The Experts below are selected from a list of 150 Experts worldwide ranked by ideXlab platform
Kjell Aleklett - One of the best experts on this subject based on the ideXlab platform.
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Giant Oil Field decline rates and their influence on world Oil production
Energy Policy, 2009Co-Authors: Mikael Höök, Robert L Hirsch, Kjell AleklettAbstract:The most important contributors to the world's total Oil production are the Giant Oil Fields. Using a comprehensive database of Giant Oil Field production, the average decline rates of the world's Giant Oil Fields are estimated. Separating subclasses was necessary, since there are large differences between land and offshore Fields, as well as between non-OPEC and OPEC Fields. The evolution of decline rates over past decades includes the impact of new technologies and production techniques and clearly shows that the average decline rate for individual Giant Fields is increasing with time. These factors have significant implications for the future, since the most important world Oil production base - Giant Fields - will decline more rapidly in the future, according to our findings. Our conclusion is that the world faces an increasing Oil supply challenge, as the decline in existing production is not only high now but will be increasing in the future.
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The Evolution of Giant Oil Field Production Behavior
Natural Resources Research, 2009Co-Authors: Mikael Höök, Bengt Söderbergh, Kristofer Jakobsson, Kjell AleklettAbstract:The Giant Oil Fields of the world are only a small fraction of the total number of Fields, but their importance is huge. Over 50% of the world’s Oil production came from Giants by 2005 and more than half of the world’s ultimate reserves are found in Giants. Based on this, it is reasonable to assume that the future development of the Giant Oil Fields will have a significant impact on the world Oil supply. In order to better understand the Giant Fields and their future behavior, one must first understand their history. This study has used a comprehensive database on Giant Oil Fields in order to determine their typical parameters, such as the average decline rate and life-times of Giants. The evolution of Giant Oil Field behavior has been investigated to better understand future behavior. One conclusion is that new technology and production methods have generally led to high depletion rates and rapid decline. The historical trend points towards high decline rates of Fields currently on plateau production. The peak production generally occurs before half the ultimate reserves have been produced in Giant Oil Fields. A strong correlation between depletion-at-peak and average decline rate is also found, verifying that high depletion rate leads to rapid decline. Our result also implies that depletion analysis can be used to rule out unrealistic production expectations from a known reserve, or to connect an estimated production level to a needed reserve base.
Mikael Höök - One of the best experts on this subject based on the ideXlab platform.
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Giant Oil Field decline rates and their influence on world Oil production
Energy Policy, 2009Co-Authors: Mikael Höök, Robert L Hirsch, Kjell AleklettAbstract:The most important contributors to the world's total Oil production are the Giant Oil Fields. Using a comprehensive database of Giant Oil Field production, the average decline rates of the world's Giant Oil Fields are estimated. Separating subclasses was necessary, since there are large differences between land and offshore Fields, as well as between non-OPEC and OPEC Fields. The evolution of decline rates over past decades includes the impact of new technologies and production techniques and clearly shows that the average decline rate for individual Giant Fields is increasing with time. These factors have significant implications for the future, since the most important world Oil production base - Giant Fields - will decline more rapidly in the future, according to our findings. Our conclusion is that the world faces an increasing Oil supply challenge, as the decline in existing production is not only high now but will be increasing in the future.
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The Evolution of Giant Oil Field Production Behavior
Natural Resources Research, 2009Co-Authors: Mikael Höök, Bengt Söderbergh, Kristofer Jakobsson, Kjell AleklettAbstract:The Giant Oil Fields of the world are only a small fraction of the total number of Fields, but their importance is huge. Over 50% of the world’s Oil production came from Giants by 2005 and more than half of the world’s ultimate reserves are found in Giants. Based on this, it is reasonable to assume that the future development of the Giant Oil Fields will have a significant impact on the world Oil supply. In order to better understand the Giant Fields and their future behavior, one must first understand their history. This study has used a comprehensive database on Giant Oil Fields in order to determine their typical parameters, such as the average decline rate and life-times of Giants. The evolution of Giant Oil Field behavior has been investigated to better understand future behavior. One conclusion is that new technology and production methods have generally led to high depletion rates and rapid decline. The historical trend points towards high decline rates of Fields currently on plateau production. The peak production generally occurs before half the ultimate reserves have been produced in Giant Oil Fields. A strong correlation between depletion-at-peak and average decline rate is also found, verifying that high depletion rate leads to rapid decline. Our result also implies that depletion analysis can be used to rule out unrealistic production expectations from a known reserve, or to connect an estimated production level to a needed reserve base.
M. B. Lagoe - One of the best experts on this subject based on the ideXlab platform.
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scales of geologic heterogeneity of a deep water sand Giant Oil Field long beach unit wilmington Field california
1993Co-Authors: Roger M. Slatt, S. Phillips, J. M. Boak, M. B. LagoeAbstract:Deep-water sands form economically important hydrocarbon reservoirs in many parts of the world. Although they have been studied extensively from a traditional, somewhat qualitative perspective, quantitative reservoir characteristics are poorly understood, and often are not described in a format suitable for reservoir engineering applications. Like other types of sands, heterogeneities of deep-water sand reservoirs can be described at four scales (terminology after Krause et al., 1987): microscale (grains and pores), mesoscale (near well bore), macroscale (interwell), and megascale (Field-size).
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Scales of geological heterogeneity of a deep-water sand Giant Oil Field
AAPG Bulletin, 1990Co-Authors: R.m. Slatt, S. Phillips, J. M. Boak, M. B. LagoeAbstract:To understand the levels of accuracy that can be placed upon different scales of reservoir description, turbidite intervals in part of the Giant Wilmington Oil Field, California, have been numerically described at four scales of heterogeneity. The degree of accuracy of the description, in terms of real geologic variability, is found to diminish with increasing scale. At the microscale (grains and pores) and mesoscale (near well bore), the following flow units, listed in order of decreasing reservoir quality, were defined by relating various geologic and petrophysical properties: thick-bedded sand, thin-bedded sand, and shale. Mutual relationships among the geologic and petrophysical properties are a result of primary depositional processes. At the macroscale (interwell), shale beds are laterally continuous over long distances and probably isolate individual sands by acting as vertical permeability barriers. Petrophysical properties, such as permeability, vary between wells within an order of magnitude of measured values. The relationships among petrophysical properties and geologic properties established at the single-well scale are sometimes but not always predictable between wells. At the megascale (Field wide), the turbidites were placed within the context of Vail's integrated sequence stratigraphy model, Walker's progradational submarine fan model, and Mutti's turbidite systems model to illustrate that theremore » is not a unique interpretation when the overall size of a depositional system is larger than that of the data grid. At this scale, petrophysical properties are averaged over a large stratigraphic interval so that there is very little interwell predictability; however, the primary depositional control on gross petrophysical properties is maintained.« less
John Mitchell - One of the best experts on this subject based on the ideXlab platform.
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Stratigraphic hierarchy and architecture of the upper Thamama (Cretaceous) Lekhwair, Kharaib and Shu’aiba formations at a Giant Oil Field, offshore Abu Dhabi, United Arab Emirates
GEO 2008, 2008Co-Authors: John Mitchell, Christine Iannello, Jon Kaufman, Ewart Edwards, Hesham Shebl, Majid H. Al SuwaidiAbstract:At a Giant Oil Field located in offshore Abu Dhabi, the Lekhwair, Kharaib, and Shu’aiba formations record deposition during a second-order supersequence. This supersequence comprises at least three second-order composite sequences that, in turn, are composed of a stack of third-order sequences. Major third-order sequence boundaries or their correlative conformities are interpreted at the base of the Thamama III, below the base of the Thamama IIIA reservoir unit, the top of Thamama III, the top of Thamama II, and above Thamama IA reservoir units. The vertical distribution of lithofacies in the Lekhwair, Kharaib and Shu’aiba formations is remarkably similar from well to well, and predictable Fieldwide. Consistency in lateral facies distribution across the Field suggests that deposition occurred on a highly aggradational, flat-topped platform with no appreciable depositional geometry. The Thamama III consists of stacked fourth-order parasequence sets. Porous and permeable packstones/grainstones dominated variously by rudist debris, coated grains and algal lumps comprise the reservoir units that form the highstand portion of these fourth-order cycles. These units in turn are sharply overlain and separated by non-porous and impermeable dense units that consist of stylolitic wackestones/packstones and grainstones with common ostracodes, dasycladacean algae, miliolid foraminifers, and intraclasts. These dense units are interpreted as forming the transgressive portion of the fourth order cycles. Similarly, within the Thamama II, lithofacies associations seen in cores have a predictable vertical succession, and represent a classic shallowing-upwards succession. In ascending order these are: peloidal-skeletal wackestone-mudstone; orbitolinid-peloidal- skeletal wackestone-packstone; algal-intraclasticpeloidal packstone-mud-lean packstone; fining-upward cycles of floatstone-rudstone-boundstone grading up into skeletal-peloidal mud-lean packstone-grainstone; and miliolid foraminifer-dasycladacean algae-sponge spicule wackestone-packstone. The Thamama IA shows an overall deepening-upwards succession of lithofacies associations. In ascending order these are: Lithocodium- Bacinella floatstone-boundstone; skeletal-peloidal packstone; skeletal-peloidal packstone-wackestone; foraminiferal wackestone/mudstone; and planktonic foraminifer-skeletal wackestone-mudstone. No obvious sequence boundary is seen at the top of the Thamama IA, suggesting that offshore, this surface is a correlative conformity.
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high resolution sequence stratigraphy and reservoir characterization of upper thamama lower cretaceous reservoirs of a Giant abu dhabi Oil Field united arab emirates
2006Co-Authors: Christian J Strohmenger, Taha Aldayyani, Ahmed Ghani, Jim L Weber, Khalil Almehsin, Omar Aljeelani, Abdulla Almansoori, Lee Vaughan, Sameer A Khan, John MitchellAbstract:Important hydrocarbon accumulations occur in platform carbonates of the Lower Cretaceous Kharaib (Barremian and early Aptian) and Shuaiba (Aptian) formations (upper Thamama Group) of Abu Dhabi. The Kharaib and Lower Shuaiba formations contain three reservoir units separated by three low-porosity and low-permeability dense zones. From base to top, the thickness of the reservoir intervals range from approximately 80, 170, to 55 ft (24, 51, to 16 m), respectively, for the Lower Kharaib, Upper Kharaib, and Lower Shuaiba Reservoir Units. Core and well-log data of a Giant Oil Field of Abu Dhabi, as well as outcrop data from Wadi Rahabah in the Emirate of Ras Al-Khaimah were used to establish a sequence-stratigraphic framework and a lithofacies scheme, applicable to all three reservoir units and the three dense zones. The Lower and Upper Kharaib Reservoir Units, as well as the lower, middle, and upper dense zones are part of the late transgressive sequence set of a second-order supersequence, made up of two third-order composite sequences. The overlying Lower Shuaiba Reservoir Unit belongs to the late transgressive sequence set and the early highstand sequence set of this second-order supersequence and is made up of one third-order composite sequence. The three third-order composite sequences are composed of 19 fourth-order parasequence sets that show predominantly aggradational and progradational stacking patterns, typical of greenhouse cycles. Conventionally, composite sequence boundaries are placed at or near the base of the three dense zones. As an alternative scenario, the possibility that the major composite sequence boundaries actually occur on top of these dense zones is discussed. On the basis of faunal content, texture, sedimentary structures, and lithologic composition, 13 reservoir lithofacies and 8 nonreservoir (dense) lithofacies are identified from core. Similar lithofacies are identified in time-equivalent rock exposures studied in Wadi Rahabah. Depositional environments of reservoir units range from lower ramp to shoal crest to near-back shoal open-platform deposits. Dense zones were deposited in an inner-ramp, restricted shallow-lagoonal setting. Intensively bioturbated wackestone and packstone, and interbedded organic- and siliciclastic-rich limestone, characterize the dense zones. Locally, mud cracks, blackened grains, and rootlets are observed. Outcrop analogs of subsurface reservoirs allow for a detailed investigation of facies architecture and structure of carbonate bodies. Integration of subsurface and outcrop data (e.g., low-angle clinoforms that cannot be seen in core data) leads to more insightful and realistic geological models of subsurface stratigraphy. Geological model realizations based on core, outcrop, well-log, and seismic data constrain fluid flow-simulation models. Results mimic known behavior in analogous producing Fields, and the process of going from rock data to simulation provides a useful training tool for reservoir characterization methods and techniques.
Jochen Guntner - One of the best experts on this subject based on the ideXlab platform.
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how do Oil producers respond to Giant Oil Field discoveries
Energy Economics, 2019Co-Authors: Jochen GuntnerAbstract:This paper studies how petroleum producers respond to a Giant Oil Field discovery. Using a large panel of country-level production data and a difference-in-differences identification approach, I show that domestic production levels respond before a newly found Oil Field has come on line, indicating that producers raise extraction rates from existing reservoirs. Given that domestic petroleum consumption rises by less in response to a discovery, at least part of the increase in production seems to go into (net) Oil exports. I find substantial heterogeneity in the impulse responses of Oil production and consumption with respect to the location and size of a Giant Oil Field and the country’s OPEC membership status.