bluuebunny/crossref_metadata_2025_split huggingface dataset:
Wellbore Stability Prediction and Anisotropic Modeling in Highly Tectonic Basin, Eastern India
Authors: Azeemuddin Mohammed , Lee Hikweon , Mishra Premanand , Waghorn David , Ong See Hong 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
Wellbore stability analysis has been carried out for wells to be drilled in a highly tectonic area, involving overpressured sands, laminated shales and steeply inclined beds, in Eastern India. Data acquired on wells abandoned in the past with 52 to 73% NPT, have been utilized to generate static mechanical properties and in-situ stress information. The NPT was associated with kicks, stuck pipe, losses, washouts, and heavy reaming. Abnormal pressures were encountered below +/- 200m, including extreme overpressures in some areas. Well walk/direction problems were indicated at least in one of the wells. Most wells could not reach their TD and were abandoned prematrurely.
Considering the nature of the identified problems, safe mud weight windows have been predictied to avoid shear failure in the native formation, slippage along the dipping bedding planes, and mud losses. Both isotropic and anisotropic failure parameters were estimated and utilized in modeling wellbore stability.
The results of the wellbore stability modeleing were utilized in the field to drill a new well to a depth of 10,000 feet. The wellbore initially had to be side-tracked after encountering stability issues and losses. Pseudo-real-time modeling updates to the pre-drill model, based on data acquired while drilling and more recent pore pressure and bedding dips information, resulted in further refinement of the model in the overpressured zone. The implementation of the updated model, which included slight modifications to the wellbore trajectory allowed the wellbore to reach reached the planned objective TD without any major problems. Lessons learned and best practices adapted have been captured and reported. It has been observed from the results that the anisotropy in shale strength, changes in bedding dips and steeply dipping beds, could play a significant role and must be considered when drilling wells in a highly tectonic area.
Comparison of Petrophysical Rock Types from Core and Well Logs Using Post Stack 3D Seismic Data: Field Example
Authors: Cheng Francisco , Contreras David 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
The prediction of the spatial distribution of petrophysical rock types within a heterogeneous siliciclastic reservoir is affected by significant uncertainties when based only on well and core information. However, integrating additional constraints, such as 3D seismic attributes, can significantly improve the accuracy of the reservoir model. This paper shows the results of a well log based reservoir study with 3D seismic data that have been used to assess the petrophysical rock type distribution. The resulting rock type volume data provides an extremely valuable benefit in the current development of the field. The calculated petrophysical rock types were obtained using the Windland R35 equation which includes information collected from core data: pore throat size distribution, porosity, and permeability. Using the available core data, the workflow started by predicting both permeability and rock type curves at the non-cored wells. Several consistency checks and quality control revisions were applied to the results from these predictions in order to have a reliable relationship between petrophysical properties and rock types.
The resulting curves at the interval of interest were correlated throughout the field and calibrated with 3D seismic data. In order to obtain the correct parameter to enhance spatial rock type distribution, a multi-attribute analysis was performed in addition to a well log and seismic attribute cross-plot. The results clearly indicate that the application of this workflow is very valuable for determining new locations to be drilled either for production or injection.
From Vision to Reality - Delivery of Smart Fields in Asia Pacific
Authors: Quillien Yvon 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
Putting the Smart Fields vision into practice is not a one-size-fits all solution. As we all know, each asset has unique features. Geological, environmental and political challenges differ from case to case, as does the maturity of a field. At Shell, we have developed a company-wide methodology to bring smart fields elements into asset planning. It identifies and enables application of the most appropriate technology. It uses a structured process that helps our people to gain real ownership of the assets they operate. And, more broadly, to gain ownership of the delivery of the Smart Fields vision in their part of the business. During what we call the "Concept Selection" phase, initial screening matches the appropriate Smart Fields integrated solutions to the specific needs of the project.
The next step is to develop a Well, Reservoir and Facility integrated Management Plan that lays out how future field optimisation decisions will be made, underpinned by the optimum amount of data acquisition, modelling and interpretation. This plan is then brought to life by application of standardised workflows and introduction of enabling technologies. These include setting up Collaborative Work Environments to improve integration between the various technical functions in decision-making in a LEAN way. It is a dynamic approach that enables us to learn from existing asset operations as well as apply innovative R&D technologies for new projects. Shell in Asia Pacific has been the leading region for implementation, demonstrated by the delivery of New Projects that are currently being designed as true smart Fields; Examples of Shell operated New Developments in Asia Pacific are used as best practice examples for Shell EP.
Floating LNG - Has Its Time Come?
Authors: Faulkner Andrew , Pek Barend Johan Jan 
Published: May 2016

This reference is for an abstract only. A full paper was not submitted for this conference.

Abstract
Floating LNG (FLNG) has captured the imagination of engineers and LNG business developers ever since it was first considered over a decade ago. The concept is simple, but attractive: "Let"s put the LNG facilities directly over the offshore gas resource rather than processing and piping the gas long distances to shore". FLNG has huge potential to extend the portfolio of traditional LNG schemes necessary to meet the energy challenge of the 21st Century. Whilst technological and commercial challenges may have prevented FLNG succeeding to date, as evidenced by the fact that there are no FLNG facilities currently in operation; and whilst today's dynamic business environment, technological advancements, maturing ‘easy gas’ developments, heightened environmental scrutiny and overheated construction market have delayed FIDs for LNG projects, this same combination of forces and trends have led to the energy industry's renewed interest in FLNG.
Shell will share its perspectives on FLNG - reflecting on the learnings of past studies as well as looking forward to its plans over the next decade, including the expectation that one or more of its FLNG solutions will be in operation globally. The current technical concept with some of its key technical challenges, and the inherent safety approach applied throughout the design will be described. The process configuration of the topsides, the design of the substructure, the environmental characteristics, and the mooring system will also be covered.
Pore to Grid Carbonate Rock-Typing
Authors: Rebelle Michel , Umbhauer Francois , Poli Emmanuelle 
Published: May 2016

Abstract
Often considered as a complex task, rock-typing in carbonates comes down to achieve reconciliation between various sources of data, including high resolution logs, representative core data and dynamic data.
The simplest statistical relationship between petrophysical classes and geological facies should be sought for.
More than 30 years of experience in carbonate fields has reinforced TOTAL's expertise leading to a specific rock-typing workflow through upscaling management of all available information from pore to plug, plug to core, core to log and log to model grid-cell.
This paper details the 8 main steps of a Rock-Typing workflow which is indifferently supported by in-house or commercial softwares.

Introduction
The main Rock-Typing studies objective is to contribute to build a predictive dynamic model by an accurate 3D-distribution of geological facies being petrophysically meaningful through porosity, permeability, Pc and Kr.
To achieve this point, petrophysical properties have to rely on 3D-predictive variables (such as Geological Facies) depending on a quantification of statistical correspondances between Geological Facies (including sedimentological and diagenetical patterns) and Petrophysical Groups (rock units with homogeneous petrophysical behavior).
Carbonates rocks require a specific approach compared to clastic ones due to a higher level of complexity (facies heterogeneity, early and/or late diagenesis, pore topology, wettability changes).
A specific workflow based on 30 years of experience on world wide carbonate reservoirs has been developed, supported by in-house or commercial softwares. As a result of more than 10 years of R&D effort on sedimentology, diagenesis and petrophysical synthesis, relying on numerous case studies (REBELLE et al., 2000; REBELLE & AL NUAIMI, 2004; REBELLE et al., 2005; REBELLE & UMBHAUER, 2008; UMBHAUER et al., 2008), this resulting workflow reflects an integrated approach of different specialities as illustrated on Figure 1.
Managing Drilling Risk and Uncertainty Standard in Well Placement
Authors: Poedjono Benny , Isevcan Erhan , Lombardo Guy Joseph , Walker John Richard , McCulloch Simon 
Published: May 2016

Abstract
An effective anticollision risk management approach is essential for drilling safely in the congested subsurface environments increasingly common in today's drilling programs. Because there is as yet no industry-wide standard for collision risk assessment and management, many companies have developed their own standards, which can differ in significant details. In one recent project, both the operator and the directional drilling contractor had developed specific anticollision procedures. The challenge was to create a drilling program that satisfied the requirements of both standards. This paper describes the problems we encountered and the solutions we created to successfully design and execute a drilling plan satisfactory to both companies.
Downhole Fluid Density for Water-Base Mud Formation-Water Sampling with Wireline Formation Tester
Authors: Mas Cholid , Ardila Mario , Khong Chee Kin 
Published: May 2016

Abstract
A vibrating rod downhole fluid density device with the unique perpendicular oscillation modes provides in-situ fluid density measurements that improve a wireline formation tester's pressure, mobility, downhole fluid analysis, and sampling applications.
The measurement applications for the real-time water-base mud (WBM) formation-water sampling include contamination monitoring, in-situ fluid density, fluids identification, pressure gradient and fluid contact, and vertical compartmentalization. Field examples validate the measurements with the sample laboratory analysis and other measurements.

Introduction
Understanding the nature and composition of formation water is just as critical to the economics of field development as determining hydrocarbon composition. Chemical analysis of formation or connate water determines the scaling and corrosion potential of produced fluids, which determination is required for the design of completion and processing facilities. It also establishes the salinity for petrophysical evaluation, and fingerprints the aquifer for studies on basin hydrology. Water composition is important for production strategies involving inhibitor injection, wellstream mixing, process sharing, and enhanced oil recovery (EOR) injection (O'Keefe 2006; Godefroy et al. 2008).
The formation water samples are required early in the exploration /appraisal phase because water will not be intentionally produced from conventional drill stem testing (DST) and will not be produced until the field cut water at the later stage, thus too late for the planning. In the offshore or in environmentally sensitive areas, where margins for error are small and large capital expenditures must be spent upfront, proper planning is crucial.
Probable Reserves and Prospects for Exploration and Development of Oil and Gas Deposits in the Russian Arctic Seas
Authors: Piskarev Alexey , Shkatov Mikhail 
Published: May 2016

Abstract
The last decade offshore oil and gas has become the main source of growth of the world's hydrocarbon reserves. Special interest to the geological structure of the Russian Arctic Seas comes from very high hydrocarbon potential of their sedimentary basins, which are expected to take a leading role in future world power supply.
Geological and geophysical characteristics of the Russian Arctic Sea sedimentary basins allowed to estimate their hydrocarbon potential by comparison with the known world analogues. Due to difficult climatic conditions in Arctic, we consider only the potential resources of giant (more than 500 million barrels of oil equivalent) deposits. With a limited seismic data, data of gravity and magnetic surveys allowed to outline the main regional structures, to ascertain relations of the discovered hydrocarbon fields to the identified structures. Five major gas-condensate and gas fields are still discovered in this region: three (Shtokman, Ludlov, Ledovoe) in the Barents and two (Leningrad and Rusanov) in the Kara Sea.
Primarily structure of sedimentary basins of the Russian Arctic Seas was investigated by geophysical methods. One of successful methods of integrated interpretation of geophysical data is a simulation. Simulation is performed based on computer calculations of gravity effects producing by density heterogeneity of lower hemisphere. The following density models of the Earth crust used seismic and geological data related mainly to the basin sedimentary cover, as well as a few data on the deep seismic boundaries (Piskarev, 2004). Sites of direct geological observations relate mostly to folded belts and basement rocks in the periphery areas.
The structure of sedimentary basins of the Russian Arctic Seas is illustrated by a number of density models which are prepared by iterative computation method. Location of sections on which the simulation was performed and which are described below, is shown in Fig. 1.
Commitment To Coax Subtleties From Seismic By Means Of An Intelligent Integrated Approach - A Case Study
Authors: Kong Vincent Wai Tin , Carrillat Alexis , Gaither John Ross , Ibrahim Ahmad Bukhari , Abdullah Irmawaty , Hernandez NIna Marie , Abdul Rahman Mohd Ramziemran 
Published: May 2016

Introduction
Much information is contained in the seismic reflectivity signal. The discernment between signal and noise, and the reduction of ambiguity of these signals is a major technical challenge. Interpreting lithology solely on normal seismic reflection strength has been well recognized to have pitfalls. This paper sets a case history of commitment by all parties involved to coax the subtle relevant data out from the seismic signals by means of an intelligent integrated approach.
It is current industry standard, with the availability of fast cost effective computer systems and data storage, to have outputs of a number of seismic data versions besides the traditional full stack seismic data. The ability to cohesively analyze all the available data in a timely manner makes the difference on the economics of petroleum exploitation from exploration through to the development phase. The result of each separate analysis should also converge for the deductions to be considered valid for interpretation.
Advances in Wireline Conveyed In-situ Reservoir Stress Testing Measurements: Case Studies from the Sultanate of Oman
Authors: Cig Koksal , Al Mandhari Alyaqdhan Sulaiman , Elmsallati Salem Mohamed , Qobi Latifa 
Published: May 2016

Abstract
In-situ reservoir stress measurements are essential input to a wide variety of the production and injection applications of reservoirs. Most of the reservoirs in this article require water injection to maximize recovery without breaking the matrices unintentionally. In some cases, it is also important to create a controlled fracture growth in a formation unit without breaking bordering barriers or zones. The main purpose of the in-situ reservoir stress testing of the case studies in this article is to calculate the minimum stress to improve the reservoir management plans for well placement, production, injection and fracturing processes.
One approach of measuring stresses in many zones is to use the wireline conveyed stress testing tools. The wireline conveyed in-situ reservoir stress testing measurements are frequently performed in the Sultanate of Oman for a wide range of operational and geomechanics applications such as but not limited to:Hydraulic fracturingFracture growth/containment issuesPolymer injectionBorehole stabilitySand production predictionStress evolution with depletion, hot and cold injection
The stress testing zones vary from tight to high permeable zones as well as shale zones. The complexity and wide variety of the stress testing applications inevitably led modifications and improvements on the wireline conveyed stress testing tools. These improvements mainly are various types of pumps, higher performance dual packers and mandrels, innovative stress testing methods. The latest improvements and methods in stress testing help addressing the broader range of formations (deep and shallow, tight and permeable) in an extensive type of wells from vertical or deviated to horizontal.
In this article, the examples of several unique stress testing applications are presented. Shale stress testing with a viscous fluid, horizontal well stress testing, tight and very high permeability formation stress testing, sleeve fracturing stress testing methods are discussed in details.

Introduction
In-situ stress magnitude and direction measurements in vertical and lateral directions are required in a reservoir for several reasons. These are for hydraulic fracture design, fracture type identification, water and gas injection management, fault activity, wellbore stability, sand production, rock mechanical properties, casing strings design, cap and base rock integrity, subsidence, and gas storage design.
A Consistent Workflow From Seismic Acquistion to Well Positioning - For Challenging Data in Block 11, Offshore Qatar
Authors: Hanitzsch C. , Bresser G. , Heerde W. , Jakob V. , Suess M.P. , Zahran M.E. , Altenkirch J. 
Published: May 2016

Abstract
This paper describes the seismic workflow for exploration in Block 11, offshore Qatar, from the decision to acquire a 3D seismic survey, via processing, interpretation, time/depth conversion and reservoir characterization to positioning of wells. The area is generally very flat in the morphology of the horizons and the targets are relatively shallow, therefore, the decision for acquiring 3D seismic data had been taken rather late. It turned out to be a textbook example why 3D seismic is imperative even in such generally flat areas. The structural history of the area, from the old basement lineaments up to the earliest Cretaceous-Tertiary aged reactivation movements, could be outlined by 3D seismic data and it shows a very complex structural pattern.

Introduction
Early 2007, Wintershall Holding AG acquired a 3D seismic survey in Block 11, offshore Qatar. The area is generally very flat in the morphology of the horizons and the targets are relatively shallow, therefore, the use of 2D seismic had been considered as appropriate in the past. However, after several wells - including a discovery and another well with poor depth prediction, it had been decided to acquire the before mentioned 3D seismic survey with the following objectives:to get a consistent 3D high quality volume allowing a continuous interpretation of geological horizons and faults,to get a seismic velocity model suited for more accurate time/depth conversion, andto get better understanding of compartments and fault patterns, that will allow a better understanding of hydrocarbon migration path ways and seal failure risk,to get seismic data suited for state of the art technologies, like seismic reservoir characterization,to assess leads and prospects, and to define future drilling locations.
Most precise velocities are of particular importance, because the overburden shows significant lateral velocity changes that cause important differences between time and depth maps. Depth structures are not necessarily visible on time maps, and apparent time structures are not necessarily existent in depth.
Plant Performance Monitoring: Improving Surveillance of Rotating Equipment on a Gas Processing Plant
Authors: Boero-Rollo Jean-Gregoire , Galtie Bernard , Tincelin Pierre-henry , Kessler Nicolas , Lacoux Xavier 
Published: May 2016

Abstract
Capitalizing on early successes in advanced well control and real-time monitoring, Total has engaged in a major "Digital Field" initiative aimed at developing real-time asset management. Combining both proven and leading-edge technologies such as real-time databases, web services, business orchestration and a distributed asset model, the Field Monitoring template proves to be a powerful tool to improve global asset management and optimize the oil and gas production chain, from reservoir to export facilities. The field monitoring solution is being implemented as a set of independent yet integrated modules. This paper presents the concept of one of the modules, the Plant Performance Monitoring (PPM) module, a real-time remote monitoring system dedicated to surface facilities. It presents and discusses early results of a pilot application to surveil major rotating equipments at a 520 mmscfd gas processing plant located on the Tierra del Fuego site in Argentina.
The objectives of the pilot are as follows:The primary objective of the pilot is to demonstrate a near real-time tool that provides advance notices on abnormal plant trip.To provide plant staff with quantitative Key Performance Indicators (KPI) such as efficiency, machine availability and utility consumption.To allow proactive maintenance, most particularly, to anticipate the effects of operational changes on assets.To provide cause and effect analysis using near real-time information available from separate components such as vibration monitoring systems, process data historians …
The PPM-Rotating Equipment (PPM-RE) application integrates online process simulations which provide new insights in terms of conditional maintenance and actual production potential or constraints. After several months of operations, The PPM-RE pilot has demonstrated its ability in improving diagnosis and decision-making through prompt collaboration between Cañadon Alfa site and Buenos-Aires (local headquarters several thousands kilometres away). Such an application can also allow the difficult-to-troubleshoot cases to benefit from the TOTAL headquarters and research centers anywhere in the world.