Petroleum Development Research Articles

Addressing Environmental Health Problems in Ogoniland through Implementation of United Nations Environment Program Recommendations: Environmental Management Strategies

On 4 August 2011, United Nations Environment Program (UNEP) submitted an unprecedented, scientific, groundbreaking environmental assessment report (EAR) on Ogoniland to the Nigerian government. This was the outcome of a 14-month intensive evaluation of the extent of pollution. The intention was that UNEP’s recommendations would be implemented to restore the devastated environment, on the one hand, and on the other, counteract the numerous environmental health issues that have for decades, plagued Ogoniland. However, five years post-EAR, and despite the seriousness of the situation, no significant resolution has occurred on the part of the government or the Shell Petroleum Development Company (SPDC) or Shell. To date, millions of Niger Delta residents particularly those living in the oil-bearing communities, continue to suffer severe consequences. Although the assessment was conducted in Ogoniland, other communities in the Niger Delta are also affected. This article explores prevailing issues in the Niger Delta, using Ogoniland (a microcosm of the Niger Delta) as an example. A multidisciplinary approach for sustainable mitigation of environmental health risks in the Niger Delta is paramount, and environmental management tools offer valuable strategies. Adopting the UNEP’s recommendations for addressing environmental health problems requires implementing the environmental management/environmental management system (EM/EMS) model. However, the persistent lack of political will on the part of the Nigerian government, and the grossly nonchalant attitude by Shell remain major obstacles towards executing UNEP’s recommendations.

Trophic pathways supporting Arctic grayling in a small stream on the Arctic Coastal Plain, Alaska

AbstractBeaded streams are prominent across the Arctic Coastal Plain (ACP) of Alaska, yet prey flow and food web dynamics supporting fish inhabiting these streams are poorly understood. Arctic grayling (Thymallus arcticus) are a widely distributed upper‐level consumer on the ACP and migrate into beaded streams to forage during the short 3‐month open‐water season. We investigated energy pathways and key prey resources that support grayling in a representative beaded stream, Crea Creek. We measured terrestrial invertebrates entering the stream from predominant riparian vegetation types, prey types supporting a range of fish size classes, and how riparian plants and fish size influenced foraging habits. We found that riparian plants influenced the quantity of terrestrial invertebrates entering Crea Creek; however, these differences were not reflected in fish diets. Prey type and size ingested varied with grayling size and season. Small grayling (<15 cm fork length (FL)) consumed mostly aquatic invertebrates early in the summer, and terrestrial invertebrates later in summer, while larger fish (>15 cm FL) foraged most heavily on ninespine stickleback (Pungitius pungitius) throughout the summer, indicating that grayling can be insectivorous and piscivorous, depending on size. These findings underscore the potential importance of small streams in Arctic ecosystems as key summer foraging habitats for fish. Understanding trophic pathways supporting stream fishes in these systems will help interpret whether and how petroleum development and climate change may affect energy flow and stream productivity, terrestrial–aquatic linkages and fishes in Arctic ecosystems.

Technology Focus: Production Monitoring/Surveillance (March 2017)

Technology Focus Industry trends in production monitoring and surveillance continue to demonstrate significant input from the academic and research fields, practical applications, and new-technology introduction. Market conditions similar to those of the previous year are driving some of the same discussions again this year. With the decline in new drilling, our peers are focusing on optimization of existing fields and examining past performance in preparation for new future developments. In many cases, these efforts are being performed with fewer personnel and limited capital resources. Optimization of existing fields is inspiring new concepts for statistical and predictive production modeling, along with new views on decline analysis. Virtual flow-measuring systems, while not new technology, are experiencing a broadened application as a more-cost-effective alternative. The focus on existing assets also has increased discussion on well integrity and how this should be monitored and maintained. As we look toward future improvements, we are also taking advantage of the decline in new drilling activity to review performance from the past several years. Specifically in regard to fracturing, we are investigating the relationships between methods for drilling, fracturing, and completion design, along with their effect on production performance. The industry is becoming more efficient and knowledgeable in its data gathering, evaluation methods, and operations. We will be better equipped as industry activity begins to increase, because of our ability to operate more efficiently at current market conditions or because of market improvements or both meeting on middle ground, in the near future. The articles selected for review demonstrate some of the achievements of our peers from the last year. Recommended additional reading at OnePetro: www.onepetro.org. SPE 183463 Well-Productivity Analysis Integrating Ultrahigh-Resolution LWD Images and PLT: A Data-Integration Case Study by H.M. Al Shehhi, ADCO, et al. SPE 179058 Well-Surveillance Operations and Data Analysis in Thermal Viscous-Crude Project in Kuwait—A Case Study by Shaikha Al-Ballam, Kuwait Oil Company, et al. SPE 183535 Implementing Fiber-Optics Distributed Sensing as a Key Surveillance Tool by S. Al Shoaibi, Petroleum Development, et al.

Key Learnings From First 2 Years of a Full-Field CSS Development in Oman

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 179833, “Key Learnings From First 2 Years of a Full-Field CSS Development in Oman,” by Solenn Bettembourg, Steve Holyoak, Abdullah Alwazeer, Mohammed Manhali, Mohammed Rawahi, and Amur Habsi, Petroleum Development Oman, prepared for the 2016 SPE EOR Conference at Oil and Gas West Asia, Muscat, Oman, 21–23 March. The paper has not been peer reviewed. The A East Haradh formation contains a 200-m-thick oil column of highly viscous oil, with viscosity ranging from 200 to 400,000 cp. Because of the high viscosity, first production was considered possible only by the use of thermal enhanced-oil-recovery techniques, starting with cyclic steam stimulation (CSS). This paper presents key learnings derived during this initial-operations phase of CSS in the A East Field, including key trial results on different well completions and artificial-lift systems. Overview of Field Startup In light of the results of a new geochemical characterization study of the crude extracted from a core, cold production was deemed feasible in the crestal area of the field. Viscosities at the top of the Haradh were estimated at 200 cp, lower than previously thought, and progressing cavity pumps (PCPs) were installed in 32 wells to start a cold-production phase. Cold production started in March 2013 and lasted until the end of 2014, when all wells in the field were converted to CSS. The cold-production period allowed early depletion of the reservoir and later improvement in steam injection. A pressure drop of up to 20 bar was observed, and fluid-level measurement in the wells and PCP performance suggested good pressure communication between the wells. Despite some early challenges, first CSS production was promising and, within a few months, was ramped up to 70% of the targeted CSS field peak oil rates. Overview of CSS Performance A typical CSS cycle in an A East well is shown in Fig. 1, using the wellhead temperature sensor as an indicator. The cycle starts with the injection phase for several weeks (initially 4 to 6). After that, the well is closed for a soaking period of a few days and then opened for free flow, which lasts for up to 3 weeks. The well is intervened with a flush-by unit (FBU) to prepare for production, followed by starting the beam pump. At the end of the production cycle, the well is stopped on the basis of end-of-cycle criteria and intervened again to prepare the well for steam injection for the subsequent cycle. The overall cycle duration is typically between 100 and 300 days and is dependent on the performance of the well with respect to preset operating envelopes.

A three-dimensional high-resolution reservoir model of the Eocene Shahejie Formation in Bohai Bay Basin, integrating stratigraphic forward modeling and geostatistics

Reservoir characterization based on geostatistics method requires well constraints (e.g. seismic data with high quality) to predict inter-well reservoir quality that is conformed to geological laws. Nevertheless, the resolution of seismic data in multiple basins or reservoirs is not high enough to recognize the distribution of different types of sand bodies. In this paper, we propose a new method to improve the precision of reservoir characterization: reservoir modeling with the constrains of sedimentary process model and sedimentary microfacies. We employed stratigraphic forward modeling, a process-based method, to constrain the reservoir modeling in one oil-bearing interval of the third member of Eocene Shahejie Formation in J-Oilfield of Liaoxi Sag, Bohai Bay Basin.We divide reservoir modeling into two orders using different types of constrains. In the first order, we use the simulated shale model from stratigraphic forward model that is corrected by wells data as a 3D trend volume to constrain the reservoir sand-shale modeling. In the second order, different types of sedimentary microfacies in the sandy part of the model are further recognized and simulated within the constrains of sedimentary microfacies maps. Consequently, the porosity, permeability and oil saturation are modeled under the control of precise sedimentary microfacies model. The high-resolution reservoir model shows that the porosity, permeability and oil saturation of distributary channel is generally above 20%, 10md and 50%, respectively, which are much higher than that of other types of sedimentary microfacies. It can be concluded that comparing to other types of sedimentary facies, distributary channel has better physical properties and more oil accumulation in the fan-delta front and therefore is the most favorable zones for petroleum development in the research area.

Risk management in petroleum development projects: Technical and economic indicators to define a robust production strategy

In this study, we consider robustness as a risk management method in the development of complex petroleum fields, complementing the well-known techniques of acquiring new information and adding flexibility to the production system. To create a robust production strategy we aim to reduce sensitivity to uncertainty. Our methodology is based on the analyzed performance of an optimized production strategy, covering all possible scenarios. We use technical and economic indicators to objectively identify and quantify refinements in this strategy to assure good performance across possible scenarios. We focus on the robust number and placement of wells, and robust platform processing capacities. We consider the robustness of net present value and of the recovery factor, computed using Multi-Attribute Utility Theory. We quantify the risk through semi-deviation, instead of standard deviation, to focus on the downside volatility. Refining an optimized production strategy significantly improved the optimization process by increasing the expected value of each objective and, dramatically reduced the downside risk.

Climatic and tectonic controls of lacustrine hyperpycnite origination in the Late Triassic Ordos Basin, central China: Implications for unconventional petroleum development

The Triassic Yanchang Formation contains the main oil-bearing strata in the Ordos Basin, central China. But the sedimentology of the Upper Triassic is still under debate, and flood-generated, hyperpycnal-flow deposits and their implications for unconventional petroleum development have long been overlooked. Our study indicates that hyperpycnites are well developed in the seventh oil member of the Yanchang Formation. They are characterized by couplets of upward-coarsening intervals and upward-fining intervals, separated by microscale erosion surfaces. The origination of hyperpycnal flows was controlled mainly by episodic tectonic movements and the humid climate. The deposits extend from distributary estuaries into the deep lake, have intercalations of dark shales and tuffs, and coexist with debrites and turbidites as a result of the progradation of subaqueous fans. The hyperpycnites have implications for unconventional petroleum reservoirs, because the flows supplied not only large amounts of coarse grains and organic material to the deep-water, fine-grained central lake sediments but also affected the ecosystems, resulting in a higher total organic carbon content in the sediments.

A Field Trial in a Carbonate Reservoir Using a Solvent-Based Waterflood Process

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 179838, “Persistence in EOR—Design of a Field Trial in a Carbonate Reservoir Using a Solvent-Based Waterflood Process,” by Abdullah Alkindi, SPE, Nasser al-Azri, Dhiya Said, and Khalid AlShuaili, Petroleum Development Oman, and Paul te Riele, SPE, Shell Development Oman, prepared for the 2016 SPE Enhanced Oil Recovery Conference at Oil and Gas West Asia, Muscat, Oman, 21–23 March. The paper has not been peer reviewed. Dimethyl-ether (DME) -enhanced which waterflood (DEW) is a process in DME is added to injection water and, upon injection, preferentially partitions into the remaining oil. As a result, it swells the oil and reduces the oil viscosity, significantly improving oil mobility. Several coreflood experiments conducted in tight-carbonate plugs have shown incremental recoveries of up to 20% post-waterflood. A field trial has been designed to derisk this technology, which, if successful, would add significant reserves. Introduction Enhancing oil recovery from low- permeability formations has been challenging. DEW presents the advantages of a miscible flood without the negative effects of density differences. DME is a slightly polar hydrocarbon that is miscible with most known crude oils. As a result, upon contact with crude oil, the DME will swell the oil and reduce its viscosity, after which the oil will be effectively displaced. DME is soluble in water and, therefore, can be injected with any existing waterflood. Because the molecule is small, there are no limitations on formation type or permeability. Its water solubility enables efficient recovery of the DME with a clean-brine chase. Because it does not interact with the formation, recovery efficiencies of DME are found to be close to 100% in laboratory core experiments. Depending on the injected-slug size and the crude-oil composition, oil recovery could be enhanced by 10 to 25% in field application. In a DEW, DME is dissolved in the injection brine and injected into the formation. The DME solubility is dependent on salinity and temperature but can be up to 38 wt% for fresh water. Upon contact with the oil in the reservoir, the DME will partition to the oleic phase, where it will swell the oil, reduce its viscosity, and mobilize the oil to the producer wells. The process is schematically presented in Fig. 1. In light-oil reservoirs, additional oil is primarily produced by oil swelling. After injection of the DME-containing brine slug, a chase phase will be used to dis-place the mobilized oil further and recover the DME from the remaining oleic phase. During this chase, DME will partition back into the initially DME-free water phase. Recovery efficiencies are found to be very high. There is no residual DME because of its solubility in the mobile phase. DME does not adsorb to the rock/fluid interface, and DME recovery occurs microscopically in a shock.

Determinants of Job Stress and Its Relationship on Employee Job Performance

Stress happens in workplaces and it arises at different levels. Job stress is becoming an alarming situation in the workplace. This study is aimed at determining job stress variables that affect employee performance. It also determine the relationship between job stress and employee performance. To achieve this objective, the study was conducted to Petroleum Development Oman (PDO) in Al-Bahja Center to 65 respondents. The study employed the descriptive research design using the survey questionnaires as its instruments and utilized the purposive sampling to obtain the sample. Originally. Questionnaires were distributed to 80 respondents but only 65 questionnaires were retrieved and analyzed. Highlights of the findings indicated that, there is significant relationship between job stress and employee performance with r=0.955. When analyzed the independent variables individually using regression analysis, results revealed that both independent variables: underutilization of skills and work overload significantly correlates to employee performance with p-values 0.000 (p=0.000 0.05) and employee performance. Based on these findings, it can be recommended that the company should consider underutilization of skills and work overload as predictors of employee performance. The company should put consideration on developing the skills of the employees and tapping their potentials. The Human Resource Department may conduct as appropriate skills inventory to identify talents and potentials of employees with proper motivation as well as revisit their policies on promotion. However, it also recommended that further studies can be conducted to consider larger sample, scope and more variables as appropriate to arrive at more reflective results.

Case History of Dehydration-Technology Improvement for HCPF Production in the Daqing Oil Field

Summary High-concentration polymer flooding (HCPF) is an enhanced-oil-recovery (EOR) method that has been used since conventional polymer flooding was applied in the main reservoirs of the Daqing oil field because its higher viscoelasticity can improve the oil-displacement efficiency. However, as a result of more produced hydrolyzed polyacrylamide (HPAM), the oil/water mixture is emulsified easily and separated with more difficulty. In this work, a case history of dehydration technology for HCPF production in the Daqing oil field is reviewed, and a laboratory investigation to assess the emulsification behaviors of HCPF-produced emulsions is conducted. Besides the dehydration-mechanism description of a high-voltage pulsed electrical field, electrostatic-demulsification performance for produced liquid from HCPF production is improved, and the operation parameters are optimized. Recent actual acceptance of the optimization recommendations is presented, and the field-application results are also discussed. The results indicate that dehydration technology for the Daqing oil field has been innovated with the industrialization of the EOR process. Traditional methods of gravity or centrifugal settling are replaced; this upgraded freewater knockout (FWKO) has the functions of adsorption, wetting, collision and coalescence, and oil pretreating for HCPF production. Because it is dominated by periodic vibration as its main mechanism, the pulsed-direct-current (DC) electrostatic-demulsification technique has some advantages in overcoming the obstacles encountered by regular types of electrical-field dehydration processes at strong emulsification stability. Compared with previous dehydration processes having complex alternating-current (AC)/DC electrical fields, the process with a pulsed-DC electrical field shows a unique advantage in terms of emulsified water-separation efficiency, energy conservation, environmental protection, lower labor intensity, and more-stable operation, and the dehydration performance meets the oil-treating standards. As the surface-matching technology of EOR, this improvement in dehydration technology is significant for promoting the construction of an HCPF demonstration project and accelerating petroleum development and production efficiently.

Women, Inclusiveness and Participatory Governance in Nigeria’s Niger Delta: A Focus on Shell’s Model of Community Development in the Region

This paper analyzed the influence of adaptive collaborative governance on women’s inclusion and participation in governance in the Niger Delta of Nigeria with focus on Shell Petroleum Development C...

Exploration Decision-Making on Energy Based On Improved Real Option Model and BP Neural Networks

Based on real options method to construct a petroleum exploration and development projects of integrated economic evaluation model, application mechanism real option method in oil and gas exploration and development projects around the expansion, the option value to identify and analyze the process of exploration and development projects exist. Finally, select the appropriate option pricing model, instance data analyzed by gas exploration and development projects, and its contrast with the traditional analysis, pointed out that application of real options method can effectively improve the investment project economic evaluation of science. In this paper, to build an economic evaluation method based on real options method of energy development projects, and to explore applications based on the principle of real options to develop economic evaluation method, proposed mostly for exploration stage oil and gas exploration and development project abandonment option binomial model and the development phase stop start option of partial differential equations, is determined based on the actual parameters of such projects, and to provide solutions to parameter estimation.

Evaluation criteria, major types, characteristics and resource prospects of tight oil in China

AbstractTight oil refers to a petroleum play that occurs in a free or adsorbed state in source rocks or tight reservoir rocks (e.g., sandstone and carbonate rock) interbedded with or close to source rocks. Tight oil has generally not experienced large-scale, long-distance migration. According to such a definition and its characteristics, 10 key indices are proposed for tight oil resource evaluation in China. Tight oil reservoirs are divided into three groups in terms of porosity and permeability. Tight oil can be classified into three types according to the contact relationship between the tight oil reservoirs and source rocks, i.e., tight lacustrine carbonate oil, tight deep-lake gravity flow sandstones oil, and tight deep-lake deltaic sandstones oil. In China, tight oil resources are widely distributed and significant exploration discoveries have been achieved in the sixth member and seventh member of the Triassic Yanchang Formation in the Ordos Basin, the Permian Lucaogou Formation in the Junggar Basin, the Middle-Lower Jurassic strata of the Sichuan Basin, and the Cretaceous Qingshankou and Quantou Formations in the Songliao Basin. The total geological resources of tight oil in China assessed by using the “analog” method are estimated to be (10.67−11.15) ×109 tones. Taking into account of the future prospects of petroleum development, tight oil may become a realistic alternative to the conventional oil resources in China.

‘Frame Conflicts’ in Natural Resource Use: Exploring Framings Around Arctic Offshore Petroleum Using Q‐Methodology

AbstractEnvironmental and natural resource issues are often framed in multiple ways by different stakeholders. Given their complexity, how these issues are framed can diverge significantly, leading to ‘frame conflicts’. Frame conflicts have implications for decision makers when addressing socio‐ecological problems; this is especially the case for Arctic offshore petroleum. Q‐methodology is used to explore framings found across a group of stakeholders on the issue of Arctic offshore petroleum development, to empirically demonstrate the extent of frame conflicts and to explore possible bridges for consensus between these framings. The issue was framed in various ways: a global sustainability concern, a development panacea for Arctic communities, an issue where economic reality clashes with environmental idealism and an issue centred on local sustainability concerns. Despite significant divergence across framings, some potential bridges of consensus were evident, centring on ideas of traditional livelihoods, the importance of emphasizing ‘human’ aspects of the debate and the inherent risks involved in Arctic offshore petroleum. The implications and challenges of frame conflicts around Arctic offshore petroleum are discussed. Copyright © 2016 John Wiley & Sons, Ltd and ERP Environment

Analysis on innovation of geological exploration technology in petroleum development process

In recent years, with the booming of petroleum industry and the continual reserve urgency of fossil oil, petroleum exploration technology in China is required to be a higher level. At present, with the improvement and development of computing technology and other technology, China's fossil oil exploration technology have been greatly improved, the oil field work has a stage improvement, petroleum exploration technology has also improved, Shaanxi Changqing Oilfield has also made remarkable progress, and it is worth mentioning that the three main techniques, the exploration technology of well logging technology, drilling technology and exploration technology, have made great progress on innovation through using new technologies. But it does not mean that the petroleum exploration technology has met the requirements of petroleum development. Petroleum exploration technology is insufficient and needs to be unremittingly combined with other techniques for its improvement and innovation. Based on this, this paper studies and analyzes the innovation of geological exploration technology in petroleum development process

Petroleum Industry in Nigeria: Environmental Issues, National Environmental Legislation and Implementation of International Environmental Law

Advances in the development of petroleum resources has contributed enormously to the global energy demand and economic development over the past decades, however, it has left profound negative impacts on the natural environment and adverse human health effects in most oil-producing host communities around the world. Apart from the loss of petroleum-derived revenue to corruption and ineffective government's petroleum development policies, the Niger Delta region has experienced a wide range of environmental pollution, degradation, human health risks and socio-economic problems associated with petroleum exploration, development and production. Over the years, several environmental laws have been institutionalized to regulate the petroleum sector in Nigeria. The Nigerian government and other African countries have played tremendous roles in the emergence of international environmental law that regulate the establishment of environmental institutions and legislations as well as strategies for conservation and management of natural resources. However, the existing Nigeria statutory laws and regulations for environmental protection appear to be grossly inadequate and some of the multinational oil companies operating in the Niger Delta region have failed to adopt sustainable practices to prevent environmental pollution. Poor implementation of national and international environmental policies associated with petroleum exploitation and production in the Niger Delta region have resulted in huge environmental costs, degradation and issues of responsibilities from the oil companies. Therefore, this research paper examines some of the contributions of multinational oil companies operation towards environmental degradation and the role of Nigerian Government in the implementation of the petroleum-related environmental policies in the Niger Delta region.

Poverty, oil and corruption: the need for a Quad‐Sector Development Partnership (QSDP) in Nigeria's Niger Delta

This article starts by charting the conflicting position in Nigeria's Niger Delta between its petroleum wealth and the poverty of its inhabitants before observing how government corruption has hampered development agencies from rectifying this situation. It then examines trans‐national company (TNC) Corporate Social Responsibility (CSR) initiatives via a case study of the Shell Petroleum Development Company (SPDC). It concludes that, while there are useful projects, their success is felt at a micro level that cannot supplant wider government development. Finally, the article sets out why Quad‐Sector Development Partnerships (QSDP) between an international development agency, the state, TNCs and civil society will help to neutralise the national problem of corruption so that Niger‐Delta socioeconomic development can be improved.

No-Damage Stimulation By Use of Residual-Free Diverting Fluids

This article, written by Special Publications Editor Adam Wilson, contains highlights of paper SPE 177495, “No-Damage Stimulation Based on Residual-Free Diverting Fluid for Carbonate Reservoir,” by Y. Shi, X. Yang, F. Zhou, Y. Gao, S. Lian, X. Li, and X. Han, Research Institute of Petroleum Exploration and Development, CNPC, prepared for the 2015 Abu Dhabi International Petroleum Exhibition and Conference, Abu Dhabi, 9–12 November. The paper has not been peer reviewed. Horizontal wells and acid stimulation are essential technologies for the development of complex carbonate reservoirs. However, conducting effective stimulation in horizontal wells with long intervals is extremely difficult because traditional acid systems can flow only into the high-permeability formations, leaving the damaged formation untreated. This paper studied three residual-free fluid systems for acid treatments and fracturing in order to develop no-damage or reduced-damage and highly effective stimulation techniques for long-interval wells. Introduction Horizontal wells are essential for the development of carbonate reservoirs in China. However, horizontal wells always have long intervals, so they are extremely difficult to stimulate. The fluid systems used are a critical aspect of high-efficiency stimulation. Traditional acid systems, which do not have diverting capabilities, can flow only into the high-permeability formations, leaving the damaged formation untreated. That is why long-interval wells with high heterogeneity need to be treated by a diverting acid system. A new diverting acid system should have the following characteristics: The capability to reduce the acid/rock reaction rate; a diverting performance to achieve uniform stimulation in a carbonate reservoir with high heterogeneity; and use of clean chemical additives to eliminate or limit damage. This paper analyzes three clean fluid systems for acid treatment and fracturing. The no-damage stimulation systems considered are a temperature-controlled deep-diverting acid system (TCA), a pH-controlled self-diverting acid system (DCA), and a fracture-reorientation technology using degradable fiber (RDF). TCA Diverting Mechanism of TCA. The TCA system is similar to ordinary gelled acid during pumping. The gelling agent can dissolve in water in a short time, reducing the frictional resistance of the system dramatically and making it easy to prepare and pump. At formation temperature, the system has a high viscosity to ensure diverting and retarding performance. After the acid fracturing treatment, the viscosity of the spent acid decreases in order to flow back easily and leave no damage in the formation.

Transient Model-Based Leak Detection and Localization Technique for Crude Oil Pipelines: A Case of N.P.D.C, Olomoro

This work presents the fundamentals and application of transient model-based leak detection and localization technique for crude oil pipelines. The dynamic parameters involved in this model such as pressure, flow and temperature were acquired by SCADA (Supervisory Control and Data Acquisition) system. The characteristic changes in the flow- mechanics and thermodynamics along a given length of pipeline were used in detecting, localizing and determining the flow rate of the leak. Measurement of pressure, temperature and flow data at both the inlet and outlet of the pipeline were used in formulating the equations obtained from the inconsistency in the continuity and law of conservation of momentum equations. This model located a leak incident in a horizontal pipeline of length 2000m and diameter 0.3556m carrying Nigeria bonny light crude oil from the Nigeria Petroleum Development Company Limited, Olomoro flow- station into UPS (Ughelli Pump Station) truck line. But the leak located by the model at 1088.12m from the inlet is 11.88m behind the actual leak position of 1100m as discovered during the pipeline leak remedial works.

Passive seismic techniques are developing in many directions

Abstract Yasin C. El-Taha, Petroleum Development Oman, reports on the 6th EAGE Passive Seismic Workshop held on 1-3 February in Muscat with the theme ‘From Data to Decisions’. Attended by approximately 50 participants, the workshop was well received both in discussions during the event and in excellent feedback submitted since. Strongly supported by various operators and service companies, the industry showed renewed commitment to the technology and its development worldwide. After an opening address from keynote speaker Salim Rawahi, geosolutions manager, Petroleum Development Oman (PDO), the workshop continued with a regional focus. From a European perspective, projects were shown with a link to strong drivers or requirements from regula­tory bodies. This situation is currently under heavy scrutiny amongst industry and media alike with high profile projects such as the Groningen gas field. An overview was given of hydraulic fracture monitoring (HFM) in China showcas­ing a rapid rise in uptake of this technology. Monitoring of fracking completions in China has progressed to an advanced stage and is now being regularly used for field development decisions, well placement optimisation and fracking design improvement.