Oil formations of Azerbaijan, their lithographic and geochemical characteristics

2021 ◽  
pp. 4-7
Author(s):  
M.Ya. Aghamammadova ◽  
Keyword(s):  
Upper Cretaceous ◽  
Oil And Gas ◽  
Produced Water ◽  
Upper Jurassic ◽  
Upper Oligocene ◽  
Valuable Metals ◽  
Lower Pleistocene ◽  
Oil Shales ◽  
Oil Gas ◽  
Middle Pliocene

Petroleum sediments in Azerbaijan have been researched and described by now in the form of complexes. Not only oil and gas deposits, but also the fields and accumulations of bitumen, bituminized rocks and oil shales are associated with these sediments. Furthermore, there are iodine, brom, the components of natural soda and so on in the oil, oil products and sediments as well. Alongside with it, a great amount of valuable metals present in the content of oil, produced water, bitumen and oil shales as an addition. This circumstance dictates the necessity of formation division of oil sediments. There are ten oil formations: Upper Pliocene-Lower Pleistocene, oil bearing-terrigenic; Middle Pliocene, oil-gas-bituminous-terrigenic; diatom-oil bearing-sand-clay; Miocene, oil-bituminous-sand-aleurite; Upper Oligocene-Miocene, oil bearing-terrigenic-carbonate; Eocene, oil bearing-clay-sand-marly; Upper Cretaceous, oil bearing-carbonate; Lower Cretaceous, oil bearing-terrigenic-carbonate; Upper Jurassic, oil bearing-sand-aleurite.

scholarly journals Characterization and Treatment Technologies Applied for Produced Water in Qatar

Water ◽  
2021 ◽  
Vol 13 (24) ◽  
pp. 3573
Author(s):  
Hana D. Dawoud ◽  
Haleema Saleem ◽  
Nasser Abdullah Alnuaimi ◽  
Syed Javaid Zaidi
Keyword(s):  
Natural Gas ◽  
Oil And Gas ◽  
Produced Water ◽  
Cost Effective ◽  
Oil And Gas Industry ◽  
Gas Industry ◽  
Treatment Techniques ◽  
Treatment Technologies ◽  
Oil Gas

Qatar is one of the major natural gas (NG) producing countries, which has the world’s third-largest NG reserves besides the largest supplier of liquefied natural gas (LNG). Since the produced water (PW) generated in the oil and gas industry is considered as the largest waste stream, cost-effective PW management becomes fundamentally essential. The oil/gas industries in Qatar produce large amounts of PW daily, hence the key challenges facing these industries reducing the volume of PW injected in disposal wells by a level of 50% for ensuring the long-term sustainability of the reservoir. Moreover, it is important to study the characteristics of PW to determine the appropriate method to treat it and then use it for various applications such as irrigation, or dispose of it without harming the environment. This review paper targets to highlight the generation of PW in Qatar, as well as discuss the characteristics of chemical, physical, and biological treatment techniques in detail. These processes and methods discussed are not only applied by Qatari companies, but also by other companies associated or in collaboration with those in Qatar. Finally, case studies from different companies in Qatar and the challenges of treating the PW are discussed. From the different studies analyzed, various techniques as well as sequencing of different techniques were noted to be employed for the effective treatment of PW.

Oil & gas produced water retention ponds as potential passive treatment for radium removal and beneficial reuse

2021 ◽  
Vol 23 (3) ◽  
pp. 501-518
Author(s):  
Bonnie McDevitt ◽  
Molly C. McLaughlin ◽  
Jens Blotevogel ◽  
Thomas Borch ◽  
Nathaniel R. Warner
Keyword(s):  
Water Retention ◽  
Oil And Gas ◽  
Produced Water ◽  
Passive Treatment ◽  
Gas Extraction ◽  
Beneficial Use ◽  
Retention Ponds ◽  
Beneficial Reuse ◽  
Oil Gas

Oil and gas extraction generates large volumes of produced water (PW) in regions that are water-stressed. PW can be passively treated in retention ponds prior to beneficial use. Oxic conditions lead to sequestration and lower bioavailability of Ra.

BARROW ISLAND OIL FIELD

1999 ◽  
Vol 39 (1) ◽  
pp. 158 ◽  
Author(s):  
G.K. Ellis ◽  
A. Pitchford ◽  
R.H. Bruce
Keyword(s):  
Lower Cretaceous ◽  
Middle Jurassic ◽  
Upper Cretaceous ◽  
Oil And Gas ◽  
Water Injection ◽  
Water Source ◽  
Upper Jurassic ◽  
Hydrocarbon Reservoirs ◽  
Oil Field ◽  
Injection Wells

The Barrow Island Field in the Barrow Sub-basin of the Carnarvon Basin was discovered in 1964 by West Australian Petroleum Pty Limited. It is the largest oil field in Western Australia. Appraisal drilling has defined in-place oil of 200 GL (1,250 MMBBL) and in-place gas of 16.5 Gm3 (580 BCF) primarily in the Lower Cretaceous Windalia Sand Member of the Muderong Shale and in- place gas of 14.5 Gm3 (515 BCF) in Middle Jurassic Biggada Formation. Additional hydrocarbon reservoirs have been discovered, including oil and gas in the Upper Jurassic Dupuy Formation, the Lower Cretaceous Malouet Formation, Flacourt Formation and Tunney Member, Mardie Greensand Member and M zones of the Muderong Shale and in the Upper Cretaceous Gearle Siltstone. Approximately 850 wells have been drilled to appraise and develop these accumulations, and to provide water source and water injection wells to enhance recovery. Production commenced in December 1966, with the first shipment of oil in April 1967. Although numerous hydrocarbon reservoirs have been developed, 95% of the 44 GL (278 MMBBL) of produced oil has been from the Windalia Sand.Structural development of the Barrow Island anticline occurred initially during the Middle Jurassic and continued intermittently during the Cretaceous and Tertiary. Initial charging of the Dupuy and Malouet formations with oil from the Upper Jurassic Dingo Claystone occurred in the Early Cretaceous prior to the development of the shallower closures. Periodic wrench- related movement on the Barrow Fault during the Early to Late Cretaceous produced closures at the Lower Cretaceous reservoirs and provided a catalyst for oil migration and charging of these closures. Significant amounts of an extremely biodegraded component, and several less biodegraded phases are present in the oil in the Windalia Sand, indicating several phases of oil charging of the Barrow structure from Middle and Upper Jurassic sediments. In the Tertiary, gas sourced from Triassic and Jurassic sediments migrated into the Barrow structure via a dilated Barrow Fault, charged the Middle Jurassic Biggada Formation and displaced some of the oil in the Lower Cretaceous reservoirs.

Environmental improvement based on advancement of water injection technologies

2021 ◽  
pp. 53-56
Author(s):  
N.T. Mammadov ◽  
Keyword(s):  
Production Efficiency ◽  
Oil And Gas ◽  
Produced Water ◽  
Water Injection ◽  
Water Control ◽  
Oil And Gas Development ◽  
Environmental Improvement ◽  
Gas Fields ◽  
The Impact ◽  
Oil Gas

The processes of produced water control in oil-gas industry lead to the periodical environmental improvement. Proceeding intensive oil development in Absheron peninsula throughtout over 150 years led to the increase of flooding percentage and oil decrease in geological reservoir. Therefore, due to the fact that the capacity of produced water together with oil exceeds for several times the total capacity of extracted oil, the issues associated with the further recycling and systematic control on produced water are particularly topical. The implementation of fully closed system of produced water control formed in the oil and gas development in Absheron territory is considered the need of the hour. It is necessary to study the current ecological situation in oil-gas fields, increase the production efficiency and reduce the impact on environment, offering more improved methods based on up-to-date scientific and methodological analysis. The reduction of produced water capacity and gradual environmental improvement may be achieved due to the decrease of operation of highly flooded wells in the old oil-gas fields. Due to the produced water deposition from the oil in the sedimentary rocks and scavenger wells, the amount of oil in the water reduced for several times, and in this case it is possible to reduce the effect of hydrocarbons on the soil, water and atmosphere.

Impact of tectonic faults on formation of oil-gas traps in Yevlakh-Aghjabedi oil-gas bearing region

2021 ◽  
pp. 4-10
Author(s):  
B.S. Aslanov ◽  
◽  
A.I. Khuduzade ◽  
R.A. Asgerova ◽  
Yu.F. Ismailzade ◽  
...  
Keyword(s):  
Upper Cretaceous ◽  
Oil And Gas ◽  
Middle Eocene ◽  
North West ◽  
North East ◽  
The North ◽  
Industrial Oil ◽  
Geophysical Surveys ◽  
Oil Gas ◽  
Gas Bearing

Via geological-geophysical surveys carried out on the north-east border of Yevlakh-Aghjabedy downfold in the second half of the last century, the oil-gas bearing content of deeply-immersed Mesozoic horizons of Upper Cretaceous, as well as shallow layers of Paleogene and Miocene has been defined. Oil-gas bearing Productive Series have been discovered within Muradkhanly, Zardab, Shykhbaghy and Jafarli structures, which belong to Zardab-Muradkhanly-Jafarli belt. Oil-gas reservoirs are lithologically associated mainly with fractured superfusive and carbonate rocks of Upper Cretaceous, as well as sedimentary-volcanogenic rocks of Middle Eocene and partially terrigenic collectors of Maikop-Chokrak, which are layer-arch type of trap. Some researchers came to the conclusion that within favorable geological circumstances on the north-east border of the downfold, collectors of Mesozoic sediments may contain industrial oil and gas deposits as well. To that end, recently the major capacity of exploration drilling and geoexploration was focused within Yevlakh-Aghjabedy downfold, where Mesozoic structures are widespread alongside with Paleogen-Miocene sediments. Deep structural-tectonic framework and oil-gas bearing content both on south-west and north-east slopes of the downfold was specified via the results of conducted works. It was defined that by hydrocarbon saturation, north-west and south-east slopes sharply differ from each other both in the view of structural-tectonic and oil-gas bearing capacity, probably associated with various cycles of folding of Cenozoic and Mesozoic ages.

scholarly journals Geology of the Dan field and the Danish North Sea

1975 ◽  
Vol 43 ◽  
pp. 1-24
Author(s):  
F. B Childs ◽  
P.E.C Reed
Keyword(s):  
North Sea ◽  
Upper Cretaceous ◽  
Oil And Gas ◽  
Upper Jurassic ◽  
The North ◽  
Average Porosity ◽  
Probable Source ◽  
Porosity And Permeability ◽  
The North Sea ◽  
Geochemical Studies

The Dan field was discovered in 1971 by the Dansk Undergrunds Consortium's fifteenth offshore wildcat, which encountered oil and gas in Maestrichtian and Danian chalk at the subsea depth of 5790-6565 feet. Production of some 800 BOPD from each of five wells began in July 1972.The field lies on the eastern flank of the North Sea Tertiary basin and near the axis of the Central Graben, a deep trough filled with a thick sequence of Permian to Cretaceous sediments. Upper Cretaceous-Danian chalk at the top of the sequence provides the reservoir for several further hydrocarbon accumulations in offshore Denmark. Geochemical studies indicate that deeper Upper Jurassic marine shales are the probable source beds for these accumulations.The Dan field is a halokinetically induced domal anticline. The chalk reservoir has an average porosity and permeability of 28% and 0.5 millidarcy, respectively. The solution GOR is 600 cu. ft./bbl and the crude oil is 30° API with low sulphur content (0.29%).

Potential of recovering elements from produced water at oil and gas fields, British Columbia, Canada

CIM Journal ◽  
2018 ◽  
Vol 9 (4) ◽  
pp. 195-214
Author(s):  
G. J. Simandl ◽  
C. Akam ◽  
M. Yakimoski ◽  
D. Richardson ◽  
A. Teucher ◽  
...  
Keyword(s):  
British Columbia ◽  
Oil And Gas ◽  
Produced Water ◽  
Oil And Gas Fields ◽  
Gas Fields

Hanna of Wyoming—The Rockies’ Deepest Basin

2017 ◽  
Vol 54 (4) ◽  
pp. 265-293 ◽  
Author(s):  
Roger Matson ◽  
Jack Magathan
Keyword(s):  
Upper Cretaceous ◽  
Oil And Gas ◽  
Thrust Faults ◽  
Depositional History ◽  
Deep Sediment ◽  
Northern Margin ◽  
Lacustrine Shale ◽  
Hanna Basin ◽  
Fluvial Sandstone

The Hanna Basin is one of the world’s deeper intracratonic depressions. It contains exceptionally thick sequences of mature, hydrocarbon-rich Paleozoic through Eocene rocks and has the requisite structural and depositional history to be a significant petroleum province. The Tertiary Hanna and Ferris formations consist of up to 20,000 ft of organic-rich lacustrine shale, shaly mudstone, coal, and fluvial sandstone. The Upper Cretaceous Medicine Bow, Lewis, and Mesaverde formations consist of up to 10,000 ft of marine and nonmarine organic-rich shale enclosing multiple stacked beds of hydrocarbon-bearing sandstone. Significant shows of oil and gas in Upper Cretaceous and Paleocene rocks occur in the basin. Structural prospecting should be most fruitful around the edges where Laramide flank structures were created by out-of-the-basin thrust faults resulting from deformation of the basin’s unique 50-mile wide by 9-mile deep sediment package. Strata along the northern margin of the basin were compressed into conventional anticlinal folds by southward forces emanating from Emigrant Trail-Granite Mountains overthrusting. Oil and gas from Pennsylvanian to Upper Cretaceous aged rocks have been found in such structures near the Hanna Basin. Only seven wells have successfully probed the deeper part of the Hanna Basin (not including Anadarko’s #172 Durante lost hole, Sec. 17, T22N, R82W, lost in 2004, hopelessly stuck at 19,700 ft, unlogged and untested). Two of these wells tested gas at commercial rates from Upper Cretaceous rocks at depths of 10,000 to 12,000 ft. Sparse drilling along the Hanna Basin’s flanks has also revealed structures from 3,000 to 7,000 feet deep which yielded significant shows of oil and gas.

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