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Mardin
Abstract A comprehensive understanding of rockfall trajectories is the key to effectively control rockfall hazards. An important characteristic that distinguishes different rockfall models is the presentation of the rock block in the model. Lumped mass models represent rock as a dimensionless point while rigid body models can consider block geometry in rockfall simulations. The potential blocks of the Mardin Castle are selected to study the differences between the lumped mass and the rigid body simulations. The trajectories of the lumped mass model are exactly the same for any size of blocks while rigid body models generate different rockfall paths and bounce height and run out distance accordingly. Increase in block size and non-circularity, cause large divergence between lumped mass and rigid body models. More reliable and conservative protection measures can be designed according to the rigid body simulations.
block size, body model, bounce height, coefficient, geometry, kinetic energy, Mardin Castle, mass model, Modeling & Simulation, protection measure, Reservoir Characterization, reservoir geomechanics, restitution 0, rigid body model, rock block, rockfall, rockfall analysis, rockfall simulation, Simulation, trajectory, translational velocity, University, Upstream Oil & Gas
Country:
- North America (1.00)
- Asia > Middle East > Turkey > Mardin > Mardin (0.64)
SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (0.48)
Analysis of Potential Rockfalls and Protection Measures for the Mardin Castle, Turkey
Dadashzadeh, N. (Middle East Technical University) | Aras, C. (Middle East Technical University) | Yesiloglu-Gultekin, N. (Middle East Technical University) | Bilgin, A. (Middle East Technical University) | Duzgun, H. S. B. (Middle East Technical University)
Abstract Rockfalls are one of the major hazards in hilly regions which can impose significant damages to the structures as well as human lives and property. Understanding the behavior of a rockfall along its trajectory is essential in order to design and implement protection measures for providing safe environment. Coefficient of restitution is one of the most important parameters for predicting a rockfall behavior. Back analysis is an effective tool in estimating the coefficient of restitution for a specific area. This study presents the analysis of rockfalls around the Mardin castle by probabilistic methods after estimating the real coefficient of restitution. Run out distance, bounce height, kinetic energy and translation velocity are studied in the area and accordingly barriers in 4m height with capacities ranging from 3000 to 5000 KJ are suggested as protective measures. 1. Introduction Rockfalls are sudden rapid phenomenon with highenergy bearing features in hilly regions which cause significant threats to the environment aswell as human lives and property. A rock fall occurs when rock boulders detach from their original locations on a steep cliff, and travels down-slope (Varnes 1978, Hutchinson 1988). Generally, the detachment of rocks is due to the climatic or biological events causing a change in the forces acting on a rock. The main triggering factors can be pore pressure increases, weathering of the discontinuities, earthquakes, freeze–thaw process, weathering of the rock, root growth and hard winds (Hoek 2007). Once a failure occurs, blocks move downslope following four basic types of motions: free-falling, bouncing, rolling and sliding (Cruden & Varnes 1996). As the controlling parameters change, different types of scenarios may happen in rockfall events. Rockfall kinematics and dynamics depend on the slope topography, block geometry, mechanical properties of the slope forming material and the block such as friction angle, roughness, restitution characteristics and rolling resistances (Alejano et al. 2010). When a rockfall event reveals a threat to people or structures, it is essential to describe the trajectory of the falling rock along a slope in order to design and implement protection measures. The accuracy of the information on boulder velocity, bounce heights, kinetic energies as well as run out distance are the major features of a correct design as well as the verification of the protective measures (Volkwein et al. 2011).
bounce height, coefficient, discontinuity, kinetic energy, Mardin Castle, potential block, prediction, protection measure, Reservoir Characterization, reservoir geomechanics, restitution, rock block, rockfall, rockfall analysis, rockfall behavior, rockfall event, Simulation, tangential restitution, trajectory, University, Upstream Oil & Gas
SPE Disciplines:
Water Shutoff Gels Improved Oil Recovery in Naturally Fractured Raman Heavy Oilfield
Demir, Murat (Turkish Petroleum Corp.) | Topguder, Nazan Necibe Senol (Turkish Petroleum Corp.) | Yilmaz, M. (Turkish Petroleum Corp.) | Ince, Y. (Turkish Petroleum Corp.) | Karabakal, U. (Turkish Petroleum Corp.) | Gould, John H. (Gel Technologies Corp.)
Abstract Raman field is a naturally fractured limestone reservoir located in southeastern Turkey. The field is a heavy oilfield with 18o API gravity oil and has strong aquifer pressure support. There are about 140 producers and daily oil production is about 6,000 bbl/d. However, average water cut has exceeded 90% in recent years because of the fractures communicating between the aquifer and the oil zone, which required some remedial treatment such as polymer gels to reduce the WOR. As it is well known, gel treatments have become a more convenient method as they can penetrate deep into the reservoir without a complete shutoff. As a pilot application, deep penetrating gels were used in seven wells. Wells with different behavior were selected as candidates on purpose, in order to see the effect of gel treatments on reducing WOR. The main purpose of the treatments was to increase oil recovery, with water shutoff was considered as a secondary benefit. Treatments were performed in September 2007. Very favorable results have been seen in the eight months following the treatments. Although gross production rates were generally reduced to get the most benefit from the gel treatments, still, pre-treatment oil rates from 0–14 bbl/d were increased to 6–91 bbl/d along with average water cut decrease from 97% to 80%, and even up to 40% in one well. These successful results will also provide the necessary clues for improving the design and field application of gel treatments which are to be extended on a field wide basis in the near future. Introduction Raman oil field, which is the first discovered oil field in Turkey, is located in Southeast Turkey (Figure 1). Raman is the second biggest oil field in Turkey with 600 MMbbls of original oil in place (OOIP). A total of 232 wells were drilled through May 2008. Eight are horizontal, 13 are deviated and 20 are dry holes. 6,000 bbls per day of oil is produced from 140 oil producers. 75,000 bbl per day of produced water is injected to aquifer by 13 water disposal wells. The main productive zone in the Raman field is the Mardin formation. However, the Garzan formation is also productive areally depending on the evolution of fractures and porosity in the east and north of the field. Because of low porosity and permeability the first 3–10 meters of the Mardin formation is non-productive. Under this non-productive zone there is, on average, a 20–25 meter productive zone in the Mardin formation. The porosity changes from 14–20 % in the Mardin formation productive zone and 10–25 % in the Garzan formation productive zone. The production mechanism is a strong water drive. Original reservoir pressure is about 1300 psi at the -200 m datum depth. Pressure is now 1100–1150 psi areally. The original WOC is -300 m. Some reservoir and fluid properties are given in Table 1. Because the reservoir is heavily fractured, in some wells the water-cut (wc) value increases rapidly due to fractures between the aquifer and the production zone. These types of wells were abandoned in a short time or are still being produced with very high wc values. Cumulative production from these wells is much lower than the average.
application, BPM, carbonate reservoir, complex reservoir, concentration, conformance improvement, crosslinker, downhole intervention, enhanced recovery, estimates of resource in place, field application, fracture, gel, gel treatment, injection, intervención de pozos petroleros, operation, Petroleum Engineer, polymer gel, production control, production enhancement, production monitoring, PVT measurement, Raman Field, reserves evaluation, Reservoir Surveillance, resource in place estimate, shutoff gel improved oil recovery, spe 116878, tank, Upstream Oil & Gas, water cut, water shut-off, Well Intervention
Oilfield Places:
- South America > Venezuela > Lake Maracaibo > Maracaibo Basin > Ayacucho Blocks > Motatan Field (0.99)
- Asia > Middle East > Turkey > Raman Field (0.99)
SPE Disciplines:
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Carbonate reservoirs (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (0.93)
- (3 more...)
The Exploration in overthrust areas presents many example shown in figure 2 is typical: the target Mardin difficulties, particularly data quality and drilling costs.
agreement, carbonate, correspond, inversion, Mardin Group, mesozoic ophiolitic mélange, MT data, Overthrust Area, Petroleum Exploration, reflection, reflector, Reservoir Characterization, sediment, seg expanded abstract main menu, seismic data, structural geology, türkiye petrolleri ao, Upstream Oil & Gas
Geophysics:
- Geophysics > Electromagnetic Surveying (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (0.30)
SPE Disciplines:
Abstract Raman oil field, located in southeastern Turkey, has been recently analyzed and studied in detail for the final objective of determining the future recovery potential under various production alternatives. original oil-in-place in Raman is estimated to be 611.4 MMSTB of 15 to 19 API oil. Production formation in Raman is the fractured Mardin limestone which receives pressure support from an underlying strong pressure support from an underlying strong bottom aquifer. The reservoir-aquifer interaction takes place through an extensive network of mostly vertical fractures. In addition to being fractured, the producing Mardin formation is also heavily faulted. The primary recovery mechanism and the recovery efficiency in Raman strongly rely on the presence of vertical fractures that are also responsible for bringing the steady-state aquifer support. With the flow direction being mainly vertical, rapid coning caused by strong influx leaves most of the oil bypassed between the wells. This paper covers a review of reservoir geology, basic reservoir engineering to characterize the production mechanism, the fractured nature of the reservoir, the interaction with the aquifer; and finally, the history match and subsequent predictions with a suitable fractured reservoir simulator. Introduction Raman oil field, owned and operated by the Turkish Petroleum Corporation (TPAO), is the second largest oil field in south-eastern Turkey, with 611.4 MMSTB of 15 to 19 API original oil-in-place. The structure is a heavily folded, faulted and fractured anticline (Figure 1). Since Raman's discovery in 1940, over 200 wells have been drilled in the field. Currently 84 producing wells exist with an average daily oil rate of 65 STB/well. The field performance curves are presented in Figure 2. Table 1 gives the basic reservoir and fluid data. The main producing zone is the Mardin limestone. The Mardin limestone is overlain by Kiradag shale above which lies the Garzan limestone which also shows productive capacity in certain parts of the productive capacity in certain parts of the field. The heavily faulted and fractured nature of the field, relatively heavy oil gravity, and the presence of active bottom water drive have made the Raman reservoir management an engineering challenge for years. This study was aimed to develop a good understanding of reservoir geology and production mechanism and to predict and production mechanism and to predict and optimize the future performance of the field which had produced only 7% of its original oil-in-place in over forty years. Following a thorough geological and petrophysical analysis, a dual porosity/permeability mode was built for the numerical model study of the Raman field. The long production history of the wells since 1940's enabled the fine tuning of reservoir parameters by history matching. Following the history match, the optimum operating conditions were identified for different characteristic portions of Raman through sensitivity predictions and full field predictions under various primary recovery operating conditions were made. P. 255
aquifer, base case, Drillstem Testing, drillstem/well testing, estimates of resource in place, flow in porous media, Fluid Dynamics, fracture, history matching, imbibition, limestone, Mardin, mardin formation, Mmstb, numerical model, permeability, prediction, PVT measurement, Raman, Raman Field, recovery, reserves evaluation, Reservoir Characterization, Reservoir Engineering, reservoir simulation, resource in place estimate, sensitivity, spe 17955, Upstream Oil & Gas, variation
SPE Disciplines:
SPE Member Abstract Reservoir modelling of a fractured reservoir with any dual porosity/permeability simulator requires three basic fracture properties - fracture porosity, permeability, and average fracture spacing - to be provided as part of the reservoir description. Theoretically, any two of these are sufficient to determine the remaining third. In many instances, however, direct measurements on these properties or good pressure test data are missing or unreliable, making it virtually impossible to infer the fracture properties. In a recently completed study on the Raman reservoir in Turkey, the spatial variations of the fracture system properties were estimated using a method developed for this purpose. The technique utilizes reservoir structure and layer net thickness data, production information, and some qualitative geological input on the nature of the fractures. The generated fracture system description was later used in successfully history matching close to 40 years of reservoir performance with a fractured reservoir simulator. This paper presents the principles involved and the methodology that was developed to estimate the required fracture description. Fracture data before and after the history match are compared to show the extent of the modifications that were needed. The proposed technique is suitable for the Raman reservoir and others like it. Its application to another situation may require appropriate modifications. Introduction Fracture system is a collection of inter-connected individual fracture cracks and fissures. The physical properties of fracture cracks and how they relate to each other and to the properties of the total fracture system have been dealt with in detail in the literature. The basic fracture system data needed to describe both the physics of fluid flow through fractures and the various exchange mechanisms between the matrix and the fractures are fracture permeability, porosity, and average fracture spacing. Another important, but generally unavailable, data item is the fracture relative permeability which is first guessed as straight lines (not necessarily), then adjusted during the history match. Fractures usually do not have a water/oil capillary pressure due to the relatively large size of the fracture width as, for example, compared to the pore throat size in the matrix. For a recently completed study on the fractured Raman Reservoir in Turkey, the fracture data were virtually unknown and no direct means of establishing such data existed. Since the simulator that was used in modelling the reservoir required the basic fracture properties, they had to be estimated from the available and relevant data within the constraints of physical laws that govern the fracture properties. The properties were then adjusted, as necessary, during the history match that followed. This paper is intended to explain the methodology developed to estimate the fracture properties and to show that the estimated fracture system description did not need extensive modifications during the history match. RAMAN RESERVOIR GENERAL FEATURES, PRESENCE OF FRACTURES Raman Oil Field, one of the largest oil fields in southeastern Turkey, is a double plunging anticline. It is owned and operated by the Turkish Petroleum Corporation (TPAO). The main producing formation in Raman is the Mardin limestone. Situated above the Mardin interval is the Garzan/Kiradag horizon showing productive capacity in parts of the northern and eastern areas of the field. P. 483^
complex reservoir, crack permeability, effective permeability, flow in porous media, Fluid Dynamics, fracture characterization, fracture porosity, fracture properties, fracture spacing, fracture system, fracture width, hydraulic fracturing, Indicator, information, modification, net thickness, ooo 0, ooo 1, permeability, productivity index, Reservoir Characterization, Upstream Oil & Gas, variation
Country:
- Asia > Middle East > Turkey > Mardin > Mardin (0.45)
- North America > United States > Texas > Dallas County (0.28)
SPE Disciplines:
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Faults and fracture characterization (1.00)
Abstract A pilot project of enhanced oil recovery by CO2 injection has been carried out in Camurlu Field for the first time in Turkey. CO2 gas was injected without using a compressor into selected C-11 and C-22 wells for three consecutive cycles during two years. Five or six fold increases in daily oil production rates of the wells especially within the first few weeks of last cycles have been observed. Field-wide application was decided since it has been understood that better working conditions and better selection of equipment and materials could yield much better results. Introduction Heavy crude oil, 11-12API, produced from Camurlu field created major operational production problems in the past causing abandonment of many wells. Recovery ratio of less than one negatively affected the plans on wild cats and development wells in the field. This phenomena brought the discussion of which EOR project can be applied to increase the recovery. Immiscible CO2 huff n puff pilot project started in Dec. 1984 and continued till Dec. 1986 and applied on two wells. The pilot project was carried out mainly by Turkish Petroleum Corporation, an exploration, drilling and production company. IFP (Inst. Francais du Petrole) participated in the laboratory studies, the reservoir studies, the design of injection and production facilities, the follow-up and the interpretation of the tests. Due to lack of equipment and personnel the project became uneconomical from time to time. However, when the project applied truly, good results were obtained to look forward hopefully. I. GENERAL INFORMATION I.1 - Field Location and Regional Geology The Camurlu Field is located about 50 miles (80 km) south of the city of Mardin in Southeastern Turkey, and lies on the border with Syria. The field was discovered in 1975 and is operated by Turkish Petroleum Corp.(TPAO). Being a Northeast-Southwest anticline it is of interest by its dimensions 3.1 miles (5 km) by 0.62 miles (1 km). Average surface elevation is about 1515 ft (500 m). See Figs. 7 and 8. There are three separated productive formations:The uppermost one, which lies around 4264 - (1300 m) below surface is AltSinan, a light brown, cretaceous limestone. Gross thickness of the formation is about 492 ft (150 m) with top 197 ft (60 m) being heavy oilbearing zone below the gas cap. Approximately 4756 ft (1450 m) below surface, Beloka formation is also a limestone formation having local productive capabilities of heavy oil with a high water cut. The lowermost layer, around 7216 ft (2200 m) deep called Mus formation is a triassic limestone having quite good gas-condensate reserve which contains 73% CO2. The structure contour map of Alt Sinan formation is shown in Figure 2. I.2 - Estimated Reserves Oil in place has been estimated to be 377 × 10(6) STB (60 × 10(6) m) in the proven area for Alt Sinan formation only. Development wells which are newly drilled proved the oil bearing area is much more than the area taken into consideration. Oil in Beloka formation had not been considered in this amount. Original gas in place contained in primary gas cap of Alt Sinan formation found to be 49 × 10(9) SCF (1.38 × 10(9) m3) of CO2 gas.
application, average rate, camurlu field immiscible co2 huff, chemical flooding methods, co 2, ell, enhanced recovery, injection, Injection Rate, oil production, Puff Pilot Project, Pwh, recovery efficiency, ressure, SAGD, spe 1 5 749, STB, steam-assisted gravity drainage, tbh, thermal method, Upstream Oil & Gas
Country:
- Europe > Norway > Norwegian Sea (0.85)
- Asia > Middle East > Turkey > Mardin > Mardin (0.24)
SPE Disciplines:
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