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Collaborating Authors
South America
Impact of Jurassic Volcanic Rocks on Hydrocarbon Exploration, North Western Desert, Egypt
Abbas, Islam (Khalda Petroleum Company) | Guinn, Stewart (Khalda Petroleum Company) | Afify, Waleed (Khalda Petroleum Company) | Ramadan, Yasser (Khalda Petroleum Company) | Jennette, Dave (Khalda Petroleum Company) | Gharieb, Ali (Khalda Petroleum Company)
ABSTRACT While exploring for Jurassic hydrocarbons in Shushan Basin, North Western Desert, Egypt, Partial or complete reservoir substitutions, alteration by volcanic, volcaniclastic deposits have led to a number of unsuccessful wells. It is therefore essential to understand the distribution and geometry of volcanics in the vicinity of the Jurassic reservoirs. Many wells have been drilled and the presence of volcanic rocks were not recognized for more than a decade. The Qasr NE -2X well was the first alert that volcanic rocks occur in the Jurassic section. This paper shows detailed integration between spectral GR, triple combo, spectroscopy and image logs were necessary to define and differentiate between volcanic rocks of similar composition or alteration from similar host rocks. The lithostratigraphic cross sections and thickness variations of Jurassic volcanics are discussed in order to distinguish the shape and the extent of the volcanics, but the key is to be able to recognize the volcanics away from well control. The results showed that the emplacement of Jurassic volcanic rocks were from extrusive volcanic events. Thin section and log response of olivine basalt and tuffaceous caps strongly suggest sub-aerial effusive eruption. The identification of volcanic rocks using 3D seismic data is critical from a prospecting point of view. If we are unable to see the volcanic seismic signature we cannot predict their presence. If the volcanic rocks as described above vary from tuffs, altered basalts to un-altered basalts then the resultant reflection coefficients will also vary and in some cases will be similar to the sedimentary country rocks. Other factors with regard to seismic imaging of variable volcanic rocks are thickness, spatial distribution, and seismic data quality. We are studying the response of volcanic rock types using VSP data and well based synthetics and some results are described in this paper. A number of seismic attributes were evaluated including AVO modeling.
- Geology > Geological Subdiscipline > Volcanology (1.00)
- Geology > Rock Type > Igneous Rock > Basalt (0.92)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- Africa > Middle East > Egypt > Western Desert > Shushan Basin (0.99)
- Africa > Middle East > Egypt > Western Desert > Khalda Concession > Qasr Field > Upper Safa Formation (0.99)
- (5 more...)
Abstract Water drive is the most important recovery mechanism for oil production. In time, water breakthrough occurs in high permeable layers, leaving oil behind in unswept layers. For 1999, the worldwide daily water production associated with oil production has been reported as 33 million m or roughly 3 barrels of water for each barrel of oil. Therefore water production imposes an ever increasing burden on our industry. Brightwater is one of polymers that were developed to control water production and enhance sweep efficiecy. This microgels polymer is characterized by swelling if they are exposed to a high temperature. The main advantage of this product is that it can be deployed by adding directly to the injection line. No rig or coiled tubing is needed. This paper present and analyze the first trial of using Brightwater as a shut off technique in Egypt. The main objective is to improve the sweeping efficiency of the water flooding in Belayim oil field by shutting off the water production. The study analyzed the flooding pattern in Petrobel Company and selected the suitable pattern. The selected pattern includes an ideal pattern of two wells. The layer between these two wells is highly heterogeneous, its permeability is 150 md and the thief zone permeability is 600 md. As a result, early breakthrough has been met after 180 days of injection start and the water cut increased to 86 ﹪. Based on reservoir condition, the suitable Brightwater grade have been selected. The performance of the Brightwater has been discussed. The treatment results were successful in the short run but in the long run, it is not much economic since the water cut starts to increase again. Heterogeneity and permeability direction are very important in applying Brightwater as the production rate of the offset well has been increased as a response of treatment indicating that the plan was not prepared enough for that treatment.
- Geology > Mineral (0.46)
- Geology > Geological Subdiscipline (0.46)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.41)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- North America > United States > Pennsylvania > Appalachian Basin > Bradford Field (0.99)
- Asia > Indonesia > Sumatra > Riau > Central Sumatra Basin > Rokan Block > Rokan Block > Minas Field (0.99)
- (11 more...)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Conformance improvement (1.00)
- Production and Well Operations > Well Operations and Optimization > Produced water management and control (1.00)
The first Italian LNG regasification plant was built and started operation near La Spezia in the 70s and in the last two decades the interest on the asset has significantly increased, with several big energy players presenting initiatives for LNG regasification plants along the Italian coast. Today's increasing need of diversification of energy sources and utilization of "clean fossil fuels" shifted the focus on small-scale plants for LNG. However, for a long time, the development of national regulation for such assets did not properly cover all of the plant's relevant aspects, making permitting path quite uncertain; only recently a few updates seems to have solved part of those issues. Notwithstanding what above, the permitting process is still something to be faced very carefully, because both the competent authorities and local communities can originate new showstoppers. RINA has quite a history in providing Environmental & Permitting services for LNG plants and is now working with increasing involvement in the small-scale business, supporting clients throughout the entire authorization process and during the whole life of the project. Lessons taught from previous projects lead us to focus the attention on the following aspects: site location, preferring brownfield underused areas to be converted for "cleaner" productive uses; identification of territorial constraints (land planning, natural protected areas, cultural goods, etc.); adequate baseline data collection, to assess the status of the environment prior the commencement of the work, and to identify potential sensitiveness; in depth impact assessment, crossing the project actions vs the environmental sensitiveness; identification of mitigation measures; definition of monitoring plan for construction and operation phases.
- Europe (1.00)
- North America > United States (0.93)
- Energy > Oil & Gas > Midstream (1.00)
- Government > Regional Government > North America Government > United States Government (0.68)
- Transportation > Freight & Logistics Services > Shipping > Tanker (0.47)
- South America > Atlantic Basin (0.99)
- North America > Atlantic Basin (0.99)
- Europe > Atlantic Basin (0.99)
- Africa > Atlantic Basin (0.99)
ABSTRACT The demand of creating an effective development strategy of marginal fields is essential particularly with this fluctuation of oil prices in the latest period by which it caused an increase in the process challenges and associated risk. For that reason the collaboration between all engineering teams has to be established in order to optimize the production of such missed potentials and difficult assets without ignoring commercial and financial aspects aiming to achieve highest possible revenue. Petrobel has a portion of its reservoir that can be considered as a marginal block and it was decided to start thinking about the suitable way to develop such a complicated part of field. The main obstacle is well drilling issues since it is a long distance (2.5-4.0 km) that separates between location of this block and the shore line, and in order to drill from the existing artificial island there is also a limitation related to free space availability Moreover this block has a weak productivity that resulted from the low quality of formation facies in addition to the poor characteristics of reservoir fluids. Therefore an integrated team had been formed in order to provide a comprehensive study and asses the risk factors related to any suggested solution. After passing the screening stage the chosen solution has offered the lowest expenditures and it is environmentally effective with minimal risk factor. It became a compromised strategy especially for the existing uncertainty. This paper presents an overview about the nature of the field, plan that yielded to reach the target, and how was the mitigation of problems. The work sequence of this project will be addressed too. Finally it ends with a discussion about obtained results of this project through showing the achieved success. INTRODUCTION With most of the world's "giant fields" already discovered and depleting, and the opportunity to find such prolific assets with high quality of recoverable reserves diminish continuously. Although production profile continues to climb up in the latest period, thanks to the progressive development of "medium and small fields". By which the concept of "giant fields" and field size is no longer holds thus it makes importance of such minor or marginal reservoirs. SHOULD THINK ABOUT MARGINAL FIELDS OR LOW QUALITY?… WHAT DOES THIS MEAN? The reduction in oil price in the latest period increased the calculated risk factor that in turn adversely affect on the economical aspects of the development process and the whole industry as in general.
- North America > United States (1.00)
- Africa > Middle East > Egypt > Gulf of Suez (0.83)
- Asia > Middle East (0.66)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Kareem Formation > Shagar Member (0.99)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Belayim Land Field (0.99)
- (3 more...)
ABSTRACT Belayim Land Field, located in the Gulf of Suez Egypt, is a giant brown oil field, characterized by medium viscous oil, currently developed by means of peripheral seawater injection. Several chemical EOR processes were investigated to increase oil production and maximize ultimate recovery. Among them, polymer flooding application was selected to improve the mobility ratio, leading to an increased oil recovery. An intensive work has been done starting from laboratory studies for proper polymer selection and characterization, tertiary core-floods with polymer solution, to a sector model. Later on a pilot test was designed to evaluate the EOR potential at the reservoir-scale before a polymer flooding full field project is implemented to address uncertainties and risks. Pilot project for polymer flooding has been established in Belayim Land Field, polymer injection has been started effectively in Feb-16 with an injection rate of 1,000 BPD and a polymer concentration of 1,500 ppm, therefore, a detailed surveillance and monitoring program has been prepared and implemented. This program was guided by way forward road maps that target injection, flooding performance, and production assessment. The purpose of this paper is to highlight the work done from the design phase till pilot project implementation and start up, to present the lessons learned and best practices for operation's continual improvement of such processes and to highlight also that quality-control is an essential element for the successful implementation of a polymer-water-flooding project. The monitoring program should include, but not limited, the routine verification of polymer concentration, routine determination of the viscosity, and periodical check of the thermal and chemical stability of the polymer. INTRODUCTION Typically, about 70% of most proven oil reserves in the world remain untapped after primary drive mechanisms. Even after applying extensive waterflooding (secondary recovery) project, there remains a significant amount of the oil resource unrecovered as a result of reservoir heterogeneity and complex geology.
- North America > United States > Texas (1.00)
- Africa > Middle East > Egypt > Gulf of Suez (0.90)
- Africa > Middle East > Egypt > Suez Governorate > Suez (0.24)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- Europe > United Kingdom > Atlantic Margin > West of Shetland > Faroe-Shetland Basin > Rona Ridge > Block 206/9 > Clair Field (0.99)
- Europe > United Kingdom > Atlantic Margin > West of Shetland > Faroe-Shetland Basin > Rona Ridge > Block 206/8 > Clair Field (0.99)
- (25 more...)
ABSTRACT The implementation and use of ad-hoc approaches and solutions, combined with advanced simulation tools, allowed facing critical aspects during the development of the reservoir model of an extra heavy oil giant field. The main reservoirs consist of fluvio-deltaic stacked sandstones bearing an oil characterized by low API gravity (7-12°API) and high viscosity (2000-10000 cP). The definition of the so-called ‘Flushed zone’, a low salinity water zone above the regional aquifer, is one of the main challenges of the modelling activities, involving static and dynamic features. The ‘Flushed zone’ is not straightforward detected by means of conventional log data set, so the combined interpretation with special logs (NMR and ADT) allowed reducing the uncertainties in its definition. The closeness of these fresh waters to the oil column negatively affects both the oil/water mobility ratio and the water-cut at the wells, so a proper modelling of the Flushed Zone is essential to reproduce a reliable well behaviour. The fine geological grid was upscaled in a coarse simulation grid; transmissibility upscaling was evaluated as the most appropriate solution in order to preserve the fine scale results. The presence of a no-flat contact and non-equilibrium hydraulic system resulted in a non-conventional initialization of the dynamic model, in which the reservoir initial conditions were directly included by means of the enumeration procedure. Due to the areal extension of the field, the coarse grid still had more than four millions of cells, so the use of a new generation simulator was also tested to assess time reduction and performance reliability. The validated dynamic model was finally used as a reference for the evaluation of possible development scenarios. A large number of development wells, grouped in clusters, were required for the field exploitation. The implementation of an automated ad-hoc workflow, that combines geological information (such as permeability and porosity) and hydrocarbon column maps, revealed to be a useful support/tool for identifying the best levels for each development cluster, reducing modelling time.
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.34)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying (0.93)
- South America > Venezuela > Eastern Venezuela Basin > Oficina Formation (0.99)
- South America > Venezuela > Orinoco Oil Belt > Eastern Venezuela Basin > Orinoco Field (0.97)
ABSTRACT Natural fractures in reservoir rocks contribute significantly to productivity. Treatments for severe-to-total lost circulation in these type of scenarios can be especially challenging since they may require a greater particle size distribution to mitigate losses; on the other hand, these particles might contribute to an undesirable production impairment, if not properly removed during the clean-up operations. The primary treatment to remove the residual formation damage is typically an acid wash, but proper placement becomes challenging when dealing with long drains. One possible alternative is the use of an acid precursor (which is itself not acidic), that provides time-controlled downhole organic-acid release for carbonate removal. One of the advantages of using this kind of filter cake breaker in the Perla field is that no special tanks or rig accommodations were required to receive acid at the rig site. This fact, together with the simplicity of the system preparation, represents a cost effective solution for those offshore wells where logistics plays an important role for material transportation, especially acids. In the present paper, the clean-up operations on three wells of Perla field (Perla 7, Perla 6, and Perla 9) will be detailed, with the use of a highly effective, field-proven delayed filter cake breaker which dissolves all acid-soluble materials present in the mud cake throughout the reservoir section. INTRODUCTION Perla gas field (Fig. 1) is a giant offshore gas field in the Gulf of Venezuela. With a volume in the subsoil of over 17 trillion cubic feet of gas, Perla field is part of Cardon IV gas block, and is considered the largest gas discovery in Latin America, marking a milestone in the nation's history of gas. Perla is part of the Rafael Urdaneta gas project, which spans about 30,000 sq km (11,580 sq mi). It consists of 29 blocks: 18 in the Gulf of Venezuela and 11 in northeast Falcon state, the world class project aims to meet the domestic market's demand for natural gas. The reservoir consists of Mio-Oligocene age carbonates with excellent characteristics, located at approximately 3,000 meters below sea level. It is about 50 kilometers (31 mi) offshore at the Cardon IV block in water depths about 60 meters (200 ft). It covers area about 33 square kilometers (13 sq mi).
- South America > Venezuela > Caribbean Sea > Gulf of Venezuela > Gulf of Venezuela Basin > Cardon IV Block > Perla Field (0.99)
- South America > Venezuela > Falcon Basin (0.93)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
ABSTRACT Gas hydrate accumulations in continental shelf sediments are considered a promising resource for future gas supply by several non-COST countries (e.g. USA, Japan, China, India, South Korea, and Taiwan). In 2013, the Research Consortium for Methane Hydrate Resources in Japan (MH21) produced gas during a successful offshore field test. In Europe, as elsewhere, demand for natural gas is continuously increasing. This COST Action is designed to integrate the expertise of a large number of European research groups and industrial players to promote the development of multidisciplinary knowledge on the potential of gas hydrates as an economically feasible and environmentally sound energy resource. In particular, MIGRATE aims to determine the European potential inventory of exploitable gas hydrates, to assess current technologies for their production, and to evaluate the associated risks. National efforts will be coordinated through Working Groups focusing on 1) resource assessment, 2) exploration, production, and monitoring technologies, 3) environmental challenges, 4) integration, public perception, and dissemination. Study areas will span the European continental margins, including the Black Sea, the Nordic Seas, the Mediterranean Sea and the Atlantic Ocean. INTRODUCTION Gas hydrates accumulating in continental margin sediments are considered as promising energy resource. Numerous countries around the world (e.g. Japan, South Korea, USA, China, Taiwan, India, New Zealand) are investing in hydrate R & D to explore their coasts and national waters, constrain the resource potential, and develop technologies for gas production from gas hydrates. Several production tests conducted both onshore and offshore have proven that gas can be produced from these unconventional natural gas reservoirs. Natural gas from indigenous gas hydrate deposits should play an important role in the future European energy system. It could i) enhance the security of energy supply, ii) contribute to the reduction of CO2 emissions by replacing coal, and iii) complement renewable energies and stabilize the power grid by proving electricity during low-wind and/or low-light periods. Ultimately, gas hydrates could replace Europe's conventional gas reserves that will be depleted within the next decades and mitigate the growing dependence of Europe on natural gas imports.
- Asia > Japan (0.65)
- Asia > South Korea (0.55)
- North America > United States (0.45)
- (3 more...)
- South America > Atlantic Basin (0.89)
- North America > Atlantic Basin (0.89)
- Europe > Middle East > Malta > Mediterranean Sea (0.89)
- (2 more...)
Methodology To Quantify Gas Hydrate Presence by Using Real Data and Theoretical Approaches: Example of Application to Real Cases
Tinivella, U. (Istituto Nazionale di Oceanografia e di Geofisica Sperimentale - OGS) | Giustiniani, M. (Istituto Nazionale di Oceanografia e di Geofisica Sperimentale - OGS)
ABSTRACT Since 1990, the researchers of OGS have developed geophysical methods to detect and quantify natural hydrate in marine sediments. The study areas are located in several oceans, including Polar Regions. Indirect methods have been applied to study gas hydrates, such as seismic method. OGS has developed a complete procedure to invert, analyze and interpret seismic data, in order to extract elastic parameters of hydrate bearing sediments, which are indispensable to estimate hydrate concentration and distribution. Compressional and shear wave velocities are used to estimate gas hydrate and free gas concentrations in pore space. In fact, knowing the theoretical behaviour of velocities versus hydrate/free gas amounts, it is possible to convert velocity anomalies in terms of gas phase presence and, eventually, detect overpressure condition. To reach this goal, we have developed two codes: ISTRICI and DRAGO. ISTRICI is applied to determine seismic velocity by using iteratively the pre-stack depth migration, while DRAGO determines the gas hydrate and free gas concentrations and eventually the pore pressure regime by using seismic velocities and theoretical models. Because the excess pore pressures related to gas hydrate dissociation in marine sediments below the BSR is an important topic, we modelled the BSR depth versus pore pressure. In fact, if the free gas below the BSR is in overpressure condition, the base of the gas hydrate stability is deeper with respect to the hydrostatic case. This effect causes a discrepancy between seismic and theoretical BSR depths. Our modelling suggested that the areas characterized by shallow waters (i.e. areas in which human infrastructures, such as pipelines, are present) are significantly affected by the presence of overpressure condition. Moreover, the information about seismic velocities is indispensable to detect the overpressure in case that the pore pressure is equal to the hydrostatic pressure plus the 50% of the difference between the lithostatic and the hydrostatic pressure. So, an accurate analysis of the BSR nature and the pore pressure are required to improve the reliability of the gas-phase estimation for different target, such as gas hydrate and free gas exploitations and environmental studies.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment (0.56)
- South America > Chile (0.93)
- North America > United States > Louisiana > China Field (0.93)
- Europe > Russia > Northwestern Federal District > Komi Republic > Timan-Pechora Basin > Pechora-Kolva Basin > Usa Field (0.93)
- Antarctica (0.93)
Abstract To support exploration in the opportunity-rich offshore Mediterranean, the best seismic imaging solutions have to be employed to unveil the complex regional geology. This features a Messinian salt sequence with heterogeneities, lateral thickness variations and sharp velocity contrasts which make the imaging of subtle hydrocarbon traps beneath the salt particularly challenging. These challenges can be overcome with a combination of truly broadband acquisition and advanced processing and imaging techniques which delivers excellent resolution in the shallow section and gives the best chance for imaging below the Messinian. The workflow contains efficient demultiple tackling water bottom and intrabed multiples and very detailed and accurate imaging velocity models.
- South America > Brazil (0.49)
- North America (0.47)
- Europe (0.33)
- Geology > Structural Geology > Tectonics (0.47)
- Geology > Rock Type > Sedimentary Rock (0.31)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (1.00)
- Geophysics > Seismic Surveying > Surface Seismic Acquisition (0.95)
- South America > Brazil > Maranhão > South Atlantic Ocean > Maranhao Basin (0.99)
- South America > Brazil > Campos Basin (0.99)
- Asia > Middle East > Israel > Southern District > Eastern Mediterranean Basin (0.99)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic modeling (0.93)