a broader scale between wells, fields, and blocks has been a challenge. This is particularly important during the planning phase of a well, when access to all available offset risk information is crucial for a successful safe well design.

This workflow, developed within a drilling engineering center, aims to better address this challenge through an integrated 3D approach, using functionality already available on the drilling engineer's desktop. The introduction of a WITSML-based workflow enables efficient and complete data transfer of risk and event data between different users and software applications with the result that the right data is available to the right people, at the right time.

In recent years, our ability to record and share information about risks and events affecting rig operations has improved significantly. An important enabler in this has been the development, and broad adoption, of the risk object within the WITSML standard. However, the ability to effectively share data on a broader scale between wells, fields, and blocks has been a challenge. This is particularly important during the planning phase of a well, when access to all available offset risk information is crucial for a successful safe well design.

This workflow, developed within a drilling engineering center, aims to better address this challenge through an integrated 3D approach, using functionality already available on the drilling engineer's desktop. The introduction of a WITSML-based workflow enables efficient and complete data transfer of risk and event data between different users and software applications with the result that the right data is available to the right people, at the right time.

Drilling risks and events are defined throughout the planning and execution of a well, for example, during surveillance operations within an operations support center or at the rig. Although risk data is generated in predominantly well-centric software, a WITSML server is used to aggregate the data and populate a regional, 3D master risk project. In this project, intelligent filtering and 3D visualization tools are used to target offset data relevant to the current operation. Relevant risks are integrated into a 3D evaluation of the proposed well design, incorporating the geological model of the current prospect. As the well is drilled, the 3D evaluation is used to alert the rig and remote support teams of potential issues ahead of the bit. This approach streamlines the evaluation of risks in the planning stage of wells and enables more effective collaboration between the drilling and geological and geophysical team during execution.
Intelligent Field Management: Real Time Monitoring and Proactive Optimization of Greater Ekofisk Area
Authors: Madahar Amit , McIntosh Alannah , Musatfin Ilnur , McAlonan Nick
Published: March 2012

An online real-time production optimization and monitoring system for the Greater Ekofisk Area of Norway was installed in 2006. The system has evolved significantly since installation; changes driven by multi-disciplinary teams in coordination with the ConocoPhillips Production Optimization Centre (POC).

The POC, Subsurface Production Delivery and Reservoir Optimization teams are tasked with assessing real time data from nominally 160 active producers and injectors in order to minimize losses and thereby maximize field production. This online system integrates data from the complete production system: reservoir to export meters. The system realises the importance of visualisation with respect to monitoring field performance, streamlined decisions, and reduced man hours mining data and analysis. The system allows real time monitoring of all wells and associated instrumentation parameters along with field three phase production allocated to the well level. The system alerts an engineer's attention when a well's performance is outside predefined tolerances thereby enabling continuous optimization of the combined field network.

This paper demonstrates how the online system addresses the following challenges:

Real-time monitoring of separator loadings, production/injection well performance Daily production/injection volume losses allocation Quick screening and allocation issues Generation of updated well models with the latest well test data for further analysis (nodal analysis, lift performance analysis) Generation of updated network models for what-if studies

The tool has an open architecture that allows information to be shared with other software packages. It is also capable of controlling and using results from other software that have open access. The tool is used daily by the POC to review the overall performance of the Greater Ekofisk Area.
Advances in Production Allocation: Bonga Field Experience
Authors: Udofia Emmanuel , Akporuno Mamoke , Vandenberg Frans , Beijer Vincent , Oguntimehen Gbenro , Oni Olatunbosun
Published: March 2012

Bonga field located in deepwater of the Niger Delta in Nigeria, started production in November 2005 and from inception with sustained water injection for pressure maintenance. By 2006, Production Universe which is a state-of-the-art Shell production monitoring and allocation tool was deployed as part of the Bonga Smart Field's Foundation Mark-1 implementation and this has been used for Bonga production allocation process. The Smart Fields Foundation Mark-1 project aimed to provide the Bonga asset with solid data and models for production surveillance and optimisation.

Accurate production allocation has always posed a threat to efficient well and reservoir management in the oil and gas in industry. The traditional approach to production back-allocation to individual wells and reservoir is usually based on ‘one-point’ well test data with the clear assumption that production from this well(s) remains constant (regardless of the prevailing situation affecting this well) for the period of interest. Meanwhile, in Bonga with the support of a real-time ‘virtual meter’ called Production Universe, we have been able to demonstrate significant improvement in our production allocation process as shown in the improved production reconciliation factor between estimated and measured field production data. Bonga is a field with varying flow rates in the producer wells with very fast response to changes in injection rates. Consequently, accurate production allocation significantly improved the Bonga well and Reservoir Management process.

The result of this paper is empirically based supported by data and shared experiences in Bonga field and could be applied in other similar operating assets with the benefit of improved production allocation.
Real-Time Factory Drilling in Mexico: A New Approach to Well Construction in Mature Fields
Authors: Codesal Pablo A. , Salgado Luis
Published: March 2012

In today's economic environment, oil and gas companies are continuously challenged by a combination of ma-turing fields (yielding less while requiring more attention), coupled with increasing human resource scarcity.

This situation is creating higher costs per barrel and changing economic viabilities for development projects around the world. One way to improve economics is to introduce new efficiency gains that reduce non productive time (NPT), reduce well construction times, and, therefore, minimize costs.

The Factory Drilling* approach for field development has demonstrated significant benefits when applied to a well-known field that has consistent well programs and reduced uncertainties. This new way of conducting drilling operations is enabled by real-time data, seamless integration of services, application of suitable technology specific to mature fields, remote operations, multi-tasking of personnel, and fit-for-project rigs. The concept has been successfully piloted in Mexico, on the above-mentioned field, and deployed in twelve land rigs simultane-ously during 2009 and 2010.

This paper describes what was done, how it was done and summarizes key results. Since then, other projects have implemented the same model (with some variations) in other parts of the world.
Design and Implementation of a Global Solution for the Management of Real-time Drilling Data
Authors: Warner Glenn , Hernandez Sergio , Lopez Jesus , Booth Jake
Published: March 2012

Chevron has a longstanding association with the use of dedicated operations centers to support drilling operations. This dates back to the pioneering work of Tenneco in the early 80's, one of a few First Generation Drilling Operations Centers (Booth, 2009). After the acquisition of Tenneco in 1988, Chevron built upon this prior experience in developing a sophisticated support center intended for use throughout Chevron's global drilling operations. As with most of the first generation centers, reduction in drilling activity changed the business case and the strategy was curtailed in 1992. More recently, in 2004, Chevron established a Well Design Execution and Collaboration Center (WellDECC) to support high-cost technically challenging deep water operations in the Gulf of Mexico.

With recent and planned changes in drilling strategies, including the prospect of supporting multiple rig onshore operations both domestic and international, Chevron is embarking on an updated strategy which will institutionalize access to and use of realtime drilling data on a global basis. This includes establishing a central facility staffed by Chevron personnel and operating on a 24/7 basis to monitor the acquisition of data and its integration with technical and operational work processes. This strategy will benefit from the experience derived from the earlier efforts mentioned above. It will also take advantage of significant subsequent advances in information technology and the development and broad implementation of the WITSML industry standard for exchange of data between the multiple parties typically involved in the drilling and completion of a well. This paper describes the strategy's underlying principles and provides information on the design and implementation of an appropriate solution.
Mechanical Diverter in Stimulation Treatments With Coiled Tubing Evaluated With Radioactive Tracers in Carbonate Reservoirs
Authors: Orozco R. Camilo , Melo Narcizo O. , Ulloa J. V. , Robles Hernandez F.
Published: March 2012

Finding new areas to exploit for hydrocarbon production has become a challenge. This has led to wells being completed with more than two or three intervals in different configurations and with various petrophysical properties, which can greatly affect production and also accepting treatment fluids.

In addition, in low-pressure wells with multiple open intervals, conducting effective stimulation treatments using chemical diverters or foamed fluids is not always the best alternative.

For cases with multiple areas, stimulation using coiled tubing (CT) is optimal to help ensure stimulation in areas where new intervals have been created as a result of having previous intervals which had preferential acceptance of fluids.

The purpose of this study is to show how stimulation using CT has evolved from using conventional, rotary, and hydraulic-cleaning tools to the development of a new application for stimulation tools, which helps achieve better placement of acid treatment systems.

The advantages obtained with this new application are Water cut can be reduced with this technique to help ensure intervals near the water-oil contact are not encouraged.It can handle higher pumping rates for effective removal of the damage.Penetration of the stimulation fluids was evaluated using radioactive isotopes, and spectral recordings were taken to assess the depth of stimulated intervals, placement and an estimate of the treatment volume, and the radial penetration of fluids.Fluid flowback is faster, which saves time on installation and introduction of CT for interventions.This acid-stimulation placement technique is the best way to stimulate wells with more than two intervals when selective treatments are required.
Dynamic Well Intervention Modeling
Authors: Newman K. R.
Published: March 2012

A dynamic soft-string finite-element torque and drag model for modeling coiled tubing, wireline and drilling operations in a wellbore has been developed. The model includes the ability to simulate axial and torsional stick-slip for complex dynamic situations such as stall torque, jarring and yo-yoing. This paper documents the equations used to develop this model, compares model results with analytical equations and presents several example simulations performed by the model.
Optimized Downhole Mud Motor Delivers Outstanding Performance Improvement in Alaska Coiled Tubing Drilling
Authors: Anyanwu Okechukwu N. , Klotz Christian , Labrecque Denis , Ulrich Carl
Published: March 2012

For almost two decades, coiled tubing drilling (CTD) has proved to be a successful method to reach the un-swept portions of Alaska’s North Slope reservoirs. This method of drilling has evolved over the years with new technologies and efforts from contractors and operators striving to improve performance from lessons learned. Despite these improvements in equipment and processes, operators and contractors must still deal with certain inherent deficiencies of this drilling method when compared to conventional rotary drilling – suboptimal weight transfer, sometimes troublesome hole cleaning — due mainly to lack of string rotation and low flow rate range, etc. These shortcomings have the potential to induce other drilling performance problems that affect the smoothness of coiled tubing drilling operations. Severe lateral vibration and severe stalling have become acceptable evils over the years, resulting in undesirable trips for failure and unacceptable non- productive time (NPT), both undermining one of the key benefits of coiled tubing drilling – rapid pace operations compared to rotary drilling.

This paper introduces a new lower-speed downhole positive displacement motor (PDM). The technology is equipped with high-performance elastomer and was engineered to improve drilling and drill-bit performance in CTD applications. Recent field deployments in Alaska’s North Slope CTD operations proved this design by eliminating earlier performance problems for improved CTD project economics. For example, the technology’s ability to allow for about 10gal/min higher flow rates (compared to other motor designs) significantly improves hole cleaning; a key aspect in CTD operations.

Up to today, this downhole mud motor design has been utilized on 13 wells, accumulating 1,303 circulating hours, 577 drilling hours and over 20,700 ft drilled. Performance improvements in depth of cut, reduced lateral vibration, reduced amount of stalls, and other benefits were achieved. There was no trip for PDM failure in all of the 34 runs, traversing different formation zones. The corresponding paper will provide additional information on application benefits by investigating two recent field deployments.
Advances in HWO Equipment Safety Features
Authors: Harrell T. , Eberhardt M.
Published: March 2012

During well intervention, control of the well is dependent on the integrity of the intervention-service provider’s pressure- containing equipment. The service company’s equipment becomes a safety critical element of the duty holder’s safety case. Also, control of the pipe string being inserted into the well during HWO is critical to successful well control.

One service provider recently developed two safety devices that enhance the safety of pipe handling and pipe control during HWO activities. A pipe-handling winch tension-limiting system (TLS) was created that helps minimize the risk of accidental overload of the HWO pipe-handling ginpole and winch by retraction of the HWO jack while the pipe is connected to both the jack and the ginpole. This device helps minimize the risk associated with pipe-handling counterbalance winches that have been equipped with brakes. Also, a slip-bowl interlock system was developed that helps minimize the risk of two pipe-handling slip bowls being opened simultaneously, which could cause lost control of the pipe that is being run in hole. This new device replaces the industry norm "weevil latch," which is used widely to help reduce this risk.

This paper describes the risks that these two safety-related inventions address and the details of the development projects that brought them to fruition.
Fiber-Optic Technology Allows Real-Time Production Logging Well Campaign To Continue Where Traditional Logging Tools Fell Short
Authors: Menkhaus A. , Ryan T. , Taboada J. , Wasson C. , Webb C. , Williamson J.
Published: March 2012

Exploration and exploitation of the shale formations in the United States has continued to accelerate since the early 2000's. Once considered to exist only as a cap rock, shale is now proving to be one of the most important reservoir rocks in North America and throughout the world. The demand for production logging (PL) in these reservoirs has increased due to the desire to better understand the basis behind higher stimulation efficiency and increased production results. Data collected via production logs can be used to evaluate efforts to enhance production through better zonal targeting, modifications to completion/hydraulic fracture design and/or alternate zonal isolation procedures.

Drilling extended reach horizontal wells has allowed for more efficient exploitation of these formations but has also increased the number of potential obstacles to overcome in order to obtain complete and accurate production logs. Some of these obstacles include: severe doglegs which interfere with logging tool bending capability, substantial wellbore debris and/or added friction surface contact impacting depth of data capture, and completion configurations that limit equipment options and ease of logging. This paper will identify these critical factors and address proper candidate well selection and job preparation. It will also illustrate a multi-well logging campaign in the Marcellus shale, which highlights the benefits of fiber optic technology as a suitable alternative to traditional production logging techniques.
Practical Cementing Technique To Repair Severe Casing Damage
Authors: Cirer David , Arze Erick , Moggia Juan Manuel , Soto Ruben Hector
Published: March 2012

We introduce a new way to repair the casing affected by severe damage, even long rupture casing. These techniques consist to pump cement through a special design of cement retainer and fiber pipes call ERFV (Epoxy Reinforced Fiber Glass), to fill the annular space between the casing and ERFV pipes. The ERFV are used as a guide for a special pilot mill (a mill with a nose of smaller diameter). Thus, achieve the integrity, the passage and the continuity of the well.

This paper will explain the method to repair severe casing damage and show the results of wells repaired.