bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using a Dynamic Coupled Well-Reservoir Simulator to Optimize Production of a Horizontal Well in a Thin Oil Rim
Authors: Nennie E. D. , Alberts G. J. N. , Peters E. , van Donkelaar E. 
Published: June 2009

Abstract
Stabilization and optimization of production are the key challenges for smart well control. In order to compare the effectiveness of different control strategies, a simulation environment can be used. To study and control the effects of for instance slugging, gas coning and wax deposition, both reservoir dynamics and the dynamics of multi-phase well flow have to be taken into account in such a simulation environment. In this paper we use a dynamic coupled well-reservoir simulator to identify instabilities of a field case and test a control strategy to mitigate gas coning and wax deposition.
The dynamic simulation environment has been developed within the research framework of the ‘Integrated System Approach Petroleum Production’ knowledge center of TNO, TU Delft and Shell. This simulator has been validated with field data of a horizontal well located in a thin oil rim, suffering from gas coning and containing a crude which has a high tendency to wax. With the help of the simulation environment it was possible to understand the production instabilities observed in this well and to determine a control strategy to stabilize and optimize its production. The results of the coupled well-reservoir simulations are presented and the phenomena that are most likely to cause the production instabilities observed in the field are identified.
In production optimization the current status is to use separate dynamic well and reservoir models. In case of significant reservoir-well interaction this approach gives a non-realistic production forecast. This project gives a clear indication that, when using a coupled simulation on a real field case, a better understanding of the instabilities and therefore a more accurate production forecast and a better control strategy can be designed.
Yardstick for Talent Pipeline in Oil and Gas Industry in India
Authors: Chatterjee Urmila 
Published: June 2009

Abstract
Talent Management is the method of nurturing the employees' potential, aptitude and ability towards the betterment of the self, keeping in view the goals of the company. The talent crisis facing today's corporate world including the hydrocarbon industries in India, is an outcome of the competition amongst different business houses to tap and retain the best. In order to nurture and build talent it is necessary to interface and pass on knowledge from more experienced employees to less experienced employees. The components of this talent pipeline are Management Development Programs (MDP); On-Job-Training (OJT); Interfacing Knowledge (IK); Talent Search, Relationship, Skill and Trust Building (TRUST); and Inspiring Leadership Qualities (ILQ). In this paper we propose a new quantitative measure called Pipeline Index to judge the progress of the talent chain and provide a methodology for its measurement. This is calculated as W × H where the weightage W is highest at the top level of management and H is the number of hours per week being spent by an employee in talent pipelining. A questionnaire was prepared and distributed to compute the Pipeline Index for a large oil and gas company in India. The response to the questionnaire is used to compute the Pipeline Index over the last 5 years for this company. Evaluation of the results shows both the key areas of strength of the company and the areas where the talent pipeline needs to be reinforced. The analysis shows that this company suffers a slight decline rather than a desirable growth of the talent pipeline over the 5 year period 2004–2008. We consider ‘Giving’ and ‘Receiving’ as two ends of the talent pipeline. The shortfall between ‘Giving’ and ‘Receiving’ is defined as the Talent Gap. Our study reveals that the talent gap is the result of employees spending time in guiding others but where the guided persons do not believe that they have benefited. The proposed definition of Pipeline Index and the questionnaire based method of its evaluation could be applied to any company and may be used to compare the talent pipeline for different companies.
Impact of the Effective Implementation of Project Integrated Quality System (IQS) From Early Stages of Design Development
Authors: Daoud Mohamed 
Published: June 2009

Abstract
Over the past 25 years, demands for quality have grown dramatically. The main factor behind this growth has been failure of plant and components in service.
Historically, the term quality has been associated with things like checks and inspections. Control of quality was only a simple matter of random inspection, i.e. the acceptance or rejection of finished products. It is now recognized that quality can not be inspected in; they must be managed in. must be designed, built into the product and controlled in systematic manner.
It is not possible to manage something which is poorly defined. Quality has come to mean: Conformance to Requirements.Conformance to specifications and standard.Fitness to use and cost.
Low Production Tester (LPT) - A Viable Solution for Marginal Wells Testing
Authors: Hodgson Paul 
Published: June 2009

Abstract
At Petroleum Development Oman LLC (PDO), well testing has successfully been carried out for the past few years utilizing multiphase meters. Although this technology provides many benefits to PDO, the meters, being basically venturi based, had a low flow limitation of 20–25 m3/day for gross liquid measurement. So in the past, these low flow wells used to go largely unmeasured or were measured using the older, conventional testing systems, which were not very reliable.
In order to overcome this issue, and provide a well testing solution for wells producing less than 20 m3/d, the operator of PDO's Mobile Well Testing Units was approached to try to develop a prototype, which could be tried in PDO under their existing Mobile Well Testing Contract. They came back with a skid based, mobile unit in October, 2006, that had a range of 3–25 m3/day of gross liquid flow as standard and could extend its range up to 100 m3/day. The unit measured 0–100 % water cut and could operate in 0–100% GVF conditions.
Following introduction of the unit in the PDO South concession areas, testing of wells has been carried out where multiphase meters have not been successful, and this has not been limited to wells producing less than 20m3/d as per the original intent but also for testing wells where the produced oil viscosity was outside the operating parameters. Results have been very favorable, with practically a 100% validation rate. The unit was thus deemed acceptable to use as an additional well testing tool and was subsequently included in the PDO Mobile Well Testing Contract, awarded in April 2007. The unit gives good reliable data for wells with low production rates and can also be used where high viscosity becomes a problem for testing by other means.
Extended Binomial Trees for Real Options Valuation in E&P Projects
Authors: Galvis C. F. , Villarreal J. 
Published: June 2009

Abstract
The following paper addresses the limitations of the Binomial Tree Approach for Real Options Valuation (ROV) when used as a direct extension from Financial Options Valuation (FOV), since the strong assumptions that support the theory do not always apply to investments in real assets. Subsequently, a solution for these problems is proposed using an extension of the binomial approach, which complies with the conditions that this theory imposes on Financial Options Valuation, and hence, on Real Options Valuation.
The proposed approach, the Extended Binomial Trees (EBT), permits sign changes to occur inside the underlying asset's tree, unlike the traditional binomial approach, and prevents skewness and kurtosis from happening in the rate of return distribution. This methodology is then presented using as framework the valuation of redeveloping the Sardinata field, in Colombia, and the results are presented in a comparative chart along with the ones obtained by means of the traditional binomial approach.
Experimental Measurement and Modeling of Asphaltene Precipitation in Crude Oil
Authors: Nikookar M. , Omidkhah M. R. , Pazuki G. R. , Sahranavard L. , Roayaei E. M. 
Published: June 2009

Abstract
In this study, at first the amount of asphaltene precipitation produced by adding different ratios of n-alkanes (n-pentane, Hexane, n-Heptane, n-nonane) into an oil sample obtained from one of Iranian oil fields has been measured. The obtained results were compatible with the results of other researchers. Meanwhile, the reversibility of asphaltene precipitation process has been investigated as an important subject in this phenomenon. Then, by using the experimental data and optimization, the scaling equation's coefficients were calculated and then the amount of asphaltene precipitation and the onset point have been obtained by the scaling approach. Finally, the obtained results have been compared with the experimental data and the model's accuracy was approved.
Azimuthal Anisotropy Analysis for Fracture Reservoir Characterisation: Supergiant Field, U.A.E.
Authors: Ribeiro Christophe , Reiser Cyrille , Al-Shekaili Fatema Saeed , Al Nahhas Mohamed Samir , Boekholt Martin 
Published: June 2009

Abstract
A fracture characterization feasibility study is conducted over a subset area of an onshore supergiant carbonate field within the Abu Dhabi emirate, using P-wave azimuthal anisotropy analysis. Multi-azimuth seismic data are pre-conditioned using Shell-proprietary filtering, CGGVeritas-proprietary geostatistical decomposition and amplitude balancing to effectively remove the noise component from the data and amplitude artifacts due to near-surface conditions. A 3D post-stack stratigraphic inversion is performed to obtain robust azimuthal acoustic impedances that are converted into anisotropy attributes. The study proves that seismic anisotropy can be attributed to the fault pattern in one layer of the main producing reservoir, and to gas injection pattern in another layer of this reservoir.
A Diagnostic Toolkit to Detect Compartmentalization Using Time-Scales for Reservoir Mixing
Authors: Muggeridge Ann H. , Smalley P. Craig 
Published: June 2009

Abstract
Unidentified reservoir compartmentalization through faulting or depositional heterogeneity can have a profound, usually adverse, effect on oil or gas recovery. Thus it is vital to characterize reservoir compartmentalization as early as possible in field life, ideally during appraisal.
One signature of compartmentalization is the detection of variable fluid properties (e.g. pressure, fluid contacts, oil or water composition) in different parts of the reservoir. Such spatial variations arise during the burial, structural and filling history of the reservoir, and gradually equilibrate through time. However such spatial variations may persist simply because sufficient time has not yet elapsed for that property to equilibrate, potentially leading to false-positive diagnoses (variations are present but relate to insufficient mixing times, not compartmentalization). In other cases, mixing can occur so rapidly that fluid variations have already mixed, leading to potential false-negative diagnoses (variations not present because mixing has occurred quickly in spite of compartmentalization that will affect the production timescale). It is thus vital to incorporate an understanding of reservoir mixing timescales into the early diagnosis of compartmentalization.
This paper provides simple analytic expressions for estimating the time taken for tilted contacts and spatial pressure or compositional variations to return to their equilibrium distribution, as a function of reservoir thickness, length, porosity, permeability, fluid viscosity, density and compressibility. These form a simple and practical diagnostic toolkit.
Use of this toolkit reveals many cases where lateral compositional variations do not indicate compartmentalization but result from incomplete mixing due to very slow molecular diffusion. In contrast, pressure may equilibrate across a micro-Darcy, permeability fault in 100,000 years, so uniform pressure does not necessarily guarantee good reservoir communication on a production timescale. Compartmentalization can only be accurately identified and quantified through integration of different reservoir data and consideration of their very different timescales for mixing.
Subtle Faults in Carbonate Reservoirs
Authors: Pion Jacques , Vesseron Marc , Dugoujard Thierry 
Published: June 2009

Abstract
Subtle or sub-seismic faults in carbonate reservoirs are often mentioned in the geosciences literature but using them as hard data to qualify reservoir connectivity is generally not an accepted standard. The present paper illustrates with field examples that even faults with very small throw (&lt;3m) can backscatter energy, that this energy appears on seismic displays as a consistent interference pattern similar to the response of thin beds. The paper further suggests a filtering method to distinguish subtle faults from image processing artifacts, and proposes a workflow allowing their integration into reservoir models, either as connectivity enhancers related to the presence of open fracture networks in the vicinity of fault surfaces or as indications of faults with minor throws acting as buffer or barrier zones.
Properly Executed Underbalanced Drilling Technology Adds Reserves and Enhances Ultimate Recovery
Authors: Babajan Salar , Qutob Hani 
Published: June 2009

Abstract
The current world petroleum industry situation is that: ➢Exploration is difficult and costs are increasing.➢The majority of hydrocarbons being exploited today are found in existing pressure depleted or complex and lower quality reservoirs➢Current oil prices are at their highest
Thus, world circumstances have forced today's petroleum industry to rethink both its operating methods and technologies aiming at improving recovery and reducing cost. It is believed that adoption of new technologies is the most important factor in adding reserves, enhancing recovery, reducing cost and increasing revenue. Underbalanced drilling technology is now seen as the way to achieve these objectives.

Introduction
Underbalanced Drilling – UBD main objectives are: ➢Preventing formation damage and improving Reservoir Benefits.➢Improving Drilling Performance & Preventing Conventional Drilling Problems.
This paper discusses in details the reservoir benefits part of underbalanced drilling technology.

What is Underbalanced Drilling?
Underbalanced Drilling is the intentional reduction of the drilling fluid density causing the hydrostatic pressure in a well bore to be lower than the pore pressure within a formation thereby permitting reservoir fluids to be produced while drilling. Underbalanced Drilling benefits the reservoir by simply adding reserves through: ➢Discovery of new zones➢Reducing formation damage and increasing intra-zone contribution➢Lowering abandonment increasing well drainage area➢Accessing challenging reservoirs➢Providing real time reservoir evaluation / characterization.
Although UBD has many advantages, it is not a magic potion for all fields, wells or drilling problems. Poor execution and planning would result in an over-enthusiastic misapplication of the technology, and possibly failure. Several real results and case studies will be presented and discussed in this paper.
Applying New Systematic and Dynamic UBD Procedures to Prevent Formation Damage, Wellbore Collapse and Improve Oil production in Hassi Massoud Field
Authors: Berkat Ali , Kartobi Khelil , Mazouzi Amine , Dhina Okba , Qutob Hani , Barakat Naiem , Grayson Fudge , Marei Ayman 
Published: June 2009

Abstract
The Hassi Massoud oil field is the largest of its kind in Algeria. The reservoir was discovered in 1956 and produces from a Cambrian-age at approximately 3400 meters depth. It produces 45°API oil from a thick Cambro-Ordovician sandstone formation.
This sandstone is extremely hard, abrasive and slow to drill. The reservoir is naturally fractured in some parts. Fractures are either open or plugged with materials such as shale, silica, anhydrite, pyrite and bitumen. Porosity is ranging from 6 to 12%. Generally, the permeability is low with a range of less than 1 to more than 100 md in open-fractures layers
Sonatrach introduced Underbalanced Drilling (UBD) primarily in an effort to improve penetration rates. However, all additional benefits obtained from UBD, such as production improvement and reservoir characterization while drilling, will be of an added value.
Well OMPZ553 is the 37th well drilled underbalanced in the Hassi Massoud field. In this well, the focus was on production improvement with minimum formation damage while the increased rate of penetration (ROP) was a secondary benefit. Another objective was the evaluation of production while the well is being drilled. This eliminates the need for expensive post drilling production testing, and also to minimize borehole instability specially when drilling in the R2 section of the drain.
In order to increase the success rate of drilling and completing this well underbalanced, Sonatrach introduced a new systematic and dynamic procedure. The new procedure consists of: Proper UBD candidate screeningCalculating the actual reservoir pressure before UB mode startsCompleting the well in UB mode
This well proved to be the best UB drilled well in Hassi Massoud field in terms of reservoir benefits and characterization. The pre-job UBD candidate screening, feasibility studies and applying the new procedures proved effective in the success of this well.
This paper describes in detail the above procedure and presents the successful application of such procedure to optimize production and enhance the ultimate recovery in the Hassi Massoud field. Lessons learnt and challenges encountered will also be discussed in this paper
Minimum and Mandatory HSE Training Program for All Personnel Working in Onshore Oil Operations, Applicability and HR Impact
Authors: Remisio Luis , El-Farmaoui Mohamad 
Published: June 2009

Abstract
In contrast with what is followed for Offshore Oil Operations the majority of the Onshore Oil Operations in the world do not have a Minimum and Mandatory required HSE training program for all personnel including contractors and subcontractors.
A comparison is drawn between the Minimum and Mandatory HSE Training Programmes applied offshore in developed areas, mainly North Sea and Gulf of Mexico and the benefits that similar programs can bring to the ME onshore oil operations are addressed by estimating the risk reduction and potential economic benefits.
The applicability of such Minimum and Mandatory HSE Training Programs is analyzed against the scenario of heavy utilization of contractors and subcontractors with different approach and standards in HSE training and also the increasing complexity of the onshore oil operations
An estimation of how many lives can potentially be saved by the introduction of such programs is provided in global and generic terms.
The HR Impact, in different aspects, specifically the ones related to HR Management is analyzed assuming the potential introduction of these mandatory HSE training programs.
Specific conclusions and recommendations are issued and the final argument of the need to introduce a Mandatory HSE Card (or passport) to all personnel working in Onshore Oil Operations is put forward as the most effective method to curb the rate of incidents, specially LTI's, Loss Time Injuries and Fatalities.
Field Development Expansion of a Giant Oil Field in Abu Dhabi Using Artificial Islands as Drilling and Production Centers
Authors: Modavi A. , Martin W. W. , Muflehi A. H. , Walters J. V. , Ismail G. 
Published: June 2009

Abstract
The current development plan for the subject field is based on drilling from numerous Well Head Platform Towers (WHPTs). The current production buildup target would require many more new WHPTs and hundreds of kilometers of new pipelines connecting the new and current towers to the field central processing complex and its satellites.
An alternative field development strategy based on a few drilling/production centers (artificial islands and/or large platforms), instead of numerous new WHPTs, will enable: Significant CAPEX reductionCover current or future variations of the subsurface planMitigation of Jack-Up rig availability & cost uncertaintiesFlexibility to capture up-side potentials during field life cycleProvisions for cost-effective/phased facilities installationsEnhanced field operability, at much lower OPEXReduced downtime losses
Islands as drilling/production centers, with land-based rigs further enable: Maximum flexibility for further developmentHonoring current reservoir management guidelines,Low risk (conservative) extended reach drilling
Condition Management as Part of Asset Management
Authors: Panzke Rolf 
Published: June 2009

Abstract
Definitions: Condition Monitoring/Management –Components of asset management condition monitoring regularly records meaningful data and information on the machine status (machines, plants and their components). The focus is on: abrasion, wear and contamination. The device should report its current status in good time before it fails.–Supports "status-based" or "predictive maintenance"–The aim is to make status data of the assets available on a continuous basis–Condition management collects the data and information, coordinates it, creates courses of action and manages the data.–Maintenance–The combination of all technical, administrative and business-management actions during the life cycle of an object in order to preserve it or restore it to such a condition that enables it to continue performing its original task.–Diagnostics–Identification of faults in the assets (machines, systems and their components)–Locating faults/evaluating the cause of faults–Log of individual faults and causes of faults–Asset–Plant components: apparatus, boilers, machines, pipes and process control instruments–The term does not include infrastructure that do not concern the production systems: buildings, roads, rails…–Plant Asset management–Comprises a "health check" of all assets, condition monitoring and diagnostic functions with the associated decision-making aids. In addition, the system predicts the remaining life and suggests appropriate maintenance measures to the user.
Condition management is an important tool of asset management for optimizing production processes with regard to plant operation, capacity, quality, quantity and reproducibility. The crucial thing here is to recognize future requirements and trends of different industrial sectors as well as regional differences. Part of this process is to develop and build up the competence of the suppliers in the individual industrial segments, in complete solutions, partial solutions, but also in individual components and in the support.
The optimization measures depend in part on the application and solution expertise of the vendor. This includes planning competencies and selection of the optimum measured variables, technologies and products/solutions. The factors that are of increasing importance here are intelligent diagnostics information, condition monitoring and its interpretation, based on the experiences from the condition management. It is the task of the supplier to point out to the customer the advantages of additional solutions in special applications in a wide variety of sectors and to present them transparently as part of the system information – from the first initial definition to the final target of process optimization.