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Unfortunately,
spud or completion dates are not available for 62% of the well population,
but Figure 4 illustrates from the known population
the significant amount of drilling that began in the mid 1940s (most early
wells classified as outposts) and has continued to present. In recent years,
the numbers of wells categorized as new field wildcats and exploratory
wells have increased relative to those classified as outposts and development wells.
PETROLEUM OCCURRENCE
Geographic
and Stratigraphic Location
Oil seeps and tar sands are common in the Timan-Pechora Basin, even within
Precambrian (Riphean) rocks of the Timan Ridge (Sobornov and Yakovlev,
1996). Petroconsultants (1996) lists 257 fields within the province (Table
1), but 31 fields have no production or reserve data published. For
the Timan-Pechora Basin Province, known ultimate recoverable reserves of
nearly 20 BBOE are distributed as 66% oil, 30% gas and 4% condensate. Five
fields are significantly distant from the mainland (Figure
1 and Figure 5). The two northernmost fields
on Kolguyev Island are likely associated with a different petroleum system
in the offshore South Barents Sea Basin (Table
1).
Foredeep basins on the east side of the Timan-Pechora Basin Province are
gas dominated, as are both the southwesternmost area along the Timan Ridge
and the northern coastal region of the Shapkino-Yuryakha and Lay Swells
(northern part of Pechora-Kolva Aulacogen, Figure 1).
The southern foredeep (Upper Pechora Trough) contains the province’s largest
field – Vuktyl, with nearly 50% of the province’s known recoverable gas
– but northeastern foredeep basins (Kosyu-Rogov and Korotaikha) are sparsely
explored. The northern Izhma-Pechora Depression contains few fields despite
having approximately 100 well penetrations. Offshore Timan-Pechora has
both oil and gas fields, and fewer than a dozen offshore exploratory wells
have been drilled away from islands.
Hydrocarbons are trapped in Ordovician through Triassic
reservoir rocks at 200 to 4500 meter depths (Kiryukhina, 1995). Scenarios
for multi-stage hydrocarbon migrations and remigrations are possible, particularly
in the Ural foredeeps, because of regionally variable burial history and
the province’s repeated tectonism (Bogatsky and Pankratov, 1993).
Most oil is reservoired in tectonically stable areas with stratigraphic
traps (Bogatsky and Pankratov, 1993). Conversely, most gas (alone or with
oil) is in active tectonic areas where more recent gas charging could have
occurred.
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Late Cenozoic Uralian uplift probably
resulted in cooling and decompression of formation fluids, allowing gas
to come out of solution and accumulate in traps (Sobornov and Rostovshchikov,
1996).
Geochemistry of Hydrocarbons(Continued
on Next Page)
Timan-Pechora hydrocarbons range from high gravity, low sulfur and low
resin oils with paraffin bases to low gravity, high sulfur and high viscosity
oils of dominantly aromatic-napthenic compositions (Kiryukhina, 1995).
Sulfur content is related to the presence of evaporites, and Kosyu-Rogov
(foredeep basin) gases contain H2S. Commonly, oils in stratigraphically
older reservoirs have lower density, fewer asphaltenes and more residual
components than those in stratigraphically younger reservoirs (Meyerhoff,
1980). Biodegradation occurs in shallow accumulations. Province-wide, oil
gravity ranges from 11° -62°
API and condensate gravity from 45° -79°
API (Petroconsultants, 1996). From the same reservoir and test data, mean
and median API gravity is 35° , and GOR
has a mean of 393 cfg/bo and a median of 289 cfg/bo (range 7 to 1500 cfg/bo).
The higher end of the GOR range is probably the more appropriate characterization
for this province.
Oil attributed to Upper Devonian ("Domanik")
source rock has the following characteristics (Abrams and others, 1999):
- Pristane/phytane >1 and <2
- Smooth distribution of n-alkanes, with a maximum at C11
- C15
- Saturates/aromatics < or = 1
- Abundant C28+
- d13C saturates
and aromatics @ -29
- Sulfur content = 1 - 4.5 wt %
- Normal to low tricyclics with C24 > C26
- C29 hopanes < or = C30 hopanes
- Generated at conditions less than peak oil for typical
type II kerogens
Hydrocarbons from other source rocks have geochemical
distinctions.Ordovician- to Silurian-sourced oils have pristane/phytane
= 1; a sawtooth alkane distribution with a predominance up to C19, odd
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