bluuebunny/crossref_metadata_2025 huggingface dataset:
Crónica Comunitaria: Actualidad institucional y económica de España en el marco de la Unión Europea (junio de 2017)
Authors: Iñarritu Beatriz
Published: October 2017

Sumario: I. Introducción.—II. El Estado de la Integración.—III. Cuestiones generales de la actualidad económica.

Publicación en línea: 01 octubre 2017
Displasia Broncopulmonar: Definição, Fisiopatologia e Tratamento: Revisão da Literatura
Authors: Silva Geovany Antonio Alves , Annes Amanda Letícia Medeiros , Pisco Maria Dilma Bezerra de Vasconcelos , Silva Ricardo Martins
Published: October 2017

Resumo:Objetivos: Apresentar uma revisão da literatura sobre a displasia broncopulmonar, sua fisiopatologia e suas formas de tratamento. Metodologia: Tratou-se de uma revisão da literatura sobre a broncodisplasia pulmonar.Na coleta de dados foi realizada a busca de artigos científicos indexados em bancos de dados e artigos de revistas de saúde que não fosse indexadaos mas que possuíssem número de ISSN. Utilizou-se artigos em português, inglês e espanhol. Foram utilizadas as seguintes palavras-chaves: Displasia broncopulmonar, ventilação mecânica, oxigenoterapia, recém-nascido pré-termo, síndrome do desconforto respiratório.A Pesquisa foi realizada em setembro a outubro de 2016 e foram utilizados 34 artigos 2000 a 2016. Discussão: A displasia broncopulmonar é uma doença multifatorial. Que vai desde a intoxicação por frações inspiradas de oxigênio elevadas, uso de ventilação mecânica invasiva por longos períodos de tempo, a doenças pré-existentes, como persistência do canal arterial, síndrome das membranas hialinas (síndrome do desconforto respiratório do recém-nascido), infecções neonatais e outras doenças.  Considerações Finais: A displasia broncopulmonar tem modificado sua forma de apresentação desde a primeira descrição até hoje, porém o cuidado com os recém nascidos com baixo peso, tem se mostrado medidas eficientes no manejo e tratamento da displasia broncopulmonar.Palavras-chaves: Displasia broncopulmonar, ventilação mecânica, oxigenoterapia, recém-nascido pré-termo, síndrome do desconforto respiratório.
Instrumentos avaliativos na formação crítico-reflexiva em enfermagem: revisão de estudos brasileiros
Authors: Lopes Christiny Regina , Prado Marta Lenise , Ferraz Fabiane , Canever Bruna Pedroso , Pilatti Patrícia , Nascimento Elieser Peper
Published: October 2017

O tema do presente estudo é a avaliação discente e tem como objetivos identificar os instrumentos utilizados para a avaliação discente nos cursos de graduação em Enfermagem no Brasil e descrever como os princípios de uma avaliação crítica estão expressos nos trabalhos analisados. Trata-se de uma revisão integrativa de literatura de 11 artigos selecionados, em um universo de 705 analisados na Biblioteca Virtual em Saúde (BVS) Brasil. No processo de avaliação discente aparecem os instrumentos: provas teóricas, portfólio, estudo de caso, autoavaliação, situação-problema, planejamento estratégico situacional, instrumento para atividades práticas, os quais são interpretados e utilizados de diferentes formas pelos docentes. O processo avaliativo continua sendo um desafio, pois aparecem incoerências entre os princípios teóricos que orientam os docentes e sua prática efetiva. Conclui-se que ressignificar a avaliação no processo ensino-aprendizagem é um imperativo para a formação de profissionais crítico-criativos e reflexivos.
Priorização de tecnologias em saúde: o caso brasileiro
Authors: Araújo Denizar , Distrutti Marcella , Elias Flávia
Published: October 2017

Hoje em dia, os governos enfrentam brechas cada vez maiores entre as necessidades de saúde da população e os recursos disponíveis para financiar a saúde. Isso acontece por diversos motivos, incluindo a transição demográfica e epidemiológica, os avanços tecnológicos, a oferta contínua e crescente de novos tratamentos médicos, o aumento da expectativa da população em relação aos seus direitos e, em países como o Brasil – em que o direito universal à saúde é garantido constitucionalmente – a judicialização da saúde. Nesse contexto, os mecanismos de priorização explícita em saúde ganham cada vez mais força. Segundo Michael Rawlins, nenhum país do mundo possui os recursos necessários para financiar todas as tecnologias disponíveis para todos os cidadãos com os máximos padrões de qualidade (2010); por esse motivo, os países precisam definir critérios técnicos, regras e processos sistemáticos, explícitos e transparentes para apoiar os processos de decisão de cobertura. Esse conjunto de critérios, regras e processos recebe o nome de priorização de tecnologias em saúde. Esta nota técnica analisa o sistema de priorização de tecnologias em saúde no Brasil, com o objetivo de avaliar seu desempenho e identificar oportunidades de melhora nos processos de decisão de cobertura e alocação de recursos públicos em saúde. Essa análise está baseada em um marco conceitual desenvolvido pela rede de conhecimento CRITERIA: Priorização e Planos de Benefício de Saúde, do Banco Interamericano de Desenvolvimento (BID), que propõe um enfoque sistêmico para a priorização em saúde.
Análise de custo-efetividade de obinutuzumabe associado à quimioterapia para o tratamento de pacientes adultos com leucemia linfoide crônica não elegíveis ao tratamento baseado em fludarabina na perspectiva do Sistema Único de Saúde (SUS)
Authors: Shimabukuro Ho Rodrigo , Souza Camila , Tsuchiya Carolina , Biondo Juliana , Alves Marcia Regina
Published: October 2017

Objetivo: O objetivo deste estudo foi avaliar a custo-efetividade da terapia obinutuzumabe + quimioterapia (GQT) versus quimioterapia (QT) em pacientes com leucemia linfoide crônica (LLC) sem tratamento prévio classificados como inelegíveis à dose completa de fludarabina (slow-go) na perspectiva do Sistema Único de Saúde (SUS). Métodos: Um modelo de Markov foi desenvolvido para acompanhar os pacientes com LLC durante o curso da doença, em um horizonte de tempo de 20 anos. Os desfechos de sobrevida livre de progressão (SLP) e sobrevida global (SG) foram avaliados respectivamente em termos de anos de vida livres de progressão (AVLP) e anos de vida ganhos (AVG). O custo de tratamento incluiu os custos de aquisição de medicamentos, manejo de eventos adversos e acompanhamento. Os dados de eficácia foram obtidos dos estudos CLL11 e CLL5. Resultados: O custo de tratamento incremental foi de R$ 72.565. Os valores de SLP para GQT e QT foram, respectivamente, 3,3 e 1,1 AVLP. Para SG, o GQT resultou em uma efetividade de 5,7 e QT 4,3 AVG. Os resultados de RCEI foram de R$ 32.477/SLP e R$ 52.252/AVG. Conclusão: A terapia GQT é uma opção que proporciona benefícios clínicos superiores quando comparada à QT e pode ser considerada custo-efetiva no tratamento de LLC em pacientes não elegíveis a doses completas de fludarabina.
Proposta de um modelo de análise da flexibilização da burocracia em organizações públicas com base nas dimensões sugeridas por Volberda: o caso da secretaria de estado da administração de Santa Catarina
Authors: Lyrio Maurício Vasconcellos Leão , Dellagnelo Eloise Helena Livramento , Lunkes Rogério João
Published: October 2017

O reconhecimento da necessidade de entender as mudanças que vem ocorrendo nas práticas organizacionais originou um conjunto de trabalhos que pode ser agrupado na temática denominada “novas formas organizacionais”. Este artigo se insere nesta temática, objetivando discutir a questão da flexibilização da burocracia em uma organização pública. Para tanto, foi estruturado um modelo de avaliação baseado nas dimensões propostas por Volberda (1988) - considerando a operacionalização da racionalidade substantiva em uma organização por meio do que o autor denomina controle dinâmico - na Secretaria de Estado da Administração de Santa Catarina. No que tange à metodologia, se configura como um estudo descritivo e se constitui em um estudo de caso. Utilizou-se como instrumento de intervenção metodologia ligada à Pesquisa Operacional, denominada metodologia MCDA-C. A contribuição da MCDA-C nesse contexto se dá pelo fato de essa metodologia permitir a organização dos critérios de análise propostos por Volberda, estabelecer uma escala de avaliação para cada um desses critérios e proceder a uma avaliação que permita quantificar o grau de flexibilização da organização em estudo. A organização obteve 35,4 pontos, o que se configurou, em uma análise geral, como baixo grau de flexibilização. Em uma análise mais específica, apresentou um maior grau de flexibilização na dimensão cultura organizacional e um menor grau de flexibilização na dimensão estrutura organizacional.
Multi-Zone Cased Hole Frac-Packs and Intelligent Well Systems Improve Recovery in Subsea Gas Fields
Authors: Burton R. C. , Gilbert W. W. , Nozaki M. , Pandey V. J. , Adams M. D. , Peterson E. M. , Zhou L. , Ray T. W. , Fleming G. , Leitch J. C.
Published: October 2017

A nine well subsea development project has been completed using cased hole frac-packs for sand control and an innovative multi-zone intelligent well system to improve recovery from a series of shallow, low pressure, gas reservoirs. In these wells, cased hole frac-packs have been installed to provide reliable sand control over the long, low net-to-gross, sand/shale target sequence: typically, three to six frac-packs per well. This outer cased hole frac-pack completion is then augmented with a multi-zone intelligent well system, consisting of isolation seals, surface controlled zonal isolation valves and downhole pressure/temperature gauges. The intelligent well system is run as a separate inner string to provide flow monitoring capability and allow shut-off of zones producing high water volumes. This critical water shut-off capability eliminates the risk of one or more high water production zones loading-up and killing adjacent low-pressure gas zones with associated loss of reserves.

To date, a total of nine wells have been completed and are being successfully produced from three subsea gas fields. To maximize recovery from the fields' numerous but relatively thin gas reservoirs, production wells are completed over three to six separate intervals. These frac-packed intervals are then grouped to allow flow control and pressure/temperature monitoring to occur through up to six surface operated Interval Control Valves and associated downhole gauges. This combination of sand control and intelligent well control has provided an ability to perform multi-rate flow tests and pressure build-up tests on each reservoir interval to detect the start of water production or identify other impending production issues. After roughly five years of production service to June 2017, four of the 34 zones completed in the nine well project have had to be shut-in to eliminate high water production. These water shut-off actions performed via the surface controlled interval control valves are estimated to have improved gas recovery factors from 50% to 60% without requiring rig intervention.

This paper will describe the reservoir challenges, completion design and operating practices employed in this successful program.
Investigation of Pressure Profiles of Reservoirs with Wells under Transient, Unstable Flow
Authors: Sousa Pedro Cavalcanti , Garcia Artur P. , Waltrich Paulo J.
Published: October 2017

In this work, to the knowledge of the authors, it is the first time that an analytical solution demonstrates how the pressure profile changes with frequency and when this change takes place. Case studies are also presented to analyze the impact of different pressure profiles on well deliverability. Reservoir pressure profiles associated with steady-state, pseudosteady-state, and transient flow for a constant pressure drawdown were derived decades ago. These profiles, however, may not be applicable near the end-life of a well due to the unstable nature of fluid flow in the wellbore (e.g., liquid loading, slugging), and could explain why certain wells stop flowing before predicted. This paper shows how the flow instability changes the reservoir pressure profile and what consequences that change might bring to well production.

Previous publications have shown numerical and experimental evidences that not only the pressure profile in the reservoir changes when there is an increase in the frequency of oscillation in the bottomhole pressure, but also that understanding this phenomenon is fundamental to reliably predict the time-dependent deliverability of wells.
Rate-Transient Analysis Based on Power-Law Behavior for Permian Wells
Authors: Chu W. , Pandya N. , Flumerfelt R. W. , Chen C.
Published: October 2017

In unconventional reservoirs, the application of many rate-transient analysis (RTA) techniques rely heavily on the identification and analysis of the linear flow regime, which is characterized by a ½ slope on a log-log plot of Δp vs. t. Through our analysis of more than 400 wells with downhole pressure gauges in the Wolfcamp shale of the Permian basin, we observed power law behavior, but with slopes much different than ½ over long periods of time. In many cases, the duration of the straight line with a slope different from ½ lasts for years, without ever converging to ½. In some cases, the slope changes over time but rarely is the characteristic ½ slope observed over long periods. Rate forecasts would be in error if were to assume that the slope would converge to ½ slope at a later time.

In this work, we present examples of Permian Wolfcamp horizontal wells with measured bottomhole pressure (BHP) to demonstrate the characteristic power-law behavior with slopes different from ½. Power-law behaviors are typical in heterogeneous systems and are identified using the Chow pressure group (CPG).

Based on the concept of the power-law behavior, we have developed a workflow to analyze multiphase rate-transient data with high quality measured BHP. Ultimately, the new workflow for rate-transient analysis uses power-law characteristics to evaluate well performance and is a complementary tool to traditional methods such as Arps decline-curve analysis. This paper outlines a power-law analysis workflow scheme and demonstrates that the Chow group is a convenient means to identify the exponents of straight lines. In addition, we present case studies to demonstrate the application of this technique to predict the long-term well performance from choked-back wells, to evaluate long-term performance changes associated with offset frac hits, and to estimate the hyperbolic decline-curve b-factor.
Comparison between Production and Economic Indicators in the Production Strategy Selection for Polymer Flooding
Authors: Botechia V. E. , Schiozer D. J.
Published: October 2017

The selection of a production strategy, seeking maximization of field performance according to some indicator, is a complex and important task. Choosing the indicator to be used to complete this task can lead to different results, and this choice must be carefully made to reflect the company objectives. Many companies seek only maximization of the recovery factor, neglecting costs and investments necessary to reach this goal. This may lead to a poor economic performance. Moreover, decisions that require extra investments (for instance, the use of some enhanced recovery technique such as polymer flooding) should be evaluated and taken into account in the analysis, since there are differences in the cash flow of the project options and these additional investments are important to the final decision.

The objective of this paper is to compare the use of production and economic indicators in the production strategy selection, considering that there are not budget constraints or platform restrictions.

The methodology consists of an optimization process using two different indicators: net present value (NPV) and oil recovery factor (RF). Three different approaches are addressed: (A) using only NPV as objective-function (OF) in the whole process; (B) using only RF as objective-function in the whole process; (C) using NPV as objective-function in the steps that the investments are not fixed (the number of wells and platform capacity are not determined yet) and changing the objective-function to RF when the main investments do not vary (number of wells and platform capacity are already determined). The application of the methodology is made in a model that represents an offshore heavy oil field using polymer flooding as recovery mechanism.

The results show that NPV has advantages when considering the whole development of the field in this work conditions (no budget or platform restrictions). In this case, the consideration of the recovery factor as single indicator leads to an overestimated number of wells, resulting in bad economic performance due to high costs, even with higher oil production in relation to the optimization made considering only NPV. The advantage of using NPV is that it considers in its calculation several parameters, such as revenues from oil production, costs from oil and water production, costs from water injection, speed of recovery, and in the case of this work, the cost for polymer injection, which can affect strategy selection, mainly when comparing with other recovery mechanisms. However, when the investments do not vary significantly (number of wells and platform already defined) there is a strong correlation between oil produced and economic return, so that the optimization considering NPV or RF leads to similar results.
Successful Integration of Drillstem Testing, Closed Chamber Testing, and Wireline Formation Testing: A Deepwater Case History
Authors: Azari Mehdi , Khan Waqar , Elshahawi Hani
Published: October 2017

For more than a decade, optimal value testing (OVT) has been advocated as a methodology that, in most cases, can replace conventional drillstem testing (DST) for in-situ permeability measurement. The term OVT refers to any pressure-transient test during which live hydrocarbons do not have to be produced directly to the surface (Elshahawi et al. 2008, 2012). Three primary types of well tests have been considered as part of the OVT toolbox: injection testing, wireline formation testing, and closed-chamber system testing with cleanup and repeat surges, which is a proprietary analysis technique.

This paper reviews the earliest OVT case studies retrospectively, with the benefit of several years of production. These cases include the first successful multicycle well testing/fluid-sampling closed system testing operation with near-emission-free and real-time data transmission to surface in deep water. Operations were conducted from a moored vessel without the use of a subsea test tree, setting a world record at the time for the maximum depth at which any vessel had been moored. The operation successfully gathered all crucial data; the overall test duration was shortened; and most importantly, safety and formation fluid handling were enhanced with no hydrocarbons offloaded or flared.

Data collected during all phases of the testing process were analyzed. These included the perforation, subsequent surge into the testing chamber, initial cleanup of flow/buildup, optimized closed-chamber surge flow, and final cleanup of flow/buildup. Standard techniques were used to analyze the traditional DST, but specialized techniques and software were developed to help plan and analyze the closed-chamber surge testing during perforation and surge testing. Data from the testing phase were used to generate an earth model to forecast production from the field. Several years of observed production confirm the early testing results and validate the OVT philosophy and the closed-chamber testing technology.

This paper discusses the testing protocols, optimized system design, and novel analytical techniques employed. It also compares pressure transient analysis (PTA) results obtained from surge testing, standard DST, and formation tester. The consistency of formation pressure and permeability measurements obtained from the various testing techniques and the agreement with actual production performance lends credibility to the results and confirms their viability for replacing conventional DSTs in many cases. Particularly in deep water, where cost and environmental constraints limit the feasibility of conventional DSTs and where early data gathering is essential, such techniques can provide a powerful complement—and often a viable replacement—to well tests.
Analytical Development of a Dynamic IPR for Transient Two-Phase Flow in Reservoirs
Authors: Sousa Pedro Cavalcanti , Garcia Artur Posenato , Waltrich Paulo J.
Published: October 2017

This work presents a new Inflow Performance Relationship (IPR) for transient two-phase flow in reservoirs. This relationship is called Dynamic IPR and it accounts for the flow dynamics at the near-wellbore region and provides a simple but robust solution for transient simulations of two-phase flow reservoirs. The Two-Phase Dynamic IPR not only couples the wellbore bottomhole flowing pressure with oil and gas flow rates, but it also provides the pressure profile within the reservoir. Commercial software are capable of coupling discretized reservoir simulators to wellbore models; however, these are computationally more expensive and complex than the Dynamic IPR. The use of conventional IPRs, on the other hand, is simple and straightforward, but they cannot account for the wellbore-reservoir dynamic, making them inaccurate in fully transient models.

The proposed Dynamic IPR is validated against the results from a state-of-the-art reservoir simulator using finite element methods. The Dynamic IPR shows an agreement of ±8% with results from the discretized reservoir simulator.
Self-Assembling Nanoparticles: A Unique Method for Downhole Sand Consolidation
Authors: Kalgaonkar Rajendra , Chang Frank
Published: October 2017

When the formation is unconsolidated, sand particles can be produced into the wellbore. Such production of sand particles is undesirable as it lowers the permeability of the producing zone, erodes surface and downhole equipment. Costly intervention may be required to mitigate the damage to the well integrity and the reservoir deliverability. The most common methods of controlling this unwanted sand production involve: 1. Filter produced fluids through a gravel pack retained by a screen or 2. Use of consolidating fluids such as resin, a curing agent, along with other chemicals to create a conducive environment for the resin curing reaction to occur. The gravel packing completion requires special tools and equipment therefore higher cost. In the case of sand control by chemical consolidation, the resinous material tends to have relatively uncontrollable setting times, strength, placement, and regained permeability leading to unsuccessful treatment. With both cost and treatment effectiveness in mind, it is desirable to develop an improved material and method to mitigate sand production by consolidating the formation sand without impairing well productivity or injectivity.

The present paper describes the development of a unique chemistry for sand control in unconsolidated formations. This chemistry involves using positive charge modified nanoparticles that can self-assemble over the unconsolidated formation sand particles to form a layer of consolidating material thus preventing any unwanted sand production. The new consolidation treatment material consists of colloidal nanoparticles modified using a cationic modifier and ionic strength modifier that can be placed downhole as a single pill. The pill has high affinity to the solid surface therefore less prone to build up in the pore space. Once cured at reservoir temperature it forms a thin layer of hard gel around the surface of the sand particles, thus cementing the sand grains together at the same time maintaining open porosity to ensure easy flow of produced hydrocarbons or injected water.

The newly developed sand consolidation formulation was studied for their ability to consolidate loose sand and at the same time maintain good permeability. The effect of various ionic modifiers on consolidation properties was studied. The ability of the cationic modified nanoparticles to self-assemble around unconsolidated sand and eventually cure to form a consolidated sand pack was investigated. Regain permeability studies showed good regain permeability of the consolidated sand pack. Furthermore, this paper describes the concentration effect of the cationic modifier on the regain permeability. Finally, it shows that the new product provides a controllable curing time, thus avoiding any premature setting of the nanoparticles in the wellbore.
Development of a Technology Transfer Model in the 2020 Era for the Oil and Gas Industry
Authors: Viscomi J. C. , Schoeling L. G. , Williams T. E.
Published: October 2017

Technology transfer or acceptance is difficult in every industry; however, the oil & gas industry has had it especially hard with volatile commodity prices, variability of technology sources and the regulatory uncertainty. In 1994 in a paper entitled, "Development of a Model Technology Transfer Program to Assist Independent Operators"5 the authors outline a model for independent operators to embrace and utilize new technology with an aim of reducing well abandonment common at the time and increasing overall production for the long term. This paper seeks to expand upon that work updating its methodology for today's more challenging operating environments. It sets the course for companies to continue to take advantage of technology and best practices in ways that optimize operations, improve economics and secure production far into the future.

This paper describes a program that any operator can utilize to get quick access to technology without significant costs while increasing oil production and decreasing operating expenses. This technology transfer program utilizes methods from other technology based industries yet is focused and builds upon past principals established by technology transfer programs like the Research Partnership to Secure Energy for America (RPSEA) and the Petroleum Technology Transfer Council (PTTC). This paper contains several fundamental components including: 1) Technology Leadership guided by industry to initiate and manage the technology transfer process, 2) Problem Identification activities that help create a two-way dialogue between industry and leadership organization, 3) Documented Demonstration Projects rooted in findings from problem identification activities 4) Focused Technology Workshops serving to disseminate demonstration project findings and 5) Regional Resource Centers with Outreach Resources serving as local and online repositories for easy future access by industry.

Additionally, this paper identifies various sources of research and technology development funding illustrating how an effective technology transfer process can improve the time between idea and technology commercialization. In the last few years the landscape of the oil and gas industry has changed dramatically in relation to technology. Many operators, out of necessity, have adopted a manufacturing or mass production mentality regarding their wells while disregarding optimization and the use of technology for long-term production.

This paper specifically addresses the needs of the modern oil and gas operator who does not have, or has limited access to industry research labs, government funding and university programs. It provides a step by step process designed to help operators become engaged in technology transfer in a cost-effective manner with a goal of improving their individual businesses as well as the industry at large.
Using Wireline Formation-Tester Data for Reservoir Characterization and Connectivity Determination in Ultradeepwater and High-Pressure Wilcox Formation in Gulf of Mexico
Authors: Azari Mehdi , Hadibeik Hamid , Eyuboglu Sami , Jambunathan Venkat , Khan Waqar , Ramakrishna Sandeep , Haack Joshua , Bargas Connie , Khan Mashiur
Published: October 2017

Deepwater turbidite reservoirs have always presented several reservoir characterization challenges. Determining the complex architecture of the sand bodies, correlating them across multiple wells in the structure, and defining the sedimentological facies to determine the reservoir vertical communication and boundaries are some challenges in these Gulf of Mexico (GOM) turbidites. Other formation-related challenges of turbidite reservoir exploration and development include understanding reservoir rock quality and compartmentalization, as well as the identification of fluids. Deepwater exploration and development require innovative, cost effective evaluation technologies—technologies that help manage ultradeep and high-pressure environments. Having a detailed description of reservoir properties, fluids characterization, and a determination of the reservoir connectivity are crucial for understanding the reservoir and optimizing the field development plan.

This study describes the wireline formation tester (WFT) operations performed in a harsh environment [ultradeepwater subsalt formation (> 32,000 ft) and high pressure (> 25,000 psi)] to obtain pressure data, establish gradients, evaluate vertical connectivity using vertical interference tests (VITs), check for compositional variation in different oil columns, and obtain clean formation fluid samples. Downhole fluid analysis was performed to help ensure the quality of formation samples and determine the fluid compositional analysis in real time during pumpout. To obtain high quality fluid samples while minimizing costs, an innovative technology—namely, a focused sampling probe—was used, eliminating the need for long pumpouts. Representative formation fluid samples were captured from three sample depths in approximately two hours per sample depth with minimum oil-based mud (OBM) contamination (< 5%).

All the available openhole log data were integrated to understand the reservoir before running the WFT. Optimizing pressure and sampling depths (most representative intervals) can help reduce uncertainty when determining the number of pressure and sample points in the reservoir. Formation mobility, near-wellbore skin damage, reservoir pressure, downhole compositional fluid analysis, and reservoir connectivity were evaluated in a unique and challenging environment. Reservoir connectivity results from formation testing show good alignment with the presence of fractures and other sedimentary features from borehole image data. A similar methodology can be extended to other deepwater turbidite reservoirs in the GOM.
Haynesville Shale Horizontal Well Completions: What Has Been Learned Through Post-Stimulation Completion Diagnostics and How These Learnings Can Be Employed to Make Better Wells
Authors: Warren Mark N. , Jayakumar Swathika , Woodroof Robert A.
Published: October 2017

The optimistic outlook of the petroleum industry, especially with regard to natural gas, has led to a renewed interest in shale gas plays and more specifically to the Haynesville Shale formation. Through the use of post-stimulation completion diagnostics, insights have been obtained that can be utilized to optimize future hydraulic fracturing completions.

This paper will illustrate the use of post-stimulation completion diagnostics in identifying trends that are associated with effective completions in the Haynesville Shale. Case histories will be presented which illustrate methods that have increased the overall completion effectiveness in relation to proppant placement, wellbore deliverability, and ultimately increased production performance.

A horizontal well database (> 500 wells) was compiled to identify effective completion trends across the Haynesville Shale formation. By employing proppant and fluid-based tracers, hydraulic fracture characteristics, well deliverability, and ultimately production performance were measured to highlight trends that increased overall completion effectiveness. Primary completion results highlighted areas including, but not limited to, effective proppant placement, full lateral production, frac stage length and containment, perforation cluster spacing, wellbore lateral length, and constrained flowback effects.

This paper reviews many of the insights that have been developed through this use of post-stimulation completion diagnostics in the Haynesville Shale formation and which have led to increased completion optimization, production enhancements, and field-wide cost reductions.
Subsea Sand Detection in Digital Oil Age: Case Study of An Innovative Virtual Erosion Probe Technique
Authors: Perrier Sebastien , Martins Licinio
Published: October 2017

The presence in the outflow of sand or minerals coming from the reservoirs is of course undesired, and generates a series of technical challenges and threats to installations.

Sand diagnosis (through conventional acoustic methods) is generally a frustrating process, with frequent false positive and false negative signals, and a large uncertainty on the detection thresholds.

This paper presents two innovative data treatment techniques, adapted to digital oil age:An original data transform to get the best of the conventional acoustic data analysisAn innovative virtual metering technique based on the continuous estimation of the erosion of the choke (‘pseudo erosion probe’).

This pseudo erosion probe technique has four key advantages:Significant reduction of the risks of confusion or indecisions with respect to classic acoustic methods of detection (lower sensitivity threshold than other technique), giving a chance to intervene earlier.Without being fully quantitative, it is possible to use the data obtained to define the grade of severity of sand production (in particular in term of well-to-well comparisons)It is very simple and requires no additional equipment in the case of wells equipped with individual flowmeters.Using a cumulative indicator (erosion) rather than instantaneous indicator (noise), low sand rate production or intermittent damaging sand events can be detected and not ‘overlooked’.

Combining the 2 techniques presented in this paper contributes to significant improvements in sand production diagnosis (production shortfall reduction, protection of assets…) and benchmarks between wells.

However, as learning by trial and error in the domain of offshore completion is very expensive, we found that those two techniques were particularly valuable to improve sand control failure diagnosis and select with good degree of information the appropriate solutions.
Coaching; An Effective Learning Tool to Fill Competency Gaps-A Case Study of an Upstream Oil & Gas Company
Authors: Al-Daihani Eisa , Nandi Arun Kumar , Razaa Syed Mohammad , Usmani Shereen
Published: October 2017

Coaching is an effective learning tool to fill Competency Gaps. This requires an identification of a pool of experts within the organization to act as coach, to equip identified experts with coaching skills and finally to ensure competency gaps are filled through effective coaching.

Coaching has an enormously important role in building and sustaining of great organizations and extraordinary workplaces. People who want to accomplish great things often get stuck along the way. Coaching helps people to deal with challenges to accomplish the objectives. An example of this is that while many leaders, executives, and managers in organizations seems to "know" intuitively what they need to do to move forward, few of them actually follow through because they're stuck in some way. Coaching helps people focus on the things that are considered as barrier or challenges, and then move beyond them.

The present paper emphasizes on the coaching process to be more effectively implemented especially targeting new hires. The improved process has helped us to manage and establish coaching culture through a systematic approach. Several elements have been analyzed for evolving a successful coaching process and experience. An approach has been adopted to identify a pool of experts who can transfer their knowledge to young professionals and more importantly they are willing to contribute in this process effectively. Finally, introduced a systematic coaching process after organizing awareness session for coaches to enhance and refresh their coaching skills.

This new coaching approach adopted has helped more than 400 young professionals towards completion of the program under new hire's roadmap. These young professionals have contributed in the real on-going projects that impacted directly or indirectly on achieving the business need of the group and the company.

Therefore, an effective coaching process has helped in creating competency based organization and building a pool of talent. Besides, it helped to equip these talents with right competencies at right time so that they can contribute in real time production.

Technical experts (SMEs) may be fully equipped with technical knowledge and skills but not necessarily having required skills to transfer their knowledge effectively. Also without having a systematic and robust quality assurance process, the efficiency and outcome will not be as desired.

Therefore, it is vital to first identify the experts to act as a coach with good communication skills and willingness. An effective approach adopted to establish a Discipline Experts Council and equip them with sufficient knowledge and skills related to "Coaching Process". In addition, Quality Assurance at all stages is equally important to measure the effectiveness.
The Effect of Survey Station Interval on Wellbore Position Accuracy
Authors: Codling J.
Published: October 2017

Operational reasons exist for surveying with measurement-while-drilling (MWD) instruments at station intervals greater than the recommended maximum of 100 ft (30 m). The objective of this study is to quantify the degradation of position accuracy with longer station intervals and to enhance the MWD survey error model by adding a survey-station, length-dependent term in a standard format.

The source data for this study include 150 continuous gyroscope surveys run in drillpipe in the open hole. The surveys are calculated to determine the change in bottomhole location from the original complete survey to the same survey calculated with the regular stations removed to simulate longer survey intervals. The resulting displacements are normalized by survey length, analysed statistically, and correlated to various factors, including interval length, hole angle, and overall angle change between stations.

The results of the study show a strong correlation between the length-dependent error and the angle change between survey stations. A minimum angle change per length was observed on each of the surveys, which is presented as a minimum statistical tortuosity. Therefore, vertical or inclined sections of wells that are planned or surveyed with little angle change still have a length-dependent error. The results of the study agree with perceived knowledge that highly curved sections of wells improve their accuracy through extra surveying, and vertical or straight sections do not degrade significantly when surveying with longer intervals. This study provides a simple formula for calculating the additional survey error in terms of units per 1,000 units of drilled depth. The formula is inserted into the MWD error model, sensitizing it to the length between survey stations. The study also contains an analysis of misalignment error at low angles, as it contributes to the interval-dependent error. Survey comparisons in near-vertical wells indicate that over short sections, the misalignment error causes a larger lateral error than is currently estimated using the MWD model, which has an impact on the collision-avoidance separation near the surface for platform wells. It also indicates that for longer survey intervals (>1,500 ft), the misalignment is actually smaller than what is estimated using the current MWD error model. If this revised misalignment error is adopted, the wellheads will need less separation at the surface or less effort to nudge them apart to maintain minimum separation rules on land pads.

The quantification of the survey-position error, which is dependent on the survey interval length, has not been previously presented and provides valuable information for well planning and accounts for collision-avoidance distances compared to wells that were previously drilled with surveys at infrequent intervals.
A Cost/Benefit Review of Completion Choices in the Williston Basin Using a Hybrid Physics-Based Modeling/Multi-Variate Analysis Approach
Authors: Mayerhofer Michael , Oduba Oladapo , Agarwal Karn , Melcher Howard , Lolon Ely , Bartell Jenn , Weijers Leen
Published: October 2017

In the Williston Central Basin the role of a well's completion design has a significant impact on well productivity and ultimate recovery. More than 12,000 horizontals have been drilled and completed while completion practices continue to vary widely across the basin. Several companies have adopted slickwater-only designs while others have dramatically increased proppant mass. Completions strategies have differed depending on the area in the basin. The objective of this paper is to discuss the impact of various completion changes in the Central Basin and determine which particular change delivers the most "bang for the buck" using a $/BO metric.

The approach centered around multi-variate analysis (MVA) from an extensive petrophysical/completion/production database to verify what completion and petrophysical parameters independently drive production in different areas. While MVA has been used by the authors and many others before, statistical models are limited by their ability to provide predictive relationships (mostly simple linear regressions and un-reliable beyond the data range). This paper provides a novel hybrid approach that uses calibrated relationships from physics-based modeling (combination of fracture and numerical reservoir modeling) between completion parameters and production response in combination with statistical MVA results. Specifically, the physics-based model is calibrated or "history matched" to a measured production/completion parameter response as provided by MVA, thus delivering a constrained and more physically realistic production response to suggested completion changes. This model is then coupled with a completion cost model to determine which completion method is the most effective to lower $/BO.

Many common completion parameter changes, such as increasing stage intensity, moving to plug & perf cemented well designs, increasing injection rate, increasing proppant mass per lateral foot and fluid volume per lateral foot, have a positive impact on production and are advantageous to lower $/BO in all areas of the Middle Bakken and Three Forks. The new hybrid MVA approach indicates that pumping slickwater treatments with average proppant concentrations of 1 lb/gal and treatment sizes from 750 to 1,150 lb/ft at pump rates approaching 100 bpm through a stage length of 200 ft (50 stages for a 10,000 ft lateral) may be the economic optimum provided there are no significant well communication issues.
Drilling Mud Loss in Naturally Fractured Reservoirs: Theoretical Modelling and Field Data Analysis
Authors: Razavi Omid , Lee Hunjoo P. , Olson Jon E. , Schultz Richard A.
Published: October 2017

Real-time analysis of drilling mud loss data is an effective tool to characterize the size, distribution and permeability of natural fractures. The estimated properties of natural fractures can then be used to modify the drilling fluid properties and design remedial mud loss treatment to stop further drilling fluid loss. Moreover, characterization of natural fracture provides crucial information for the design and application of reservoir stimulation operations.

In this paper, we present a theoretical model to simulate the invasion of the drilling fluid into natural fractures. Mathematical modelling was performed for two types of rheology constitutive models which are commonly used for drilling fluids, namely Bingham Plastic and Herschel-Bulkley. The fluid leak-off into the formation is modelled using Carter's model. Moreover, a simplified local elasticity equation is used for the fracture width variation due to fluid pressure. A forward finite-difference numerical scheme is used to solve the pressure drop equation. The developed model is then validated against well-known analytical solutions and numerical simulations. Parametric studies were conducted to evaluate the impact of the fracture deformability, formation leak-off properties, drilling fluid rheology, and the pore fluid contribution. Finally, the output of the developed model is compared with the field data of a welldocumented mud loss incident.

The obtained results indicate that the incorporating the effect of the fluid leak-off may significantly increase the rate of mud loss volume. Therefore, for highly permeable formations (such as carbonates), considering the impact of the fluid leak-off effect seems necessary for a realistic characterization of the mud loss problem. Fracture deformability affects the mud loss volume, with higher deformability leading to a larger mud loss volume. Also, the numerical results confirmed that the rate and magnitude of mud loss volume is significantly affected by the rheological properties of the drilling fluid, in particular the yield stress. In contrast, the effect of pore fluid seems relatively negligible for typical formation fluid types. Comparing the results of our simulation with mud loss field data shows that the developed model can accurately predict the rate and total volume of mud loss into the fractures. Moreover, it shows that incorporating the impact of the fluid leak-off and the fracture stiffness may significantly affect the fracture width prediction. Therefore, these factors should be considered to obtain an accurate estimate of the natural fracture aperture.
Dynamic Modeling to Support the Successful Start-Up of a Challenging Well
Authors: Wang J. Y. , Troshko A. A. , Gallo F. G. , Mayer C. S. , Rosenbaum D. F. , Lopez T. H. , Helgestad D. E. , Seitinger P.
Published: October 2017

Effectively managing risks to achieve a safe and reliable start-up is a crucial step before diverting a well to production facilities. This paper describes a successful offshore well start-up in Norway's Sigyn field, assisted and guided by advanced well simulation. The field's low reservoir pressure presented a challenge to offload drilling mud from the well lower completion. Thus, a decision was made to displace the upper completion with lift gas to facilitate unloading. However, start-up of the Sigyn well still presented a challenge due to complex multiphase transient flow during offloading and the possibility of large liquid surges during kick-off. These surges could potentially overwhelm the test separator and force the well to be shut in. To minimize these risks, robust start-up guidelines were needed accounting for a range of completion, flow lines, surface separator and reservoir conditions.

To develop these guidelines, an integrated multiphase dynamic model was developed to evaluate the merits of different completions and start-up strategies. The model was able to simulate 3-phase, 5-species (mud/brine/nitrogen/oil/reservoir gas) multiphase flow in the well and facilities including tubing, annulus, gas lift valve, choke, riser, pipeline and separator. Modeling results provided operators with data about expected flow parameters and timing of events. This information enabled the host platform to anticipate the time and magnitude of liquid surges. Associated well completion erosion risks during mud clean-up from an unconsolidated reservoir were also assessed and managed. Sensitivity studies allowed selection of the fit for purpose equipment and identification of the consumables required to start up the well.

The well was successfully unloaded in July 2016. Good agreement was found between the real-time measurements and model predictions. The results demonstrated that information gained from complex modeling can provide valuable insights leading to development of the informed guidelines for the safe and reliable start-up.