Deir ez-Zor Governorate

Collaborating Authors

Deir ez-Zor Governorate

Experimental Analysis of the Effect of Entrapped Air on Liquid Impact

Wei, Z. J. (State Key Laboratory of Coastal and Offshore Engineering, Dalian University of Technology) | Shen, L. M. (State Key Laboratory of Coastal and Offshore Engineering, Dalian University of Technology) | Du, X. P. (State Key Laboratory of Coastal and Offshore Engineering, Dalian University of Technology) | Wang, Z. M. (State Key Laboratory of Coastal and Offshore Engineering, Dalian University of Technology) | Zhai, G. J. (State Key Laboratory of Coastal and Offshore Engineering, Dalian University of Technology)

OnePetroNovember, 2020

ABSTRACT In order to investigate the effect of the entrapped air on liquid impact, a series of experiments are designed and performed in an elastic rectangular tank under nearly 2D shallow-water condition. The evolution of free surface and the development of entrapped air near the vertical wall are recorded by the high-speed camera. Furthermore, the impact pressure and the wall deformation during slamming are measured. The results show that the presence of entrapped air can change the impact mode. Furthermore, the impact pressure and wall deformation induced by liquid slamming decreases due to the entrapped air, which shows the air cavity plays a cushion effect during liquid slamming. It is suggested to consider air compressibility during liquid slamming with entrapped air. INTRODUCTION The challenges to design Floating Liquefied Natural Gas facilities have attracted enough attention from industry and academia. The FLNG is used for production, liquidation, storage and unloading offshore gas. Therefore, the FLNG system needs lager volume tanks and has no restrictions of filling condition. Liquid tends to slosh in a partially tank during shipping. Sloshing-induced slamming in a tank at low filling depth resulting in the structural local damage during FLNG shipping is one of the main loads in the design of super-large storage tanks (Gavory and De Seze, 2009). Thus, it is important to determine the slamming load and investigate the physical evolution of a wave impact during the sloshing process in a partially field tank. But during liquid impact, the physical phenomena with gas-liquid, gas-solid and gas-liquid-solid are complicated for researchers to predict the evolution of free surface and slamming load with theoretical and numerical methods (Abramson et al., 1974; Lee and Choi, 1999; Faltinsen and Timokha, 2009). For example, Delorme et al. (2008) numerically found that the maximum pressure calculated by their numerical method is greater than the experimentally measured values due to the presence of air. Therefore, from physical mechanics point of view, it is necessary to use experimental methods to study the liquid impact with entrapped air in the tank.

OnePetro

ISOPE

ISOPE-P-20-110

The Fourteenth ISOPE Pacific/Asia Offshore Mechanics Symposium

Country:

Asia > Middle East > Syria > Deir ez-Zor Governorate (0.24)
Asia > China (0.16)

Genre:

Research Report > New Finding (0.84)
Research Report > Experimental Study (0.70)

Industry: Energy > Oil & Gas > Midstream (0.49)

SPE Disciplines:

Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems (0.68)

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Game Changing Technology for Treating and Recycling Frac Water

Ely, John W. (Ely and Associates) | Horn, Aaron (Hydrozonix) | Cathey, Robbie (Ecosphere Energy Services) | Fraim, Michael (Texas A & M University) | Jakhete, Sanjeev (Consultant to Ecosphere Technologies)

OnePetroOctober, 2011

Abstract This paper addresses an advanced oxidation and precipitation water treatment process employed as an on-the-fly fluid pretreatment during hydraulic fracturing operations. The water treatment technology will allow for substantial reuse of flowback and produced fluid while at the same time completely replacing liquid biocide and scale inhibitor fluid treatment during fracs. Additionally, the treatment process generates zero waste. To date, the technology has been used on hundreds of wells successfully treating over 17 million barrels. The paper will report on more than 2 years of field operations on hundreds of frac stimulations as well as numerous pilot operations in multiple shale plays. Dynamic tube-blocking tests show that the treated fluid will not deposit scale even after days of storage in an open frac tank. Field sample testing shows the injected brine has 3 to 6 log-cycle kill of sulfate-reducing and acid-producing bacteria populations. With the move toward environmentally safe chemicals, an economical process eliminating chemicals is a step forward for our industry. The equipment is purposely designed to segue directly into the fracturing process without interfering with service company pumping operations or having any compatibility problems with any service company products. Our paper will show definitive results from field operations of an economic water treatment system that will allow for a reduction in liquid chemical usage and closed-loop management of wastewater. The newest design would treat 80 barrels per minute, occupying a footprint roughly the size of a frac tank. The units can be deployed in tandem for higher flow rate requirements.

OnePetro

doi: 10.2118/145454-MS

SPE

SPE-145454-MS

SPE Annual Technical Conference and Exhibition

AOPP system, chemical treatment, Disinfection, frac tank, hydraulic fracturing, hydrodynamic cavitation, model assumption, operation, operator, pandit, produced fluid, produced water discharge, reactor, scale inhibitor, thermal treatment, ultrasound, Upstream Oil & Gas, water management

Country:

North America > United States > Arkansas (0.46)
North America > United States > Oklahoma (0.28)
North America > United States > Ohio (0.28)
(3 more...)

Industry:

Water & Waste Management > Water Management > Lifecycle > Treatment (1.00)
Water & Waste Management > Water Management > Lifecycle > Reuse (1.00)
Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
(11 more...)

SPE Disciplines:

Well Completion > Hydraulic Fracturing (1.00)
Health, Safety, Environment & Sustainability > Environment > Water use, produced water discharge and disposal (1.00)

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Improvement of Arrestability For Brittle Crack For Welded Joint:Development of Higher Toughness YP47 (460N/mm2) Class Steel Plate For Large Container Ships-3

Otani, Jun (Nippon Steel Corporation) | Works, Oita (Nippon Steel Corporation) | Funatsu, Yuuji (Research & Rule Development, Indian Register of Shipping) | Inoue, Takehiro (Plate Steel Research Labs, Nippon Steel Corporation) | Shirahata, Hirouki (Plate Steel Research Labs, Nippon Steel Corporation)

OnePetroJune, 2011

ABSTRACT: Recently, the amount of handling of the sea container increases rapidly by rapid economic growth in the east Asian nations including China. Therefore, needs of the enlargement of the container ship have risen in the shipping company's trying to decrease the cost of transportation, to suppress the fare, and the ship's trying to load with a lot of containers. Therefore, thickness of steels is becoming. So, the weight of the hull is increasingly and the welding operation is becoming difficult. To reduce these problems, Nippon Steel developed YP47 steel which is high tensile force more than conventional YP40 steel and applied it to actual ship. Double integrity is the main concept to develop YP47 steel. One is the quality which is hard to initiate brittle crack, and the other is prevention brittle crack spread even if brittle crack occurred (arrestability). This concept is the one generally applied in the tank field, and we applied to new development steel. This arrestability had been researched by the industry-university cooperation up to now, and the conclusion that the crack that occurred in the welding was highly the possibility of missing to the parent material by the influence such as the residual stresses and arrested. However, that the steel plate to be investigated is YP36 steel plate and plate thickness by thinness with about 35mm in high tensile steel. So, it is not investigated in high tensile steel and 40mm thickness and over like YP47 steel. This paper refers in detail about the arrestability which is one of "double integrity" put up as a development objective. INTRODUCTION While internationalization in a market is developed and increases in the marine transportation amount in recent years, steel development which corresponds to building of a high added value ship is being desired.

OnePetro

ISOPE

ISOPE-I-11-351

The Twenty-first International Offshore and Polar Engineering Conference

arrestability, brittle crack, brittleness, class Steel Plate, container ships-3, development steel, excellent arrestability, freight & logistics services, higher toughness yp47, marine transportation, metals & mining, model test, Nippon Steel Corporation, refining, steel, yp47 steel

Country:

Asia > China (0.35)
Asia > Middle East > Syria > Deir ez-Zor Governorate (0.25)
Asia > Japan > Kantō (0.15)

Industry:

Materials > Metals & Mining > Steel (1.00)
Transportation > Freight & Logistics Services > Shipping > Container Ship (0.63)

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Analysis of Field Responses to Low-Salinity Waterflooding in Secondary and Tertiary Mode in Syria

Mahani, H.. (Shell Global Solutions International) | Sorop, T. G. (Shell Global Solutions International) | Ligthelm, D.. (Shell Global Solutions International) | Brooks, A. D. (Shell Global Solutions International) | Vledder, P.. (Petroleum Development Oman) | Mozahem, F.. (Al-Furat Petroleum Company) | Ali, Y.. (Al-Furat Petroleum Company)

OnePetroMay, 2011

Abstract Low-salinity water injection is an emerging IOR/EOR technique, applicable to mixed-to-oil-wet sandstone reservoirs. This paper describes the field response for two large fields: Omar (secondary flood) and Sijan (tertiary flood). The data were analyzed using analytical and numerical modelling tools. This included evaluation of scaling numbers, mixing and dispersion and calibration. Insight was obtained on relevant drive mechanisms. The responses to low-salinity flooding differ for the two fields: In Omar, a dual-step water-cut development was observed, which is characteristic for a change in wetting state. Our interpretation is that in this field, viscous forces provide the dominant drive mechanism, which is favorable to low-salinity flooding. We were able to history match the low-salinity response using a simple conceptual model. In Sijan, the low-salinity flood appears to be still immature and breakthrough of low-salinity water has not (yet) been observed. The reasons for the muted response thus far are explored, including a rather strong buoyancy effect caused by the higher permeability of the block, and the significant effect of injectant mixing with the highly saline aquifer. A proposal is made for a workflow on how to apply this analysis to future low-salinity flooding implementation in field cases.

OnePetro

doi: 10.2118/142960-MS

SPE

SPE-142960-MS

SPE EUROPEC/EAGE Annual Conference and Exhibition

aquifer, capillary force, dispersion, enhanced recovery, formation water, numerical simulation, oil saturation, omar 103, Omar Field, producer, reservoir, salinity, sijan block 105, Simulation, tertiary mode, Upstream Oil & Gas, water injection, waterflooding, wettability change

Country:

North America > United States (1.00)
Asia > Middle East > Syria > Deir ez-Zor Governorate (0.36)

Genre:

Research Report > Experimental Study (0.66)
Research Report > New Finding (0.46)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

North America > United States > Alaska > North Slope Basin > Duck Island Field > Endicott Field > Kekiktuk Formation (0.99)
Asia > Middle East > Syria > Sijan Field (0.99)
Asia > Middle East > Syria > Deir ez-Zor Governorate > Omar Field (0.99)

SPE Disciplines: Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)

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Implementation Of A Microbial Control Program For An Offshore Production System In Nigeria

Keasle, Victor (Nalco Company) | Bennett, Brian (Nalco Company) | Moninuola, Babatunde (Mobil Producing Nigeria, Ltd.) | Franco, Robert J. (ExxonMobil Production Company) | Lefevre, Don (ExxonMobil Production Company)

OnePetroMarch, 2011

ABSTRACT: A 30-year-old offshore pipeline system in Nigeria was found to have severe internal corrosion, which was attributed to microbiologically influenced corrosion (MIC). A laboratory investigation was undertaken to develop a microbial and solids control program to overcome the most significant challenges including: the inability to pig the majority of the system, treating isolated sump tanks that likely harbor large quantities of bacteria, and minimizing internal corrosion of a critical pipeline delivering crude oil to the processing facility. The laboratory findings were presented at NACE International 2010 (TEG 286X). Based on the laboratory testing, a program was implemented in the field that included a surface-active and non-oxidizing biocide for microbial control, a solid biocide for extended treatment of sump tanks, and a cleaner to assist in removing solids from unpiggable parts of the production system. Success of the program was measured by several different metrics. Bacterial loads were compared year-on-year for the incumbent versus the new biocide using serial dilution and ATP quantification. In addition, bacterial enumeration was correlated to biocide residuals and used to optimize the biocide treatment dosage. Bacterial control in sump tanks using a solid biocide was evaluated via a 10 tank field trial to establish biocide efficacy and length of control. Most importantly, the success of the program was measured by comparing results of intelligent pig runs before and after implementation of the new treatment program. INTRODUCTION: The role of microbiologically influenced corrosion (MIC) in oilfield systems has been well recognized in the industry. However, control of microbes remains a significant challenge as every system is unique and numerous different organisms have been identified in oilfield systems including oil-producing wells and production water1-4. In many systems, problems associated with microbes increase as a field becomes more mature and water cuts increase. This is because an increased water cut can provide a larger nutrient supply for microbes, making their growth conditions more favorable. Despite the diminishing economic returns as a field ages, minimizing the risk of corrosion from microbes is a critical factor in preventing environmental upsets and maximizing profitability of the system. Controlling corrosion from microbial growth has become an important issue for the asset described in this paper. This asset is a complex pipeline network which transports full wellstream crude, emulsion, and water from offshore platforms to an onshore production separation facility. The field has been developed over the past 35 years, with no major corrosion issues during the first 25 years of operation. However, the incumbent chemical program was not effectively controlling microbial numbers or corrosion rates and required optimization. A detailed set of laboratory testing was performed in 2008 to understand the microbes present in the system (species identification by DNA sequencing) and the optimal biocide program to minimize the risk of MIC (dynamic laboratory flow loop testing). This laboratory work describing the identified microbes and the recommendation for a new biocide program was published at NACE 2010 in San Antonio, TX (paper # 10250)5.

OnePetro

NACE

NACE-11235

CORROSION 2011

Country:

Africa > Nigeria (0.70)
Asia > Middle East > Syria > Deir ez-Zor Governorate (0.25)
North America > United States > Texas > Bexar County > San Antonio (0.24)

Genre: Research Report (0.68)

Industry:

Water & Waste Management > Water Management > Constituents (1.00)
Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
Production and Well Operations (1.00)
Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)

Technology: Information Technology (0.46)

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Seismic Response of LNG Storage Tank Under Different Base Conditions And Liquid Height

Lee, Kangwon (R & D Center, Korea Gas Corporation) | Kim, Jun Hwi (R & D Center, Korea Gas Corporation) | Seo, Heung Seok (R & D Center, Korea Gas Corporation)

OnePetroJune, 2010

ABSTRACT In this study, several parametric studies were executed for finding out the effect of sloshing and structural responses due to earthquake. Using the method developed for analyzing LNG storage tank, seismic analysis was conducted for LNG tank with 150,000m3 storage capacity. The seismic responses such as sloshing height and overturning moment were analyzed for different base conditions of fixed base and isolated base. Also the results for different liquid height in the tank were calculated and compared. INTRODUCTION As the consumption of LNG is increasing, the need for the storage tank is also keep growing. Thus, more LNG storage tanks are required to meet the growing consumption of LNG. However, the design, construction and analysis of LNG storage facility need highly advanced technology compared to the general structures due to the fluid-structure interaction and the low temperature of LNG. Among them, one of the most important elements to be considered in the design of LNG storage tank is earthquake since LNG storage tanks are susceptible to damage when subjected to seismic excitations. When earthquake occurs, LNG storage tank receives a big impact pressure at the wall and bottom plate by dynamic conduct of the interior fluid. The overturning moment caused by hydrodynamic pressure tends to lift the tank off its foundation and develops highly-concentrated compressive stresses which may cause buckling of the shell. Also, in case of using base isolation under the tank bottom, sloshing of interior fluid becomes excessive and thereby impact load occurs at the wall and hitch of the roof. Sloshing height is also an important factor in design of LNG storage tank especially in suspended-deck type tank which can be damaged when high sloshing occurs.

OnePetro

ISOPE

ISOPE-I-10-469

The Twentieth International Offshore and Polar Engineering Conference

boundary element, different base condition, dynamic response, Earthquake, gas monetization, interaction, isolated time 2, isolator, liquefied natural gas, liquid storage tank, liquified natural gas, LNG, LNG storage tank, LNG tank, Midstream Oil & Gas, seismic response, storage tank, tank, value 0

Country: Asia > Middle East > Syria > Deir ez-Zor Governorate (0.25)

Geophysics: Geophysics > Seismic Surveying (1.00)

Industry: Energy > Oil & Gas > Midstream (1.00)

SPE Disciplines: Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)

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Low Salinity Water Flooding: Proof Of Wettability Alteration On A Field Wide Scale

Vledder, Paul (Al Furat Petroleum Company, Dummar Tower 1204, P.O. Box 7660, Damascus, Syria) | Fonseca, Julio Carrera (Al Furat Petroleum Company, Dummar Tower 1204, P.O. Box 7660, Damascus, Syria) | Wells, Terence (Al Furat Petroleum Company, Dummar Tower 1204, P.O. Box 7660, Damascus, Syria) | Gonzalez, Ivan (Al Furat Petroleum Company, Dummar Tower 1204, P.O. Box 7660, Damascus, Syria) | Ligthelm, Dick (1 Shell International Exploration and Production, Kessler Park 1, 2288 GS Rijswijk, The Netherlands)

OnePetroApril, 2010

Summary Low salinity water injection is an emerging EOR technology, applicable to mixed-to-oil-wet sandstone reservoirs. Flooding with low salinity water causes desorption of petroleum heavy ends from the clays present on the pore wall, resulting in a more waterwet rock surface, a lower remaining oil saturation and higher oil recovery. A secondary flood application is discussed in the Omar field in Syria showing a change of wettability from oil wet to a water-wet system. This change in wettability is supported by the observation of dual steps in watercut development. In between the two steps the watercut was constant. This behaviour is a known indicator of changing wettability. Moreover, direct connate water banking measurements confirm the change. The field observations are supported by spontaneous imbibition experiments in core material and a single well Log-Inject-Log test in an analogue field. From the field observations, the change in wettability is estimated to be nearly complete, leading to an associated incremental recovery of 10–15% of the Stock Tank Oil Initialy In Place (STOIIP). The significance of this work is that this is one of the very few documented proofs of concept on a reservoir scale. Work is ongoing to prove this concept in a tertiary flood as well.

OnePetro

doi: 10.2118/129564-MS

SPE

SPE-129564-MS

SPE Improved Oil Recovery Symposium

banking, cation, enhanced recovery, experiment, low salinity water flooding, low salinity water injection, Morrow, Oil Recovery, oil saturation, reservoir, rock surface, salinity, spe 129564, Upstream Oil & Gas, water management, watercut development, waterflooding, wettability

Country:

North America > United States (1.00)
Europe (0.93)
Asia > Middle East > Syria > Deir ez-Zor Governorate (0.26)

Industry:

Energy > Oil & Gas > Upstream (1.00)
Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.36)

Oilfield Places:

Asia > Middle East > Syria > Deir ez-Zor Governorate > Omar Field (0.99)
Asia > Middle East > Syria > El-isba Field (0.98)

SPE Disciplines:

Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)

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Repair Of A 50 Foot Diameter Frp Hydrochloric Acid Storage Tank

Cowley, Terry W. (DuPont) | Poland, Duane W. (DuPont)

OnePetroMarch, 2010

INTRODUCTION ABSTRACT A 50 foot (15.2 m) diameter by 36 foot (11 m) straight shell field erected fiberglass reinforced plastic (FRP) tank containing 37% hydrochloric acid developed a leak at its third module seam, approximately 18 feet (5.5 m) off the ground. The tank is made up of four filament wound horizontal sections or modules that are 50 feet (15.2 m) in diameter by 8 feet (2.4 m) high. The leak occurred in a vertical crack at the joint between the second and third modules. This paper discusses interesting findings, fabrication issues, and describes the repair techniques used to successfully return the vessel to service. In light of the large field erected vessels being fabricated for the United States power industry today, this paper is particularly applicable to repairs these vessels may require in the future. A leak was detected by plant personnel in a 50 foot (15.2 m) diameter FRP tank used to store 37% hydrochloric acid. The tank has a 36 foot (11 m) high straight shell wall. The tank is made up of four filament wound horizontal sections or modules (mods) that are 50 feet (15.2 m) in diameter by 8 feet (2.4 m) high. An external visual inspection indicated that the leak was occurring about 18 feet (5.5 m) above ground level at the joint between the second and third modules. Once the tank was cleaned and cleared properly, an internal visual inspection revealed vertical cracks at the modules joint. Further examinations revealed additional vertical cracks that went around about a third of the tanks circumference. SUMMARY A leak was discovered in the third mod seam of the shell of the vessel (Figure 1). A mod is the section between each external weld. The mods were fabricated separately, shipped to the site, and the tank field fabricated by installing one mod on top of the other. The external welds hold the mods, as well as, the top and bottom sections in place. An internal inspection of the vessel revealed that there were 10 vertical cracks about 2 inches (51 mm) long in the corrosion barrier. The corrosion barrier was removed by grinding in order to examine the structural wall of the tank for cracks. It was found that the cracks extended into and through the horizontal filament wound structural wall (Figure 2). This type of crack is more difficult to repair than a hand lay-up structural wall because repairs can't be made in kind. The white area at the top area of the vertical crack is resin putty that was used to fill in the gap between the second and third mod. Resin putty is commonly used to fill gaps between FRP parts when fitted together. There was some concern that the amount of putty might be indicative of an excessive gap between the mods. Additional grinding of the corrosion barrier revealed a total of nineteen cracks at the seam between the second and third mods.

OnePetro

NACE

NACE-10041

CORROSION 2010

adhesion test patch, corrosion barrier, diameter, frp hydrochloric acid storage tank, hydrochloric acid, laminate, mod, module, plug, seam, strand glass mat, structural wall, tank, test patch, Thickness, Upstream Oil & Gas, vertical crack, visual inspection, weld seam

Country:

North America > United States > Texas > Hopkins County (0.24)
Asia > Middle East > Syria > Deir ez-Zor Governorate (0.24)

Genre: Research Report (0.34)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Well Completion > Acidizing (0.83)
Facilities Design, Construction and Operation > Processing Systems and Design > Tanks and storage systems (0.40)

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Technology Focus: Mature Field Revitalization (January 2009)

Ali, Syed A. (Schlumberger)

OnePetroJanuary, 2009

Technology Focus Even as new discoveries are developed and produced, substantial additional reserves can be secured by enhancing recovery from mature fields. Mature fields have the potential to contribute significantly to future reserves—provided that recovery can be optimized. Usually, it is the new discoveries that capture the attention of the oil industry; however, 70% of the hydrocarbon liquids produced in the world today actually come from mature fields. With most of the world's potential oil provinces having already been explored and major new discoveries becoming increasingly rare, mature fields are destined to play an ever-more-prominent role in energy supply. It is generally accepted that 30 to 35% of the original oil in place will be recoverable by the end of the normal production period. However, advances in technology (fueled by higher oil prices) are making it feasible to access remaining reserves. Considering the substantial quantities of remaining oil at stake, boosting the recovery factor on all the world's oil fields by a mere 1% would cover 3 years of worldwide consumption. Techniques to improve the recovery factor include: secondary- and tertiary-recovery schemes, horizontal and multilateral drilling, improved perforation and stimulation methods, new completion techniques, advanced logging procedures, and optimal placement of the new wells. Mature fields, however, offer their own set of challenges. In addition to dealing with aging installations and earmarking investments to access additional reserves, all aspects must be considered carefully from a project-economics point of view. Water is another problem in reservoirs nearing the end of their production life; most oil companies produce far more water than oil, raising environmental concerns and water-handling expenses. Consequently, mature fields would require a strategy that is based on tapping bypassed oil, improving recovery from existing producing zones, cutting costs, and implementing leading-edge technologies to maximize production. Mature Field Revitalization additional reading available at the SPE eLibrary: SPE 113684 • "Mature-Field Rejuvenation of a Tight Gas Carbonate Utilizing Coiled-Tubing Underbalanced-Drilling Techniques" by C. Mykytiw, SPE, FX Solutions Group, et al. SPE 113271 • "Techniques in Marginal and Mature Fields in the Pannonian Basin, Hungary: Case Study" by A. Holoda, MOL, et al. SPE 112940 • "The Omar Field (NE Syria) Is Overcoming Its Mid-Life Crisis" by J. Neidhardt, Shell, et al. SPE 112586 • "Horizontal Extended-Reach Re-Entry Drilling of Sidetracks at Sakhalin Island Increases Oil Production From Mature Oil Fields" by M.L. Drnec, SPE, Schlumberger, et al.

OnePetro

doi: 10.2118/0109-0058-JPT

SPE

SPE-0109-0058-JPT

Journal of Petroleum Technology

Completion Installation and Operations, Directional Drilling, drilling operation, january 2009, mature field revitalization, new discovery, recovery factor, reserves evaluation, Schlumberger, SPE, Technology Focus, University, Upstream Oil & Gas

Country:

Europe > Hungary (0.57)
Asia > Russia > Far Eastern Federal District > Sakhalin Oblast (0.26)
Asia > Russia > Far Eastern Federal District > Sakhalin Island > Sea of Okhotsk (0.26)
Asia > Middle East > Syria > Deir ez-Zor Governorate (0.26)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Europe > Austria > Pannonian Basin (0.99)
Asia > Middle East > Syria > Deir ez-Zor Governorate > Omar Field (0.99)

SPE Disciplines:

Well Drilling > Drilling Operations > Directional drilling (1.00)
Well Completion > Completion Installation and Operations (1.00)
Reservoir Description and Dynamics > Reserves Evaluation (1.00)
(2 more...)

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The Omar Field (NE Syria) is Overcoming Its Mid-Life Crisis

Neidhardt, Jurg (Syria Shell Petr. Devel. B.V.) | Farran, Herve (Syria Shell & AFPC) | Gonzalez, Ivan Ernesto (Syria Shell & AFPC) | Vledder, Paul (Shell Syria & AFPC) | Doughry, Yahia (AFPC)

OnePetroMarch, 2008

Abstract With an approximate STOIIP of 760 MMbbls, the Omar field is the largest field in Al Furat Petroleum Company's portfolio. The field - located in the Euphrates Graben 45km SE of DeirEzZor - was discovered in 1987 and holds a maximum undersaturated oil column of more than 500m with two original oil-water contacts of 3750 and 3778 meters subsea. The oil production almost exclusively originates from two sandstone formations: the Cretaceous sheet-like shallow marine Lower Rutbah (RUL) and the Triassic coastal fluvial plane Mulussa F (MUF) formation. The Omar Field is formed by an elongated, high relief tilted horst block, which is internally compartmentalised. Originally, the field produced naturally at a peak net oil rate of some 80kbpd but production declined rapidly because of the lack of any pressure support. Following the implementation of water injection from 1991 onwards a plateau production of around 60–70kbopd was achieved for some five years (1994–1997) declining to the current net oil production of 20 kbopd. Despite the structural complications, the injector-producer connectivity in the laterally extensive RUL sands could be established rather confidently and recoveries in excess of 55% should eventually be achievable. Predicting water-flood efficiency in the Mulussa F 3D sand channel labyrinth turned out more complicated. As a matter of fact, it was demonstrated that the resolution achievable by static reservoir modelling was not sufficient to predict the water-flood efficiency meaningfully. As a consequence a statistical infill campaign was launched with a focus to infill the existing major gaps between the MUF wells and secondly to establish a line drive waterflood pattern while investigating the merits of a dense five spot. The results of this infill drilling campaign (executed in 2005–2006) and a new 600-fold high-resolution seismic survey gave a multi-disciplinary team the challenge to improve in identifying more attractive targets while reducing the downside drilling results observed during the infill campaign. A combination of the new structural data with a regional geological well correlation fully and iteratively integrated with dynamic well information and production data, indicates that the recovery in the MUF formation could well be optimized through a more deterministic instead of the previously adopted statistical infill drilling approach. Introduction The Omar field STOIIP of 760 MMstb is located for about 50% in the Cretaceous sheet-like shallow marine Lower Rutbah (RUL) and some 45% is contained in the Triassic coastal fluvial plane Mulussa F (MUF) formation. The field is an elongated, high relief, tilted horst block, which is internally compartmentalized. The field is delimited by two main boundary faults and sealed by an erosional unconformity (BKU), which has removed the Rutbah reservoirs over the crestal part of the structure. A schematic cross section is shown in Figure 1. The Lower Rutbah consists of well-developed shallow marine and tidal channel sands with a high net-to-gross ratio (~73 %). The full Lower Rutbah thickness typically varies between 120 to 130 m in areas without BKU erosion. The Mulussa F1 and F2 (MUF1, MUF2) consist of fluvial channel sands and flood plain shales with a total thickness of up to 350m. The Mulussa F1 is characterised by a lower net-to-gross ratio (~22 %) than the Mulussa F2 (~35 %). Connectivity in this thinly bedded (single sand thickness is around 5m), 3D labyrinth-type reservoir is affected by extensive faulting with a multitude of throws below the seismic resolution of ~50 m. The Mulussa F3 formation below the Mulussa F2 has an even lower net-to-gross, and is underlain by the Mulussa E carbonates.

OnePetro

doi: 10.2118/112940-MS

SPE

SPE-112940-MS

SPE North Africa Technical Conference & Exhibition