bluuebunny/crossref_metadata_2025_split huggingface dataset:
Production Integrated Sand Control Benchmark for Mature Field Development
Authors: Chan Keng Seng , Chong Danny , Masoudi Rahim , Othman Mohamad B. , Bt M Nordin Norbashinatun Salmi 
Published: May 2016

Abstract
Current offshore marginal field development and mature field re-development in Malaysia consistently encountered high development cost and low recovery or incremental recovery. Wells are being drilled and completed at a high cost of15 to 30 M$ per well while the estimated ultimate recovery (EUR) per well is as low as &lt; 0.4 M Bbl. The associated well development cost (WDC) can be higher than 75 $/Bbl. This high WDC cost can be further aggravated by a significant increase in completion cost if an expensive sand control method is required to mitigate risk of sand production. Rock mechanical properties, stress and pressure distribution can vary widely, from layer to layer, rockfacies to facies in the reservoir. Reservoir pore pressure and its distribution could also change drastically during the entire production life cycle. With results of field case studies as examples, this paper is to share our engineering approach in first determining where and when we need sand control based on the geo-mechanical sand-free critical drawdown pressure (CDP)evaluation for the selected well type, configuration and completion. The generated CDP will be later coupled with the current pressure and fluid distribution predicted from the reservoir simulation model and confirmed with the historical pressure and production data for well type, completion and sand control strategy in mature fields. Decision to implement a proper sand control can be made by comparing the CDP with the minimum drawdown pressure (MDP)required to meet the expected production rate target. Sand control method selection shall then be based not only on the sand particle size distribution, well life and the mode of well production (single selective or commingle) but also on maximizing reservoir contact and oil and gas recovery per well. The presented workflows and methodologies is to constitute a new sand control benchmark for well design and production optimization and serve as an engineering guide for optimizing the sand control cost in Malaysia.
Surmounting the Challenges Leads to Discovery of New Field in Deep Jurassic Formation. : A Case Study.
Authors: Al-Ibrahim Abdullah Reda , Duggirala Vidya Sagar , Manimaran A. , Al-Salali Yousef Zaid , Packirisamy S. , Ibrahim Anwar 
Published: May 2016

Abstract
This paper shares and discusses the challenges faced and activities that led to a significant discovery in a deep carbonate reservoir. It covers the successful well-testing design as well as the methods and procedures adopted to complete short term test of this well safely.
A new structure in the state of Kuwait was identified for drilling the first exploratory well targeted at deeper Jurassic formations. Adjacent fields to this structure are HPHT naturally fractured reservoirs and fluids are sour in nature. The target well was sidetracked twice with two different kick-off points while drilling the deep formations due to well control problems. Deep formations in combination with HPHT and sour environment created unusual challenges while testing several zones in this well.
Based on past experience, a simple test string assembly suitable for HPHT and sour environment was selected for this well. Perforating using deep penetration TCP guns, stimulation with Breakdown acid followed by emulsified acid and testing with Drill Stem Testing (DST) techniques were applied for evaluating the deep formations. During short term testing of second zone, gun hanger has moved upward by about 900 feet and plugged 5" production liner top preventing any flow/access from the zone below. Though this zone produced hydrocarbon, full potential could not be established due to plugging. The last zone was successfully tested and produced significant amount of gas and 44.5o API oil with 1% H2S. Meticulous planning and testing strategies could overcome many challenges to discover commercial quantities of hydrocarbon from new field.
This new discovery adds significant hydrocarbon reserves and put a new field on the map of the state of Kuwait. Based on the commercial success in this well, further exploration and development activities are being planned to focus on the same structure.
Applications of Downhole In-Situ Reservoir Fluid Properties in Interval Pressure Transient Test
Authors: Hademi N.R. , Daungkaew S. , Chokthanyawat S. , Kiatpadungkul W. , Platt C. , Limniyakul T. , Last N. 
Published: May 2016

Abstract
Pressure transient analysis has been known as an important tool to properly characterize a reservoir. The scales of measurement for different testing methods depend mainly on their radius of investigation, i.e. how far pressure changes/disturbance can be seen into reservoirs. In a large reservoir, a fullscale testing method such as a Drill Stem Test (DST) is required to test enough reservoir volume for flow assurance purposes. To test for the reservoir extent, a production test is required to reach reservoir boundaries.
In recent years, there have been tremendous developments for short period testing methods. The Formation Tester (FT) is one of the tools that are used to evaluate reservoir fluid properties and acquire pressure transient data from both dual packer and single probe configurations. With the current Downhole Fluid Analyzer (DFA) technology, reservoir fluid properties such as composition, Gas-Oil-Ratio (GOR), in-situ density, and viscosity can be obtained in real time. These insitu fluid properties can be used to analyze pressure transient data for reservoir permeability, skin factor, and reservoir heterogeneity; and as a result, the DFA serve to push IPTT applications to another step forward.
This paper will specifically focus on the application of DFA for IPTT purposes and also a continuation of several published papers which discussed the use of different scales of pressure transient data. The results from this paper will mainly focus on the use of single probe and dual packer IPTT to obtain reservoir properties in thinly bedded reservoirs with waxy crudes from the South East Asia region. The viscosity variation from oil based mud filtrate to reservoir fluid during the pump-out and its effect on the pressure derivative will be discussed using actual examples to demonstrate this point.
The end results may contradict traditional testing methods on the use of virgin reservoir fluid properties for pressure transient analysis. Hopefully, this paper might open another option when FT is deployed together with the current DFA tool for quick and effective reservoir evaluation in thinly bedded reservoirs which are often encountered in many parts of the world.
Petrophysical Reservoir Characterisation of a Complex Heavy Oil Carbonate Reservoir in North Oman
Authors: Al-Bulushi Nabil , Al-Mjeni Rifaat , Said Dhiya , Al-Yaarubi Azzan 
Published: May 2016

Abstract
There have been a number of major heavy oil discoveries in Oman in recent years. In order to devise efficient and cost effective recovery mechanism careful and detailed subsurface understanding of these fields is critical. To this end, petrophysical understanding plays a critical role, as it represents a basic building block of the static and dynamic models. The field under study is a fractured carbonate reservoir with high viscous oil. It is believed that this reservoir has gone through various cycles of drainage and imbibition. Thus, in addition to the complex geology, understanding of fluid distribution and fluid mobility are among major challenges that detailed petrophysical evaluation needs to address. Understanding these parameters will help determine the feasibility of the recovery methodology to be adopted.
This paper details a novel petrophysical workflow that integrates 3D NMR, multiarray/multi frequency dielectric measurements, borehole images, and core analysis. The core analysis focused on capillary pressures, Dean-Stark, and rock typing. Fracture studies included detailed image analysis and extensive fall off test for understanding the nature and distribution of the fracture network in the reservoir. The wealth of well data coupled with geological and dynamic data reduced the overall reservoir properties and fluid distribution uncertainties.
Dielectric data provided resistivity independent saturations validated by Dean-Stark data. Combining dielectric and 3D NMR data allowed better formation characterization and fluid type evaluation and their present day distribution. Additionally, this combination indicated that water is not at an irreducible state in the reservoir. This was supported by the core saturation height function which indicated that present day saturation should be much higher if the reservoir was in drainage mode. These results were crucial to evaluate development options, underlying uncertainty/risks of this reservoir, and design optimum future data acquisition requirements.
Well Integrity During Operating the First Offshore Gas Wells in Saudi Arabia; Experiences and Lessons Learned
Authors: Alsyed Samih M. , Uzcategui Elio A. , Adesegha Rotimi , Al-Ahmari Abdulrahman S. 
Published: May 2016

Abstract
Annulus pressure is an important key to maintaining Well Integrity. During the start-up of Saudi Arabia's first offshore non-associated gas field containing high pressure high rate sour gas wells, a continuous increase of some annuli pressures was experienced despite the fact that these annuli were cemented to surface. During any well production, the heat transfer from the produced fluid to the trapped annuli fluids causes annuli pressures to increase to levels that could exceed collapse and/or burst pressure limits of the casings. This is especially true during early startup of the well when all annuli fluids are cold (offshore wells) or at ambient temperature (Onshore wells).
To ensure that the pressures does not exceed the maximum allowable limit of well tubular various calculations were performed, taking into account not only the tubular limitations but also the formation pressures these casings encountered, to set the maximum limit. Periodic bleeding of pressures and continuous monitoring was necessary to avoid reaching this maximum set limit for the first four months of production.
In this paper performance of the different annuli is analyzed and discussed. Calculation methods are also discussed in details which were employed to determine the maximum allowable pressure limit for each annulus. Elimination of frequent bleeding of 1st casing-casing annulus in one of the wells by revisiting the maximum limit, taking into consideration the formation pressure the casing was set in are some of the lessons learned documented during this first offshore gas field startup and will be put forth in the paper.
Improving Safety & Reliability Through Process Safety Management in Gas Handling Facilities
Authors: Al-Adwani Adnan Eid , Kapavarapu Venkata Madhusudana Rao 
Published: May 2016

Abstract
During the whole Facility Life Cycle of a Gas handling plant, Risk Management for protection of environment and communities and prevention of major hazards along with Asset Management are the key drivers for making the facility compliant with Health & Safety Regulations and Environmental issues and at the same time profitable economic and able to preserve asset value by improving the level of operational and process safety has become a crucial and challenging issue in a HSE perspective in Gas handling facilities.
Process safety can be placed at the intersection of these independent but interrelated aspects and can be regarded as the key element for performing an integrated and comprehensive analysis capable to maximize plant effectiveness ensuring the best safety level, minimizing risks to safety and security and limiting at the same time downtime due to operational disruption or interruption, thus achieving consistency throughout the whole project life cycle.
Therefore an effective process safety management demands a holistic and systematic approach for improving operational and process safety throughout the whole project life cycle from design and construction, through operation and maintenance, to decommissioning.
In light of the above considerations a tool for process safety management has been elaborated and is hereafter described as a new structured approach of BAD ACTOR Identification in the facilities and its mitigation methods.
Process Improvement approach was adopted in Kuwait Oil Company in Gas Management group and Gas Operations team and the similar culture was inculcated in to the operation employees to report all process incidents and BAD ACTORS. These BAD ACTOR events will be analyzed based on risk prioritization by conducting structure Risk analysis and Root cause analysis of various methods and recommendations will be implemented to avoid similar incidents to improve the reliability of the plant operations.
Collapse Strength Study for the Solid Expandable Tubular
Authors: Chen Qiang , Gao Shan , Li Yiliang , Li Tao , Bi Xiuling , Han Weiye , Sun Qiang 
Published: May 2016

Abstract
The paper summarized an experimental and theoretical study of the collapse resistant ability of solid expandable tubular (SET)after expansion, and the formula used to calculate the collapse strength of casing was modified to make it adaptable to the expandable tubular.
One key limiting factor of the expandable tubular in its application in the open hole well to replace the casing is its post-expanded mechanical properties. The collapse strength of the expandable tubular after expansion was significantly compromised as the result of the comprehensive influence by the change of factors like the ovality, eccentricity and residual stress. In view of these problems, firstly full-scale expansion experiments were performed to examine all the impact of those factors; secondly the formula was modified based on the experimental data; thirdly the collapse experiments were carried out to test the strength of post-expanded tubulars as well as the accuracy of the modified formula.
The results demonstrated that after large-scale plastic deformation, the dimension of the tubular changed dramatically as represented by the increase of eccentricity and ovality, the residual stress also appeared on both inside and outside surface of the tubular, the starting point of the collapse occurred at the position with the least wall thickness. The calculation results which reflected the average collapse strength of the tubular were larger than the actual experimental outcome but the error was kept well within 15%.
We expect the research will contribute to the better understanding of the collapse resistant ability of post-expanded tubular and form the necessary technical basis for it future broad use.
Lithofacies Classification: From Sedimentologic Analysis to 3D Reservoir Modelling
Authors: Chen Jiajie 
Published: May 2016

Abstract
Deepwater depositions are complicated processes reflecting the combined effects of global eustatic sea-level variation, regional sediment input, climate, paleo-topography, and many other factors. The complex depositional processes give rise to various depositional facies, which significantly impacts reservoir connectivity and quality. The description of deepwater depositional facies can be performed in details at sedimentologic level based on corematerials, in which complex sedimentation feature such as grain and matrixcomposition, grain-size distribution, color, sorting, roundness, climbingripple, cross bedding, various amount of mud clasts within massive sandstone, degree of bio-alteration, and so on, are considered to classify the facies. Such a detailed facies analysis is necessary because it provides information regarding the geological processes and associated environment that is responsible for the accumulation of the reservoir rocks. However, when dealing with reservoir modeling, it can be too sturdy to include all detailed facies types from sedimentologic description. Main attention should be paid to identify just the major facies types that bear geological environment signature, yet simple enough for any reservoir simulators to handle. This study integrates outcrop data with subsurface data, compares patterns of facies variations from outcrops to several deepwater fields, and suggests that for reservoir modeling purpose most of the deepwater turbidite fields can be described by four major facies types, channel/lobe axis, off-axis, margin, and background. Each of these facies has its range of reservoir properties, and the overall performance of the reservoirs depends on the relative proportions of various facies types and their spatial arrangement. By applying advanced technology, log data are trained to recognize facies types based on the patterns defined from core studies. The detailed log facies types can also be represented by four major groups. As a result, integration of core, log, and outcrop data leads to a robust solution for handling the complex lithofacies issues in 3D geological model, enabling better development of strategy forfield development.
A Dynamic Hybrid Model to Simulate Fractured Reservoirs
Authors: Shuhong Wu , Xiaobo Li , Qiaoyun Li , Hua Li , Baohua Wang , Wen Yuan 
Published: May 2016

Abstract
Fractured reservoirs simulation has long been challenge to reservoir engineers to handle the complex geometry structure of fractured reservoir and fluid flow processes in it which includes viscous, capillary, gravitational and diffusive effect. In traditional reservoirs simulation, the fractured reservoir is usually divided into matrix and fracture interacting continua such as Dual Porosity model or Dual Permeability model. It is assumed in these models that the fracture system is in a steady state which the width, length, density of the fractures in reservoir does not change during the whole production history, therefore, it is not possible to simulate fractures variation effect with these models.
In order to simulate the unsteady state of fracture system, a dynamic hybrid model has been developed in the paper which a dynamic transitivity tensor model is overlapped to Dual Porosity model. It is assumed that the fracture network is the primary continuum for fluid flow, the matrix of low permeability, high storability is considered to be a sink or source to the fracture. The matrix and the fracture communicate through an exchange term which describes the fluidflow between matrix and fracture. The fracture network is considered to be in unsteady state in which fracture has possibility to widen, lengthen, and close during oil production. A transitivity tensor is introduced to describe these processes, which is a function of pressure, stress, density of fractures.
The paper will detail the dynamic hybrid model such as its assumptions, equations, mechanisms and also its applications in the fractured reservoirs simulation. The simulation results show that the dynamic hybrid model has high potential to accurately simulate the dynamic fracture network as well as the fluid flow with the capillary, gravitational and diffusive effects between matrix and fracture.
First Installations of the 9-5/8-in. Enhanced Single-Trip Multi-Zone Sand-Control Technology in Offshore Brunei
Authors: Fourie Bernard , Marpaung Billman , Jansen Rene , Wong Andrew , Mok David 
Published: May 2016

Abstract
Brunei Shell Petroleum (BSP) operates the mature South West Ampa (SWA) and Bugan Fields in Brunei Darussalam. The fields, located 10 to 21 kilometers offshore Brunei in water depths ranging from 10 to 40m, are major sources of oil and gas production. Controlling sand production is a key completion challenge as the reservoirs are composed of multilayer unconsolidated sands, requiring sand control for safe production. Cased-hole, stack-pack systems were considered as the default solution for shallow reservoir zones and wells. Dueto the reduced production rates in some reservoirs in the fields and increasingrig costs there is a demand to improve the cased-hole gravel pack efficiency.
The wells require zonal isolation and sand-control treatment. Cased-hole stack packs have been a reliable completion method, due to their capabilities for better zonal isolation and multi-zone functionality. Due to the reduced production rates in the mature fields, however, wells were no longer considered economically feasible. Therefore, BSP decided to try a new 9-5/8-in. enhanced single trip multi zone gravel pack system. This system appeared capable of providing significantly greater cost efficiency than conventional cased-hole stack-pack systems, which would make the marginal wells profitable.
This paper describes the 3 wells completed by BSP in 2010 and 2011 using the enhanced single trip multi zone gravel pack system. For the 3 wells, a total of10 zones required a sand control treatment. The paper also will describe why the enhanced single trip multi zone gravel pack system was chosen and will discuss the wellbore configuration, the implementation, and other field possibilities for the system. Finally, the paper will discuss the "bestpractices" learned from the first enhanced single trip multi zone gravel pack system installations; the challenges encountered during the job execution, and also, will compare the enhanced single trip multi zone gravel pack system with the conventional cased-hole stack-pack system to highlight the advantages of the new system.
Hawiyah Gas Plant New Thermal Oxidiser Combustion Control Philosophy
Authors: Almubarak Yousef , Al-Tawil Haider M. 
Published: May 2016

Abstract
Hawiyah Gas Plant at Saudi Aramco recently commissioned a thermal oxidizer. The thermal oxidizer unit has two main functions that shall be achieved. The first function is to oxidize and destroy the Acid gas which has minute quantities of BTX. The BTX shall be fully destroyed at a temperature above 1800 deg F. The second main function of the unit is to provide heating media for the hot water which is used in the re-boiler of the DGA stripper in sweet gas treating unit. The hot water temperature controller has a set point of 350 Deg F thus providing constant water temperatures to the gas treat process. Hawiyah gas plant will share through this paper the internal effort to rectify the original control philosophy design problems submitted by the equipment vendor of the thermal oxidizer that fail to accommodate both functions at the same time. The paper will shed the light on all of the new innovative major advance control loops configured to achieve the appropriate hot water temperature, combustion chamber temperature in addition to the Oxygen trimming advance control. The new control scheme helps the plant to achieve more reliable system to any process changes, it helps to maintain the targeted process parameters set points and optimize the fuel consumption. Hawiyah Gas Plant will present the actual reduced figures in the fuel consumption after the modification and shows the improved in the equipment reliability.
In the first part of the paper, brief description of HGP process will be shown. And In this introduction, the role and function of the Gas Treating unit 6 and its thermal oxidizer units will be discussed.
Then there will brief disciption of the basic start up and firing scheme for the thermal oxidizer. After that, the paper will discuss the refractory dry out and the heat up requirements and how this is achieved by the logic.