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IPTC 2014: International Petroleum Technology Conference
- Conference date: 19 Jan 2014 - 22 Jan 2014
- Location: Doha, Qatar
- Published: 19 January 2014
61 - 80 of 354 results
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Sequence Stratigraphy Framework of late Early to Middle Cenomanian Rumaila and Late Cenomanian to earliest Turonian Mishrif Formations, Onshore Kuwait
Authors A.H. Youssef, A.P. Kadar and K.A. KaramA high resolution biostratigraphic and paleoenvironmental investigations were integrated with sedimentology and wireline-log-data to establish a sequence stratigraphic framework of Rumaila/Mishrif section, Kuwait. The biostratigraphic analysis of over 500 core/chips from 9 wells recognized six 4th order sequences over the study section. All the identified sequences correlated regionally. Three 4th order sequences were identified within the Rumaila Formation: RU100, RU200, and RU300. The RU100-SB lies on the boundary between the non-calcareous restricted shale of the upper Ahmadi Formation and the highly fossiliferous, calcareous marine shale at base of Rumaila Formation. The RU100 and RU200 sequences are represented by marine calcareous shale or marl containing common nannofossils and marine microfossils at their MFSs. The RU300-SB lies on top of the shallower facies, poorly fossiliferous highstand of the under-laying sequence. The RU300-MFS is indicated by abundant micro/nannofossils. This marine event is equated with the regionally known K130. The Rumaila/Mishrif contact is placed at the shift in facies from the deeper water facies of Rumaila to a shallower facies of Mishrif. The shallower facies of Mishrif is bioclastic wack/packstone enriched upward in rudistid and coralline fragments forming a fair/good quality reservoir. Three 4th order sequences were identified within the Mishrif Formation: MISH100, MISH200 and MISH300. The MISH100-SB lies on top of recrystallized wack/mudstone and packstone ending up with a dolomitic wackstone. The MISH100-MFS is indicated by planktonic foraminifers. MISH200-SB lies on top of Praealveolinid wack/packstone of the previous sequence. MISH200-MFS is indicated by planktonic and benthonic foraminifers. The MISH300-SB lies on top of the Praealveolinid wack/packstone ending up with lagoonal non-calcareous shale. The MISH300-MFS is indicated by planktonic and benthonic foraminifers. This marine event could be equated with the regionally known K140. The Rumaila is considered as a good seal all over Kuwait while the Mishrif is considered as a fair/good quality reservoir towards the south. Micritic matrix, moldic, vuggy and fracture porosity reservoir is represented in parts of MISH100, MISH200 and MISH300, while the rudist, coralline floatstone reservoir is existing within MISH300-HST of some areas. Geologic model is presented to show; depositional setting, paleoenvironments, basin configuration and geographic extension of different sequences.
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Advances in GTL Requires Effective De-Risking
More LessWith the realisation and start-up of Pearl GTL in Qatar - the largest Gas to Liquids plant in the world, a memorable milestone has been reached for both Qatar and Shell. For Shell, the journey started with a vision and ambition in the 1970’s to develop GTL technology, commercializing stranded gas and converting it to high quality hydrocarbon products as an alternative and differentiator to LNG. Following a successful commercial scale 14,000 barrels per day GTL plant application in Bintulu, Malaysia, the GTL technology and product marketing was well-matured for further scale up and was matched with the vision of Qatar to not only become the LNG capital but also the GTL capital of the world. The Shell GTL journey has been extensive with an ongoing evolution in applied technologies in syngas production, Fischer-Tropsch synthesis and product refining besides continuous development of new products and markets. Effective deployment of new technologies in highly complex and capital intensive GTL operations requires efficient and thorough de-risking processes for markets, technology and its operations. The commercial operations in Bintulu, along with additional dedicated industrial scale test units, continue to play a crucial role to test and develop new technologies and prepare products for market developments. This paper will cover elements of the development journey, with particular focus on the process of de-risking for new GTL technologies, operations and products. The Shell Gasification Process for syngas production is an example of a technology that evolved with considerable scale-up and could be effectively de-risked and subsequently successfully applied. An example of a new product development is the “clean burning and high energy” GTL Jet Fuel now used in commercial flights by Qatar Airways.
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Integration of a Geospatial Framework with a Suite of Numerical Models for Operational, Environmental and Regulatory Aspects of Cooling Water Usage
Authors E. Febbo, J. Duggan, V. Kolluru and S. PrakashUse of complex mathematical models and geospatial information systems (GIS) has traditionally been a mutually exclusive process. Spatial and temporal modeling is performed using a suite of well-established numerical models for a particular domain or area of interest (AOI) and outputs are produced for the same domain framework. GIS, on the other hand, allows integration for managing, storage, analyzing, connecting to perihyls, output (ie. hardcopy, softcopy) map and image products along with visualizing data for interpretation in two dimensions (2D) and three dimensions (3D) from many sources and different formats. A GIS system can include; marine data: biota, sediment types, water quality, hydrodynamic data, and ecological sensitivity information, in addition to atmospheric meteorological data. The ability to project and integrate results from numerical models in a GIS system could potentially be a powerful spatial decision support system (SDSS) for operational aspects of coastal and offshore industrial activities to support environmental management and for regulatory reporting requirements. The system would incorporate a web-based computing infrastructure where geospatial data can be accessible to many users with access controls set by data owners that are appropriate to needs. The vision is the implementation of integrated diverse multi-scale, multi-disciplinary spatial data with analytical and numerical models for environmental and industrial management. The initial SDSS developed in this stage of work integrates the physical and logical components of the modeling system into a GIS framework such that seamless interaction and functionality amongst existing GIS data sets and cooling water dispersion model scenarios can be further analyzed and visualized in a spatial format. The system will also have the flexibility to incorporate additional datasets, analytical or numerical models, and other decision making tools in the future. Such systems can assist users such as plant managers (adaptive management), emergency response teams (response planning and action) and policy advisors (impact assessment and planning). The recent emergence, although still in a nascent stage, of web-based, spatial referencing GIS tools show promise in many key aspects of environmental and operational management, research and public policy, including data storage, analysis, and decision making. Systems such as the SDSS developed in this work can help facilitate the use of these emerging technologies.
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Wireline Straddle Packer Microfrac Testing Enables Tectonic Lateral Strain Calibration in Carbonate Reservoirs
Authors T. Ihab, R. Naial, D.A. Moronkeji, J.A. Franquet and S.S. SmithWireline straddle packer microfrac tests have become an important technology in creating microfractures to measure in-situ formation breakdown pressure, fracture re-opening pressure, fracture closure pressure and stress contrast between reservoir and non-reservoir intervals. The formation tensile strength can also be estimated from the difference between breakdown and re-opening downhole pressures. This case study describes the use of microfrac tests measurements to validate and calibrate the horizontal stress profile in various intervals of the carbonate reservoir. Well-injection plans, cap-rock integrity assessment, shale reservoir fracture containment, stress contrast and minimum and maximum horizontal stress estimations can all be quantified from microfrac test measurement. Six straddle packer stations were tested for microfracturing in this study well. One microfrac test was repeated in one formation due to observed poroelastic effects in the fracture re-opening pressure responses. Poroelastic effects around the borehole occur when the pore pressure near the borehole increases with the injection cycles, thereby making it more difficult to effectively re-open the pre-existing induced fracture. When poroelastic effects are evident, it is important and recommended to record the first pressure fall-off cycle after the formation breakdown for fracture-closure identification. Subsequent cycles will indicate higher fracture closure pressures and therefore overestimate the minimum horizontal stress in the interval. This paper describes the pre-job modeling, real-time monitoring and post-job interpretation of straddle packer microfrac testing for recalibration of the geomechanical model to provide continuous logs of in-situ horizontal stress profiles over the entire interval.
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Horizontal Well Productivity Restoration - Successful Stimulation Application in a Large Onshore Field
Authors S. Tiwari, R. Singh, D. Prasad, P. Kumar, M. Jha, R. Tandon, A.K. Singh and G. DangwalThis paper discusses the step by step procedure to identify damage mechanism and remedial treatment in horizontal wells flowing with ESP (Electrical Submersible Pump) in one of the largest onshore field Mangala situated in Barmer, Rajasthan, India. Mangala field was discovered in 2004 and was brought on production with hot water flooding in August 2009 and is currently producing at plateau rate of 150,000 bopd (barrels of oil per day). The reservoir, in general, is of high quality with multi-darcy permeability, relatively viscous (15cp) and waxy crude (wax appearance temperature only 5 deg C below reservoir temperature). The Fathegarh is the main reservoir unit which is sub-divided into FM1 (top) to FM5 (base). FM3 and FM4 are dominated by well-connected sheet flood and braided channel sands having net to gross ~80%. These massive FM3 and FM4 sands have been developed with down-dip edge water line drive water injectors and up-dip horizontal producers. These horizontals wells (lateral length >500m) are completed with screens with ICD’s (Inflow Control Devices).The initial PI (productivity index) of wells has been of the order of 50-100 b/d/psi. However, with rise in water cut and increased withdrawal rate the productivity of these horizontal wells started to decline. This paper discussed the optimized production practice required to maintain optimum production rate from these horizontal wells. Due to the fact that even relatively shallow invasive near-wellbore damage may substantially impede flow; plan was prepared to identify the damage mechanism and accordingly engineer suitable remedial treatment. Envisaged damage mechanism included fines mobilization, asphaltene / wax dropouts and carbonate and sulfates scales. An inherent problem with these wells was poor acid distribution during matrix acidizing, especially due to high permeability in long horizontal sections. The low cost systematic stimulation design and placement technique resulted into the liquid PI restoration and improved ESP performance, which has been discussed in length in the paper.
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Barzan Completions Success Through Innovative Stimulation and Testing Technologies
Authors B. Clancey, M. Aly, M. Bugti, C. Shuchart, R. Sau, M. Grubert and A. FarahThe North Field Barzan Development was executed with focus on identifying and implementing effective completion solutions that addressed new technical challenges and operational constraints presented by the wells of this project. The primary challenges were in areas of matrix stimulation, spent acid clean-up, and production testing. Stimulation issues included implementing designs for a wide range of permeability contrasts, addressing stimulation vessel pump rate and acid capacity limitations, managing live acid corrosion due to sour environment, and assessing effectiveness without production logs. Spent acid clean-up operations required protecting downhole safety valves and achieving fluids composition criteria required for production into carbon steel pipelines. Production testing challenges included fluids modelling and equipment solutions that decreased Safety, Health and Environment (SHE) risk and operational complexity, while allowing accurate measurement of gas and liquids flow rates and obtaining required fluid samples. The solutions included improvements to the acid stimulation system chemical diverter and corrosion inhibition package, custom design and manufacture of a subsurface safety valve protection sleeve, adoption of well clean-up criteria tailored to pipeline and facilities requirements, evaluation of multi-phase flow meter and real time fluids analysis technologies, and development of a simplified multi-phase flow rate calculation algorithm based on choke manifold and fluids composition data. Implementation of differentiating technologies enabled cost savings and SHE benefits due to reduced flaring, execution of single stage stimulations, smaller test equipment layout, and innovative flow rate calculation techniques. Stimulation designs were demonstrated as successful based on interpreted changes in zonal flow contributions derived from minimum surface fluid compositional data. Wells were completed and ready for handover, meeting all requirements for the surface production facilities.
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Successful implementation of Through Tubing Technology (Sand Control and Gas Lift) in Challenging Offshore Environment as an Integrated Development Strategy for Sustainable Development of Marginal Fields: A Case Study
Authors A. Sharma, A.K. Singh, S. Anand, A. Parasher, A. Sharma and S. KaleWell AB-5 was drilled & completed in a marginal field in offshore West coast of India. Initially well produced only gas, till the oil bearing sands were perforated & it was being put on commingled oil & gas production. Through tubing sand control was installed in the well in view of continuous sand fill observed post perforation due to unconsolidated sand formation. Over the period of time, formation pressure depleted and the well eventually load up & died in absence of any mode of artificial lift on the unmanned platform. The Challenge was to unload & activate the well using gas lift in a commercially viable manner, avoiding expensive Barge based operation without having the said facility & provisions available. Since no Gas Lift Mandrel was present in the upper completion, a Thru-tubing Gas lift technique using retrievable straddle packers with GLV in between & conveyed on slick line was being adopted. A temporary arrangement of nitrogen tanks, pumps & surface set up for subsequent well unloading was organized. Further, a 20 T modular crane was installed on the platform after a detailed platform structural load analysis for spotting the surface equipment. Detailed NODAL analysis was being carried out for modeling the required nitrogen rates and the well performance at different gas lift parameters. Post GLV installation, nitrogen was pumped thru the annulus via the GLV, installed against circulating SSD, into the tubing. This Paper not only describes the Job design, technique implemented & challenges overcome during successfully activating a theoretically dead well to approx. 1000 BOPD production, thus establishing the viability of Through Tubing Sand Control (TTSC) & Thru-Tubing Gas Lift (TTGL) technologies but also delivers an integrated development strategy for sustainable development of marginal fields. The same technology is now being implemented in other water loaded wells of the field having similar technical and logistical constraints.
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Advanced Slim Hole Logging Tools for Precise Mapping of Hydrocarbons and Lowering Drilling Cost
By J.J. RajivDue To The Emergence Of Advanced Slim Hole Logging Technology (ASHL) with an advanced silhoutte and advances in drilling technology, there is a general preference to drill smaller diameter wells due to the comparative cost advantage, which also incubated for silhoutte of Precise MAPPING OF HYDROCARBONS In recent times, this preference has led some wireline service companies to start to offer open hole formation evaluation services with slim tools having a diameter in the 2” to 2½” range. At present, most of the traditional petrophysical measurements can be acquired utilizing slim log tools. In addition, several“specialized” measurements, such as x dipole sonic, formation pressure testing, and resistivity imaging can also be acquired. The use of battery, computing memory technologies has allowed these tools to be deployed using a broader range of convenient techniques allows for reduced risk in the entry of slim hole wells. The provision of slim hole logging services has created an opportunity in the industry to leverage these tools for the economic development. Therefore, short horizontal sidetracks, well re-entries tests deeper horizons can be drilled and logged successfully.
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In-situ Residual Oil Saturation And Cluster Size Distribution In Sandstones After Surfactant and Polymer Flooding Imaged With X-ray Micro-computed Tomography
Authors S. Iglauer, M. Sarmadivaleh, C. Geng and M. LebedevWe imaged a sandstone at connate water saturation, residual waterflood oil saturation, residual surfactant flood oil saturation and residual polymer flood oil saturation at high resolution in 3D with a micro-computed tomograph. We measured oil saturations, porosities, residual oil cluster size distributions and oil cluster surface areas on each image. We found that the waterflood and polymer flood reduced the oil saturations significantly (from 68.4% initial oil in place to 38.3% after waterflooding and 28.5% after polymer flooding). The surfactant flood was ineffective, which is probably due to the formulation we used and/or the fluid equilibration times we applied. The residual oil cluster size distributions and cluster surface area-volume relationships followed power-law relations, consistent with previous experimental measurements. We conclude that micro-computed tomography can enhance understanding of pore-scale fluid dynamics significantly.
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Accurate 3D Seismic Interpretation of Large Braided Delta Reservoir and Outcrop Analogs in Northwest China
More LessThis paper presents a first discovered braided delta images (area of 562.5 square kilometers, depth more than 3400 meters) with perfect river channels by accurate 3D seismic interpretation in the hinterland region of JR basin in northwest china. We can clearly identify micro facies like the main channels in the delta plain, underwater distributary channels in the delta front, mouth bar and sheet sand from the very fine 3D seismic images. Methods are discussed for identifying and dividing the features of braided delta sediments, using sequence stratigraphy, well log characteristics, core observation, 3D seismic data and outcrop analogs. The most effective and visual methods to reveal the characteristics of this special geological body are 3D seismic interpretation and outcrop analogs. Based on high-resolution sequence stratigraphic framework and well drilling, a work program focused on the fine description of this large braided delta reservoir has integrated accurate 3D seismic interpretation and outcrop analogs, which include: synthetically seismic attribute analysis, spectrum analysis, seismic waveform classification display, 3D coherency interpretation, logging constrained seismic inversion, 3D visualization Interpretation and outcrop studies. This method is a key to do a multi-angle research, and to find out the distribution law of favorable sedimentary facies belt. Matching the modern outcrop sedimentary observation, accurately identify geophysical response of special geological body from 3D seismic images has greatly promoted present oil exploration. The high quality of this complete braided delta images will not only provide a new typical braided delta geologic model for geologists to do deep studies, but also be very useful to further develop the similar reservoir at home and abroad.
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Greenhouse Gas Emission Reduction and Tailgas Maximization At ORYX GTL
Authors N.P. Saravanan and K. VyasORYX GTL, a joint venture between shareholders Qatar Petroleum and Sasol Synfuels International, is a pioneering gas-toliquids (GTL) facility that produces premium diesel fuel, naphtha and LPG. The objectives of this paper are related to Greenhouse Gas (GHG) management at ORYX GTL: it aims to a) identify the various sources of GHG b) describe the methodology to quantify GHG emissions c) identify various opportunities to reduce GHG emissions, and d) provides a case study on GHG emission reduction through utilization of tailgas as fuel in fired heaters. The paper is organized in two sections; the first section presents a brief overview of the ORYX GTL process, identifies the various GHG emission sources, quantifies the GHG emissions and describes the concepts and options to reduce GHG emissions. The second section describes a case study on the opportunity to optimize fired heaters to make use of tailgas and steps that can be taken to make use of these opportunities. A brief overview is also provided on projects executed by ORYX GTL to support the company’s strategy of optimizing sustainability and stability by reducing GHG emissions. The major GHG emission sources from the ORYX GTL facility are broadly classified as combustion and flaring emissions. The GHG emissions at ORYX GTL are derived from estimates and calculations taking into account the composition of fuel streams, the energy content of the fuel, available measurement data, emission factors and mass balance approaches. It was found that flaring of tailgas contributes significantly to the release of GHG emissions from the ORYX GTL facility. The GHG reduction was achieved by making use of Advanced Process Control techniques, utilization of tailgas for fuel, and recovery of low pressure vent gases to use as fuel in process heaters. The use of tailgas as a fuel to fired heaters increased from 10% to 90-95% of total heat duty since start-up. The increase of tailgas as fuel resulted in the reduction of natural gas as fuel, improving the carbon efficiency of the plant and thus reduced the environmental impact. In 2012, a 23% reduction in GHG emissions was achieved compared to 2011 levels due to maximizing tailgas utilization as fuel and stable plant operations. The results from this study highlight that a further reduction of GHG emissions is achievable by focusing on plant stability and flare reduction projects.
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Waterflood Optimization and its Impact Using Intelligent Digital Oil Field (iDOF) Smart Workflow Processes: A Pilot Study in Sabriyah Mauddud, North Kuwait
Authors M.Y. Khan, H. Chetri, L. Saputelli and S. Singherms. The transformation of raw data into information is achieved through intelligent, automated work processes, which are referred to in this paper as “smart workflows.” These smart workflows assist engineers with daily well surveillance activities, aid productivity, and help improve the speed and quality of their decision-making process. The workflow presented is related to waterflood management; however, it is part of a family of smart workflows (e.g., electrical submersible pump [ESP], subsurface waterflood optimization [SWFO], and smart production surveillance [SPS] workflows), which have been discussed in other work. These smart workflows and a commercial software, Oil Field Manager (OFM) for Decline Curve Analysis (DCA), have also been used in waterflood optimization for the optimum production allowable selection, with the ultimate goal of improving asset performance. This paper shares how these smart workflows are used for waterflood optimization and illustrates a case study of an injection pattern optimization and its impact on production. Comprehensive monitoring of the waterflood has been performed using real-time data through iDOF smart workflow processes, illustrating the analysis of real-time data, which includes pump intake pressure, flowline pressure, water cut (WC), and flowing bottomhole pressures. Other data used include static bottomhole pressure, production log results, and production flow tests. Monitoring is planned in such a way to understand waterflood movement within the reservoir from injector to producers and its impact on the production behavior of the surrounding producers. A positive response in terms of pressure maintenance and production increase has been observed and confirmed using various analytical tools.
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Empowering Women in the Workforce: Leadership Roles
By M. YousufGlobal general perception of leadership roles. Worldwide leadership roles are traditionally held by men. While the share of women in the workforce is increasing, it remains difficult for them to reach senior positions, which are mostly held by men. The Qatar National Development Strategy 2011-2016 seeks to increase the number of women in leadership roles by 30 per cent. Perceptions in the GCC that have traditionally limited career advancements for women. A number of cultural, organisational and personal challenges hamper women from reaching senior positions. Women are perceived to work responsibilities. In addition, traditional views on what constitutes appropriate spheres for women’s employment influence education choices for education and promote occupational discrimination. How to promote women to leadership positions. Research and evidence indicate that the appointment of women as top managers can positively improve the performance of a company. Global corporations, conscious of the value of gender balance at all levels, are more eager to hire and promote women. Developing professional women’s skills in decision-making and leadership help them realise their full potential. Examples of development opportunities include providing training, instituting career development initiatives and mentoring programs, and ensuring networking opportunities. Sustaining continuous growth for women in leadership roles. Today, some professional women in Qatar are already in challenging leadership roles. We need to ensure that we sustain these current positions while encouraging continuous growth. [Actual paper will review statistics and demographics for GCC, and in particular State of Qatar, and how they align with the Qatar National Vision 2030 for Qatarization].
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Barzan Gas Project: Clean Source of Energy Supporting Qatar’s Vision
Authors W. Bacon and E.M.M.R. Al-KuwariRasGas Company Limited (RasGas), on behalf of Qatar Petroleum and ExxonMobil Barzan Limited, is in the execution phase of the Barzan Gas Project, constructing two of the largest natural gas processing trains in the world to provide the State of Qatar with natural gas and associated liquids to fuel its growing economy. At peak, more than 30,000 people from over 40 nations will work together to execute this project in a safe and environmentally responsible manner. Natural gas from Qatar’s North Field, the world’s largest non-associated gas field, will be produced at a rate of 1,900 million standard cubic feet per day (mmscfd) by Barzan Gas Project offshore facilities, comprising three unmanned wellhead platforms, two subsea pipelines, and two onshore gas processing trains, all of which will be operated by RasGas Company Limited on behalf of Barzan Gas Company Limited. In addition to producing natural gas, ethane and field condensate for the domestic market, Barzan Gas Company Limited will export liquefied petroleum gas (LPG), sulphur, and plant condensate to the international market. Against the background of Qatar’s unparalleled rapid rise to prominence on the world stage, broad development of its economy, industry, commercial and social systems, and the hosting of high–profile international events, including the 2022 World Cup, ambitious and impressive expansion programmes are being undertaken, including a new airport, new seaport, metro and rail networks, doubling the number of hotel rooms, new schools, universities, hospitals, sports stadiums, conference and exhibition centres. Natural gas supplied from the completed Barzan facilities, a landmark development, will play a key role in supporting Qatar’s growth with a clean and reliable source of energy from world class production facilities, and in doing so, support the four pillars of the Qatar National Vision 2030: human development, social development, economic development, and environmental development. The Barzan Gas Project takes its name from a fortified tower built in the early 20th century located north of Qatar’s capital city Doha.
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Assessing the Biotreatability of Produced Water from a Qatari Gas Field
Authors A. Janson, M. Katebah, A. Santos, S. Adham and S. JuddBiological treatment is generally regarded as the most cost-effective method for the removal of organics from wastewater. Biotreatment of produced water (PW) presents many challenges when compared with municipal wastewaters or industrial waste streams. These challenges are typically linked to its high level of organics (including refractory organics) and salinity which can dramatically reduce biological floc formation and biomass settleability in conventional clarifiers. In a membrane bioreactor (MBR), an ultrafiltration membrane separates the treated water from the biomass and settleability is not a factor. This paper summarizes the results of tests conducted in Qatar with three parallel bench-scale membrane bioreactors to assess the biotreatability of PW from a local gas field. The testing was partially funded by Qatar National Research Fund which is testament to the importance of the research and the value it brings to Qatar and the world. The test program followed a Box-Behnken experimental design requiring 13 separate tests with input parameters of hydraulic retention time, solids retention time and temperature and response parameters of % COD removal and oxygen uptake rate (OUR). The results indicated ≈60% of the COD is removed through treatment in a membrane bioreactor. Statistically, only SRT was shown to be a factor in the percentage COD removal. At an SRT of 60 days, the average percentage COD removal was 62%, 4% higher the 58% average COD removal obtained at an SRT of 120 days. The OUR ranged from 0.10 to 0.19 mgO2/L-min and was shown statistically to be only dependent upon HRT with the highest OUR obtained at the shortest HRT of 16 hours. It is concluded that if biotreatability is shown to be cost-effective, it can contribute as part of an overall system to treat PW prior to recycle or reuse. This can reduce the facility's demands for fresh water and can thereby make existing potable water supplies available for other important uses.
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Driving Continuous Performance Improvement in Qatar’s North Field
Authors K. Akyabi, B. Clancey, F. Yurkiw, J. Babb and C. ChisholmRasGas Company Limited has been utilising the ExxonMobil Fast Drill Process to drive continuous improvement in drilling operations in Qatar’s North Field since its roll-out in 2005. Implementation of the process has resulted in significant increases in drilling performance and unique changes in operational practices. In recent years, continued North Field development in new areas has introduced unique challenges requiring innovative drilling solutions to continue to raise the bar in drilling performance. This paper details how RasGas has utilised the Fast Drill Process to identify and extend new performance limiters in wells of increasing drilling complexity. It also details the development and roll-out of a new Flat Time Reduction initiative that targets performance improvement in areas previously untouched by the Fast Drill Process workflow. The combined impact of these initiatives has resulted in another step change in performance and well delivery in more complex areas of the North Field. The performance improvements have accumulated cost savings in excess of $250 Million USD for RasGas and its Shareholders and have been achieved while maintaining and building upon an industry leading safety record. The performance improvement initiatives described in this paper are applicable for any large scale drilling campaign that requires increased Rate of Penetration (ROP), reduced plateau times, and accelerated well delivery.
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Best Practices in Asset Integrity Management System
More LessThe main objective of an Asset Integrity Management System (AIMS) is to ensure that the physical assets of facilities and pipeline system are operated in a reliable, efficient, and safe manner. Such motives can include the fitness to function safely and reliably; Consistency with all industry requirements and international standards; Compliance with company’s AIMS Philosophy, Operating & Maintenance Philosophy & Engineering Standards/Specifications as well as industry regulations. The AIMS goals shall demonstrate the persona of the company where an inward look into the company’s values and shall be subjected to evolution rather than revision. At Dolphin Energy Limited (DEL), the QHSE philosophy of - zero injuries, zero accidents, zero releases and no (minimal potential negative) impact to the public, the surrounding environment, and customers (Zero Leak Thresholds) was support by DEL’s implementation of the most appropriate technology available in the world along with KPI development in areas of defect management; specified tolerances; assessing infrastructure fitness-for-purpose & measuring the effectiveness of AIMS activities. This review paper will demonstrate DEL’s great focus on proactively understanding the type, extent, and the effect of all potential defects and by implementing a process where such learning is re-injecting and the results are structured and documented. The importance of regular internal reviews of the AIMS to ensure internal conformance, and the appropriate evolution of such approach as well as measuring its effectiveness are all important in making the right decisions in cases where emerging issues are supported and maintained. The AIMS approach shall be proactive where asset safety and reliability start with prevention by utilizing rigorous QA/QC related to design; materials, coatings, cathodic protection system infrastructure, and non-destructive examination. Participation in the initial project development teams & project approval processes and providing Integrity related input/approvals of projects design bases and construction activities are of an extreme value to Asset Management. Generally, aging infrastructure does become susceptible to the manifestation of time-dependent failure mechanisms where monitoring programs shall be structured usually into Operational Monitoring programs as well as large-scale monitoring programs such as (ILI) for pipelines. Any potential issue identified through risk assessment and/or monitoring activities shall be effectively mitigated to ensure Asset Integrity. Mitigation programs of AIMS shall also be addressed and may include regular preventative maintenance programs & repair activities. On the engineering Asset Integrity side, defect data validation studies and Failure Investigation & Root Cause Analysis, defect Assessments and feature growth analysis, risk based inspections (RBI) shall be considered within the AIMS overall structure. Another important component of AIMS is the utilization of application software that will assist in decision making which also can be based on a GIS based platform tool for integrity-related decision making. Such application can perform comprehensive Risk & Data Management capabilities. This review paper shall demonstrate how AIMS at Dolphin Energy Limited has been evolving in the UAE by highlighting the best practices in the industry.
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Produced Water Management for Sustainable Reinjection––Bench Scale Tests to Remove and Destroy KHI
Authors M. Al-Shaabi, K. Emadaddhi and D. RoquetDolphin Energy Limited’s (DEL) production scheme is based on a wet transport of well effluents from offshore platforms (DOL-1 and DOL-2) to the onshore treatment plant. At the onshore receiving facilities, sour gas is routed to gas sweetening, condensate is stabilized and treated and produced sour water is routed to water treatment units. Since the plant startup in 2006, non-chemically contaminated waste water is used for irrigation after treatment. Produced waste water and chemically contaminated waste water are re-injected into a deep reservoir without any major treatment further to H2S stripping, oil skimming, pH control and multi-media filtration. However, local authorities have expressed their concerns about the quality of water injected and the potential risk of long term injectivity loss. Indeed, as sealines need to be protected all year round against corrosion using a Corrosion Inhibitor (CI) and hydrate formation during winter by using Kinetic Hydrate Inhibitor (KHI), produced water recovered onshore is chemically contaminated with polymer based chemicals. As KHI could damage the reservoir, it has to be removed from produced water prior to reinjection. However, no technology was clearly available and referenced for this application. Dolphin Energy launched numerous bench scale tests with a third party laboratory to identify the best treatment scheme to remove KHI. The paper will first explain the overall strategy put in place to identify applicable processes. Then, it will describe the laboratory tests on produced water for KHI removal and destruction. Eventually, results will be presented and compared in order to conclude with applicable treatment schemes that would remove and destroy KHI from produced water for sustainable reinjection.
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CO2 Capture From Sulfur Recovery Units’ Effluents
Authors D. Roquet, I. Aslam and K. EmadaddhiDolphin Energy Limited (DEL) is considering reducing the native Greenhouse Gases (GHG) emissions from its Ras Laffan plant in the state of Qatar. One important source of native Carbon Dioxide (CO2) is the gaseous effluents from the two Sulfur Recovery Units (SRU’s). Dolphin studied the possible options for recovering up to 50 MMSCFD CO2 from the subject SRU’s effluents upstream the thermal incinerator section in the SRU using the existing infrastructures in its Ras Laffan plant. The recovered CO2 would be exported at medium pressure (MP, 7 bara) and/or high pressure (HP, 190 bara) to other users. The study investigated the possible options to recover and compress the CO2 product. Capital costs, utilities requirements, operating costs, carbon intensity savings, layout and electrical power supply were all studied. The study investigated the following technologies, which are based on amine solvents: • HP scheme with some feed gas compression to improve the performance of the solvent and reduce equipment size • LP scheme with low pressure efficient technology that does not need much feed compression • Revision of existing treatment scheme in the Sulfur Recovery Unit to perform Acid Gas Enrichment, Tail Gas Treatment and CO2 capture with minimum modifications The study considered that either (i) each SRU train will get its own CO2 recovery unit and compressors, or (ii) the SRUs’ effluents from both SRU trains will be combined before treatment. The paper will present main outcomes of this study and highlight specific requirements with regard to CO2 properties in terms of phase behavior, design criteria and Health, Safety and Environment.
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Reservoir Fracture Characterization and Modeling in a Shuaiba Reservoir
Authors R. Corbeanu, S. Nasoetion, K. Yang, M. Labiadh, R. Narayanan, M. Mubarak and K. HabibMassive mud losses, well logging, seismic data together with observed conformance issues and significant variation in well performance suggest a well developed fracture system in a regional Shuaiba reservoir. Proper characterization of such fractures plays a critical role in modeling reservoir fluid flow and production. Fracture corridors are the dominant fluid flow paths in Shuaiba reservoirs and are the focus of this study. Their spatial distribution and conductivity are characterized by integrated analysis based on drilling, logging, core, seismic, and well performance. Geological analysis, including tectonic/structure history, strain/stress variation, and rock mechanical stratigraphy are performed to better understand the fracture system. Overall well performance is clearly related to fracture distribution throughout regional fields. During early stages of production, before water flooding, conductive fracture corridors connected the underlying aquifer to producers and occasionally resulted in premature water breakthrough in high strain areas. Following the implementation of water injection, these fracture corridors also connect some injectors and producers. As a result, continued development requires recognizing and mapping these fracture corridors. This is done by acquiring saturation data in recent horizontal wells. Together with borehole image data, the width and configuration of fracture corridors can be characterized. A practical approach is taken in 3D fracture modeling. Fracture corridors are interpreted in 3D by integrating all static and dynamic data available. Their conductivity is classified into high, mid and low using dynamic data and mud losses. Fracture distribution and flow properties are related to or constrained by geologically more predictable attributes including reservoir curvature, current day stress field, structure pattern, and mechanical stratigraphy. Using the approaches described above, an improved characterization of the fracture system was developed and exported to a geologic model for use in a dynamic simulation model to better predict waterflood performance.
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