bluuebunny/crossref_metadata_2025_split huggingface dataset:
Experimental Investigation of Oil Recovery from Carbonate Reservoir Rocks Under Oil-Wet Condition: Waterflood, Gas Injection, SWAG and WAG Injections
Authors: Fatemi Mobeen , Shahrokhi Omid , Sohrabi Mehran , Vieira Raphael , Ahmed Kamran 
Published: November 2015

Abstract
Gas injection schemes (including WAG and SWAG injections) are among the most widely used Enhanced Oil Recovery (EOR) processes for carbonate reservoirs due to their usually low rock permeability. Because of the complex nature of carbonate reservoirs (structural heterogeneities and mixed- to oil-wet conditions), most of the existing reservoir simulators are not able to adequately model EOR processes in these reservoirs. Performing reliable laboratory experiments in reservoir cores under reservoir conditions is necessary in order to evaluate the performance of these oil recovery techniques and obtain the required data to assess the prediction of the currently available models in commercial simulators.
In this paper, we present the results of a series of coreflood experiments performed in carbonate rocks. Both reservoir core plugs as well as a dolomite outcrop core were used in the experiments. The cores were aged in reservoir crude oil to restore wettability. Gas and water injection experiments were performed under reservoir conditions and with different injection strategies. Separate multi cycle WAG injection experiments were performed starting with gas (WAG-DI) or water injection (WAG-ID) in order to compare the impact of the order of fluid injection. SWAG injection experiment was also performed with an injection gas to water ratio of unity. The injectivity and production data of different injection strategies were compared. Generally speaking, dolomite cores showed less oil-wet characteristics compared to reservoir carbonate cores which showed strongly oil-wet behaviours. WAG injection starting with waterflood and SWAG injection performed better than waterflood or gas injection alone. Ultimate oil recovery by gas injection was considerably less than that obtained by waterflood. As a result of poor efficiency of the gas injection, the WAG injection starting with gas injection (WAG-DI) showed lower recovery performance compared to the waterflood up until the end of 3rd WAG injection cycle. Nevertheless, WAG-DI ultimately outperformed waterflood. Although SWAG injection outperformed the WAG-ID for the first two cycles of injection but the ultimate residual oil saturation was lower for the WAG-ID injection. In addition to lower ultimate oil recovery, SWAG injection test showed more injectivity issues compared to the WAG-ID injection sequence. The observed trends of residual gas and oil saturations in carbonate reservoir cores were different compared with those of water-wet and mixed-wet sandstone rocks reported in our previous studies in which the residual oil to water was reducing linearly with an increase in trapped gas. The results provide useful insights into mechanisms of oil recovery by gas and water injection in carbonate reservoirs and highlight some important differences with sandstone reservoirs.
Experience on Custody Transfer Using MPFM
Authors: Yusuf S. A. , Menchaca T. F. , Altaf B. , Khan M. N. 
Published: November 2015

Abstract
During the initial development phase of a new field operated by Abu Dhabi Marine Operating Company (ADMA-OPCO), due to the unavailability of processing facility, produced fluid is designed to flow into a pipeline operated by Zakum Development Company (ZADCO). The produced fluid is metered using two Custody Transfer Multi Phase Flow Meters (MPFM) with a normal operating philosophy of one-operating-one-standby and can be operated in series for verification purposes. This paper discusses the operational challenges for the custody transfer of ADMA fluid to ZADCO processing plant.
The challenges discussed in this paper are due to low production during commissioning and commingled production from multiple reservoirs.
During commissioning of the production platforms, the production was lower than the operating envelope of the meter. This would result in significant error in the meter readings. Since there was physical separation between the production facility and the metering is about fifteen kms away, the time lag between the meters and the production platform did cause further uncertainty in the measurement. To overcome this challenge a strategy was developed to meter the produced fluid with most accurate meters as available at each stage with consensus from both parties.
The commingled production from three reservoirs with significant difference in parameters posed challenge for the use of appropriate PVT properties in the custody transfer MPFMs for the conversion from line condition to standard condition. This was overcome by performing sensitivity analysis on the mixtures, developing PVT tables for commingled production ratios based on reservoirs and implementing a process on the selection of the appropriate table based on the changes in production contribution from the different reservoirs.
Other minor operational issues related to the MPFM metering are also discussed in the paper.
Enhanced SIMOPS Expect Additional 3 Million Barrels of Oil Production and Increased Injection Rates
Authors: Salman Mohamed Wajeeh , Warraich Awais , Moussa K. Abdel-Ghani 
Published: November 2015

Abstract
Simultaneous Operation (SIMOPS) i.e. concurrent execution of two or more activities at the same time and place, which due to their interaction result in increased operational complexity and level of risk.
While challenging existing practices, team has benchmarked Company practices with shareholders, other OPCOs and Service Providers. All the activities having major impact on Production/Injection shut down were captured. Industry standard risk management approach followed to assess all the risks associated with each individual activity. After reviewing all the hazards and safeguards in place, activities were declared as Permitted / Restricted /Not Permitted.
In total 17 activities were reviewed, 11 activities assigned as "Permitted", 4 activities as "Restricted" and 2 activities remained "Not Permitted" under SIMOPS.
By enhancing SIMOPS efficiency by 30%, expected 3 Million Barrels of additional Oil production per year and increased injection rates. Saving above 150 Million USD per year (using current oil price of 50$/bbl). Benefits will further magnify after full scale implementation of multiple SIMOPS per field and increased rig activities in future.
Enhanced SIMOPS efficiency helped the Company to increase effective production capacity and achieve its sustained production assurance milestones without any compromise on safety and with no additional cost.
CNPC Occupational Health Management Model and Results
Authors: Xu Wenbo , Men Xiaotang , Ye Hong , Du Weidong , Huang Zhiling 
Published: November 2015

Abstract
Being as one of China's largest oil and gas producer and suppliers, China National Petroleum Corporation (CNPC), with more than 1,500,000 employees, has about 90 large and medium subsidiary enterprises, and occupational hazard inevitably occur during the construction and production operation, which has the characteristics of wide geographic distributions, enormous employees contacting hazard factors and various hazard factors resulting in occupational diseases. According to the characteristics of occupational disease hazard factors in petroleum and petrochemical industry, and characteristics of occupational health hazards for oversea operations and field operations, CNPC has set up its own occupational health (OH) management models to control occupational disease hazards from the source. In recent years, 92–97% of the employees contacting hazard factors have passed occupational health examinations and there were no hazard accidents of occupational diseases. Therefore, the job concerning OH has obtained satisfactory results.
WellCON: An Early Kick Detection System
Authors: Velmurugan Naveen , Bansal Gopal , Sharma Tushar 
Published: November 2015

Abstract
The main objective of the work is to provide an automated system of early kick detection and control system which monitors and reports the physical conditions of the inside of wellbore annulus instantaneously through time measurements of primary waves propagation through the annulus. This system is graphically modelled as virtual instruments using the software, LabVIEW and is named ‘WellCON’ by authors. Authors propose a model in which time taken for this wave propagation in the annulus reveals the physical condition of the wellbore and denotes the fluids present in the annulus. In case of an unexpected event of kick, the model instantaneously provides the type of fluid in the kick and notifies the driller. To understand the capacity of the well to take a kick, kick tolerance are calculated at every instance of drilling. Based on the severity of the kick influx, considering the tolerance level, commands are sent to BOP to shut-in, leading to complete automation of the kick handling system.
GPS Aided Oil Spill Tracking and Mapping System: Application to Offshore Petroleum Industry
Authors: Velmurugan Naveen , Belay Masho Hilawie , Linse Christoph , Dai Yukun , Navas Sergio Sánchez , Ramesh Kumar K. C. 
Published: November 2015

Abstract
There are varied types and severity of marine oil spills. Authors focus on the oil spills that are results of a blowout especially in the offshore petroleum industry. Blowouts are considered as nightmare situation for oilfield workers and oil blowouts from offshore rigs are horrible disasters causing loss of human lives, oil spills causing damage to marine life and environment besides huge economics impacts. Precise information about time course or the extent of oil spill is crucial for fast and effective response. This paper describes the result of a work carried out by the authors to design and develop an autonomous offshore oil spill system that is robust, financially affordable and suitable for day and night operations. Authors propose an arrangement of anchored and floating buoys fitted with GPS (Global Posistioning System) as described in this paper for real time tracking and mapping of an oil spill. Experiments and computer simulations have been conducted to test the efficiency and working methodology of the proposed system.
Comparison of Condensate Recovery by Hydrocarbon and Nonhydrocarbon Injection
Authors: Gohary Mohamed El , Bairaq Ahmed Mohamed , Bradley David C. , Saeed Yaway 
Published: November 2015

Abstract
The challenge in the development of gas condensate reservoirs is to recover the most valuable hydrocarbon component, "condensate". Pressure drops below the dewpoint anywhere in the reservoir cause condensate dropout. When the pressure drops near the producing wells, condensate banking can occur, which impedes production. Gas recycling is one of the efficient ways of developing such reservoirs because it maintains reservoir pressure and hence increases the condensate recovery.
Demand for gas has resulted in a strategy of nonhydrocarbon (NHC) injection in selected areas of the field. An NHC method under study has the potential to raise the dewpoint of the reservoir fluid making it more susceptible to condensate dropout. The objective of this study was to quantify the effect of NHC injection on recovery of condensate and hydrocarbon gas and the effect on productivity of wells. In this study, sector models are extracted from a full field model. The molar recovery of hydrocarbon component and condensate recovery were analyzed under the effect of reservoir properties and distance between wells and injection stream. NHC breakthrough time and tracer modeling were also studied.
The NHC under study was found to be inefficient compared to the hydrocarbon injection in all cases; however, the properties of the rock and distance between wells impact the efficiency. The difference in recovery factor at two pore-volume injection with NHC injection was nearly 5% less than that with hydrocarbon injection at pressure 4,700 psi, and this difference increased to 10% at 3,000 psi. NHC is poor in revaporizing the condensate dropped in the reservoir whereas hydrocarbon gas can efficiently revaporize condensate either by first-contact miscibility or by a multicontact miscible process.
New Innovation Improves Performance and Reliability of Downhole Plugs
Authors: McGowan Robin 
Published: November 2015

Abstract
Sealing technologies provide a vital role in a wide range of applications no more so than in the design and development of Retrievable Bridge Plugs (RBP) where performance is a vital safety and operational consideration. Moreover, for workover operations using RBPs it is also essential that deployment and recovery are equally as reliable as the pressure and temperature performance of the plug.
Traditional retrievable bridge plugs based on solid elastomeric seals have been the mainstay of well intervention since the 1940’s. However, the long-term shift towards gas production, higher pressures, higher temperatures and increased regulatory standards means these systems can no longer provide the performance the industry demands. New innovative technologies are needed to bridge this gap and this paper provides evidence of once such technology with the potential to service the next era of exploration and production. The paper explores some of the operational and practical limitations of traditional solid elastomer sealing technology for RBPs and introduces a new type of hybrid metal-polymer seal offering significantly improved sealing performance, larger running clearances and enhanced reliability. The new seal technology is described alongside experimental data on the seal’s performance and operational configuration.
Assisting Extension of Life for Aging Assets with Deluge System Technology
Authors: MacKenzie Hugh , Jones Callum 
Published: November 2015

Abstract
Extending the life of aging assets is an important topic in an industry where many platforms are operating beyond their initial planned life. Preserving an asset over 40 years is particularly problematic when operating in environments such as the Middle East and the North Sea, where platforms are exposed to some of the harshest conditions in the world. This paper will outline a ground breaking technology, developed to enable operators to test deluge systems without the need for water, mitigating the issues associated with wet testing and helping extend the life of an asset.
The current industry practice to verify compliance of a deluge system is to perform a wet test. This involves flowing seawater through the system to the nozzles at which point it is directed over a designated area. This technology circumvents the main source of the issues which cause corrosion. This technology will be detailed, from proof of concept to deployment in field and the benefits which this brings in comparison to conventional wet testing and other dry-testing technology.
Field Development Plan Optimization for Tight Carbonate Reservoirs
Authors: Alyan Mohand , Martin John , Irwin Drew 
Published: November 2015

Abstract
This paper describes the simulation study done on optimizing the field development plans for undeveloped tight carbonate reservoirs with limited production history and surveillance data. The successful implementation of a water injectivity pilot test has enabled waterflood as a recovery method in the low permeability carbonate reservoir. The field optimization consists of three major components: well orientation, spacing and wellbore placement.
Based on this study, a data collection program was proposed to target the uncertainties associated with developing the assets. The first part of the study focuses on the proper orientation of wells considering the factors of thermal fractures mitigation, developing the highest oil in place and ease of well drillability. The second part is concerned on studying the optimum spacing for achieving the target rate while maintaining an effective water displacement performance. The third part involved studying the well's placement for achieving a high rate early on during the production build-up while maximizing recovery in the long term. The combination of these three parts has led improved understanding of the important uncertainties associated with the reservoir which will be targeted in the ongoing appraisal program.
High Efficient Metal Sulphide Based Porous Carbon Matrix for Mercury Removal
Authors: Reddy K. Suresh , Alshoaibi Ahmed , Srinivasakannan C. 
Published: November 2015

Abstract
The presence of elemental mercury in wellhead natural gas is an important industrial problem as even low levels of mercury can damage cryogenic aluminum heat exchangers and other plant equipment. Mercury present in the natural gas stream will also dramatically shorten the useful life of many precious metal catalysts. The present work focus on development of high efficient metal sulfide based adsorbents for mercury removal application in gas processing as well as refining operations, through preparation techniques that offer high activity and low pressure drop. The adsorbents were tested in bench scale setup for mercury adsorption capacity in a simulated environment mimicking plant conditions. The results show that a good improvement toward mercury adsorption capacity compared to its counter parts.
Implementing a Disciplined Process Safety Framework in Mature Assets: Two Case Studies on Onshore Sour Field
Authors: Petrone Annamaria , Scataglini Luciano , La Rosa Laura , Salvador Carlo , Frattini Luca , Manfredi Giusto 
Published: November 2015

Abstract

Objective/ Scope
Despite all the technological advancements and lessons learnt from past incidents, the oil and gas business has still a long way ahead in the journey towards an accident free working environment. In particular process-safety incidents characterized by low-frequency but severe consequences represent a big concern not only for downstream plants and refineries, but also for upstream activities due to their dramatic aftermath: loss of containments and release of toxic substances have in fact the deadly potential to escalate to fires, explosions and unwanted releases into the environment. Therefore e&p operators needs to get a better understanding of how managing major accident hazards through structured and systematic approaches. This issue becomes increasingly important when it comes to deal with mature assets where ageing wells, flowlines and facilities can pose integrity issues and operational risks. In such circumstances the possible presence of H2S can make the picture even more complex as regards health and Safety of people and Emergency Response readiness. This paper provides an overview of the holistic and systematic approach that has been set up in the company and implemented throughout the asset life with the precise aim to ensure integrity of its operation, managing major accident and deliver the fundamentals of process safety consistently across its subsidiaries

Method Procedures, process
In the Company efforts to enhance process safety have been translated into the identification of focus areas representing the main pillars for Process Safety: Risk identification assessment and management, assurance verification and continuous improvement and last but not least Process Safety Leadership, culture and training.

Results, Observations, Conclusions
Within each focus area, a number of elements have been singled out to define the key aspects of operations that organizations need to get right in order to assure integrity (e.g. management of change, incident investigation and analysis, emergency planning and response, Safety Critical Elements etc.)

Novel Additive Information
In the paper all support strategies, methodologies and dedicated tools (e.g. BART BAse line Risk assessment Tool, production checks, Safety Critical Element Management, PS Audits) that constitute the bedrocks of the system and contribute to an effective and thorough implementation of the Process Safety framework are described through its successful roll out on selected pilot cases, two sour mature fields onshore.
Integrating Community Well-Being in Business Decisions
Authors: Shah Vishal , Rivera Patricio 
Published: November 2015

Abstract
Ensuring the well-being of the local communities during flaring is considered as one of Al Hosn Gas' key areas of stakeholder management. While the Company endeavours to minimize flaring and there will be no continuous flaring during normal operation of the plant, temporary flaring has been carried out previously during well-testing and clean-up activities. It is also currently being carried out during the start-up phase of the plant until it achieves steady state operations.
Al Hosn Gas's stakeholder management process comprises of two stages. The first stage explores potential impacts of flaring on local communities using quantitative dispersion modelling tools. As an example, the potential impacts of flaring during start-up have been studied extensively to determine whether it would be safe to commence plant operations while the annual Moreeb Hill festival was being celebrated approximately 18km upwind of the gas plant. In a situation where flaring is imperative, the Company enters into the second stage of stakeholder management, under which a Flaring Awareness Program is executed in a systematic and co-ordinated manner.
Quantitative dispersion and risk modelling studies have aided Al Hosn Gas in making executive decisions, such as planning the plant start-up date after the Moreeb Hill festival to eliminate any impact on festival visitors. In another case, a Flaring Awareness Program was conducted prior to the Company's well testing & clean-up activities as a stage 2 activity. Based on the feedback, it was observed that all stakeholders were appreciative of Company's efforts. The effectiveness of the stakeholder management process has been demonstrated by a smooth flaring operation without community concerns. The stakeholder engagement activities have additionally raised awareness of the project within local communities resulting in increased interest to be part of the Company family in the future.
Al Hosn Gas is completely aligned with ADNOC's aim to reflect positive HSE performance by showing concern for its neighbours, contributing to sustainable development, and earning the confidence of the society at large. This in turn also helps the Company to win a "Local License" to operate smoothly.
Mapping of Mubadala Petroleum Asset Integrity and Process Safety Practices to International Best Practices
Authors: Grassian David , Scott Trevor , Bahatem Mohammed Hussain 
Published: November 2015

Abstract
This paper examines the development of best practices in Process Safety and Asset Integrity over the last thirty years and provides an overview of the performance of Mubadala Petroleum (MP) against the resultant best practices. Best practices are typically developed in response to catastrophic process events. The response to catastrophic events is usually a public outcry followed by legislative and industry initiatives and while it is unfortunate that the main catalyst for innovation is catastrophic accidents, this defacto process has yielded an impressive collection of practices. This research catalogs best practices from several sources and identifies the commonalities as well as the divergences. The comparison revealed that the commonalities significantly outnumber the divergences, which is indicative of an emerging consensus across the industry and across the world. There were some slight differences in the approach which are discussed in detail.
This research laid the groundwork for a comparison of Mubadala Petroleum's performance against international best practices. The elements of Mubadala Petroleum's Operational Management System (OMS) were mapped to the compiled list of twenty-seven international best practices. There was a corresponding OMS element and supporting procedures for each and every practice identified.