bluuebunny/crossref_metadata_2025 huggingface dataset:
Ética empresarial y sociedades en crisis desde un enfoque axiológico
Authors: Sotomayor Morales Eva María , Cámara de la Fuente Macario
Published: June 2014

A comienzos del siglo XXI, cuando aún no se han terminado de consolidar los posicionamientos paradigmáticos que otorgaban a la empresa una función social más allá de la mercantilista, la crisis económica ha provocado cierta fractura de las bases en las que fundamentaban estos discursos, lo que genera un interés por el análisis de la ética empresarial desde diversas perspectivas. Partiendo de estos antecedentes, desde un enfoque axiológico, el objetivo de este trabajo es realizar una disertación conceptual a través de la discusión del fenómeno en torno a las necesidades y a los valores, al objeto de analizar los patrones referenciales presentes en los ámbitos normativos, las demandas sociales y los factores comparativos con otros períodos análogos, como la Gran Depresión de 1929, tomando como base para ello la teoría de las necesidades de Bradshaw. Con la finalidad de sentar las bases analíticas para futuras investigaciones, el resultado ha sido la agrupación de los conceptos en cinco grandes díadas necesidad/valor.
Integrating Security into Agile Models
Authors: Ghani Imran , Arbain Adila Firdaus Bt , Azham Zulkarnain , Yasin Nor Izzaty , Jeong Seung Ryul
Published: June 2014

Agile methodologies have gained recognition in recent years as being efficient development processes through their quick delivery of software, even under time constraints. Agile methodologies consist of a few process models that have their own criteria in helping different types of projects. However, agile methods such as Scrum, Feature-Driven Development (FDD), and eXtreme Programming (XP) have been criticized due to the lack of availability of security elements in their various phases, resulting in the development of unsecure software. Thus, the authors propose the idea of a set of security-focused elements to enhance the existing agile models. In this chapter, the findings of the related research and the highlights of improved agile models after the integration of security are presented.
Turkish Case of E-Government Strategy Development and Policy-Formulation Process
Authors: Balcı Asım , Medeni Tunç Durmuş , Nohutçu Ahmet
Published: June 2014

Use of Information Communication Technologies (ICTs) by governments all over the world has opened new avenues in terms of redesigning the relationship between the state and not only the society but also the businesses, creating new forms of relationships with wider meanings especially for the society as a whole, and ideas and practices regarding policy making process. While enjoying centralist tendencies and a strict hierarchical bureaucratic model intrinsic to the inner cycles of the organizational levels, the Turkish administrative system has been trying new forms of governance models exemplified in e-government policies. This paper tries to analyze and discuss the main tenets, actors, coordinating and partnership mechanisms, undertakings, evaluation techniques and prospects of e-government policies as a newly emerging policy area with specific reference to Turkish e-transformation efforts, policies and initiatives. Firstly, the paper would underline the “formation” and “participation” (formulation) dimension and stage of the ICT policy process. Presenting up-to-date information and analyses regarding the developments in recent and current stage of evolution, guidelines and suggestions for future are also provided. The discussion will also be furthered by an analysis of country (Turkey) rankings in international (United Nations) e-government reports as an up-to-date case of strategy development, policy formulation and implementation.
Relationship Between Near Seafloor Seismic Amplitude, Impedance, and Soil Shear Strength PropertIes and Use in Prediction of Shallow Seated Slope Failure
Authors: Brand J. R. , Lanier D. L. , Berger W. J. , Kasch V. R. , Young A. G.
Published: June 2014

The movement of petroleum exploration and production to the frontier deepwater and ultra-deepwater of the Gulf of Mexico presents a variety of engineering challenges. One such challenge is the placement of seafloor production infrastructure on or near the base of steep slopes associated with the Sigsbee Escarpment. As a result, the potential hazards associated with shallow seated slope failures have become a legitimate concern. These types of failures can result in the formation of debris flows and turbidity currents capable of damaging or destroying seafloor structures in their path. The potential for significant damage or loss of seafloor facilities from such an event merits a comprehensive understanding of the factors that influence shallow slope failures. However, total field coverage with geotechnical cores to assess these factors is neither logistically or economically feasible nor practical. We present a new method for integrating these factors with available geotechnical core data and 3D seismic to quantitatively extrapolate and predict the location of critical areas of potential shallow seated slope failure.
GIS Based Analysis for Pipeline Protection Against Ice Gouging
Authors: King T. , Phillips R. , Barrett J. , Cuff A.
Published: June 2014

GIS-based software has been developed under the PIRAM (Pipeline Ice RiskAssessment and Mitigation) program for performing pipeline routing and burialanalysis for protection against ice keel gouging. Results are presented for ahypothetical pipeline in the Canadian Beaufort Sea. A probabilistic pipelineburial analysis is incorporated that accounts for the influence of sub-gougesoil displacements. Ice gouge rates and geometry are based on repetitivemapping survey data.
Natural Gas Hydrate (NGH) Arctic Ocean Potential Prospects and Resource Base
Authors: Max Michael  D. , Johnson Arthur H.
Published: June 2014

The compact Arctic Ocean region is the last major hydrocarbon frontier areain the Northern Hemisphere and may possibly be the single richest natural gashydrate (NGH) province on Earth. Because of the extreme weathering and erosionconditions associated with the alternating glacial and interglacial conditions, much of the sediment in accessible gas hydrate stability zones (GHSZ) may havethe same well bed-differentiated, coarse grained character of excellent NGHreservoir hosts. These reservoirs are of the same type that may hostconventional hydrocarbon deposits in more deeply buried sediments. Existingindustry exploration techniques have been used to identify potential NGHdrilling targets, and drilling in the northern Gulf of Mexico has validated theexploration technique. The Nankai deposits off SE Japan and the depositsdrilled in the northern Gulf of Mexico are excellent examples of thesand-turbidite continental margin paratype. It is estimated from examples andapplication of NGH petroleum system analysis that over 6,000 Tcf of natural gasin place may be present in NGH-enriched deepwater turbidite sands within deepcontinental shelf and slope sediments of the Arctic Ocean. In addition todeepwater turbidites, which are well known from other continental margin areas, such as the Gulf of Mexico, two other prospective zones may exist in the ArcticOcean. Troughs, which are glacially excavated depressions that generally deepentoward the shelf margins, may host NGH in sediments that are transitionalbetween the deepwater turbidites and continental shelf sedimentation. Concentrations of NGH may also be accessible from isolated outliers, which areupstanding continental crust fragments that are present within the Amerasia andEurasia Basins.
Application and Evaluation of a NanoFluid Containing NanoParticles for Asphaltenes Inhibition in Well CPSXL4
Authors: Zabala Romero Richard Disney , Acuna Hector M. , Cortes Farid , Patino Jose Edgar , Cespedes Chavarro Carolina , Mora Edgar , Botero Oscar Fabian , Guarin Liliana
Published: June 2014

This paper describes the evaluation of a fluid containing nano-materials with high adsorption capacity for Asphaltenes inhibition in a volatile oil field in Colombia. Asphaltenes precipitation has been identified as one of the most potential damaging mechanism affecting the well productivity in Cupiagua Sur Field. Before this work traditional techniques have been tested in the field for asphaltenes inhibition. The goal of the injection of nano-fluids containing nano-particles of alumina with high surface area (>120 m2/g) is to absorb the asphaltenes before being flocculated and carry them with the condensate avoiding precipitation near the well bore.

In the first stage of this work, lab testing, the adsorption capacity of alumina nano-particles for the asphaltenes produced in the field was evaluated, next, the nano-fluid containing nano-particles was evaluated in the Mirador formation plug cores by performing flowing core tests at the reservoir conditions. Returns of the relative permeability curves were quite good, improving Ko from 0,09 md to 6,13 md which enabled us to recommend the application of this nano-fluid in the well CPSXL4.

For the Field Application, the job was designed by forcing 220 bbl of nano-fluid within a radius of 8 ft. After the job, through monitoring with SARA analysis in produced fluids and the residual tracking of nano-particles as well. Maintenance of asphaltenes concentration in the produced fluids has been observed. Also, significant gain in the oil and gas production has been reported, with more than 100,000 bbls of cumulated gain production in only 4 months after the job was performed. Results may be promising and now it is possible to extend application of nano-fluid in other wells in this field.

INTRODUCTION

The Cupiagua Sur field is located 110 kilometers northeast of Bogota in the foothills of the eastern mountain chain of the Colombian Andes, close to other fields discovered in this area such as Floreña, Pauto, Volcanera, Recetor, Cupiagua and Cusiana (Fig. 1). Despite the fact that Cupiagua Sur is very close to Cupiagua, this reservoir is totally independent and separate. It is formed by a back thrust structure with several reservoir pressures, properties and contact fluids.

Cupiagua Sur is a compositional volatile oil reservoir with an average API gravity of 38°; there is no free gas cap at initial conditions. The main formations are Mirador and Barco which are quite similar about petrophysical and fluid properties (average permeability is 21 md and average porosity is 6.5%).

It is a prolific oil field that in fifteen years of production has recovered 88 MMstb gross out of 189 MMstb original in place from Mirador and Barco reservoirs in a developed area with four producer and two injector wells.
Comparison of Various Methods for the Assessment of Wind and Current Loads on a Semi-Submersible Platform
Authors: Croonenborghs E. , Sauder T. , Fouques S. , Reinholdtsen S.A.
Published: June 2014

The wind and current loads on a large semi-submersible platform were assessed using various methods by several participants. All participants treated the current and wind analyses separately. The current analyses were performed in a uniform flow. The wind analyses were performed in an atmospheric boundary layer flow. Flow angles ranging from 0 to 360 degrees were considered. Participants 1 and 2 performed wind tunnel tests on the same 1:250 scale model. Participant 3 performed steady-state full scale CFD simulations. Participant 4 performed towing tests (for the current loads only) on a 1:60 scale model. This paper presents, compares and discusses the results obtained with the different methods. The objective of this paper is to evaluate the variability which can be obtained in the results when using different validated and trusted approaches. The comparison shows significant discrepancies between the obtained wind and current loads. These discrepancies may be due to various aspects of the method setups such as the modeling of the atmospheric boundary layer flow, the scaling effects and the experimental uncertainty regarding the measurements.

Introduction

Wind and current loads contribute significantly to the total environmental loads on offshore structures. An accurate determination of those loads plays an important role in the assessment of e.g. stability and design of positioning systems. While underestimating the loads may lead to unacceptable safety margins, overestimation yields an inefficient design of offshore structures, e.g. a reduced deck load and costly design of positioning systems.

The flow patterns around the offshore platform are very complex. For accurate predictions of the wind and current loads, it is important that the assessment method includes a complete modeling of all the relevant physics. The traditional and most trusted method is based on wind tunnel tests on a scaled model. Towing tests also fulfill this requirement for current loads assessment. CFD simulations have also the potential to assess wind and current loads and are now recognized as a valid alternative to wind tunnel tests for analyzing flows around offshore structures. Independently of the method used, the loads must be determined in a carefully modeled environment.

In this study, four participants were asked to evaluate wind and current loads on a floating semi-submersible platform. The hull comprises a ring pontoon with six columns to support the topside. Participants 1 and 2 performed wind tunnel tests on the same 1:250 scale model. Participant 3 performed CFD simulations. Participant 4 performed towing tests (for the current loads only) on a 1:60 scale model. This paper presents, compares and discusses the results obtained by the four participants. The variability which can be obtained in the results when using different validated and trusted approaches is evaluated in this paper.
Establishment of Operational Criteria for Safe Launch of Free-Fall Lifeboats From a Turret-Moored FPSO
Authors: Fouques Sebastien , Croonenborghs E. , Aksnes Vegard , Luxcey Neil , Reinholdtsen Svein-Arne , Jokstad Cecilie
Published: June 2014

The evacuation of personnel from floating production, storage and offloading (FPSO) vessels in case of accidental scenarios is generally ensured by free-fall lifeboats launched from skids. Safe lifeboat launches occur for a specific range of pitch angles at water entry: flat water impacts may cause dangerous acconal criteria for safely launching the lifeboats. The importance of the wind velocity and direction with respect to the lifeboats is investigated. The study mainly focuses on the acceleration loads experienced by the passengers during water-entry and it is based on numerical simulations and model tests for the validation of the simulation tools and models.

Introduction

Free-fall lifeboats launched from skids constitute the primary means for evacuating FPSOs in sea states that do not permit helicopter landing, i.e. typically when the significant wave height Hs is larger than 5m. These lifeboats are generally installed at the bow of the FPSO at ca. 20m above the calm water level. The lifeboat launch is then influenced by environmental parameters such as the significant wave height Hs, the spectral peak period Tp and the 1-hour mean wind velocity Uw. In addition to environmental parameters, other factors like the heading strategy of the FPSO with respect to waves and wind, the loading conditions of the FPSO and the lifeboat, possible damage scenarios for the FPSO including loss of thrust or additional trim and list are also of significance.

The present paper is concerned with the establishment of operational criteria for safe launch of free-fall lifeboats from a turret-moored FPSO in the Norwegian Sea. The final goal is to estimate the probability of successful launch as a function of a selected set of the parameters listed above. So far, the main failure mode considered in this study has been possible human injury during water impact due to large accelerations. An example of quantity one aims to estimate is the conditional probability of being injured when seating in the aft seat row of a fully loaded lifeboat, if Hs is between 8 and 10 meters and the mean wind velocity Uw is larger than 20m/s. Provided a weather forecast, the obtained probabilistic model can then be used to decide if the lifeboats can be used in this sea state or if some seating restrictions have to be applied.
Maximizing Heavy Oil Production and Reserves Through a Multidisciplinary Well Construction Process
Authors: Haugen Vibeke Eilen Jensen , de Lima Claudio Jose Teixeira , Galletti Eduardo , Loures Luiz Geraldo Lucchesi
Published: June 2014

The paper discusses the aspects of the multi-disciplinary well construction process (WCP) that is being applied in the development of Peregrino field located offshore Brazil. Peregrino field is a heterogeneous sandstone reservoir containing a large volume of viscous oil in a complex depositional geological environment. The field development is based on a large number of long horizontal and multilateral wells equipped with high energy-demanding Electrical Submersible Pumps (ESP) for artificial lift.

The well construction process covers the feasibility, concept selection, detailed plan and execution phases. The efforts towards a multi-disciplinary process allow cost optimization, risk mitigation and production and reserves maximization. Multi-disciplinary teams include not only the usual subsurface disciplines (geophysics, geology, operations geology, petrophysics, reservoir and production technology) but also drilling, completion, topside and operations from an early stage.

In viscous oil fields it is especially important to meet the requirements in reservoir properties, well length and completion design to develop such a field economically. The applied WCP is allowing Peregrino field to achieve its goals in terms of numbers and quality of wells planned and drilled. More than 20 wells have been drilled so far with very good results. Peregrino is now producing at plateau production with a daily oil production potential of 100,000 bbl.

Introduction

Peregrino is currently the largest offshore heavy oil field in Brazil (14 ºAPI density and viscosities up to 400 cP) on production. The field is located in the southern part of Campos Basin, offshore Rio de Janeiro state (Figure 1). The reservoir lies between 2150 and 2350 m TVD MSL at a water depth of 120 m. Statoil is the operator (60%) with Sinochem as partner (40%).
Minimizing Scale Deposition Through Surface Enhancement in Downhole Tools
Authors: Graham Gordon Michael , Bezerra Maria Carmen Moreira , Goodwin Neil , Albino Eduardo Henrique , Pinto Hardy Leonardo , Bhavsar Rashmi B.
Published: June 2014

Inorganic scales are a significant production issue with extensive inorganic scales observed in many Brazilian offshore fields and is also a worldwide phenomenon resulting in considerable productivity impairment. With the intervention of more sophisticated downhole tools such as inflow control devices (ICDs) and inflow control valves (ICVs), increased shear stresses are experienced in the wellbores near these devices resulting in an increased risk of scale formation and adherence even under very mild levels of oversaturation. The impact of scaling on or near ICDs or ICVs will have a dramatic impact on productivity since scaling would form in the wellbore itself.

In this work we have focused on downhole carbonate scaling under Petrobras new deepwater field conditions where the drawdown in the near wellbore area results in oversaturated brine systems. Downhole conditions have been modeled and closely simulated in the laboratory to ensure that laboratory conditions closely match the mild level of over saturation expected due to drawdown such as the ones present in ICV orifices.

The work initially examines the relationship between increased shear and scaling examining both bulk scaling (homogeneous precipitation) as well as the relationship between shear and surface scaling. The results show that there is interdependence between bulk and surface precipitation as a function of increased shear. In addition the work examines a range of different materials of construction commonly used in ICVs including different metallurgies, and different surface finishes as well as coatings specifically designed to minimise the potential for scaling.

Work at a variety of shear conditions clearly shows the potential to minimise surface scaling by careful material selection and / or by the use of specially formulated surface coatings. A mock valve has also been designed and commissioned to allow testing of the potential for scaling under realistic downhole flow conditions at representative downhole temperatures and pressures. Preliminary work using this more representative " pilot" test design is also discussed.
Increasing Oil Recovery on the Grane Field With Challenging PWRI
Authors: Tipura Lejla , Tjomsland Tore , Fagerbakke Ann-Kristin
Published: June 2014

The G-32 well was the first PWRI (produced water re-injector) to be drilled into the Heimdal Formation at the Grane oil field, located in the Norwegian Sea. Reservoir simulations suggested that G-32 would improve reservoir drainage in the area, providing an important increase in oil recovery through the nearby oil producers. The well was planned as a matrix injector rather than a fractured injector to optimize the reservoir drainage. This gave challenges related to well cleanup and also required good water quality to avoid loss of injectivity by screen/formation plugging. A large effort was made in the preparation phase for G-32 to minimize the risk related to these issues and with the precautions taken, low risk of plugging and loss of injectivity was predicted. This paper will summarize the G-32 experience from both a production and a reservoir management point of view. Simulations and testing performed prior to starting up the G-32, including fracture simulations, produced water analysis, lab tests of the completion fluids and injection experience will be presented. Finally, expectations from the reservoir simulations performed prior to G-32 start-up will be discussed and compared with production experience.

Introduction

The Grane field is a mature oil field located about 185 km west of Haugesund, in the North Sea, Figure 1. It was discovered in 1991 and the field came on stream September 2003 with license to produce until 2030 (J.A. Haugan et al, OTC 18234). Oil is currently produced from 26 wells, 14 of them are multilaterals. Three injectors are drilled into the reservoir, two gas injectors and one water injector (G-32). Two water disposal wells are injecting water into the shallower Utsira Formation.
Aboriginal Engagement and Development of Northern Projects
Authors: Bosgoed Gary , Collett Blaine , Willier Dion
Published: June 2014

Positive and sustained relationships are essential to ensure successful project outcomes. In fact, according to Independent Project Analysis, an important best practice is an Integrated Project Team. The public attention to recent Oil Sands related projects in northern Canada is an example of the need for projects to effectively engage local communities early and to seek out opportunities to make all project stakeholders successful. Aboriginal communities are an often overlooked part of a project's execution plan and its long term success.

Success in remote locations means project objectives must be aligned with local cultures, traditions and social values. In the past, the economic benefits of a project were the primary driver of community alignment with development. Today economic development, while important, must align with the needs of Aboriginal societies. Because the underlying resource reserves are very large, project benefits may need to be realized over two or more generations.

An Aboriginal Engagement strategy has been developed and implemented with Aboriginal communities most affected by northern energy, mining and infrastructure development projects. A core part of this strategy is to have corporate values and policies committed to open, positive, long-term and sustainable relationships with Aboriginal communities most of whom in this paper are in northern Canada. This paper will discuss ways of effectively engaging Aboriginal communities to align their traditional and cultural lives with the socio economic benefits of northern development. This contributes to the ongoing well-being of the community over the life of the project.

Aboriginal Engagement must start well ahead of the project's Permit to Build. This facilitates appropriate engagement with Aboriginal communities to fully understand the traditions, culture and underlying social and economic structures so that subsequent agreements realize both community and corporate benefits, and to craft relationships respectful of both aboriginal and corporate values. In the case of large projects, a company may need to engage with several communities. Successes and progress in implementing this strategy will be covered, as will ongoing application of the process to adapt to unique community needs for others.

The numerous challenges faced by Aboriginal communities in the face of northern industrial development will be discussed, including the unique project opportunities afforded to them. Engagement and empowerment of Aboriginal youth through education and skills will also be covered in light of expected labor shortages, particularly in the construction industry.
Arctic Pipeline Leak Detection using Fiber Optic Cable Distributed Sensing Systems
Authors: Thodi P. , Paulin M. , Forster L. , Burke Julie , Lanan G.
Published: June 2014

Multiple offshore Arctic fields have been developed over the past three decades and the world demand for oil and gas will continue to drive hydrocarbon development in Arctic and sub-Arctic environments. Arctic pipelines are used for the safe and economic transportation of hydrocarbons. While pipelines are designed not to leak, excessive strains due to the effects of ice gouging, strudel scour, frost heave and permafrost thaw settlement along with other loading and failure mechanisms (i.e. corrosion, third party damage) could result in a leak. Failure to detect leaks in a timely manner could have severe safety, environmental, and economic impacts. Large leaks can easily be detected, but small chronic leaks may go undetected for a period of time, especially when pipelines are buried in remote locations or under seasonal ice cover.

First, this paper reviews existing Leak Detection System (LDS) technologies for their potential use on Arctic and sub-Arctic pipelines. The technology evaluation based on regulatory requirements and functional criteria suggests that Fiber Optic Cable (FOC) distributed sensing systems have a high potential to be used on Arctic pipelines. Distributed sensing FOC can be used to detect and locate leakages. Pipeline leakage would generate a local change in temperature. These thermal anomalies can be captured by FOC Distributed Temperature Sensing (DTS) systems with good spatial and temporal resolution. Similarly, the acoustic signature generated by leaking fluid can be detected using FOC Distributed Acoustic Sensing (DAS) systems. Inelastic Brillouin and Raman backscattering principles are used for measuring temperature in DTS, whereas the Rayleigh backscattering principle is used for measuring acoustics in DAS. This paper presents information on applicable regulations, operating principles, optical budgets, system integration, sensor positioning, installation and maintenance assessment, technology status, risk analysis using Failure Mode, Effects and Criticality Analysis (FMECA) and field implementation challenges.
Spectral Fluorescence/Reflectance Optical Sensor Systems for Arctic Oil Spill Detection and Mapping
Authors: Mooradian Greg , Richter Dean , Marttila E.J. , Solonenko Michael , Saade Edward
Published: June 2014

In the rapidly expanding field of oil exploration and production, there is an emerging requirement to reliably detect, characterize and geospatially map oil spills in ice-covered waters during both summer and winter months in the Arctic. This paper postulates two possible platform-based sensor architectures and examines predicted performance for the following:an airborne, high-search-rate Spectral Fluorescence/Reflectance Lidar (SF/RL) that has the potential to detect and geolocate oil beneath the Arctic ice as well as accurately measures ice thickness andan autonomous underwater vehicle (AUV)-borne sensor that can operate between the seafloor and the base of the ice utilizing an active optical spectral detection and discrimination sensor for oil trapped under the ice, settling on the seafloor and drifting in the water column. Search rates for an aircraft at 2,000 ft and 125 kts through 4 inches of snow and 8 feet of ice with nominal Lidar system parameters is predicted to be 336 km2/hr (1.5 km swath width and 20 m spatial sampling). The AUV-borne sensor would be composed of a compact SF/RL payload that conically scans ± 50° from nadir at a nominal oil detection depth of 75 ft.
Ice Gouging and Its Effect on Pipelines
Authors: Liferov Pavel , Nes Hroar , Asklund Joakim , Shkhinek Karl , Jilenkov Alexander
Published: June 2014

The objective of this paper is to demonstrate how modelling can be used to account for the inherent correlations while assessing the pipe response to ice gouging – and thus narrow down the uncertainties associated with the pipeline design process.

A custom-developed numerical model of ice gouging has been developed and exercised to better understand how the environmental conditions affect the gouging process. Further, numerical simulations of the keel-soil-pipe interaction have been performed, relating to the input and output of the ice gouging model.

The ice gouging simulations quantitatively demonstrated the effect of the governing parameters on the gouge depth. Geotechnical conditions are very important as the main source of resistance against the driving force from ice, making a noticeable difference in the gouge depth. Force balance is also important, in particular how the vertical forces are generated or/and limited by natural phenomena such as the shape of an ice feature, seabed topography and tides. The effect of the driving force and the keel resistance limits have not been dealt with within the scope of the present study.

The ice gouging simulations demonstrated that ridges with steeper rake angles result in deeper gouges. Similar gouge depths have been attained irrespective of the path – via water level changes or via seabed slope - as long as the driving force was available. The keel-soil-pipe simulations demonstrated that increasing the rake angle results in lower pipe response. Deeper gouges give larger effect at the same clearance between the top of the pipe and the gouge bottom.

Considering the performed simulations jointly, it can be concluded that selecting the n-year gouge depth implicitly sets the conditions for assessing the variability in the additional governing parameters. This is mainly applicable to the keel's rake angle as the factor having the strongest correlation with the gouge depth, keeping other parameters unchanged. Appreciating the correlation above and its effect on the n-year pipeline load effect can prevent possibly overly-conservative parameter combinations.

It is argued that steeper keels have the highest potential to produce deepest (extreme) gouges. For these conditions, the extreme gouge load effect seems to be acceptable as long as there is a gap between the pipe and the ice keel and the pipe wall thickness is relatively large. Thus, the pipeline design against ice gouging load effects is likely to be governed by the maximum gouge depth, as the gap itself is found to define a sharp limit between an acceptable and an unacceptable design condition. In turn, this sets high requirements to reliable determination of the gouge depth.
Arctic Offshore Pipeline Design and Installation Challenges
Authors: Paulin Mike
Published: June 2014

With the oil industry's continued quest for oil and gas in frontier offshore locations, several developments have taken place in regions characterized by seasonal ice cover including the US Beaufort, North Caspian, and Sakhalin Island. In these projects, pipeline transportation systems have been used, which are a cost effective, safe and reliable mode of hydrocarbon transport to shore. Ice gouging is one of the key design issues that affect engineering considerations with respect to strain based design, target burial depth requirements, cost, and safety.

It is generally accepted that offshore pipelines in ice environments will need to be trenched and backfilled for protection. Burial depths can be greater than those that might normally be required for pipelines in temperate climates. Burial depth requirements will be a function of the design ice gouge depth (to prevent interaction between the ice and pipe) and an acceptable level of subgouge deformation beneath a gouging ice keel (which potentially strains the pipeline). There still exists uncertainty on the magnitude and extent of subgouge soil deformations due to ice gouging and the importance of sediment transport mechanisms for biasing gouge statistics.

Other challenges that must be considered include strudel and hydrodrnamic scour, thaw settlement and frost heave, and upheaval buckling. These considerations may also influence burial depth requirements.
Control of Bottomhole Pressure in Managed Pressure Drilling using IMC Controller
Authors: Nandan Anirudh , Imtiaz Syed , Butt Stephen
Published: June 2014

In this paper we present a simple proportional integral (PI) with internal model controller (IMC) tuning for kick/loss rejection for managed pressure drilling (MPD) process. Arctic regions are very fragile and hence precaution must be taken to avoid any blow out. MPD is a promising technology for well control. Several complex controllers are available in the literature for controlling MPD but design and implementation of such controllers require the knowledge of advanced controls. It would be beneficial to check the suitability of simple controllers for the control of MPD. We propose a switching PI controller with IMC tuning. In order to synthesis the controller the process between the bottomhole pressure and choke opening was identified. It was observed that the process was highly nonlinear for lower choke openings and hence two separate cases of choke openings were considered for controller synthesis. The synthesized controller was used to reject a kick of 100 lpm and it was observed that performance of the controller was reasonable. We also show that the controller will be able to track the setpoint robustly at different choke openings. The proposed controller requires minimal human interference and it is very simple to implement. We demonstrate that complex advanced controllers will be beneficial from a technical point of view and to meet tough conditions, nevertheless simple controllers can also deliver a reasonable performance.
Methodology for Combined Local and Global Ice Pressure Estimation based on a Probabilistic Model of High Pressure Zone Behavior Derived from Field Data
Authors: Taylor R.S. , Richard M.
Published: June 2014

As our understanding of the failure processes and mechanics associated with individual hpz behavior advances, new models are needed to link hpz behavior with local and global pressures for full-scale interactions. This paper is focused on the development of a probabilistic compressive ice load model for thin first-year sea ice based on statistical descriptions of high pressure zones (hpzs) derived from the analysis of tactile sensor data collected during the Japan Ocean Industries Association (JOIA) medium-scale field indentation test program. The aim of this work is to provide a probabilistic model of hpz behavior that simulates observed local and global pressures and associated scale effects, particularly for interactions involving thin first-year sea ice. Probabilistic descriptions of high pressure zones based on field measurements have been extracted and are incorporated into a model for linking hpzs with methodology for ice pressure estimation. A comparison with local and global pressure design curves generated using methodology provided by ISO 19906 is included.
Comprehensive Adjustment Techniques Based on Detailed Oil Distribution Enhance Oil Recovery at Mature Offshore Field
Authors: Li Tingli , Wang Yunxian , Liao Xinwu , Zhao Chunming , Yang Qinghong , Su Yan chun , yong Hu , Wei Qin , Xu Yuxia , Bie Xuwei , chao Liu , Su Jinchang , Zhang Yunlai , rong Fu , Yu Dengfei , Wei Zhang
Published: June 2014

Qin Huang Dao 32–6 (QHD32–6) oil field located at Bohai Bay of China is a large heavy oil (74–260mPa.s) field with flat structure, multi-pay zone, complex oil and water contact system discovered by CNOOC (Fig. 1). The development plan is drilling vertical wells to penetrate multi zones with large well space (350-400m) in 3 blocks (North, South, and West). Due to comingle production pattern and quickly coning of the bottom water, the wells became mainly water producer and faced to be shut-down after a short period of the first oil.

Measurement like water zone isolation and water injection optimization has been conducted to improve the production for short time. However, it is still not feasible in a long run to enhance oil recovery based on the research of water sweeping condition and remaining oil distribution. We faced a number of challenges, such as low oil production (35m3/d), high water cut of the field(86.6%) and low recovery factor(11.3%). A quick implementation of field comprehensive adjustment plan is needed to arrest the quickly water coning and fast production decline. While designing, a workflow integrating geological, well log, seismic and dynamic production data was developed to optimize the oilfield recovery factor.

Following the workflow, we started with detailed reservoir description of sandbodies and systematically analyzed the remaining oil distribution mode. Then the comprehensive adjustment plan focus on develop from separate zones was carried out and the first batch of infill horizontal pilots was implemented. The responses from pilots were very positive resulting in better oil productivity (64m3/d) and longer low water-cut period.

Finally, the comprehensive adjustment plan put forward 101 new infill wells and converted some part of old vertical wells to inject water for separate zones production, which resulting in 10% recovery factor enhancement. The oil recovery rate is raised from 0.8% to 1.7%. Our experiences showed that such comprehensive adjustment techniques based on detailed oil distribution is crucial to achieve better water-flooding development efficiency for offshore reservoir.
Post-installed Mudmat
Authors: Fontaine Emmanuel , Dilosquer Steven
Published: June 2014

The paper presents a new subsea structure foundation concept and installation method, called the post-installed mudmat. With this new method, the thermal expansions and displacements of HP/HT flowlines are no longer limiting criteria for the subsea structures. It is applicable to the pipeline end termination (PLET), either first end or second end, and In-Line Tee structure to be laid in any mode (S, J or Reel lay). Combined with Subsea 7 experience of installing structure in all modes, the study is based on computer works to verify the installation sequence, the pipeline integrity and the geotechnical strength.

The post-installed mudmat concept is applicable to the projects where the pipe laying method includes structures. In the present application, the pipeline is laid in standard S (also applicable to J or Reel lay) mode with a piping module, including valve and connectors, going through the vessel tensioners and stinger also called firing line. Generally two mudmat wings are added before reaching the stinger and then unfolded subsea. In the new method, a purposely designed mudmat and associated devices is post-installed at sea-bed level on top of a previously laid simple pipeline and module. The specific mudmat guiding and securing device allows the pipe module leveling and weight transfer before the mudmat fulfills its foundation functionality.

Comprehensive computer simulations have been performed to verify the laying of pipe module and the new post-installed mudmat on the sea-bed. Calculations confirm the integrity of the pipeline at anchor point to the mudmat after installation. Geotechnical simulations also verify the piping module temporary bearing and the final foundation capacity and settlement. The post-installed mudmat design brings a significant contribution to the pipeline laying method. The mudmat size is no longer a limiting parameter for its integration in the main line. Compared to its opposite design, the pre-installed mudmat, it is not impacted by the installation tolerances which would make it larger and longer. It can also be fixed, sliding or fitted with rails to accommodate the pipeline thermal expansion without significant impact on the piping module design going through the main line. It presents an alternate to other method with separate deployment table generally retained for PLETs or In-Line Tees too large for the standard main line. This post installation process is patent pending.
Jack-St. Malo Marine Operator Training Simulator
Authors: Hudson Chris , Walker Kevin , Rastogi Ankur , Bhaumik Tirtharaj
Published: June 2014

A Marine Simulator was developed for the Jack-St. Malo field located in approximately 7000 feet of water in the Gulf of Mexico Walker Ridge block. The simulator presented operational information in a form similar to that on the actual facility and provided operational personnel with extensive operational experience and training on scenarios as may be faced in the actual facility, prior to and subsequent to facility start-up.

The design of the ballast system for this Semi-Submersible Floating Production Unit (FPU) called for a comprehensive training procedure as an added operational safety measure for the marine operators. The Jack-St. Malo Marine Simulator utilizes process and safety control configurations that are the same as the facility. It includes a Load Management system and an Environment and Facilities Monitoring System (EFMS) integrated with a high fidelity dynamic model for the hull ballast and bilge systems.

The simulator proved to be an effective tool to perform Control System checkout during pre-commissioning. Lifts for production, generation and compression modules were first tested on the Marine Simulator before actual lifts were conducted in the yard. Naval architects were consulted to verify anticipated ballasting operations before actual operations. The simulator gave operators a feel of the Process Dynamics, Process Control, and Safety System and familiarity with the Operator Station graphics well before start up. The simulator was successfully used as a dummy platform along with the Load Management Advisory Program to demonstrate the ballast procedure for the successive installation of three heavy modules onboard the actual platform. Scenarios simulated include hurricane shutdown and start-up, instrument failures, damaged mooring line situations and damaged compartment scenarios due to collision or inadvertent flooding, among many others.

Operator training to operate Jack-St. Malo ballast and bilge systems using facility Operator graphics and control system was thoroughly carried out using this Simulator and this contributed to the high level of confidence in hull commissioning operations including lifts and ballasting operations. The simulator was a useful tool for validating Standard Operating Procedures (SOP) before actual facility start-up.
Human Factors Analysis and Classification System (HFACS): Investigatory Tool for Human Factors in Offshore Operational Safety
Authors: Hollaway D.M.A. , Johnson J. D.
Published: June 2014

It is axiomatic that 60 to 80 percent of mishaps are attributed to human error. The Human Factors Analysis and Classification System (HFACS) was developed by Dr. Scott Shappell and Dr. Douglas Wiegmann for the U.S. Navy to reduce human error in aircraft operations and maintenance. It is a broad human error framework that was originally used to investigate and analyze human factors aspects of aviation mishaps. HFACS is heavily based upon James Reason's ‘Swiss Cheese’ model of human error mishap causation. The HFACS framework provides a powerful tool to determine incident and accident root causal factors, generate leading indicators for potential mishaps, and target prevention efforts for maximum efficacy of loss prevention through systematic identification of active and latent failures within an organization. Moreover, the HFACS may be used to generate leading as well as lagging indicators for mishap prevention by applying to near-miss investigations.

HFACS has seen remarkable success in a variety of complex, tightly-coupled industries subject to large, catastrophic losses due to human error and organizational failure (aerospace, nuclear power generation, mining, construction, rail, and healthcare). The HFACS is adapted and presented for use in offshore operations involving offshore oil and gas exploration, production and support.
Mooring Integrity Management: A State-of-the-Art Review
Authors: Gordon Robert B. , Brown Martin G. , Allen Eric M.
Published: June 2014

There is consensus within the offshore oil & gas industry that there are too many instances of premature mooring line replacement and failure. In response to this situation, there has been rapid growth in mooring integrity related research and development. It has become difficult to keep track of all of this activity. The purpose of this paper is to provide a comprehensive review of the current state-of-the-art in mooring integrity management. Particular focus is given to coverage of the latest information on mooring failures, component degradation processes, monitoring and inspection technology, and mooring integrity management systems.
Thermodynamic State of Gas Hydrate in the Krishna-Godavari Basin Inferred From Well Log Analysis
Authors: Meyer Dylan W. , Flemings P.B.
Published: June 2014

We examined the in-situ hydrate saturations and salinities of gas hydrate-bearing sediments at National Gas Hydrates Project (NGHP) Site 01–10A in the Krishna-Godavari Basin, offshore India, to determine the thermodynamic state of the hydrate system. We determined hydrate saturations using logging-while-drilling (LWD) data in an iterative application of Archie's Law. The in-situ salinities were calculated from core-derived salinities by assuming that salts remained in the pore space, that the hydrate dissociated completely, and that pore volume remained constant with hydrate formation and dissociation. The in- situ salinity was compared to that required for three-phase equilibrium. We interpret two regions between 45 – 90 and 123 – 160 meters below seafloor (mbsf) where the system is at three-phase equilibrium at Site 01–10A.