ROBE RIVER — AN ONSHORE SHALLOW OIL ACCUMULATION

1978 ◽  
Vol 18 (1) ◽  
pp. 3
Author(s):  
B. M. Thomas
Keyword(s):  
Structural Control ◽  
Oil And Gas ◽  
Seismic Survey ◽  
Large Area ◽  
Oil Accumulation ◽  
Late Tertiary ◽  
Present Distribution ◽  
Artesian Aquifer ◽  
Artesian Water ◽  
Made In

Aeromagnetic depth-to-basement estimates made in 1966 led to the concept of the "Robe River Embayment", a structural depression related to a block of Palaeozoic sediments which has been douwnfaulted into the Precambrian in the northeastern corner of the onshore Carnarvon Basin. During a subsequent seismic survey (1966-67), a deep shothole blew out at 77 m. About 20 litres of heavy brown crude oil were recovered, followed by a strong artesian water flow. The search for a shallow oil accumulation followed with a programme of nine coreholes in 1967-68. Shows of oil and gas were encountered in seven of the wells, but producibility was not established. Further drilling in 1969 (one well), 1972 (five wells) and 1974 (two wells) has better defined the area of hydrocarbon occurrence, but no significant tests have resulted despite promising shows in many of the wells.Robe River oil is of low gravity (14.5 to 20° API), highly aromatic, and biodegraded. It is found at depths ranging from 65 to 165 m mainly within the low-permeability Mardie Greensand. The greensand is underlain by the highly permeable Yarraloola Conglomerate which is an artesian aquifer and has probably acted as the main conduit for oil migration out of the Barrow Sub-basin. There is no evidence of major structural control on the Robe River oil shows which occur sporadically over a large area. Whilst permeability barriers within the Mardie Greensand probably influence the present distribution of hydrocarbons, there is also evidence that the hydraulics of the Yarraloola Conglomerate have been important in the localization of this accumulation. Water salinity studies suggest that the influx of meteoric water from the Yarraloola Conglomerate outcrop has resulted in a hydrodynamic trap for oil as it migrated updip from the Barrow Sub-basin. During the late Tertiary a much larger accumulation may have existed within the Yarraloola Conglomerate and the Mardie Greensand. The northwesterly flow of water has now ceased and the oil has dispersed, except where it is trapped within the relatively impermeable Mardie Greensand.

SEISMIC INVESTIGATION OF THE MERRIMELIA FIELD

1983 ◽  
Vol 23 (1) ◽  
pp. 192
Author(s):  
B. L. Smith
Keyword(s):  
Oil And Gas ◽  
Seismic Survey ◽  
Gas Field ◽  
Central Dome ◽  
Oil Reserves ◽  
Oil And Gas Field ◽  
Well Data ◽  
Field Area ◽  
Made In ◽  
Commercial Oil

The Merrimelia oil and gas field, 40 km north of Moomba in SA, is located on the central dome of the Gidgealpa-Merrimelia-Innamincka Trend within the Cooper/Eromanga Basins.Geophysical studies have been instrumental in the investigation of the field since the discovery of commercial Permo-Triassic gas at Merrimelia- 5 in 1970 based on the results of the Merrimelia Seismic Survey. Subsequent seismic recorded during the 1980 Karawinnie Survey resulted in the location of Merrimelia-6 which, in 1981, discovered commercial oil in the Jurassic Namur Member and Hutton Sandstone, and Triassic gas, previously unknown.To allow accurate mapping of the field's oil reserves, a detailed half kilometre grid was recorded during the 1981 Namooka Seismic Survey. The programme comprised 110 km of 24-fold Vibro- seis coverage. Interpretation of the seismic and well data has resulted in recognition of a complex stratigraphic component superimposed on the Merrimelia structural high. Considerable detailed seismic work has contributed to a better understanding of the seismic reflection sequence and hence improved geophysical prognoses.Seismic studies of the Merrimelia field are continuing as further discoveries, most recently oil in the Triassic at Merrimelia-12 and gas in the Tirrawarra Sandstone at Merrimelia-13, are made in the field area.

GEOPHYSICAL CASE HISTORY OF THEUVENINS CREEK FIELD, TYLER COUNTY, TEXAS

Geophysics ◽  
1961 ◽  
Vol 26 (6) ◽  
pp. 682-690
Author(s):  
T. Y. Chang
Keyword(s):  
Oil And Gas ◽  
Correlation Method ◽  
Seismic Profile ◽  
Seismic Survey ◽  
South Central ◽  
Cumulative Production ◽  
History Of ◽  
Structural Closure ◽  
Continuous Seismic Profile ◽  
Made In

Theuvenins Creek Field is located along the Wilcox producing trend in south‐central Tyler County, Texas. The field was discovered jointly by Sinclair Oil and Gas Company and the Atlantic Refining Company. The first seismic survey of the area was made in 1938. In 1942, a reconnaissance seismic survey was made using the spot correlation method. This work indicated anomalous conditions. In 1955, the area was detailed using a continuous seismic profile method. The seismic data were later reviewed, and the reviewed interpretation substantiated the existence of Wilcox structural closure. Based on seismic evidence, Atlantic and Sinclair spudded the Brown Fee No. 1 wildcat well on August 15, 1957. This well was completed on October 12, 1957 as the discovery well of the field. From an Upper Wilcox sand the well produced 279 barrels of oil per day. Subsequent drilling developed two producing sands in the Uppper Wilcox. A total of 38 producing wells have been drilled on the structure with no dry hole to date. To January, 1961, the total cumulative production from the field was 1.4 million barrels of oil.

DETERMINATION OF RESERVOIR DISTRIBUTION OVER THE BLACKBACK/TERAKIHI OIL FIELD, GIPPSLAND BASIN, AUSTRALIA

1993 ◽  
Vol 33 (1) ◽  
pp. 1
Author(s):  
M.D. Gross
Keyword(s):  
Oil And Gas ◽  
Group Structure ◽  
High Amplitude ◽  
Oil Field ◽  
Seismic Survey ◽  
Seismic Attribute ◽  
Oil Accumulation ◽  
Well Control ◽  
High Impedance ◽  
Gippsland Basin

The Blackback/Terakihi oil accumulation is located within the Gippsland Basin permit Vic-P24 on the edge of the present-day continental shelf in water depths ranging from 300 to more than 600 m. Accurate structural mapping, depth conversion and delineation of the reservoir units remain as major uncertainties associated with this oil and gas accumulation. To date three wells, Hapuku-1, Blackback-1 and Terakihi-1 have been drilled on the structure and a 3D seismic survey interpreted.The top of the Latrobe Group structure is a complex erosional remnant somewhat laterally offset from a deep-seated northeast to southwest trending, faulted anticline. Most of the hydrocarbons intersected to date have been encountered within the top of the Latrobe Group closure. All three wells drilled to date have intersected oil at the top of the Latrobe Group in three markedly different reservoir units. These reservoirs range in age from Late Cretaceous to Eocene, with porosity ranging from less than 12 per cent to 26 per cent and permeability from less than 1 md to greater than 3000 md.Given the extreme variation in reservoir quality and the field's location in relatively deep water, delineating the distribution of reservoir units using all available data remains crucial.The generation of seismic attribute maps such as dip, dip azimuth and horizon amplitude slices, calibrated on existing well penetrations has played a major role in delineating a complex reservoir distribution at the top of the Latrobe Group. The calibration of high amplitude seismic events with a high impedance channel infill unit of Eocene age was supported by modelling using SIERRAR modelling software.The integration of existing well control, seismic stratigraphy and fault geometry together with seismic attribute mapping and modelling has resulted in a more tightly constrained estimate of the field reserves.

EXPLORATION IN THE EAST COAST BASIN, NEW ZEALAND

1972 ◽  
Vol 12 (1) ◽  
pp. 39
Author(s):  
W.C. Leslie ◽  
R.J.S. Hollingsworth
Keyword(s):  
New Zealand ◽  
Oil And Gas ◽  
East Coast ◽  
Geological Structure ◽  
Seismic Survey ◽  
Porosity And Permeability ◽  
Rugged Topography ◽  
Complex Geological Structure ◽  
Petroleum Development ◽  
Made In

Numerous oil and gas seeps have been known in the East Coast Basin of New Zealand since the last century; however, no commercial discovery has been made in the region. Although a number of wells was drilled earlier, the present phase of systematic geological and geophysical exploration was begun by BP Shell Todd Petroleum Development Limited in 1957 and by 1970 had resulted in the drilling of five wells. These wells indicated the presence of thick marine mudstones and siltstones of Cretaceous through Tertiary age, but failed to find any suitable reservoir beds. This, plus complex geological structure and rugged topography are major problems of the region, particularly in the northern portion.Beaver Exploration subsequently became interested in the area because of the presence of a porous Pliocene coquina limestone (known as the Te Aute Beds) cropping out in the Southern Hawke's Bay region. This unit was considered to be a good drilling target if it occurred adequately sealed in the deeper parts of the basin. In an effort to determine this, Beaver conducted a Seismic Survey with the object of tracing the limestone from outcrop into the subsurface, where hopefully it would be found structurally closed.The survey was successful and three drill sites were chosen. In two of these the drill penetrated the Te Aute Beds which had excellent porosity and permeability but were water filled; in the third well the reservoir was missing. Correlations between the seismic and the drilling results indicated that the Te Aute Beds are probably mappable at least over some parts of the Southern Hawke's Bay region. The problem now is to find these beds in areas where they are less likely to be water flushed.

scholarly journals Monitoring the Impact of the Large Building Investments on the Neighborhood

2021 ◽  
Vol 11 (14) ◽  
pp. 6537
Author(s):  
Marian Łupieżowiec
Keyword(s):  
Groundwater Level ◽  
Soil Improvement ◽  
Deep Excavation ◽  
Large Area ◽  
Safety Measures ◽  
High Rise ◽  
The Impact ◽  
Large Building ◽  
Additional Safety ◽  
Made In

The article presents the concept of monitoring buildings and infrastructure elements located near large construction investments (the construction of high-rise buildings of the Oak Terraces housing estate in Katowice and the construction of a tunnel under the roundabout in Katowice along the intercity express road DTŚ). The impacts include deep excavation, lowering of the groundwater level over a large area, and dynamic influences related to the use of impact methods of soil improvement. The presented monitoring includes observation of the groundwater level with the use of piezometers, geodetic measurements of settlement and inclinations, as well as the measurement of vibration amplitudes generated during the works involving shocks and vibrations. It was also important to observe the development of cracks on the basis of a previously made inventory of damage. The results of the monitoring allow corrections to be made in the technology of works (e.g., reduction of vibration amplitudes, application of additional protections at excavations, etc.) or the use additional safety measures. Currently, there are also monitoring systems used during the operation of completed facilities.

Application of Seismic Sequence Stratigraphy for Delineating Mishrif Prospects in Western Onshore, Abu Dhabi, UAE

2021 ◽  
Author(s):  
Subrata Chakraborty ◽  
Monica Maria Mihai ◽  
Nacera Maache ◽  
Gabriela Salomia ◽  
Abdulla Al Blooshi ◽  
...  
Keyword(s):  
Abu Dhabi ◽  
Seismic Sequence ◽  
Large Area ◽  
Oil Accumulation ◽  
Sequence Stratigraphic ◽  
Stratigraphic Analysis ◽  
Seismic Sequence Stratigraphy ◽  
Well Data ◽  
Seismic Reflectors ◽  
Sweet Spots

Abstract In Abu Dhabi, the Mishrif Formation is developed in the eastern and western parts conformably above the Shilaif Formation and forms several commercial discoveries. The present study was carried out to understand the development of the Mishrif Formation over a large area in western onshore Abu Dhabi and to identify possible Mishrif sweet spots as future drilling locations. To achieve this objective, seismic mapping of various reflectors below, above, and within the Mishrif Formation was attempted. From drilled wells all the available wireline data and cores were studied. Detailed seismic sequence stratigraphic analysis was carried out to understand the evolution of the Mishrif Formation and places where the good porosity-permeability development and oil accumulation might have happened. The seismic characters of the Mishrif Formation in dry and successful wells were studied and were calibrated with well data. The Mishrif Formation was deposited during Late Cretaceous Cenomanian time. In the study area it has a gross thickness ranging from 532 to 1,269 ft as derived from the drilled wells; the thickness rapidly decreases eastward toward the shelf edge and approaching the Shilaif basin. The Mishrif was divided into three third-order sequences based on core observations from seven wells and log signatures from 25 wells. The bottom-most sequence Mishrif 1.0 was identified is the thickest unit but was also found dry. The next identified sequence Mishrif 2.0 was also dry. The next and the uppermost sequence identified as Mishrif 3.0 shows a thickness from 123 to 328 ft. All the tested oil-bearing intervals lie within this sequence. This sequence was further subdivided into three fourth-order sequences based on log and core signatures; namely, Mishrif 3.1, 3.2, and 3.3. In six selected seismic lines of 181 Line Km (LKM) cutting across the depositional axis, seismic sequence stratigraphic analysis was carried out. In those sections all the visible seismic reflectors were picked using a stratigraphic interpretation software. Reflector groups were made to identify lowstand systems tract, transgressive systems tract, maximum flooding surface, and highstand systems tract by tying with the observations of log and core at the wells and by seismic signature. Wheeler diagrams were generated in all these six sections to understand the lateral disposition of these events and locales of their development. Based on stratigraphic analysis, a zone with likely grainy porous facies development was identified in Mishrif 3.0. Paleotopography at the top of Mishrif was reconstructed to help delineate areas where sea-level fall generated leaching-related sweet spots. Analysis of measured permeability data identified the presence of local permeability baffles affecting the reservoir quality and hydrocarbon accumulation. This study helped to identify several drilling locations based on a generic understanding of the Mishrif Formation. Such stratigraphic techniques can be successfully applied in similar carbonate reservoirs to identify the prospect areas.

scholarly journals ADAPTATION OF THE METHOD OF CHROMATOGRAPHIC ANALYSIS OF GASOLINE TO ACHIEVE PURPOSES OF GEOCHEMICAL PROSPECTING FOR OIL AND GAS

2019 ◽  
pp. 16-23
Author(s):  
A. R. Kurchikov ◽  
R. I. Timshanov ◽  
E. A. Ustimenko
Keyword(s):  
Chromatographic Analysis ◽  
Oil And Gas ◽  
Seismic Survey ◽  
Near Surface ◽  
Petroleum Potential ◽  
Geological Interpretation ◽  
Gasoline Hydrocarbons ◽  
Snow Water ◽  
Individual Hydrocarbons ◽  
Background Content

Geochemical survey is commonly applied during geological exploration to predict petroleum potential of large areas and to estimate the content of traps identified by the results of seismic survey. C1-C6 hydrocarbon concentrations in samples of surface and subsurface air, soil, snow, water, etc. are used as predictive indicators. At the exploration stage the capabilities of geochemical methods can be significantly expanded by comparing the content of gasoline hydrocarbons in samples of formation fluids and in samples of near-surface sediments. The method of chromatographic analysis of gasolines Chromatec Gazolin has been adapted for sample analysis. The taken measures to increase the sensitivity allowed us to register individual hydrocarbons C1-C10 in concentrations up to 0,01 ppb, which is obviously lower than their background content in the oil prospect areas. The revealed patterns are used in the geological interpretation of geochemical distributions based on theoretical ideas about the subvertical migration of hydrocarbons from the reservoir to the surface.

scholarly journals Morphometric Characteristics of the Aziana Valley Basin

2021 ◽  
Vol 32 (2) ◽  
pp. 163-180
Author(s):  
Heba Mohammed Fayyad ◽  
Isaac Saleh Al-Akam
Keyword(s):  
Morphometric Characteristics ◽  
Elongation Ratio ◽  
Large Area ◽  
Parallel Patterns ◽  
Erosion Processes ◽  
Drainage Patterns ◽  
Drainage Networks ◽  
Mixed Sediments ◽  
Sedimentation Processes ◽  
Made In

The present study aims at examining quantitatively the morphometric characteristics of Iziana Valley basin that is located in the northern part of Iraq; particularly in south of Erbil Governorate. This basin is considered one of the small sub-basins where its valleys run on formations of the Triple and Quadrant Ages, which are represented by the Bay Hassan formations, and the sediments and mixed sediments of the cliffs, respectively. The area of ​​the Iziana basin amounts to (36.39 km2) whereas the percentage of its rotation reaches (0.17); a low percentage, which indicates that the basin diverges from the circular to the rectangular shape. The value of the elongation ratio of the basin reaches (0.38) while the terrain ratio of the basin is (0.03), a low percentage that entails the weakness of its erosion processes and the small volume of the carried and transported sediments. As for the relative topography of the basin, it was (1.08), which is also a low value. It indicates a relatively large area of ​​the basin and the impressive strides that it has made in its erosion cycle. The total river levels of the basin reach (5) ranks, and their numbers vary from one rank to another. Moreover, the total length of the drainage networks in the basin reached (187.4 km), and the prevailing drainage patterns in the basin are the tree and parallel patterns. The researcher has adopted spatial, formal, topographical, and river net-work properties for the purpose of first determining the shape of the basin, the stage of its erosion, its secondary basins, and its terrestrial features that have been developed as a result of the contrast between the erosion and sedimentation processes. 

scholarly journals Removal of Hydrogen Sulfide (H2S) Using MOFs: A Review of the Latest Developments

2020 ◽  
Vol 2 (1) ◽  
pp. 27
Author(s):  
Amvrosios G. Georgiadis ◽  
Nikolaos D. Charisiou ◽  
Ioannis V. Yentekakis ◽  
Maria A. Goula
Keyword(s):  
Hydrogen Sulfide ◽  
Oil And Gas ◽  
Great Promise ◽  
New Developments ◽  
Specific Heats ◽  
Gas Streams ◽  
Long Time ◽  
Metal Organic ◽  
Bed Stability ◽  
Made In

The removal of hydrogen sulfide (H2S) from gas streams with varying overall pressure and H2S concentrations is a long-standing challenge faced by the oil and gas industries. The present work focuses on H2S capture using metal–organic frameworks (MOFs), in an effort to shed light on their potential as adsorbents in the field of gas storage and separation. MOFs hold great promise as they make possible the design of structures from organic and inorganic units, but also, they have provided an answer to a long-time challenging issue, i.e., how to design extended structures of materials. Moreover, the functionalization of the MOF’s surface can result in increased H2S uptake. For example, the insertion of 1% of a fluorinated linker in MIL-101(Cr)-4F(1%) allows for enhanced H2S capture. Although noticeable efforts have been made in studying the adsorption capacity of H2S using MOFs, there is a clear need for gaining a deeper understanding in terms of their thermal conductivities and specific heats in order to design more stable adsorption beds, experiencing high exothermicity. Simply put, the exothermic nature of adsorption means that sharp rises in temperature can negatively affect the bed stability in the absence of sufficient heat transfer. The work presented herein provides a detailed discussion by thoroughly combining the existing literature on new developments in MOFs for H2S removal, and tries to provide insight into new areas for further research.

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