Day 1 :
Statoil Chair in Reservoir Engineering at Memorial University of Newfoundland, St. John’s, Canada
Time : 10:00-10:40
Professor M. Enamul Hossain has the expertise in reservoir engineering and simulation, sustainable drilling engineering, and enhanced oil recovery where he contributed over 150 articles, seven books, and seven patents. Currently, he is holding the Statoil Chair in Reservoir Engineering at Memorial University of Newfoundland, St. John’s, Canada. In over 22 years, Prof. Hossain has developed new methodologies, techniques, and materials in areas of his expertise. Prof. Hossain is the associate editor of Journal of Nature Science and Sustainable Technology (JNSST), Journal of Characterization and Development of Novel Materials (JCDNM), Nova Science Publishers, USA and Journal of Sustainable Energy Engineering (JSEE), Scrivener and Welly publishing, USA. He has been an active member of a number of international societies, including the SPE. Prof. Hossain is the founder and Chairman of Aziza Trust (www.azizatrust.com) and was on the Board of directors of Aziza group in Bangladesh, Bright Coral in Canada.
Reservoir simulation is a critical element in the development, planning and production management of oil and gas fields. The ultimate goal of reservoir simulation is to aid the decision making process throughout all stages of field life. The major sources of uncertainties are the linearization of all governing equations – a standard practice in reservoir modeling. It is currently considered that obtaining exact solutions is not achievable due to the lack of non-linear solvers. In literature, it has been shown that this assertion is not justified for most of the realistic range of petroleum parameters, even for single-phase flow. The impact of linearization is even more important for multiphase flow. Recent literature shows that few models include non-Darcy flow under multiphase flow conditions, even fewer use non-Darcy equations for dual-porosity, dual-permeability description, and none uses transition between various flow regimes within porous media and fracture networks. Further, there is a limited number of studies on non-Newtonian nature of petroleum fluids. So, there is an immense need to focus on developing new sets of mathematical models of complex reservoir rock and fluid systems that will lead to the development of more accurate, and state of the art performance prediction tools. However, challenges remains on how to solve these highly non-linear models, and validate the numerical findings through experiments. Experimentally, capturing memory is a real challenge because it cannot be visualized and tracked easily with conventional experimental practices.
Numerical solutions of non-linear equations, including considerations of time function both in fluid and rock systems, will produce multiple solutions, forming a cluster of points. Challenge remains how to tag these points with confidence. In parallel, specifically designed experimental trials will be a choice to validate these mathematical models. These models, combined with non-linear solvers that are capable of tracking multiple solutions, will possibly make the most comprehensive reservoir simulator to-date. The resulting simulator can be applied to highly heterogeneous and heavy oil reservoirs.
German Aerospace Center (DLR), Germany, Stuttgart
Dr.-Ing. Ralph-Uwe Dietrich leads the research area Alternative Fuels at the Institute of Engineering Thermodynamics at the German Aerospace Center (DLR) in Stuttgart. He is responsible for the research group on techno economic and ecologic evaluation of alternative fuels for aviation and global transport. He received his PhD in Engineering at the Technical University Clausthal in 2013 as a Scientific coworker at the Clausthaler Umwelttechnik Institute (CUTEC-Institut GmbH). Before that, he got 15 years of project manager experience at different enterprises (SME and Fortune 500) of the process and automation industry.
Advanced technologies, optimized operation and infrastructure are not sufficient to achieve the CO2 mitigation goals agreed on for the aviation sector. Carbon neutral alternative liquid fuels are required to fill the gap towards a carbon-neutral growth from 2020 on. The Power-to-Liquid process is one option to produce synthetic jet fuels from renewable energy. The technical and economic performance of production processes based on renewable electricity and CO2 was investigated and evaluated.
Hydrogen can be generated by water electrolysis from fluctuating renewable power sources. Together with CO2 – e.g. sequestrated from industrial resources – the reverse water-gas-shift reaction forms syngas. The Fischer-Tropsch synthesis produces long chained hydrocarbons from syngas. Downstream product separation and upgrading generates gasoline, jet fuel and diesel. Another process concept is based on high temperature co-electrolysis of steam and CO2 producing synthesis gas at high temperature and pressure.
The process performance is evaluated via flowsheet simulation models and pinch point analyses comparing the Power-to-Fuel efficiency as well as carbon conversion into liquid fuels. A baseline Power-to-Fuel efficiency of 44 % for the concept based on water electrolysis can be increased to 60 % using the co-electrolysis concept. The baseline carbon conversion of 73 % grows to 98 %. The sensitivity of various operation conditions was analyzed.
A cost analysis based on market data and equipment factors was performed for the investment year 2014. Employing stationary power input of 105 €/MWh, production costs of 3.38 €/kg were found for the water electrolysis concept. The production costs of the co-electrolysis concept compare to 2.83 €/kg. The sensitivity of the electrolyzer capital cost and electricity prices were analyzed and their effect on the production costs will be presented.
Investment and operating costs to fill the gap towards carbon-neutral air transport growth from 2020 on can be predicted based on 2014 costs and technology status. A comparison to other renewable jet fuels regarding land use, feedstock potential and economic measures will be provided.
- Petroleum Geology
Research Institute Research Institute of Petroleum Exploration and Development, CNPC, China
Research Institute Research Institute of Petroleum Exploration and Development, CNPC, China
Time : 11:40-12:15
Dr. Yunsheng Wei began his professional career at RIPED in 2006, having abundant experience in unconventional gas development about 10 years. He has made great contributions to improving reservoir engineering, especially in tight gas and shale gas. He has published more than 30 papers in reputed journals and has been serving as an editorial board member of several gas engineering journals.
Shale gas in China has realized the great-leap-forward development because of the significant strides of development technique for marine shale resource, becoming the second largest shale gas producer only to USA. At present, a complete technique series for the development of shale resource buried less than 3500m (<3500m) has been established by operating technique research and field trail, including five main key techniques of geological evaluation, optimum & fast drilling, multistage hydraulic fracturing, productivity evaluation, and development parameters optimization:
(1) The integrated technique of geophysics data interpretation and geological evaluation to identify high-quality shale interval provides a guidance for the target optimization of drilling horizontal well and the mass arrangement of multi-well.
(2) Optimum & fast drilling technique is realized by incorporating rotary steerable drilling and factory operating pattern, contributing to shorten single-well drilling cycle by 50%.
(3) Volume fracturing technique integrating low-viscosity slick water, low-density proppant, zipper-style fracturing and factory operating pattern, is conducted to enhance fracturing efficiency by 50% and improve testing production rate to 20×104m3/d.
(4) Productivity evaluation technique incorporating multi-scale fracture network and stochastic simulation is performed to analyze production performance with probabilistic forecasts.
(5) A systematic optimization of fracturing parameters and well spacing is established by type curve matching, production performance modeling, and analogy with exploited shale field in North America.
At present, shale resource in China has not been fully exploited besides the marine shale resource (<3500m). It would be the future development trend to enhanced ultimate recovery of shale gas (<3500m). Moreover, 2/3 recoverable resource is stored in the formation (>3500m). With the further process of development technique for marine shale, shale gas is expected to the single type of gas reservoir contributing to the highest annual production rate in the near future
Time : 12:15-12:50
Kjeld Bokstijn is a process engineer that has been active in the industry over the last 22 years, working in production and engineering functions in The Netherlands, the United States and Spain. He holds a BSc. and MSc. in Chemical Engineering and is currently employed by Fluor as a process director working on projects mainly in the chemical, petro-chemical, refining and power generation area. However due to the interfaces between the gas plant and the petrochemical units consuming the NGL feedstock from these, he has become involved in this NGL recovery and gas-production feasibility study. Fluor´s Energy and Chemicals division, an international engineering contractor, is involved in all these areas from upstream, midstream, downstream, petrochemical, chemical and energy business and as such can bring together multi-functional teams to work on these diverse projects offering these kind of interesting assignments to their personnel.
Fluor was approached by a client requesting a feasibility study for a rich gas field development and debottlenecking the offshore and downstream NGL facilities. Fluor is primarily involved with gas/oil production, transportation, and gas processing/NGLs facility design and does not perform reservoir assessments in-house. In this case, Fluor and the client worked out an integrated solution with a subcontracted reservoir engineering effort to assess current in place gas/liquid volume that could be produced from the fields to support the desired gas feed rate for the offshore and onshore NGL facilities our client wanted to debottleneck.
The reservoirs have been evaluated to assess the original hydrocarbons in place for each reservoir, material balance results have been compared to the current reservoir pressures to validate the reported gas production and gas re-injection values over time, and to obtain the current in place volumes. Based upon the current gas in place and the reservoir pressure profiles, a well development program was prepared to support the production plan. As part of the reservoir assessment it was found that the current in place gas/liquid volume in the reservoir does not support the clients originally proposed production plan. Hence as a result of these feasibility study findings the client postponed the offshore development and NGL recovery facilities revamp scopes.
Overall Fluor has been able to successfully and effectively coordinate the different interfaces between the client´s intended production plan and availability of data of the existing reservoirs to the reservoir engineering consultant and from the output of the reservoir engineering study back into the data needs for the required production to identify the potential offshore development and downstream NGL processing facilities’ revamp.
chief geologist in the Field division of petroleum engineering department for the North Oil Company, Ministry of oil, Kirkuk, IRAQ
Time : 12:50-13:25
Faraj A. Al Suleiman, is chief geologist in the Field division of petroleum engineering department for the North Oil Company, Ministry of oil, Kirkuk, IRAQ, He received his BSc degree from Mosul University in general geology in 1982, and received MSc and PhD degree in structural geology from Baghdad university, in 1989 and 1998 respectively, since 2000 he joined North oil company as supervisor for logging operation and interpretation. In addition to work in North Oil Company, he lectured in kirkuk and Tikrit universities.
Storage of liquids and gases in solution mined salt caverns was reportedly first in Canada in the early 1940 s during world war. Storage in the salt caverns of liquid petroleum gas (LPG) and other light hydrocarbons spread rapidly in the early 1950s in North America and several European countries. Storage of crude oil reportedly occurred first in England, also in 1950s during the Suez crisis. Natural Gas Storage followed the storage of liquid hydrocarbons by about decade in the U.S.A. and Canada,(Dreyer,1920).Kirkuk underground storage project locate on the southern west limb of Kirkuk anticline near Kirkuk city, North Iraq,(fig-1).In 1978 eight wells were drilled for the purpose of LPG storage ,five wells of them(2,5,6,7,8) were selected for leaching operations as the thickness of salt layer in these wells was suitable to create cavern of salt and economical size.
Geologic evaluation of the Kirkuk underground was conducted by comparison of the geometric properties of the cavities derived from two surveys running during 1989 and 2015.the vertical cross sections of the cavities show that most cavities have show that most cavities have irregular shape because of the presence of impurities in the salt bed that cause different leaching velocities in different directions .the relationship of the cavity roof with tilted salt bed was Image
TPL (RE/PE) Senior Specialist at Subsurface Team of R&T Group at Kuwait Oil Company (KOC)
Time : 14:25-15:00
Currently a TPL (RE/PE) Senior Specialist at Subsurface Team of R&T Group at Kuwait Oil Company (KOC). Prior to this, he occupied a number of both industrial and academic positions in UK. He holds a First Class Honors BEng in Petroleum Engineering and a Ph.D in Steam-foam drive process in EOR from University of Strathclyde, Glasgow, UK. He has had over 30 years of academic, industrial and research experiences mainly associated with the upstream sector of the oil and gas industry. He is currently the EOR Cluster Leader within the Subsurface Team. The job involves advanced technology screening and implementation for relevant Reservoir subsurface challenges and adopting the most efficient and economic ones to address them. Major Area of interest: EOR, Reservoir monitoring and simulation, Uncertainty analysis, new technologies and innovation, unconventional reservoirs, and production optimization.
The current work is concerned with the development of a web-portal knowledge-based Enhanced Oil Recovery (EOR) expert system for screening and designing EOR process. Conducted and ongoing projects including all the spectrum of laboratories, pilot, and full-fields scale implementation need to be shared among oil and gas community for the ultimate goal of sharing of best practices, technology transfer and lessons learnt in such highly demanded area. On the other hand, on local scale oil and gas operators would benefit from such expert system in setting an informed workflow and screening/design tool aims at selecting the most appropriate. The industry is currently lacking of such system and there is no single source of knowledge on EOR technologies and their application. The industry has clearly expressed a need for an expert system to aid operators in selecting optimum EOR applications and procedures. The project creates an “enabler” for oil and gas operators and financial institutions, thus helping to popularize EOR screening as a routine aspect of field development planning even in early stages of a field’s life cycle. The EOR KB will address these technology gaps.
The ultimate aim of this industrial is to develop a computer module (expert system) in the form of web portal knowledge bases EOR system to be used as a screening /design tool for adopting the most suitable EOR. The methodology used here includes published data on completed projects and world-wide experience and expertise. Existing analytical models and correlations on the three methods (Gas-Chemical-Thermal) are used to develop the module. The web portal contents include reservoir properties, reservoir performance, operations & lessons, and costs & economics.
The system allows different scenarios to be run including cost and Net Present Value (NPV) comparison, availability of gas, CO2, Chemicals, and other commodities. It enables companies to screen and prioritize EOR technique potential as applicable to the specific field opportunities.
The developed EOR KB addresses the need for an Expert System to aid EOR decision making and will provide a comprehensive single resource for best practices, lessons learned and case histories across the EOR spectrum. In fact, the development tool adds a new customised tool to the engineers and earth scientist in general working kit including handling new technologies such as LowSal and MEOR.
China University of Petroleum, China
Title: The application of architectural elements analysis in characterizing complex reservoir: A case study of Yong’an town oil field, Dongying Sag, Bohai Bay Basin, China
Time : 15:00-15:25
Sun ke, PhD. candidate, engaged in petroleum geology research, Department of Geology, College of geological science and technology, China University of Petroleum
As the exploration and development of oil and gas fields gets deeper and deeper in our country, characterization of complex reservoir has become one of the most important research fields. The characteristics of complex reservoir are that rock composition is complex, space structure is complex, kind of reservoir space is various, heterogeneity is strong, physical properties is changeful et al. In view of the above characteristics, there are three problems in traditional reservoir characterization methods which is about gradation, structure and genesis. That architectural elements analysis put forward offers method and idea for solving the above problems. Compared with traditional reservoir characterization methods, the advantages of architectural elements analysis mainly display in three points: first, it can be applied to divide high frequency level of reservoir; second, it can be applied to analyze complex structure of reservoir; third, it can be applied to explain the genesis of reservoirs. The Application of architectural elements analysis in characterizing complex reservoir need to pay attention to the applicable condition of the method, the choice of the basic research unit and the relationship between architectural elements and pay zone units. This paper takes Es26 of mouth bar which belongs to the Yong3-1 fault block of Yong’an town oil field in Dongying Sag as example, combining with the advantages of architectural elements analysis and problems that should be noticed, thoroughly studies the issues on the division of bounding surface, reservoir sedimentary genesis and the distribution characteristics of oil and water, and comes to the conclusions: the original 61 layer could be divided into six times accretions of mouth bar(architectural element of 3 level)，the dip angle of mouth bar accretions is between 2~3°; six times accretion of mouth bar had the characteristics of retrogradation from west to east； the oil and water distribution of 61 layer was mainly controlled by accretion of mouth bar.