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Collaborating Authors
Norway
A Riveting Review of Worldwide Industrial Geological Carbon Capture and Storage Projects with the Junction of CO2 Emissions in Algeria.
Deghmoum, Abdelhakim (Sonatrach/AMT/The Division of Laboratories, Boumerdes, 35000, Algeria) | Baddari, Kamel (University of M'hamed Bougara Boumerdes (UMBB)/FS/Physics Depart/LIMOSE Laboratory, Algeria)
Abstract The geological sequestration of CO2 is a relatively new technology that seems to have rapidly maturated in providing an effective process of capturing CO2 from industrial pollutant emissions and storing it securely in deep geological formations. Through this technology, the anthropogenic CO2 emissions can be reduced by 20% globally by 2050. Furthermore, it is expected that by the end of this century, more than 55% of CO2 emission can be captured and stored geologically. The compression, the transport and the injection of CO2 have been well used and controlled in the petroleum industry for many decades. However, CO2 capture process remains the weak point that should be overcome in order to make CCS economically feasible at industrial level. Moreover, no risk of leakage can occur at very long term in order to make CCS technology possible and generalized. The objective of this review is to analyze and to compare briefly the quantification of CO2 emissions in Algeria and to illustrate, with different case studies, the worldwide geological CCS pilot projects, particularly, those applied at industrial scale. The review is an attempt to assess critically what has been done and to predict what is ahead in this domain. Based on this review, the authors conclude that the global warming is the consequence of human egocentrism. CO2 should be considered as a valuable gas and not a waste, and CCS as a solution to global warming. Although there is negligible CO2 emission in Algeria, In Salah CCS project, built by BP-Statoil-Sonatrach consortium, is for demonstrating that pollution has no boundaries and every country is concerned by environmental issues. Thus, developing and developed countries should be urgently implicated in a serious and strong cooperation in the deployment of CCS technology before reaching irreversible global warming consequences.
- North America > United States > Texas (1.00)
- Africa > Middle East > Algeria (1.00)
- Overview (0.88)
- Research Report > New Finding (0.66)
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (1.00)
- Geology > Geological Subdiscipline > Geomechanics (0.67)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.67)
- Government > Regional Government > Africa Government > Middle East Government > Algeria Government (0.34)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (84 more...)
Abstract The benefits of Hydraulic Fracturing (HF) are well recognized in the oil industry, even if in many world regions it is still seen as a remedial operation rather than a reservoir development strategy. The big part of worldwide HF operations, are performed extensively in the US and Canada, primarily for reservoir development purposes of tight gas fields. However during the last few years, the global trend has seen a change and HF is now encouraged for adding new reserves, aiding the development of low permeability marginal reservoirs and prolonging life of brown fields. In Congo Onshore, HF is now a consolidated reality, with more than 70 frac jobs pumped. Good results have encouraged management to increase fracturing activity: nowadays HF is performed on all the infill wells that are drilled in the low permeability layers of the reservoir. From the early stages of development only the layers with the higher permeability were produced, while the possibility to develop the low permeability layers was not considered, because of very poor or zero production results due to the application of conventional completion strategy. Since HF is now performed as a standard practice on new wells, it has been reconsidered for the application on old wells completed in the low permeability layers. The challenge encountered on these old wells, has been the presence of long perforated interval. Rigless operations (such as sand plug) and work-over operations (such as cementing of old perforated interval and re-perforations) have been needed for fracturing in order to avoid fracture initiation issues like multiple fractures and early screenout. This paper will show the lessons learned and the main results achieved during this campaign and it is particularly focused on operational and logistic aspects, offering a full operational overview to all Companies and Operators that intend to apply this technology on their assets, maximizing oil recovery.
- Geology > Structural Geology (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- North America > United States > California > Sacramento Basin > 3 Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/8 > Valhall Field > Tor Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > Central Graben > Block 2/8 > Valhall Field > Hod Formation (0.99)
- (4 more...)
Strategies to Unlock the Unexploited Oil Production Potential in Ashrafi Field, Gulf of Suez, Egypt
Sabaa, Ahmed (Agiba Petroleum Company) | Crema, Giordano (Agiba Petroleum Company) | Salvini, Giovanni (Agiba Petroleum Company) | Konga, Felix I. (Agiba Petroleum Company) | Abdelnabi, Tamer (Agiba Petroleum Company) | Bekheit, A.. (Agiba Petroleum Company) | El Farahaty, M.. (Agiba Petroleum Company)
Abstract Mature fields have the potential to contribute significantly to future reserves provided that the recovery can be optimized. The main objective of this paper is to discuss the application of some techniques and technologies to optimize the production in Ashrafi Field offshore, Gulf of Suez (GOS), Egypt. Ashrafi Field, located in south-western part of the Gulf of Suez was discovered in 1987 and put in production in 1992 from its Main Area. In 1997, the South-West Area, discovered one year before, started contributing significantly to the overall field production. The field consists of sedimentary reservoir units partially overlying a tilted block of fractured Basement reservoir. The field reached its peak production of 25,800 BOPD in June 2000 from 12 naturally flowing wells and then the production declined drastically. The only artificial lift type that was suitable for the field was the gas lift system and it was implemented starting 2004 in 80% of the wells. The strategy to unlock the unexploited potential in the field was to search for the bypassed oil through cutting edge technologies, using special techniques for stimulation of fracture Basement reservoir, combating scale and paraffin depositions in an efficient and economical manner. The final result for the use of such techniques and technologies was the increase of the oil production to more than 225 % of its levels before the intervention campaign, the increase of the gas production needed for gas lift system feeding and the decrease of the amount of produced water.
- Africa > Middle East > Egypt > Gulf of Suez (1.00)
- Africa > Middle East > Egypt > Suez Governorate > Suez (0.40)
- Asia > China > Sichuan > Sichuan Basin > Southwest Field > Longwangmiao Formation (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Nubia Formation (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Kareem Formation > Shagar Member (0.99)
- (2 more...)
Abstract Ideally, geoscientists would like to have quantitative information about rock properties, along with information about fluid content of potential reservoirs relatively directly from the seismic as this information is available as oppose to the well data. Historically, seismic images have stopped short of delivering this, as the seismic bandwidth was limited due to the conventional streamer design and acquisition method. The ability to predict reservoir properties away from the well using seismic information is a key element in quantitative interpretation. Quantitative seismic interpretation combines various types of data: well, seismic and seismic interpretation or geological prior information. Thus, this workflow is integrated and the quality and accuracy of each individual constituent is of great importance to the accurately estimate the volume of hydrocarbon in place in a particular reservoir interval. Seismic plays a key role in this, and if the seismic data contains very strong low frequency information and the seismic image is of high quality/resolution, it is possible to directly estimate the absolute impedance at each point within a seismic volume. Over the last few years, new acquisition methods and technologies exist aiming to provide a broader seismic bandwidth: streamer towed shallow at the front and going deeper at the mid of the streamer, towed acquisition with some streamers at shallow and deeper depth, and the dual-sensor towed streamer. These new broadband seismic data volumes are bringing the seismic a step closer to the reservoir and this is what we will try to demonstrate in this presentation. We will have the latest look at some of the newest and most exciting improvements in reliably unraveling the rock properties from the 3D seismic data.
- Oceania > Australia > Western Australia (0.28)
- North America > United States > Texas > Dawson County (0.25)
- Europe > United Kingdom > North Sea > Northern North Sea (0.16)
- Europe > Norway > North Sea > Northern North Sea (0.16)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition > Marine Seismic Acquisition (0.91)
- Geophysics > Seismic Surveying > Seismic Interpretation > Seismic Reservoir Characterization > Reservoir Properties from Seismic (RPFS) (0.67)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling > Seismic Inversion (0.49)
- Oceania > Australia > Western Australia > Carnarvon Basin (0.99)
- Oceania > Australia > Victoria > Bass Strait > Gippsland Basin (0.89)
- Europe > United Kingdom > North Sea > Northern North Sea > Northern North Sea Basin (0.89)
- Europe > Norway > North Sea > Northern North Sea > Northern North Sea Basin (0.89)
Abstract This study deals with simulation model of Foam Assisted Water Alternating Gas (FAWAG) method that had been implemented to two Norwegian Reservoirs. Being studied on number of pilot projects, the method proved successful, but Field Scale simulation was never understood properly. New phenomenological foam model was tested with sensitivity analysis on foam properties to provide a guideline for the history matching process (GOR alteration) of FAWAG Pilot of Snorre Field (Statoil). The aim was to check the authenticity of presented new foam model in commercial software whether it is implementable on a complex geological model for quick feasibility studies, either for onward practical pilot or as justification for more detailed technical study. The simulation showed that Foam model is applicable. The mismatch between history and actual GOR in some periods of injection is due to the complexity of the fluid flows control inside reservoir. The way; how specific properties control the time of gas arrival and values of GOR are described. The analyses of the improvements in the injection schedule are shown. With increasing number of CO2 and FAWAG methods in preparation worldwide, the use of the simulation contributes to more precise planning of the schedule of water and gas injection, prediction of the injection results and evaluation of the method efficiency. The testing of the surfactant properties allows making grounded choice of surfactant to use. The analysis of the history match gives insight in the physics of in-situ processes. Detailed Qualitative analysis is presented for foam modeling against the FAWAG historical data that provides sharp idea of the behavior of Foam model for different foam factors, which in turn provides reasons for the unpredictable foam behavior in WFB Project and also serve as quick reference for future general foam pilot simulations at field scale.
- North America > United States (1.00)
- Europe > Norway > North Sea > Northern North Sea (0.34)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 104 > Block 30/9 > Oseberg Field > Tarbert Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 104 > Block 30/9 > Oseberg Field > Oseberg Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 079 > Block 30/9 > Oseberg Field > Tarbert Formation (0.99)
- (15 more...)
Abstract History matching is a key task for field reviews. Over the past decades, assisted history matching techniques have effectively automated parts of the process. Methods commonly applied include genetic algorithms, adjoint methods, ensemble Kalman filters, streamline-based inversion, and conventional Newton-type methods. All these methods, however, are numerically expensive, often to a prohibitive degree for large and complex reservoirs. A novel method aims to overcome this limitation. It combines the advantages of two well-established technologies: a numerically efficient Newton-type optimization scheme and full-physics proxy-type modeling using grid coarsening. It focuses on unknowns that can be readily re-parameterized, such as relative permeability and capillary pressure functions, fluid and rock properties, or fluid contacts. In addition, the statistical analysis of the parameter identification allows the establishment of confidence intervals, parameter correlations, and sensitivities. Newton-type optimization methods can numerically be less expensive and potentially show superior convergence behavior under certain conditions. Although they are prone to converge to local minima and are less suitable for adjusting permeability or porosity distributions, they can be advantageous for smaller parameter spaces when using a re-parameterization approach. At the same time, grid coarsening allows drastically reduced runtimes while maintaining realistic geological and physical assumptions. Using the Newton-type calibration technique, the workflow suggested comprises initial screening, ranking of parameter sensitivities, and subsequent detailed parameter calibration to obtain the optimal parameter set. A large reservoir dataset in which simulation runtimes would not allow for traditional assisted history matching approaches shows the advantages of the novel method. Convergence is rapid and minimal time is required to optimize sets of relative permeabilities, including endpoints and curvature of each individual function. As illustrated, the re-parameterization also allows imposition of a physically sensible solution. Most importantly, the statistical analysis of the results identifies key sensitivities in the reservoir, ultimately contributing to a better understanding of data gaps and uncertainties.
- North America > United States > Texas (0.69)
- Europe (0.68)
- Africa (0.67)
- Geology > Rock Type (0.70)
- Geology > Geological Subdiscipline > Geomechanics (0.48)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL 128 > Block 6608/10 > Norne Field > Tofte Formation (0.99)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL 128 > Block 6608/10 > Norne Field > Not Formation (0.99)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL 128 > Block 6608/10 > Norne Field > Ile Formation (0.99)
- (5 more...)
Abstract Assisted history-matching is now widely used to constrain reservoir models. The objective of history match process is to improve the model in order to reproduce the production history while honoring the structural properties of the geological model. For that purpose, an objective function is defined in order to measure the mismatch between the simulation results and the production history. This objective function is usually minimized using a gradient-based optimization algorithm. However, history-matching of a large number of parameters in hydrocarbon reservoirs is a challenge because of several reasons: scarcity of available measurements relative to the number of unknowns, computational effort required for large reservoir and the need of insure that solutions are geologically realistic. All of these problems can be helped by using algorithms that rely on efficient and parsimonious descriptions (or parameterizations) of reservoir properties. In this work, a history matching methodology is presented. First, a sensitivity study is performed for identifying the most relevant inversion parameters affecting the history-matching. The gradual deformation method is applied for the parameterization. Then, a new optimization technique, based on data partition for the gradient calculations, is studied for regional and well level history matching. The objective function is first split into local components, and the principal parameters are reduced for each component. In this context, we can propose perturbation designs with a smaller number of perturbations for the gradient computation. The proposed new technique is successfully applied on a real case in Libya in an integrated workflow, which makes history-matching with a large number of parameters tractable.
- Europe (1.00)
- North America > United States > Texas (0.46)
- Africa > Middle East > Libya (0.34)
- Overview > Innovation (0.49)
- Research Report (0.46)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.46)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.34)
- Europe > Norway > North Sea > Central North Sea > South Viking Graben > PL 046 > Paleocene Formation (0.99)
- Africa > Middle East > Libya > Sirte District > Sirte Basin (0.99)
Abstract Accurate determination of the crude oil PVT properties is essential for solving many reservoir engineering, production engineering, and surface production and operational problems. A large number of PVT correlations for oil exist in the petroleum literature and numerous studies are also present for with data favoring one correlation over the other. In the absence of PVT data from laboratory experiments, it is often difficult to choose which correlation to use to calculate different PVT properties. We approached this problem in two ways. First, we developed an expert system that checks the input parameters (e.g. reservoir parameters) against the valid ranges of input data for different correlations, and then recommends which correlations to use for specific input parameters. Second, we tested all available PVT correlations for black oil on a database of selected 35 Egyptian crudes to develop guidelines on which correlations to use for each PVT property for the specific range of input data. These specific crudes were selected to allow testing of those guidelines on a wide range of reservoir input data for black oils. Our database included oils with oAPI ranging from 17 to 51, gas-oil-ratios of 8 to 7,800 scf/STB, formation volume factor at bubble point of 1.04 to 4.47 bbl/STB, bubble point pressures of 60 to 4,739 psia, and reservoir temperatures of 40 to 270 °F. The present work included 13 bubble points, 6 solution-gas-oil ratio, 14 formation volume factors, 13 oil compressibilities, 14 dead oil viscosities, 9 saturated oil viscosities, 10 under saturated oil viscosities, 12 under-saturated densities, 2 total formation volume factors and 2 saturated density correlations. Based on this study, guidelines for selecting an appropriate correlation for PVT oil properties are introduced. These guidelines are recommended in programming of PVT correlations regardless of their geographic origin.
- Asia (0.93)
- North America > United States > Texas > Harris County > Houston (0.28)
- Europe > United Kingdom > North Sea (0.89)
- Europe > Norway > North Sea (0.89)
- Europe > Netherlands > North Sea (0.89)
- (3 more...)