bluuebunny/crossref_metadata_2025_split huggingface dataset:
Optimization of Perforated Completions for Horizontal wells in a High-Permeability, Thin Oil Zone. Case Study: Hassi R'mel Oil Rim, Algeria
Authors: Bourenane Mahdi , Tiab Djebbar , Recham Reda 
Published: December 2007

Abstract
A considerable number of studies have been conducted to optimize the perforated completions for horizontal wells, but very few of them took into account the effect of reservoir heterogeneity and coning problems in the completion design. One of the most relevant work directly related to this topic is the one developed by Goode and Wilkinson7. They have presented an analytical solution for the performance of partially completed horizontal well. Their model, however, has two major limitations: (1) it considers the reservoir as homogeneous and ignores heterogeneity, and (2) it does not take into account the water and gas coning effects.
In this study, a numerical solution has been developed to optimize the perforated completions for horizontal wells in a heterogeneous reservoir laying between a large gas cap and an active aquifer (double coning problem). Another objective of this study was to examine the performance of various perforation schemes for horizontal wells in Hassi R'mel oil Rim using reservoir simulation. Since the capability of the numerical simulators to model a horizontal well performance is largely controlled by the quality of the geological description of the reservoir, therefore, a reservoir characterization based on geological (sedimentary) units was performed on the A-Sand reservoir of Hassi R'mel oil Rim.
The simulation modeling in this study was undertaken in two large parts. First, a sensitivity analysis was conducted to investigate the effects of the most relevant reservoir parameters on the horizontal well performance for different perforation schemes. This allowed us to examine the effect of the perforation length and its distribution and to find the optimum perforation scheme for horizontal wells in Hassi R'mel oil Rim. Second, the simulation modeling was involved in a real case where the performance of the well HRZ-09 was a concern. The reason for taking this well as a case study is that it was completed non-conventionally using the Inverted High Angle technique. This completion led us to investigate the possibility of perforating the slanted section of the well, in addition to the horizontal section (Double perforation scheme).
As a result of this study, correlation curves have been generated to optimize the perforated completions for horizontal wells in Hassi R'mel oil Rim. It has also been found that the optimum perforation scheme for horizontal wells in Hassi R'mel oil Rim corresponds to the case of 60% uniformly distributed perforation. From the case study, it was found that there is no extra-recovery to be expected from the double perforation of the well HRZ-09. Moreover, such perforation scheme yields much higher gas-oil ratio in comparison to the actual perforation case. This result was confirmed by an economic analysis performed on three proposed perforation schemes.
Technology Mastery - Foundation for Technical Specialists
Authors: Nor Rosly Mohd , Kario Mohamed Wahid , Kosuma Christine G 
Published: December 2007

Abstract
Global uncertainty and heavy competition require E&P companies to remain effective in investments and prudent in people development. These challenges compel us to have a learning system that links to business objectives and enables effective knowledge transfers. This paper outlines a structured learning framework which is a competency-based system that links learning objectives to desired business results and establishes a mechanism for identifying, developing, measuring and tracking individual competencies and capabilities.
The Technology Mastery Program is part of an integrated program, which covered data, processes, tool and people as the heart of the program. It is to maximize the return on investment in technology, reduce interpretation cycle time, enhance the workflow application, improve quality of the result and decision-making.
The structure uses a credit-based system to monitor and measure technical competencies through accreditation of technical skills. The learning curriculum is built to facilitate cross training by offering broad-based competencies in multiple disciplines. The learning sequence complements the methodology by providing web-based training before, and after the course, immediate application in the current work, mentoring, and assessment. The process addresses common problems that occur with many training programs including timeliness, relevancy, transfer of skills to the job, and learner accountability for results.
People can accelerate their acquisition of technical knowledge and increase professional development in this selfdriven framework. Furthermore, the program is aligned to meet the requirements that lead to the specialist technical ladder which was recently introduced in the company.
The program was conducted in stages commencing midAugust 1999 and has proven to be very successful. It is currently in its third stage and as each stage progressed, new disciplines were added and program upgrades made based on lessons learnt. As of June 2003, one hundred and eighty five staffs from Geology, Geophysics, Formation Evaluation, Reservoir Engineering, Production Technology and Petroleum Economics have enrolled into this program. They are working either in exploration, development or production based projects and have benefited from this program, which resulted in reserves addition, and profitability of the company.
Pipeline Integrity Management System - A New Approach In Managing Pipelines
Authors: Abd Satar Fairudul Azhar , Raja Ismail Raja Zahirudin , Saidin Khairul Taufiq 
Published: December 2007

Abstract
Managing pipelines in operation divisions of PETRONAS Carigali Sdn Bhd (PCSB) always as important as producing a hydrocarbon from its fields. Three (3) PCSB domestic operation regions namely Peninsular Malaysia Operation (PMO), Sarawak Operation (SKO) and Sabah Operation (SBO) are currently operating a total of more than 277 pipelines. Due to aging pipelines that PCSB are currently operating in which some are more than 25 years, a prudent management in term of its risk and consequence as well as cost of operating the aging pipelines need to be re-assessed via a comprehensive management system that can be used as a tool to inform PCSB management in term its integrity.
It is imperative that an integrated pipeline integrity management system (PIMS) to be made available to ensure pipelines integrity always available upon request and are up to date with the latest integrity status. Before the development of the PIMS for PCSB, all the pipeline integrity management for each region is residing with the individual(s)/units that performing specific functions e.g. inspection, engineering and operations. With the development of the PIMS, all those effort related to pipeline integrity are managed and integrated in more effective manner by single point reference i.e. Pipeline Competent Person in PCSB. It was determined that the adoption of an integrated approach in managing pipelines would be the optimal way to facilitate prudent management and surveillance of pipeline integrity.
The purpose of this paper is to discuss the effort that had been put in making the PIMS project materialised as well as to share the experience in developing the system with the help of other resources from internal and external of PCSB organisation.
Having the PIMS implemented in PCSB it will reduce considerable amount of time and effort that previously needed to acquire the integrity status of pipelines. Adopting an integrated team effort throughout the company has provided the necessary forum for open and inter-disciplinary exchange of ideas and experiences on PIMS related matters. As a result, it has aided in enhancing cooperative actions and the capturing of synergism, all to the benefit of the PCSB.
Quantitative Evaluation of Information Loss in Reservoir Upscaling
Authors: Qi Dasheng , Hesketh Tim 
Published: December 2007

Abstract
Upscaling technique has become an increasingly important tool in recent years for converting highly detailed geological models of reservoir to simulation grids. However, how to qualify the upscaling results, i.e. whether an upscaled results provides a good or bad approximation, is one of the outstanding problems remained in this research field.
Comparing the simulation results for the reservoir before and after scale-up is direct and adaptable. But the shortcoming is the simulation results of the original fine model is too costly even can not be obtained. This paper evaluates the characteristics of information loss in reservoir upscaling and proposes two new indicators of information loss, ILIa and ILIb. Based on information loss, a method- independent technique for evaluating upscaling results in reservoir engineering is proposed. The new validation method can be used to evaluate the upscaling results before simulation stage.
Bokor Field Redevelopment—A Brown Field Integrated Modeling Workflow Case Study
Authors: Flew Stephen , Mulcahy Matthew , Stelzer Hermann , Boitel Alain , Zainuddin Faizal , Harun Abd Rahman , Hassan Zulkarnain , Aziz Kamaroll Zaman A. 
Published: December 2007

Abstract
After more than 20 years of production, the 800 million STB Bokor field, offshore Sarawak, Malaysia, is set to undergo a revitalization to increase production rates and recovery factors. A joint PETRONAS Carigali (PCSB)-Schlumberger team was formed to review the field and develop the first full field simulation model, which will be utilized as a 'live' model for identifying further potential and for future reviews. This paper outlines the modeling workflow and processes developed to allow the study to be completed within a shorter duration than with a conventional approach, as well as the key study results.
Made up of some 130 vertically stacked reservoirs over a 6,000-ft interval, evaluation of the field is hampered by the lack of any useful seismic images over the hydrocarbon zone, owing to shallow gas and other anomalies. Understanding the reservoir behaviour has always been a challenge, with the degree of sand consolidation in the reservoirs varying from totally unconsolidated at 1,500 ft subsea, filled with 10 cP oil, to consolidated deeper sands, with 0.1 cP oil at 7,500 ft subsea. In addition, the limited pressure depletion owing to the presence of a very strong aquifer, and the fact that many fluid contacts have not been penetrated, means that significant uncertainty still exists over the likely stock-tank oil initially in place (STOIIP).
By fully utilising all available data and an iterative team-based approach to history-matching the geostatistical models with production data, an understanding of the key parameters was gained. This revealed that in many reservoirs, what was previously considered poor-quality rock was in fact a major contributor to reservoir flow, being neither as poor in permeability nor as high in water saturation as previous interpretations suggested.
Through the increased understanding gained during the review, robust predictions have allowed new facilities to be appropriately sized, allowing the field to begin its new lease of life.
Optimising Brown Field Redevelopment Options Using A Decision Risk Assessment: Case Study—Bokor Field, Malaysia
Authors: Wongnapapisan B. , Flew S. , Boyd F. , Hassan Z. 
Published: December 2007

Abstract
The proposed revitalization of the Bokor field is affected by many surface-facility constraints as well as the subsurface complexity of laminated stacked reservoirs. Such complex problems require a truly integrated multidisciplinary methodology using a decision-and-risk- assessment approach to screen development options. This paper presents the process adopted and used to screen and rank the various options.
Any field redevelopment needs to begin with an identification of system bottlenecks and proposals to remove them, but often this is only considered at a facilities level. In proposing a revitalization plan for the Bokor field, the joint Petronas Carigali Sdn. Bhd (PCSB)-Schlumberger team had to develop a complex decision-making process to select an optimal development plan that would solve the constraints while minimizing unit technical operating cost (UTOC) and maximizing production.
Often, brownfield redevelopments are limited to maximizing existing facilities (slots, processing plant). However, in the case of Bokor, essentially no additional oil can be produced without an impact on existing production (lack of gas lift, lack of export compression). Thus, an approach was required that not only solved the existing bottlenecks but also allowed for sufficient additional capacity to sustain a cost-effective revitalization plan. The process had to be iterative, assessing the risks and uncertainties of each approach and its economic impact.
The solution was an approach that considered each reservoir target by discounted cumulative oil, thus producing a ranked list of opportunities that could be added together to form any development scenario. Hence, rather than running a reservoir simulation on each development case, this approach allowed multiple facility development options to be tried quickly. Each development scenario was then analysed using a tornado diagram. From this diagram was prepared a decision tree that gave the most likely outcome. This approach allowed options as diverse as subsea tiebacks to full integrated platforms with a high number of electrical submersible pumps (ESPs) to be risked and ranked equitably within a reasonable timeframe.
In-situ Stress and Pore Pressure Fields in the North Cuu Long Basin, Offshore Vietnam
Authors: Thi Thanh Nguyen Binh , Tokunaga Tomochika , Okui Akihiko 
Published: December 2007

Abstract
Knowledge of the in-situ stress field is vital for planning optimum orientations of inclined and horizontal wells, for reservoir characterization, as well as for a better understanding of geodynamic processes and their effects on basin evolution.
In this study, we analyzed in-situ stress and pore pressure fields of Pre-Cenozoic basement and cover strata in the northern part of the Cuu Long Basin, offshore Vietnam, for the first time, based on available data from petroleum exploration and exploitation wells.
The directions of minimum and maximum horizontal stresses were evaluated from borehole breakout and drilling-induced tensile fracture orientations. The maximum horizontal stress is oriented approximately NNW-SSE to N-S, and the minimum horizontal stress is ENE-WSW to E-W orientation.
The magnitude of overburden stress was determined from density logs. Minimum horizontal stress was analyzed from good quality extended leak-off tests and mini-falloff tests. Maximum horizontal stress was estimated using breakdown equation of hydraulic fracture.
Pore pressure was measured by RFT and DST. Overpressured condition was found in the upper Oligocene, while other units showed nearly hydrostatic condition except for the depleted intervals due to production.
The effect of pore pressure change on in-situ stress magnitude was established based on the data from depleted pore pressure zone. From the obtained results from this analysis, we can reasonably well delineate in-situ stress and pore pressure fields of the area.
New Analytical Correction for Multi-Phase Flow Effect in Near-Well Regions of Coarse-Grid System
Authors: Nakashima T. , Nomura M. 
Published: December 2007

Abstract
In a finite difference scheme, continuous multi-phase flow variables that appear in conservation equations such as saturation are spacially discretized on grid blocks. When coarse grid blocks are used for reservoir simulation, the numerical solution tends to magnify the discretization error. This causes numerical errors called as coarse grid effect.
Through a coarse grid reservoir simulation, injection pressure showed quite difference with that of fine grid model.
This is because total mobility at the injection well is defined by the finite difference based average saturation in the injection well grid block. In other words, the saturation gradient that would appear in the near-well region is ignored in such coarse-grid system.
In this study, the areal average saturation in the injection well grid block was calculated analytically by the newly derived radial displacement approximation which was extende from the Buckley-Leverett linear displacement problem, taking account of pressure difference between the injection well and the injection well grid block. Consequently, the corrected total mobility was provided, by defining new value of total well index and transmissibility.
The injection pressure computed by this technique with for coarse grid model is reasonably agreed with the numerical solution of fine grid model. The practical application of the developed well-pseudo is validated through an actual reservoir simulation study.
Rights Of Access And Permitting For Coalbed Methane Operations
Authors: Lear J.D. Phillip Wm. 
Published: December 2007

Proposal
This paper provides a summary of access and access-related legal issues for operating personnel covering access to and on oil and gas leases on federal public, Indian, state, and private lands. The author admits to a decidedly western orientation and perspective, as the western experience includes the private and state lands issues from the east and mid-continent, while adding by superimposition the federal public lands and Indian experience. These issues will cover access on the leasehold surface access of split-estate leaseholds, access over adjacent lands to the leasehold, access through mineral estates to subjacent minerals, and access during simultaneous mineral operations.
Field Experience With a New Formation Pressure Testing-During-Drilling Tool
Authors: Frank S. , Beales V. J. , Dilling S. , Meister M. , Lee J. , Haugen J. 
Published: December 2007

Abstract
Formation pore pressure is a key parameter for reservoir description. However, the pressure measurement traditionally performed in highly deviated or horizontal wells with drill pipe conveyed wireline tools is time consuming. To provide the measurements earlier, a formation pressure tester has been developed as part of a logging while drilling bottom hole assembly.
To meet the challenges of short station duration and limited telemetry rates, the new tool is equipped with a downhole intelligent system for real-time operational decision. The flexibility of the tool design allows basic pressure tests with preset drawdown and build-up tests with preset fixed volume and rates, or repeated drawdown and build-up tests with different drawdown rates and volumes optimised downhole in real-time.
In this first trial, the longevity and repeatability of the tool were tested. The primary requirement of the pressure data acquisition was to define the pressure profile of the well for application in the completion design. In the proximal section of the well, a zone of low pressure was identified as predicted. The real-time data quantified the reservoir pressure, which allowed the drilling engineers to optimise the mud programme and efficiently complete the drilling of the well. The tool performed well and subsequent data analyses supported the real-time pressure measurements.
One hundred forty-two pressure tests were performed at 64 different depths along the 13,673 ft reservoir section. Drilling was completed, in two bit runs, in 204 rotational hours during which the angle was built from 66° to 90° with a maximum dogleg of 3.5°/100 ft.
The successful operation of the tool resulted in considerable time/cost savings due to the optimised drilling of the well and the cancelled pipe conveyed logging job.
Reaching the Drilling Objective "Nobody Gets Hurt"
Authors: Parker Donna J. 
Published: December 2007

Abstract
A fundamental belief at ExxonMobil is that we can achieve a work environment in which "Nobody Gets Hurt" and we are driven to consistently articulate and relentlessly pursue this vision. Safety requires both a disciplined systematic approach and a culture where people are aligned with the vision and actively involved in its pursuit. This paper will focus on the distinct yet mutually dependent critical success factors, Safety Management and Safety Leadership, and their impact on our Drilling Contractor safety performance. Our Contractor Lost Time Incident Rate (LTIR) per 200,000 work hours was 0.06 in 2003, down 67% since 2000 and 1/10th the International Association of Drilling Contractors (IADC) average.
Surface BOP: Equipment Development for Extending the Water Depth Capability of a D.P. Semisubmersible to 10,000 ft and Beyond.
Authors: Brunt Graham , Elson Scott , Newman Tim , Toudouze Paul 
Published: December 2007

Abstract
The water depth operating capability of a dynamically positioned semisubmersible drilling rig normally rated for 8,100 feet, has been extended to beyond 10,000 feet by deployment of a Surface BOP, a 13 3/8" casing riser and a Subsea Disconnect System (SDS). The rig and equipment package has recently successfully drilled an exploration well in 9,474 feet water depth, representing a new record for both the operator and the host country Brazil.
This paper focuses on the 5 main features of the equipment concept, design, development and deployment:
Setting Up the Operator-Service Provider Joint Team and Alignment of Goals Defining the Functional Requirements Combination New Technology and Off The Shelf Components Description of System Units: Surface BOP, Subsea Disconnect System, Surface and Subsea Control Systems and Acoustic Digital Spread Spectrum system (ADS2). Rig Interfaces
The paper describes the output from early hazard assessment exercises used to define the basic design parameters, the selection of appropriate acoustic communication technology to provide the opportunity for future developments, risks and how they were managed, Integration Testing and Deployment.
Surface BOP: Testing and Completing Deepwater Wells Drilled With a Surface BOP Rig
Authors: Mason D. L. , Wilie C. L. , Tharp W. 
Published: December 2007

Abstract
Many deepwater development projects in Operators' portfolios require lower costs to meet internal economic thresholds. Shell has therefore looked at extending Surface BOP activities to include well testing and completion techniques for deepwater wells in conjunction with Surface BOP drilling.
The cost advantages of Surface BOP drilled wells have been demonstrated (notably in the Far East), but the recent Surface BOP drilled Brazil well is a milestone in terms of extending the applicability to deeper water and harsher environments. The enabling technology has been the Subsea Disconnect System (SDS). Testing and completion techniques have therefore been developed to be compatible with Surface BOP wells drilled with an SDS.
The paper will focus on the following aspects:
Well testing using Surface BOPs from a moored rig Well Completions using Surface BOPs from a moored rig
Shell has developed a testing configuration to carry out a DST essentially using standard equipment. The well testing equipment configuration is currently ready for use, waiting for the opportunity to be run.
In completion operations, the availability of a high pressure riser does not add significant complexity and even actually simplifies some of the completion activities. Conceptual studies and early hazard/risk assessments have shown there are no obvious showstoppers and the duration of a Surface BOP rig completion is expected to be very similar to a subsea BOP rig completion.
The paper describes the results of the conceptual studies, early hazard assessment exercises used to define the basic design parameters and more detailed hazop studies.