bluuebunny/crossref_metadata_2025_split huggingface dataset:
MPFM Commissioning Optimization: A Case Study
Authors: AlDabbous Mohammad S. , Al-Kadem Mohammad S. , AlMashhad Ali S. , AlSadah Hassan A. , Alzahrani Mohammed S. 
Published: November 2015

Abstract
Multiphase flow meters (MPFMs) are being widely employed in the oil and gas industry for a higher rate test frequency in the producing wells and for continuous production monitoring. But after the installation and before it provides services, a MPFM experiences a lengthy process that is comprised of meter calibration, settings configuration and wellhead sampling for liquid density checking. To accomplish this process is often challenging in offshore fields due to the adverse weather conditions and the high costs of offshore activities. That has hindered the MPFM commissioning activities in many Aramco offshore fields and consequently affected the testing requirements.
A MPFM is an intelligent metering device which is very sensitive to the fluid's PVT properties, fluids densities, H2S and CO2 contents. A typical calibration of a MPFM in Aramco offshore fields often requires taking fluid samples from each individual well for the fluid density check and determination of mass attenuation of oil due to the fluid density variations in a field. An offshore MPFM often covers the testing requirements for all 6 to 8 producers on a platform. Hence this method always takes a long time to take wellhead fluid samples for completing the calibration process of a single MPFM, and tends to lag far behind their planned commissioning schedule.
In 2013, thirty seven new MPFM were installed in 37 different platforms covering more than 122 wells in one Aramco field. A commissioning and calibration campaign was launched early this year with a different approach after carefully analyzing the PVT properties of the produced fluids. In this approach the typical calibration work was first performed on 3 wells, and then the same settings and parameters were copied and uploaded as a batch to those remaining MPFMs covering other 119 wells in this field. This method significantly reduced the time for marine boat support. Furthermore, those 119 wells are being remotely flow tested in a batch via Supervisory Control and Data Acquisition (SCADA) to verify if any further adjustment is required. Due to H2S and CO2free in the produced fluids, and the almost constant liquid densities throughout the area in this field, the accuracy of the MPFM measurement can't be compromised by taking this process. The paper describes a new method that significantly reduced the total time for the 37 MPFM calibration and commissioning jobs and saved the costs.
Owning Risk to Improve Equipment Integrity
Authors: Henry Neil S 
Published: November 2015

Abstract
Many applications of risk based practices are used in industry for inspection and Process Safety Management. There are benefits to integration of the two processes and ensuring relevant local data is included, to show how risk can be managed by effective "ownership".
In the process of carrying out numerous studies for a range of petrochemical industries, it has become clear there is a relationship and synergy of these techniques which can strongly influence the mechanical integrity of assets. It has been found that focussing on the consequences of an event may unduly influence risk management practices, when trying to ensure integrity of process equipment. In many cases, the probability of a failure and its scale, from a small leak to a major failure, are not fully utilised to help define accurately the integrity risks for process equipment.
The observations used in preparing this paper, have been drawn from both failure investigation and integrity reviews. These suggest a lack of confidence in understanding the potential for deterioration of assets. This in turn results in difficulty to assess where the true risk of a loss of containment is greatest and how it can be managed. Examples of combining the information used for risk based inspection or process hazard studies are shown, and how this knowledge may be applied in practice are given.
Application of operational experience is used to demonstrate these principles and their influences on equipment condition. The basis of the approach is to start from understanding real deterioration risk and working on prevention to reduce probability, rather than assigning a theoretical value, then trying to manage the consequential risk.
Improving the Accuracy of Onshore Pipeline Remaining Life Assessments and Optimising Field Verification Activities from Detailed Assessment of Corrosion Metal loss Feature Interactions
Authors: Morris J. R. , Regis R. T. , Upadhyay S. H. , Rajashekar V. K. , McNaughtan D. 
Published: November 2015

Abstract
This paper discusses approaches to improve the accuracy of onshore pipeline remaining life assessments and optimise the targeting of locations for field verification activities via detailed assessment of reported corrosion metal losses and corrosion feature interactions. The overall aim is to show how confidence in assessments can be increased while ensuring adherence to industry standards.
Evaluation of interactions between corrosion features is a necessary consideration as specified in industry standard fitness-for-service (FFS) methodologies. In accordance with developed FFS standards, if corrosion features are sufficiently close together, they should be considered to act as a single, larger feature. However, in the authors' experience, detailed assessment of corrosion feature interactions is not always performed. This can lead to overly optimistic/pessimistic results, and a subsequent lack of focus for future field verification activities with respect to inspection locations and techniques.
FFS assessments are often based on results from in-line inspections (ILIs), which, depending on the pipeline condition, can report many thousands of individual corrosion features. In the case of heavily corroded pipelines, where corrosion damage is reported along approximately the same orientation (for example at 06:00, the bottom of the line), inadequate consideration of corrosion feature interactions could significantly overestimate the maximum allowable safe pressure of the pipeline. In contrast, conservatively assuming a grooving metal loss morphology and simplifying FFS calculations to assume infinitely long corrosion can appreciably lower calculated safe pressures, resulting in premature remediation activities (such as repairs, de-rating). In both cases, neither method of assessment allows specific targeting of field verification activities as areas of maximum corrosion interaction will not have been determined.
This paper will demonstrate the benefits of performing a detailed assessment of corrosion feature interactions during an integrity assessment in comparison to overly optimistic or simplified assumptions, and show the benefits of such detailed assessment with respect to future field verification activities.
Robotic Inspection Solutions for Petrochemical Pressure Vessels
Authors: Bos Barend van , Mallion Adam , Wilson Craig , Zwicker Ekkehard , Schler Andreas , Black Timothy 
Published: November 2015

Abstract
Virtually all equipment in the oil, gas and petrochemical industry requires some kind of periodic inspection. Pressure vessels are an important part of the production process; currently the inspection of these are being done by human inspectors that require entry into the vessels. The working environment inside these vessels is potentially dangerous, and substantial precautions must be taken ensure the safety of the inspectors. These precautions take considerable time, making the inspection both very costly and hazardous.
Robotic technology offers a safe alternative to human entry, and is now advanced enough to perform inspections remotely, minimising human entry thus increasing safety.
The PETROBOT project has brought together inspection methods and robotic technology to reduce risks and cost involved in inspection of pressure vessels. PETROBOT comprises the complete value chain, from robot and inspection technology providers, to inspection service providers and end-users. The project has developed robotic deployment platforms and adapted industry standard inspection techniques to demonstrate the benefits of remote pressure vessel inspection.
This paper presents the use case and progress made under PETROBOT for the inspection of pressure vessels. Two different, yet complementary robots have been developed, one a magnetic crawler; the other, a snake-arm robot. The two systems enable robotised inspection capabilities in a variety of pressure vessel designs. The robots carry a payload consisting of inspection tools: a camera for visual inspection, structured light for profilometry, and an ultrasonic transducer, and an eddy current transducer.
These novel inspection technologies have been integrated into the robotic systems and have been tested and verified on artificial defects, as well as real pressure vessels in a laboratory environment. During the final stages of the PETROBOT project, they will be deployed in real installations of the participating end users.
Successful Chemical Water Shut-Off Treatment in an Omani Field Heavy-Oil Well
Authors: Dupuis Guillaume , Bouillot Jerome , Templier Arnaud , Zaitoun Alain 
Published: November 2015

Abstract
This paper relates the successful water shut-off treatment of a heavy-oil Omani well combining the use of microgel and gel.
As many sandstone reservoir with strong aquifer in Southern Oman, this vertical well faced early water breakthrough along with sand production. Water cut increased dramatically until reaching 100%. The average permeability was around 500 mD but effective permeability ranged from milli Darcy to several Darcy. Due to well characteristics (several perforation intervals, gravel pack, etc…), it was not possible to identify and isolate the water production zones, which oriented the strategy towards the use of RPM products (Relative Permeability Modifiers). The treatment consisted of microgel and gel injections which were bullheaded into the whole open interval. After the treatment, the water cut dropped from 100% to 85% and sand production was stopped over a period of time superior to one year. The treatment was cost effective, producing more than 9000 bbl of extra oil in one year.
In this paper, we describe the treatment design methodology combining laboratory study and near wellbore simulations, and the optimization of injection sequences. Finally, the treatment execution is detailed followed by the presentation of the results obtained since the realization of the operations.
The results show that combining low-risk approach and low-cost RPM technology is an attractive way to restore productivity of watered out wells, in which conventional water shut-off zone isolation is not feasible.
Alternative Conveyance Method for Log Data Acquisition in Abu Dhabi Onshore Oil Fields - A Case Study
Authors: Ahmed Basma Ali , Celma Rafael , Dhache Ali , Mostafa Hassan , Chinchayan Gustavo , Farouk Omar El 
Published: November 2015

Abstract
One of the major challenges in Abu Dhabi onshore oil fields is the substantial increased water production with time. This is mainly attributed to unforeseen the presence of sub seismic faults and fractures along the drain hole. To address this, smart completions are being introduced to control water production by moderating the flow profile across the completed interval, whereby water and gas breakthrough are delayed in producing wells and injection rates are optimized in water and gas injectors across the full wellbore face. The smart completion design is supported by dynamic and static reservoir information. In this study, production logging tool (PLT) data was available to benchmark and confirm the results from dynamic simulation modeling. However, geologic features that cause the uncontrolled water inflow were not confirmed due to lack of lack of image data.
A novel methodology has been implemented allowing resistivity image acquisition in workover wells by utilizing a compact memory tool that addresses the challenge of accessing old wells in Abu Dhabi onshore oil fields. The poor condition of the well is a result of prolonged production, post-stimulation and subsequent borehole degradation. The technique consists of acquiring data using drill pipe with significant savings in rig time and a higher chance of accessibility when compared to alternative techniques. This technique also protects the tool from becoming stuck and incurring damage during entry, thus improving data acquisition quality and minimizing the possibility of re-runs. When compared with common pipe-conveyed wireline alternatives (TLC) in previous wells, up to 33% savings in logging time was observed with a much safer operation.
The procedure was achieved with success in terms of image data quality and execution time. In the absence of core data, the microresistivity imaging technique gives the best possible picture of the rock. It has been effective in characterizing rock fabric required for structural analysis (including fracture identification and fault identification and analysis), geomechanics, sedimentology (including paleocurrents analysis and facies determination) and image petrophysics applications such as identifying vuggy secondary porosity. A quick- turnaround in data processing allows the introduction of detailed fractures and fault interpretation, which in turn allows optimization of the completion design.
Liquid Waste Management in E&P - Cairn India Case Study
Authors: Ray Rimjhim , Kapadia Gautam , Sambasivam Srikrishna 
Published: November 2015

Abstract
With an average gross operated production of 211,671 boepd in FY2015, Cairn India Limited (CIL) is the largest private sector producer of crude oil in India. In FY 14-15, around 120 wells were drilled in Mangala, Bhagyam and Aishwariya alone. Waste water generation in Operations has seen a massive increase in recent years because of increased production and an aggressive drilling campaign.
CIL operates on Zero Surface Effluent discharge philosophy making it imperative to deliberate on waste water disposal strategy. Managing the huge volumes of waste water in a sustainable manner is a challenge. Accordingly, waste water treatment plant for reuse and waste pits and guard ponds were created to evaporate waste water. Due to waxy nature of oil in waste water, high level of suspended solids and bacterial degradation, natural evaporation is almost negligible. Waste water accumulation over a long period of time has resulted in inventory buildup of all the pits. It has become business critical requiring strategic focus to ensure business continuity and sustainability.
Given the challenges of waste water management in onshore Oil & Gas operations, the paper describes the various technologies available in the market and tested by Cairn, results of market studies carried including pros and cons of each option, followed by pilot-scale implementation of the chosen technologies. The paper not only describes the success of the pilot studies and the related technical aspects, but also the commercial, socio-economic and stakeholder challenges and the approach to applying the selected option for full-field implementation. The paper concludes with suggested way forward for full-field implementation including associated challenges and success factors.
The objective of this paper is to share the experiences of an operating company with other oil & gas Companies worldwide on various aspects relating to waste water treatment and management in onshore oil & gas operations. The typical process for an Oil & Gas Operator is to evaluate all aspects, right from technology finalization to economic optimization and finally develop an integrated roadmap for the entire project. A firm methodology was adopted to validate the technical as well as the commercial aspects of the project. The final treated water is put for reuse thereby delivering twin benefits in terms of handling waste water in a sustainable manner as well as optimizing the water footprint.
Managing Process Safety Through Effective Integrity Management
Authors: Holthoon Evert van 
Published: November 2015

Abstract
Shell Upstream has been through a significant journey to establish and/or confirm Design Integrity, Operating Integrity, Technical Integrity and to strengthen Integrity Leadership. This covers existing assets as well as design, construction and startup of large projects.
This paper aims to provide a fresh perspective on the pivotal role of Integrity Leadership, needed to deliver the journey to Goal Zero, No Harm and No Leaks. The paper covers: What it takes to understand Process Safety Performance, and how to develop local as well as global insights across a large asset baseIndustry benchmarking, and the opportunity it presents for PS Performance benchmarking.Shell's perspective on more effective application of Learning from Incidents (LFI), using a more engaging and reflective learning setup. The reflective learning material for Process Safety, "I own my barrier", was released in April 2015.New insights gained from PS culture surveys.The role of Leaders at different levels in the organization to manage and improve Process Safety performance. What it takes to move from a Calculative to a more Proactive culture in existing assets.
Planning of Low Salinity Water Flooding with the use of Novel Laboratory and Numerical Simulation Studies
Authors: Othman F. , Aljehani A. , Kanfar M. F. , Abdel Azim R. , Ding H. , Gholizadeh N. , Rahman S. S. 
Published: November 2015

Abstract
In this paper, we present an integrated approach to study the effect of low salinity water flooding on the oil recovery. This is achieved in four steps: first, we have extended our multiphase fluid flow simulation in porous matrix discrete fractures by integrating the electrochemical model. The electrochemical model estimates disjoining pressure from the knowledge of which in turn is a function of different chemical species and their concentration, pH and temperature. Next, the film thickness, which is controlled by different chemical species is determined by using atomic force microscopy and compared with the values estimated by the chemical model. In the third step, we carried out low salinity water flooding on fractured carbonate core samples using a combination of different ions and their concentrations and recovered oil was measured. In these laboratory experiments water floods in core samples with single fractures are simulated to study the effect of heterogeneity (discontinuity) on oil recovery. In the final step we have used our multiphase flow simulator to study low salinity water flooding in laboratory core scale. The results of this study are evaluated by comparing with the results obtained in the laboratory.
The results of this study show that the water film thickness is directly related to brine concentration. There exist, however, an optimum concentration at which maximum thickness can be reached. Above this optimum concentration water film thickness gradually decreases. Core flood tests have shown similar results, that is maximum oil recovery can be obtained at an optimum brine concentration.
A Semi-Analytical Model for Extended-Reach Wells with Wellbore Flow Splitting; a Production Optimization Scheme
Authors: Al Qahtani Abdullah , Al Hashim Hasan , Al Yousef Hasan 
Published: November 2015

Abstract
Well design have evolved noticeably during the last decade from the design of conventional vertical wells to extended-reach/multilateral horizontal well design using directional drilling technology. Evolving horizontal well design range from simple horizontal wells with single wellbore to complex multilaterals with multiple sublaterals (fishbone wells). Furthermore, advancements in horizontal well drilling allows horizontal wells to be drilled several thousands of feet long. However, field experience and flow meter surveys on long horizontal drain-holes revealed that the frictional pressure losses in the wellbore is an important factor limiting the effective length of long horizontal wells and consequently hindering the full use of the entire length of the horizontal wells. The frictional pressure losses may be comparable with the drawdown at the producing end of the well rendering a portion of the horizontal drain-hole unproductive.
Well completions have also been advancing to cope with the technological advancement in horizontal well drilling and new equipment for monitoring and subsequent selective control have been developed to optimize the productivity of the horizontal wells. The complex architecture of those wells generally makes them more expensive to drill and complete. Therefore, these wells must be planned efficiently.
For these reasons we present a viable method to produce these long horizontal wells and laterals from the two ends (heel and toe) by using U-shape wells. The introduction of the U-shaped wells is driven by the need to maximize flow contribution from the entire drain-hole lengths. To confirm the viability of this idea, a rigorous semi-analytical model was developed to study the performance of the U-shape horizontal well under different production scenarios. The model incorporates the impact of wellbore hydraulics into the solution, and the U-shaped wells can be produced from both ends at constant rates to predict the pressures at the two ends. The model was used to calculate the flow profile along the horizontal section under different production scenarios. Furthermore, the model can be used as an optimization tool to maximize the benefits from long horizontal drain-hole as it allows producing the two wings at different flow rates. The U-shape wells can also be optimized to have more uniform flux distribution along the horizontal drain-hole in reservoirs subjected to water drive. The developed model can also be used to evaluate the reservoir parameters in such well architecture by calculating the classical horizontal well performance and reservoir characteristics by measuring wellbore pressure at one or both wings.