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AAPG HEDBERG CONFERENCE Near-Surface Hydrocarbon Migration: Mechanisms and Seepage Rates APRIL 7-10, 2002, VANCOUVER, BC, CANADA Exploration Studies using Surface Geochemical Data: Case Studies in the Eastern and Western Venezuelan Basins

ROMERO, IRENE; Sequera, Zoraima; Perdomo, Ender; Ruggiero Armando; Arrieche Morrella; Zambrano, Carmen; Odehnal, Marco; and Giraldo, Carlos PDVSA, Caracas-Venezuela The detection of soil-gas anomalies is a useful tool for hydrocarbon exploration studies. The key to reliable soil-gas data interpretation is the way in which this technique is applied and understood, since there is a large number of geological factors that can affect the expression of gas anomalies on the surface, such as: depth, reservoir quality, seal integrity, and presence of fractures/faults. In addition, other minor effects like soil-type and meteorological changes have been reported (Jones et al., 2000). Since 1993, several surface geochemical surveys were conducted in Venezuela for exploration studies, covering 7.500 Km2 with free soil gas data, 6.000 Km2 with sorbed soil gas data, and around 700 Km2 with microbial techniques. Also, there are some offshore areas with sniffer data. (See Figure 1). The signal intensity that has been registered in onshore exploration areas with free soil gas data varies significantly, with an ethane-median from 30 ppb in producing areas to more than 900 ppb in some non-producing areas. Nevertheless, the laboratory calibration might affect these magnitudes. Recent efforts to optimize geological-geochemical models of exploration studies have required a review of numerous surface geochemical data, specially using free soil gas data, which have matched well with the geological and structural data.

Calibration

Data of 152 well-head gases of more than 24 production fields located in Western and Eastern Venezuela have been used to calibrate the free soil gas data, using Pixler gas ratios. The results show 4 zones in which the composition of the surface-gas can be correlated with the underlying reservoirs of: heavy/segregates crudes (Zone 1), medium&light crudes (Zone 2), free gas (Zone 3) and dry gas/biodegraded crudes (Zone 4). (See Figure 2). Table 1 shows the calibration ranges that have resulted from this work to infer the probable subsurface hydrocarbons accumulations using free soil gas data. The ranges for medium and light crude oils could not be well differentiated. The depletion degree of the fields and its gas/oil ratios could alter the real location of the curves in the pixler graph. Probably isotopic analysis may contribute to have a better definition of these pixler traces, with the real association of the gases with their own fluids through the isotopic fingerprints. The results of this work are quite similar to those for the ranges of medium & light crudes and gas reported by Jones & Drozd (1983). However, major differences occur for the ranges of some heavy and extra-heavy crudes. The high values of methane obtained in gas samples were related with probable contributions from biodegradation processes. These processes are also common in some Canadian shallow reservoirs (Rich et al., 1994).

Romero, et al These calibration ranges were tested in three producing fields using Pixler graphs, to compare anomalous soil gas samples with well-head gases. The results show good agreement of the surface oil predictions with the production data, specially with the C2/C3 gas ratio less affected by biodegradation processes. The displacement observed in Oil Field 2 might be associated to different origins of the sources. (See Figure 3).

CASE 1:

350 free soil gas samples were taken by PDVSA in a 70-Km2 region located in the Eastern Venezuela Basin. In this area a wild cat was drilled recently. The ethane data in this area showed a normal asintotic distribution (from 0 to 3,000 ppb), that has been separated with the ethane-median to differentiate the non anomalous samples from the anomalous ones. Distribution resulted in about 50% of the samples in each group. This statistic has been quite consistent in all the studied areas. The bubble map of ethane displayed over the shallow structural features of the area showed excellent alignments of the higher surface gas anomalies with the flanks and tops of two shallow structural highs. On the other hand, lower gas anomalies were located along the syncline that separate these two highs. This effect can be understood by the preferential migration of the gases to the flanks and tops of the highs, that decreases the signals in the deeper parts. Close to the exploratory location some lower gas anomalies were also detected. (See Figure 4). On the other hand, the structural section North-South with stratigraphic data presents the location of oil shows at 1 sec depth (5000 feet). The surface ethane bubbles along this section are found aligned with the shallow structural high illustrated in the previous ethane bubble map, and also close to the south part of the exploratory location. (See figure 5). The area where oil shows were detected was analyzed by a special epi-fluorescence technique developed at PDVSA-Intevep. Cutting samples at a depth from 3,900' to 7.500' were taken to be submitted on color and intensity fluorescence variation associated with the oil composition and maturity (Ruggiero et al., 2001). The fluorescent results showed an estimated API distribution between 15° to 30° API gravity, discarding the mud interference. This API range matches the prediction of the surface gas data, proposing that the source of the surface gas anomalies might be the oil shows. In addition, the shallow structural highs in this area might focus on the gas migration to the surface from it. Actually, other deeper sources are being studied until completion of the wild cat evaluation. In thrusted areas like case study 1, different migration pathways of the hydrocarbons to surface may difficult the integration between surface and subsurface data.

CASE 2:

The second example is in a 375-Km2-exploration area located in Western Venezuela. In this case, 725 "free soil gas" data (ETI Job 97-516) showed an ethane distribution with similar pattern to that in Case Study 1, with 50% of non-anomalous samples. However, the signal intensity of ethane (from 0 to 66,000 ppb) and heavier hydrocarbons were higher by more than one order of magnitude. Outcrop samples of La Luna Formation (source rock in this area) showed reflectance values in the Oil Window, and original Total Organic Carbon (TOC) between 1 and 5 %. In addition, the generation potential was estimated between 500 to 600 mg HC/g TOC. All this data suggest excellent conditions to have an active "Kitchen Area", where important surface gas anomalies are also found. These results have been confirmed with geochemical modeling, which indicate that the hydrocarbon expulsion is still ongoing and is feeding the oil seeps located in the study area (Gallango et al., 2001). (See figure 6).

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Romero, et al The surface observation of the "Generation Area" was also studied by remote sensing data, in which spectral anomalies related to stressed vegetation were detected (Arrieche et al., 2001). Other magnetic susceptibility measurements were conducted to confirm the location of anomalous zones in this area related with hydrocarbons gas leakage (Aldana, et al., 2001). On the other hand, the structural section West­East aligned with the surface ethane bubbles, shows the "Generation Area", which is active only in the Eastern part. The main Cretaceous reservoir rock is located above La Luna source rock, with oil migration pathways indicated by blue arrows. In this section, larger gas anomalies were found aligned with the flanks and top of one of the most important exploratory location of this area, showing a "Halo Effect". Also, there are important anomalies in which an oil seep was located, and other gas anomalies were found aligned with a fault merging to the surface. (See figure 7). Nowadays, PDVSA is studying the economics of the exploratory locations of this area.

References:

Aguasuelos Ingeniería and Exploration Technologies. (1997). Surface Geochemical Evaluation, Rubio Study Area.Tachira State, Venezuela. ETI Job NUMBER 97-516. October 16. Aldana, M.; Díaz, M.; Costanzo-Alvarez, V.; González, F.; Romero, I. (2001) EPR studies in soil samples from a prospective area at the Andean Range, Venezuela. Revista Mexicana de Física. To be published. Arrieche, M.; Vera, A.; Romero, I.; González, M. and Gala, S. (2000) Use of Remote Sensing and Field Reflectance Data Integrated with Surface Geochemistry and Geology for Detecting Possible Areas of hydrocarbon Presence. VII Simposio Bolivariano de Exploración de Cuencas Subandinas. Caracas, Venezuela Gallango, O.; Fintina, C.; Zambrano, C. and Novoa, E. (2001) Petroleum System of the Rubio Block, Mérida, Los Andes, Venezuela. 20th International Meeting on Organic Geochemistry. Abstract Volumen 1, Nancy - France, p.137. Jones, V. and Drozd, R.J. (1983) Predictions of oil and gas potential by near surface geochemistry. AAPG Bulletin, 67, 932-952. Jones, V.T.; Matthews, M.D. and Richers, D.M. (2000) Light hydrocarbons for petroleum and gas prospecting, in M.Hale, ed., Geochemical Remote Sensing of the Subsurface: Handbook of Exploration Geochemistry, Vol7 (G.J.S. Govett, ed.): Elseiver Science B.V., p. 133-212. Rich, K.; Muehlenbachs, K.; Greenwood, G.; Ehrich, K. (1994) Characterization of migrating gas in Heavy Oil Fields of Alberta by Stable Isotope Analyses. 4th Annu Environ CAN et al Groundwater & Soil Remediation Symp (Calgary, CAN, 9/21-23/94) Proc PP 425-433, 1994. Ruggiero, A.; Gallango O.; Suarez, H.; and Savian, V. (2001) Applications of epi-fluorescence as a tool for the estimation of the crude quality in reservoirs. 20 th. International Meeting on Organic Geochemistry, 10-14 September, Nancy, France.

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Figure 1: Areas with surface geochemical data

Caribbean Sea

Atlantic Ocean

Guyana

VENEZUELA

Colombia 9.000 km2 6.000 km2 700 km2 20.000 km2

200 kms

Free soil gas Sorbed soil gas Microbial data Sniffers data

Brazil

Figure 2: Pixler Graph with Venezuelan Well-Head Gases

100000

Dry Gas Well 1 Dry Gas Well 2 Dry Gas Well 3 Dry Gas Well 4 Dry Gas Well 5 Dry Gas Well 6 Dry Gas Well 7 Gas Well 1 Gas Well 2 Extraheavy Oil Field 1 Extraheavy Oil Field 2

10000

"Dry Gas"/ Biodegraded Crudes

1000

Extraheavy Oil Field 3 Extraheavy Oil Field 4 Heavy Oil Field 1 Heavy Oil Field 2 Heavy Oil Field 3 Heavy Oil Field 4

8-16°API

100

Gas Medium / Light Crudes

Heavy / Segregated Crudes

Condensate Oil Field 1 Condensate Oil Well ALBERTA FOOT HILLS (Gas/Condensate) Light Oil Field 1 Light Oil Field 2 Light Oil Field 3 Light Oil Field 4 Light Oil Field 5 Light Oil Field 6 Light Oil Field 7

10

Non Productive C1/C2 C1/C 3

20-50°API

Light Oil Field 8 PERMIAN BASIN (Crude Oil)

1

Gas Ratios

C1/nC 4

C2/C3*10

Medium Oil Field 1 Medium Oil Field 2 Medium Oil Field 3 Medium Oil Well (segregate) NO PRODUCTIVE

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Romero, et al

Table 1: Pixler correlations with well-head-gas data of Venezuelan oil fields

Pixler Gas Ratios

C1/C2

ZONE 4 ZONE 3 ZONE 2 ZONE 2 ZONE 1 Dry Gas/Biodegraded Crudes Gas Light/ Medium Crudes Heavy/Spilled/Segregated Crudes >100 20,1 - 100 10,1 - 20 4,0 - 10 <4

C1/C3

>160 40,1 - 160 20,1 - 40 5,0 - 20 <5

C2/C3

>45 30,1 - 45 20,1 - 30 15,0 - 20 <15

Figure 3: Validation of the calibration ranges with surface anomalous samples in three Venezuelan production fields.

OilOil Field 1 1 Field

100000

(34- 40 °API)

Dry Gas / Biodegraded Crudes

Oil Field2 2 Oil Field

100000

(40- 50 °API)

Dry Gas / Biodegraded Crudes

Oil Field 3 Oil Field 3

100000

(18 - 24 °API)

Dry Gas / Biodegraded Crudes

10000

10000

10000

1000

1000

1000

Gas

100

Gas

100

100

Gas

Light / Medium Crudes

10

Heavy / Segregate Crudes

1 Non productive

10

Light / Medium Crudes Heavy / Segregate Crudes

Marine Terrestrial?

?

Light / Medium Crudes

10

Heavy / Segregate Crudes

1 Non productive

1

Non productive

C1/C2

C1/C3

C1/nC4

C2/C3*10

C1/C2

C1/C3

C1/nC4

C2/C3*10

C1/C2

C1/C3

C1/nC4

C2/C3*10

Gas Ratios

Gas Ratios

Gas Ratios

Free Soil

Gases Gases Well Head

Gases Well Head Gases

Free Soil

Gases Well Head Gases

Free Soil

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Romero, et al

CASE 1

Figure 4: Bubble map of ethane (ppb) overlapped to the shallow structural features of the area.

Exploratory Location Shallow Structural Features Interpreted seismic lines

N

N

ENE

WSW

C2/C3 >45 3.5-4.5 2.5-3.5 1.5-2.5 <1.5

ENE

0 500 850 1700

S

Ethane (ppb)

2 kms

Figure 5: Structural section N-S with surface ethane bubbles along it.

Legend Mid. Mio.Pleistocene Lower Miocene Oligocene

Inmature Source Rock

TWTT (sec) TWTT (msec)

Upper Cretaceous Lower Cretaceous Shallow Structural High Oil Shows Oil Accumulation

Ovemature Source Rock

Wild Cat Apraisal well 11 Km

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Romero, et al

CASE 2

Figure 6: Contour map of ethane overlapped to the structural map (top) of La Luna source rock

Structural map (top) of La Luna source rock

Generation Area

Ethane (ppb)

Interpreted seimic line 2 kms 7 kms

Original TOC Original S2

3-5% 500-600 mgHc/g.TOC

Gallango et al., 2001

Figure 7: Structural section W-E with surface ethane bubbles along it.

Legend Seal Reservoir Reservoir Seal Source Rock (La Luna) Main Reservoir Reservoir Faults Upper Cretaceou s Lower Cretaceou s Eocene (Paleocene)

15 Km 7

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