Wednesday, 22 January 2014

Conclusion

This will be the last note on the blog.
I have chosen the Jeanne d'Arc Basin no without reason.
I wanted to find out a little bit about opening of the Atlantic Ocean and when I was writing the second note I have completed my knowledge about it.
For me the most interesting thing was petroleum resources. Preparing the January note involved broadening my knowledge in petrouleum geology. Right now I know more about structural, sedimentary traps or seals or resource rocks.
I tried to write notes connected with subjects of Paleogeography and Basin Analysis course as much as possible but the availability of free papers about the Jeanne d'Arc Basin was poor.
In the end I want to say that thanks to writing notes in English I have expanded my english geological vocabulary, which is very important to me.

Stay classy and work like crazy, baby! :)
~Weronika




Saturday, 18 January 2014

Petroleum Resources of the Jeanne d'Arc Basin



In this note I want to mention a little bit about petroleum resources of the Jeanne d’Arc Basin. 

Hydrocarbon source, migration and trapping

 

It was geochemically traced that the most important and almost exclusive source rock is the Kimmeridgian Egret Member, which I described in November.


The Egret Member occurs all over the Jeanne d’Arc Basin and is buried to depth, which varies from 3300 m and 5000 m. The quality of the source rock is very high, contain oil-prone type I and II Kerogen. The TOC is ranging from 2% to 12%. According to API grades, oils are light and have about 30-35°. This kind of oil is the most desirable from economical point of view. Also heavy oil pools have been discovered. Maturation paths which led to hydrocarbon generation were diverse and that is why maturity is different even in stacked pools within the same field.
Central and northern parts of the basin are overmature, which is connected with gas-prone occurring in these areas (Fig. 1). 




Fig. 1 Egret source maturity map. (from: Enachescu, 2006).



Vertical variations suggest that appeared a few episodes of oil migration and emplacement, which took place between the Mid-Cretaceous till the Early Eocene. Hydrocarbons have migrated:

  • vertically (most abundant) along the existing extensional faults.
  • laterally along basin flanks
As we know, the HCs move out from source rocks and migrate into reservoir rocks. To stay in this reservoir rock and not move further is necessary trap, which is sealed by impermeable rocks on top and the sides.
The Jeanne d’Arc Basin is rich in rocks which can serves as seals. Oil and gas accumulations in the basin are sealed by thick Late Jurassic to Late Cretaceous shales which constitute among others by the Fortune Bay, White Rose, Dawson Canyon, Nautilus Formations. Another good seal occurring in the basin are Paleogene-Neogene fine-grained clastics from Banquerau Formations.


Structural framework, which has developed during the complicated geological history (rifting, subsidence) of the Newfoundland Margin, had a strong influence on the trapping of the hydrocarbons in the Jeanne d’Arc Basin.


The predominant structural traps occurring in the Jeanne d’Arc Basin are: structural anticlines, faulted anticlines, faults (listric normal, transfer), roll overs, faulted and tilted blocks, folds, transfer folds. Salt induced structures such as pillows, domes, diapirs, allochtonous teardrops also occur.


Sedimentary traps are abundant in the Jeanne d’Arc Basin and most of the discovered fields have this kind of trapping. Sedimentary traps are pinchout, onlap, truncuation, lens.


Reservoirs occur in:


-syn-rift, silicoclastic units (Late Jurrasic to Early Cretaceous): the Jeanne d’Arc, Hibernia, Catalina and Ben Nevis/Avalon Formations (Fig. 2).


-passive, silicoclastic unit (Upper Cretaceous to Eocene), sandstones from the South Mara member belonging to the Banquereau formation (Fig.2).

Fig. 2 Regional geological cross-section (SW-NE) through the Jeanne d'Arc Basin. Main reservoirs are indicated. (from Enachescu, 2006, after: Sinclair, 1994).


The Ben Nevis/Avalon Reservoir

The Avalon/Ben Nevis Reservoir consist of the older Avalon Formation (I described this formation in December) which is uncomformably overlied by the younger Ben Nevis Formation. The Nautilus Formation which occurs above the Ben Nevis Formation consist of siltstones and calcareous shales which provide a great seal. (Fig. 3)




Fig 3. Structural cross section. White Rose area. In this section can be observed the Avalon Formation (reservoir rock), which is covered by the Nautilus Formation (seal). (from: Enachescu, 2006).


Reserves

Total reserves in 18 fields add up to 2,117 MMbbl oil, 5,050 BCF gas, 290 MMbbl condensates. It’s not total amount, researchers estimated that probably 3,3 millions barrels of oil are waiting for discover.


The first discovery (in 1979) and the largest one was in the Hibernia Field. The Hibernia Field is located 300 km to the east, south east from Newfoundland and Labrador. It was estimated that contain 874 million barrels of recoverable oil, which occur in two reservoirs: the Hibernia (Early Cretacous) and The Ben Nevis-Avalon (Aptian-Albian). (Fig.1)

Another very important place is the Whiterose Field, which was discovered in 1984 and is located about 350 km east of Newfoundland and Labrador. This field contain one, very important reservoir: the Ben-Nevis Avalon. (Fig.1)

The Terra Nova Field was also discovered in 1984 and is located near the White Rose field, consist of one reservoir: the Jeanne d’Arc. (Fig. 1)





Table. 1. Oil and gas daily and total annual production in the Jeanne d'Arc Basin from 2005. (from: Enachescu, 2006)



Important terms

MMbbla (million barrels)

1 barrel (bbl)- 42 US Gallons= 35 imperial Gallons= 158,76 litre (volume)

BCF (billion cubic feet)

1 CF = 28.32 litres

Play- it is a larger area with possibly hydrocarbons, a smaller one is called prospect

Seal- is a cap rock, which don’t let hydrocarbons to migrate

API (Amercan Petroleum Institute) gravity- is an indicator, which show how heavy or light is a petroleum liquid in compare to water. The higher the API gravity, the lighter the crude.

Light crude oil: API gravity > 30 °
Normal crude oil: API gravity from 30 ° to 22 °
Heavy crude oil: API gravity < 22 °

TOC (the total amount of organic carbon)

TOC quality (weight in %)
< 0,5 poor
0,5 - 1,0 fair
1,0 - 2,0 good
2,0 - 4,0 very good
> 4,0 excellent

Oil pools- the subsurface traps in which occur petroleum, they are within reservoir rock, can be isolated, or stacked on top of one another, or occur laterally from one another.

Oil field- areas with oil pools.


Bibliography: 

Enachescu, 2010. Petroleum Exploration Opportunities in Jeanne d d’Arc Basin Arc Basin, Call for Bids NL10-01.

Enachescu, 2006. Newfoundland and Labrador, Call for Bids NL06-1. Jeanne d'Arc Basin. 

Spila M., 2005. Application of Ichnology in the Paleoenvironmental Reconstuction and Reservoir Characterization of the Avalon Ben Navis Formations, Hibernia Field, Jeanne d’Arc Basin, Grand Banks of Newfoundland, doctor thesis, University of Alberta/

Monday, 30 December 2013

The Avalon Formation



In this note I want to describe the Avalon Formation. Deposition of this unit was mainly controlled by tectonism. 
The Avalon Formation consist of cycles, which are characterized by siliciclastic dominance (Fig. 1). The formation begins with calcareous limestones and sandstones which  are assigned to the ‘A’ Marker member.  The ‘A’ Marker member at the bottom contact with the Whiterose Formation, which is represented by silty shales. The thickness of the member regionally changes. Sandstones are developed as quartzose, very fine to fine-grained. Cement of this sandstones is mainly calcitic. Bioclastic debris is present. Limestones which also are assigned to the ‘A’ Marker member are bioclastic, peloidal, oolitic and contain high amounts of sand grains. Thin interbeds of red, green and grey shales occur locally. (Sinclair, 1992)


Fig. 1. Correlation of the particular units. South Mara C-13 to North Ben Navis M-61. It can be observed shoaling -upward cycles of the Avalon Formation. (after: Sinclair, 1992).




Deposits of this member in the southern part of the Jeanne d’Arc Basin, contrary to the northern part are more abundant in sand grains, which indicates that clastics derived from the south. Oolites formed on sand grains and have calcite coats. Oolites are indicative of wave-dominated, shallow-marine environment. In the southern part developed more thin beds of oolitic, bioclastic limestones, which make known more distal environment. Bioclatic debris are also characteristic of this kind of environment. It was interpreted that deposits formed in shoals, lagoons and barriers. (Sinclair, 1992).
Green, grey, red shales were deposited in marsh environment which occured at the end of the deposition of the regressive 'A' Marker member.
The top of the ‘A’ Marker member is sharp and is overlied by coarsening-upward sandstones cycles  Sandstones are silty and composed of very fine grains, cemented by silica. Sandstones are generally bioturbated. At the base of this sandstones occur intercalations of grey shales, which are also bioturbated. Upward sandstone change gradually into more clean without silt, cross-beded, fine to medium grained  also bioturbated and cemented by silica. This cycle represents transition from offshore to shorface environment. (Fig. 1). Clean sandstones represent lower to middle shorface. Upward changing to coarser grain is a record of coastline progradation.
This coarsening-upward, shoaling sandstones are repetitive and was interpreted as record of episodic progradation or shifting of point sources  and delta lobes connected with avulsion.
The Avalon Formation is ended by angular mid-Aptian unconformity. This unconformity is observed on the seismic sections and is reflected as truncation of reflectors (Fig. 2)(Sinclair, 1992).


Fig. 2. Seismic Section. The southern part of the Jeanne d'Arc Basin (after: Sinclair, 1992).


Above the unconformity lie rocks, which are assigned to the Ben Navis Formation. The Ben Navis Formation is mainly represented by sandstones. This unit is divided into the Gambo member constituting the bottom of the formation and fining-upward sandstone sequence. 



Fig. 3. Carbonaceous conglomarates assigned to the Gambo member overlie truncated section of sandstones of the Avalon formation. (from Sinclair, 1992). 

The main factor which controlled sedimentation of the Avalon Formation was tectonism. The Avalon sequence was deposited when thermal subsidence took place, which occured after Late Cimmerian rifting. Barremian to Aptian time was characterized by huge detritus input from the south. The progradation of coastline was into the north. During this time, the Avalon Uplift was rejunvenated and it was the main alimentation area.  The 'A' Marker member has similar thickness, the same litology and the paleoenvironmental facies, and it was interpretated as lack of active faulting during mid-Baremian deposition. Late Baremian-early Aptian deposites, which lie above the 'A' Marker member has different thickness. It was caused by subsidence increasing to the north and progressing uplift and erosion of the Avalon Uplift. During deposition of the Avalon Formation only the Murre fault was active. It was reflected by higher thickness off the Mure Fault (Fig.4). 


Fig. 4. Izopach map of sediments of the Avalon Formation without the Egret Member (from Sinclair, 1992).


In mid-Aptian conditions, which controlled deposition in the Jeanne d’Arc Basin changed and was created unconformity, which defines the top of the Whiterose/Avalon sequence. Such conditions lasted till late Albian. This period is characterized by active faulting. North-east and south-east faults was active and distinctive changes in deposits thickness occur across this zone. All sediments of the Ben Navis and the Nautilus Formation deposited under active-faulting conditions and it has an refelection on difference of thickness. The sedimentary package and underlying basmenent was fractured in mid-Aptian.

To sum up, main factors which controlled depostion of the Avalon Formation was subsidence and sediment input. 



Wish you a Happy New Year, by the way. :)
Cheers,
~ Weronika







Sinclair K., 1992. Tectonism: The dominant factor in mid-Creataceous deposition in the Jeanne d'Arc Basin, Grand Banks, Marine and Petroleum Geology, Vol. 10, No. 6, 530-549.