Relatório de reservas da OGX

DeGolyer and MacNaughton
5001 Spring Valley Road
Suite 800 East
Dallas, Texas 75244
This is a digital representation of a DeGolyer and MacNaughton report.
This file is intended to be a manifestation of certain data in the subject report and as such are
subject to the same conditions thereof. The information and data contained in this file may be
subject to misinterpretation; therefore, the signed and bound copy of this report should be
considered the only authoritative source of such information.

Suite 800 East
Dallas, Texas 75244
APPRAISAL REPORT
as of
JUNE 30, 2013
on
RESERVES
of the
TUBARÃO MARTELO FIELD
in the
CAMPOS BASIN, BRAZIL
owned by
OGX PETRÓLEO e GÁS PARTICIPAÇÕES S.A.
EXECUTIVE SUMMARY

TABLE of CONTENTS
Page
FOREWORD............................................................................................................1
Scope of Investigation ................................................................................................1
Authority................................................................................................................3
Source of Information ............................................................................................3
DEFINITION of RESERVES................................................................................4
ESTIMATION of RESERVES...............................................................................7
VALUATION of RESERVES.................................................................................9
SUMMARY and CONCLUSIONS.......................................................................13
TABLES
Table 1 – Summary of Gross and Net Oil Reserves
Table 2 – Projection of Proved-plus-Probable Reserves and Future Net Revenue
Table 3 – Projection of Proved-plus-Probable-plus-Possible Reserves and Future
Net Revenue

Suite 800 East
Dallas, Texas 75244
APPRAISAL REPORT
as of
JUNE 30, 2013
on
RESERVES
of the
in the
CAMPOS BASIN, BRAZIL
owned by
OGX PETRÓLEO e GÁS PARTICIPAÇÕES S.A.
EXECUTIVE SUMMARY
FOREWORD
Scope of Investigation This appraisal report as of June 30, 2013,
presents estimates of the extent of the
proved, probable, and possible crude oil reserves and the estimates of the value of
the proved-plus-probable and proved-plus-probable-plus-possible reserves of the
Tubarão Martelo field located in the Campos Basin, Brazil, in which OGX Petróleo e
Gás Participações S.A. (OGX) has represented that it owns a 100-percent working
interest.
Estimates of proved, probable, and
possible reserves presented in this report have been prepared in accordance with the
Petroleum Resources Management System (PRMS) approved in March 2007 by the
Society of Petroleum Engineers, the World Petroleum Council, the American
Association of Petroleum Geologists, and the Society of Petroleum Evaluation
Engineers. These reserves definitions are discussed in detail in the Definition of
Reserves section of this report.

2
Reserves estimated in this report are
expressed as gross and net reserves. Gross reserves are defined as the total
estimated petroleum remaining to be produced from these properties after June 30,
2013. Net reserves are defined as gross reserves after deducting all interests owned
by others, including royalties paid in kind. OGX has represented that its royalty
obligation is paid in cash; therefore, the net reserves do not exclude a volume
associated with the royalty obligation. A summary of the gross and net oil reserves is
shown in Table 1.
This report also presents values that were
estimated for the proved-plus-probable and proved-plus-probable-plus-possible net
reserves using prices and costs, as of June 30, 2013, provided by OGX. In this report,
the prices and costs are held constant for the life of the properties. A detailed
explanation of the future price and cost assumptions is included in the Valuation of
Reserves section of this report. All values in this report are expressed in United
States dollars (U.S.$).
Values of the net reserves in this report
are expressed in terms of estimated future gross revenue, future net revenue, and
present worth. Future gross revenue is that revenue which will accrue to OGX from
the production and sale of the estimated net reserves. Future net revenue is
calculated by deducting operating expenses, capital costs, production taxes, and
Brazilian income taxes from the future gross revenue. Operating expenses include
field operating expenses, transportation expenses, compression charges, and an
allocation of overhead that directly relates to production activities. Present worth is
defined as the future net revenue discounted at a specified arbitrary discount rate
compounded monthly over the expected period of realization. In this report present
worth values using a nominal discount rate of 10 percent are reported in detail and
values using nominal discount rates of 8, 12, 15, 18, and 20 percent are reported as
totals.
Estimates of reserves and future net
revenue should be regarded only as estimates that may change as further production
history and additional information become available. Not only are such estimates
based on that information which is currently available, but such estimates are also
subject to the uncertainties inherent in the application of judgmental factors in
interpreting such information.

3
Authority This report was authorized by
Mr. Luis Carneiro, Chief Executive
Officer, OGX.
Source of Information Information used in the preparation of
this report was obtained from OGX. In the
preparation of this report we have relied, without independent verification, upon
information furnished by OGX with respect to property interests owned, production
from such properties, current costs of operation and development, current prices for
production, agreements relating to current and future operations and sale of
production, and various other information and data that were accepted as
represented. A field examination of the properties was not considered necessary for
the purposes of this report.

4
DEFINITION of RESERVES
The proved, probable, and possible
reserves presented in this report have been prepared in accordance with the PRMS
approved in March 2007 by the Society of Petroleum Engineers, the World
Petroleum Council, the American Association of Petroleum Geologists, and the
Society of Petroleum Evaluation Engineers. The petroleum reserves are defined as
follows:
Reserves are those quantities of
petroleum anticipated to be commercially recoverable by application of development
projects to known accumulations from a given date forward under defined
conditions. Reserves must further satisfy four criteria: they must be discovered,
recoverable, commercial, and remaining (as of the evaluation date) based on the
development project(s) applied. Reserves are further categorized in accordance with
the level of certainty associated with the estimates and may be sub-classified based
on project maturity and/or characterized by development and production status.
Proved Reserves – Proved Reserves are those quantities of petroleum
which, by analysis of geoscience and engineering data, can be
estimated with reasonable certainty to be commercially recoverable,
from a given date forward, from known reservoirs and under defined
economic conditions, operating methods, and government regulations.
If deterministic methods are used, the term reasonable certainty is
intended to express a high degree of confidence that the quantities will
be recovered. If probabilistic methods are used, there should be at
least a 90-percent probability that the quantities actually recovered
will equal or exceed the estimate.
Unproved Reserves – Unproved Reserves are based on geoscience
and/or engineering data similar to that used in estimates of Proved
Reserves, but technical or other uncertainties preclude such reserves
being classified as Proved. Unproved Reserves may be further
categorized as Probable Reserves and Possible Reserves.
Probable Reserves – Probable Reserves are those additional
Reserves which analysis of geoscience and engineering data
indicate are less likely to be recovered than Proved Reserves
but more certain to be recovered than Possible Reserves. It is

5
equally likely that actual remaining quantities recovered will
be greater than or less than the sum of the estimated Proved
plus Probable Reserves (2P). In this context, when probabilistic
methods are used, there should be at least a 50-percent
probability that the actual quantities recovered will equal or
exceed the 2P estimate.
Possible Reserves – Possible Reserves are those additional
reserves which analysis of geoscience and engineering data
suggest are less likely to be recoverable than Probable
Reserves. The total quantities ultimately recovered from the
project have a low probability to exceed the sum of Proved plus
Probable plus Possible Reserves (3P), which is equivalent to the
high estimate scenario. In this context, when probabilistic
methods are used, there should be at least a 10-percent
probability that the actual quantities recovered will equal or
exceed the 3P estimate.
Reserves Status Categories – Reserves status categories define the development and
producing status of wells and reservoirs.
Developed Reserves – Developed Reserves are expected quantities to be
recovered from existing wells and facilities. Reserves are considered
developed only after the necessary equipment has been installed, or
when the costs to do so are relatively minor compared to the cost of a
well. Where required facilities become unavailable, it may be
necessary to reclassify Developed Reserves as Undeveloped. Developed
Reserves may be further sub-classified as Producing or
Non-Producing.
Developed Producing Reserves – Developed Producing Reserves
are expected to be recovered from completion intervals that are
open and producing at the time of the estimate. Improved
recovery reserves are considered producing only after the
improved recovery project is in operation.
Developed Non-Producing Reserves – Developed Non-Producing
Reserves include shut-in and behind-pipe Reserves. Shut-in
Reserves are expected to be recovered from (1) completion

6
intervals which are open at the time of the estimate but which
have not yet started producing, (2) wells which were shut-in for
market conditions or pipeline connections, or (3) wells not
capable of production for mechanical reasons. Behind-pipe
Reserves are expected to be recovered from zones in existing
wells which will require additional completion work or future
recompletion prior to the start of production. In all cases,
production can be initiated or restored with relatively low
expenditure compared to the cost of drilling a new well.
Undeveloped Reserves – Undeveloped Reserves are quantities expected
to be recovered through future investments: (1) from new wells on
undrilled acreage in known accumulations, (2) from deepening
existing wells to a different (but known) reservoir, (3) from infill wells
that will increase recovery, or (4) where a relatively large expenditure
(e.g. when compared to the cost of drilling a new well) is required to
(a) recomplete an existing well or (b) install production or
transportation facilities for primary or improved recovery projects.
The extent to which probable and possible
reserves ultimately may be recategorized as proved reserves is dependent upon
future drilling, testing, and well performance. The degree of risk to be applied in
evaluating probable and possible reserves is influenced by economic and
technological factors as well as the time element. Probable and possible reserves in
this report have not been adjusted in consideration of these additional risks to make
them comparable to proved reserves. There are no proved reserves attributable to
this field.

7
ESTIMATION of RESERVES
Estimates of reserves were prepared by
the use of appropriate geologic, petroleum engineering, and evaluation principles
and techniques that are in accordance with practices generally recognized by the
petroleum industry and in accordance with definitions established by the PRMS.
The method or combination of methods used in the analysis of each reservoir was
tempered by experience with similar reservoirs, stage of development, quality and
completeness of basic data, and production history.
The volumetric method was used to
determine the original petroleum in place. Estimates were made by using various
types of logs, core analyses, and other available data. Formation tops, gross
thickness, and representative values for net pay thickness, porosity, and interstitial
fluid saturations were used to prepare structural maps to delineate each reservoir
and isopachous maps to determine reservoir volumes. Where adequate data were
available and where circumstances justified, material-balance and other engineering
methods were used to estimate the original petroleum in place.
Estimates of ultimate recovery were
obtained by applying recovery efficiency factors to the original quantities of
petroleum in place. These factors were based on consideration of the type of energy
inherent in the reservoir, analysis of the fluid and rock properties, the structural
position of the properties, and the production history. In some instances,
comparisons were made with similar producing reservoirs in the area where more
complete data were available.
Where adequate data were available and
where circumstances justified, material-balance and other engineering methods
were used to estimate recovery factors. In these instances, reservoir performance
parameters such as cumulative production, producing rate, reservoir pressure,
gas-oil ratio behavior, and water production were considered in estimating recovery
efficiencies used in determining gross ultimate recovery.
For depletion-type reservoirs or other
reservoirs where performance has disclosed a reliable decline in producing-rate
trends or other diagnostic characteristics, reserves were estimated by the
application of appropriate decline curves or other performance relationships. In

8
analyzing decline curves, reserves were estimated to the calculated economic limits
based on current economic conditions.
In certain cases where the previously
named methods could not be used, reserves were estimated by analogy with similar
reservoirs where more complete data were available.
Production forecasts of the proved-plus-
probable and proved-plus-probable-plus-possible reserves and corresponding
revenue projections were prepared. These forecasts were prepared using the field
development plan, including the drilling of additional wells. Reserves were limited to
the economic limit as defined in the Definition of Reserves section of this report or
the expiration date of a production license, whichever occurs first.
Crude oil reserves for the Tubarão
Martelo field were estimated using the volumetric method with a static geo-cellular
model and a dynamic reservoir simulation model. The planned field development
included utilizing a floating production, storage, and offloading vessel (FPSO) and
drilling an additional producing well and three water-injection wells. Since only the
proved-plus-probable and proved-plus-probable-plus-possible reserves were economic
cases, no proved reserves were estimated.
A summary of the gross and net oil
reserves of the Tubarão Martelo field is shown in Table 1. Proved reserves have been
estimated to be zero for this field due to the uneconomic nature of the project related
to the proved reserves.

9
VALUATION of RESERVES
This report has been prepared using price
and cost assumptions specified by OGX. Future prices and costs were estimated in
accordance with guidelines established by the PRMS.
Values for probable and possible reserves
were based on projections of estimated future production and revenue prepared for
these properties with no risk adjustment applied to the probable and possible
reserves. Probable and possible reserves involve substantially higher risks than
proved reserves. Revenue values for probable and possible reserves have not been
adjusted to account for such risks; this adjustment would be necessary in order to
make probable and possible reserves values comparable with values for proved
reserves.
Revenue values in this report have been
estimated for the Tubarão Martelo field in accordance with the terms of the
concession agreement. Discussion of the relevant economic parameters follows:
Fiscal Terms
The Government of Brazil’s Petroleum Law n° 9,478, the
Petroleum Law of 1997, affords the Brazilian Government
three elements of government take: 1) petroleum levies
consisting of royalties, a special participation fee, and surface
rentals; 2) direct taxes, which are levied through the corporate
income tax, and two social contribution taxes; and 3) indirect
taxes, which are levies on equipment and services used by
companies engaged in exploration and production activities
(ICMS).
Royalties
The federal royalty rate in Brazil varies by field between 5 and
10 percent. OGX has advised that the royalty obligation for the
Tubarão Martelo field is 10 percent.
Oil royalty is assessed on the market value of the oil (and
condensate), which is defined as the greater of the sales price

10
or the market valuation as determined by the National
Petroleum Agency (ANP). Gas royalty is levied on the market
value of the gas production less gas injected.
Special Participation Fee
The special participation fee (SPF) is a tax assessed at the field
level on a sliding scale basis that varies depending on the
location of the field (onshore or offshore), water depth, level of
production, and number of years on production. The tax basis
for the SPF is similar to the tax basis for corporation tax (CIT)
with some exceptions. Drilling costs are depreciated using a
units-of-production basis for SPF, but expensed for CIT. An
annual provision for abandonment costs is also deductible for
SPF, but expensed in the year incurred for CIT. In years in
which the SPF is paid there is an additional 1-percent research
and development fee assessed.
Surface Rental Fees
Rental fees are payable to the ANP and vary by field,
depending on stage of activity (exploration or development),
geological characteristics, and location of sedimentary basin.
OGX provided the contracted area for the evaluated properties
and the associated stage of activity and corresponding rental
rate in Brazilian reais (R$) per square kilometer.
Corporate Income Tax
Corporation tax in Brazil is assessed on a consolidated entity
basis at a statutory rate of 34 percent. This rate consists of the
base tax rate of 15 percent, surtax of 10 percent, and a social
contribution component of 9 percent. For purposes of this
evaluation, corporation tax was applied on an individual field
basis without considering the effects of consolidation on OGX’s
combined corporate tax liability. OGX has represented that it is
eligible for tax benefits that reduce the corporate tax rate to
15.25 percent through 2023. This benefit is included in the
calculations herein. Additionally, a sunk-cost balance of

11
U.S.$650 million (gross) was provided by OGX as an offset to
future tax liabilities.
Social Contribution Taxes
Two social contribution taxes are levied on the market value of
oil and gas sales. The Contribution for the Worker’s Social
Integration Program (PIS) is assessed at a rate of 1.65 percent
and the Contribution for Social Security Funding (COFINS) is
levied at a rate of 7.6 percent.
Indirect Taxes
OGX has advised that the oil revenue is not subject to an ICMS
levy, as the oil will not be sold domestically.
Oil Prices
OGX provided an oil price of U.S.$110.00 per barrel for Brent
crude with a corresponding field quality discount of 5 percent.
A transportation tariff of U.S.$1.50 per barrel was also
deducted to account for shuttle tanker expenses. This price was
held constant through the life of the evaluation.
Operating Expenses and Capital Costs
Estimates of operating expenses and capital costs were based
on data provided by OGX. Estimates of future costs may vary
from estimates provided by OGX in order to conform to specific
reserves cases. Future operating expense and capital cost
estimates were not adjusted for the effects of inflation.
Abandonment Costs
Abandonment costs were estimated based on data provided by
OGX. These costs were not adjusted for the effects of inflation.

12
Exchange Rate
An exchange rate of R$2.04 per U.S.$1.00 has been provided by
OGX and used to convert the respective currencies.
Detailed summaries of the future net
revenue for the proved-plus-probable and proved-plus-probable-plus-possible
reserves are presented in Tables 2 and 3.

13
SUMMARY and CONCLUSIONS
OGX has represented that it owns a
100-percent working interest in the Tubarão Martelo field located in the Campos
Basin offshore Brazil. The estimated gross and net proved, probable, and possible
reserves of the Tubarão Martelo field, as of June 30, 2013, are summarized as
follows, expressed in thousands of barrels (Mbbl):
Oil Reserves
Gross
(Mbbl)
Net
(Mbbl)
Proved 0 0
Probable 87,891 87,891
Possible 20,591 20,591
Note: Probable and possible
reserves have not been risk
adjusted to make them
comparable to proved
reserves.

TABLE 1
SUMMARY of GROSS and NET OIL RESERVES
as of
JUNE 30, 2013
for the
in
BRAZIL
for
OGX PETRÓLEO E GÁS PARTICIPAÇÕES S.A.
Gross Net
Proved Probable Possible Proved Probable Possible
(Mbbl) (Mbbl) (Mbbl) (Mbbl) (Mbbl) (Mbbl)
0 87,891 20,591 0 87,891 20,591
Note: Probable and possible reserves have not been risk adjusted
to make them comparable to proved reserves.

TABLE 2
PROJECTION of PROVED-plus-PROBABLE RESERVES and FUTURE NET REVENUE
as of
JUNE 30, 2013
of the
in
BRAZIL
attributable to
After After
Corporation Corporation
PIS, Tax Tax
Future COFINS, and Corporate Future Present
Net Production Sales Prices Gross Royalty Operating Capital Indirect Income Net Worth at
Oil Gas Oil Gas Revenue Paid in Cash Expenses Costs SPF Taxes Taxes Revenue 10 Percent
Year (Mbbl) (MMcf) (U.S. $/bbl) (U.S. $/Mcf) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$)
2013 (6 mos) 635 0 103.00 - 65,405 6,558 23,990 255,900 0 120 0 (221,163) (214,853)
2014 6,268 0 103.00 - 645,604 64,893 288,000 145,800 0 120 24,434 122,357 110,346
2015 3,434 0 103.00 - 353,702 35,548 280,200 520,000 0 120 0 (482,166) (393,617)
2016 5,960 0 103.00 - 613,880 61,678 295,000 0 0 120 0 257,082 189,976
2017 7,592 0 103.00 - 781,976 78,533 270,000 0 0 120 0 433,323 283,734
2018 7,529 0 103.00 - 775,487 77,868 295,000 0 0 120 36,325 366,174 218,029
2019 7,221 0 103.00 - 743,763 74,678 270,000 0 0 120 40,691 358,274 196,379
2020 6,805 0 103.00 - 700,915 70,378 295,000 0 0 120 40,837 294,580 146,162
2021 6,360 0 103.00 - 655,080 65,778 270,000 0 0 120 43,775 275,407 123,696
2022 5,723 0 103.00 - 589,469 59,194 295,000 0 0 120 30,960 204,195 83,019
2023 5,142 0 103.00 - 529,626 53,187 270,000 0 0 120 66,183 140,136 51,574
2024 4,543 0 103.00 - 467,929 46,996 295,000 0 0 120 42,776 83,037 27,663
2025 3,893 0 103.00 - 400,979 40,280 270,000 0 0 120 30,797 59,782 18,028
2026 3,465 0 103.00 - 356,895 35,857 295,000 0 0 120 8,812 17,106 4,670
2027 3,115 0 103.00 - 320,845 32,237 205,000 0 0 120 28,386 55,102 13,616
2028 2,864 0 103.00 - 294,992 29,644 230,000 0 0 120 11,978 23,250 5,201
2029 2,630 0 103.00 - 270,890 27,223 205,000 0 0 120 13,106 25,441 5,151
2030 2,440 0 103.00 - 251,320 25,258 230,000 0 0 120 0 (4,058) (744)
2031 2,272 0 103.00 - 234,016 23,520 205,000 0 0 120 448 4,928 818
2032 0 0 - - 0 0 113,000 0 0 0 0 (113,000) (16,971)
2033 0 0 - - 0 0 0 0 0 0 0 0 0
2034 0 0 - - 0 0 0 0 0 0 0 0 0
2035 0 0 - - 0 0 0 0 0 0 0 0 0
2036 0 0 - - 0 0 0 0 0 0 0 0 0
2037 0 0 - - 0 0 0 0 0 0 0 0 0
Total 87,891 0 9,052,773 909,308 4,900,190 921,700 0 2,280 419,508 1,899,787 851,877
After Corporation Tax
Present Worth (M U.S.$) at:
8 Percent 1,004,420
Notes: 12 Percent 719,515
1. Explanation of abbreviations – Special Participation Fee (SPF). Contribution for the Worker’s Social Contribution Fund (PIS). Contribution for the Social Security Funding (COFINS). 15 Percent 552,941
2. OGX has represented that PIS and COFINS liabilities are not applicable to this project. 18 Percent 417,963
3. Probable reserves and the values associated with probable reserves have not been risk adjusted to make them comparable to proved reserves. 20 Percent 342,400

TABLE 3
PROJECTION of PROVED-plus-PROBABLE-plus-POSSIBLE RESERVES and FUTURE NET REVENUE
as of
JUNE 30, 2013
of the
in
BRAZIL
attributable to
After After
Corporation Corporation
PIS, Tax Tax
Future COFINS, and Corporate Future Present
Net Production Sales Prices Gross Royalty Operating Capital Indirect Income Net Worth at
Oil Gas Oil Gas Revenue Paid in Cash Expenses Costs SPF Taxes Taxes Revenue 10 Percent
Year (Mbbl) (MMcf) (U.S. $/bbl) (U.S. $/Mcf) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$) (M U.S.$)
2013 (6 mos) 635 0 103.00 - 65,405 6,557 23,990 255,900 0 120 0 (221,162) (214,852)
2014 6,268 0 103.00 - 645,604 64,875 288,000 145,800 0 120 24,436 122,373 110,360
2015 3,886 0 103.00 - 400,258 40,218 280,200 520,000 0 120 0 (440,280) (359,423)
2016 7,424 0 103.00 - 764,672 84,504 295,000 0 746 120 0 384,302 290,216
2017 9,802 0 103.00 - 1,009,606 111,551 270,000 0 11,561 120 48,798 567,576 378,807
2018 9,079 0 103.00 - 935,137 103,313 295,000 0 7,022 120 60,626 469,056 284,023
2019 8,551 0 103.00 - 880,753 97,300 270,000 0 4,739 120 57,410 451,184 247,305
2020 7,969 0 103.00 - 820,807 90,676 295,000 0 2,336 120 55,668 377,007 187,059
2021 7,164 0 103.00 - 737,892 74,105 270,000 0 0 120 55,133 338,534 152,049
2022 6,390 0 103.00 - 658,170 66,105 295,000 0 0 120 40,383 256,562 104,309
2023 5,686 0 103.00 - 585,658 58,829 270,000 0 0 120 83,315 173,394 63,814
2024 5,100 0 103.00 - 525,300 52,769 295,000 0 0 120 60,320 117,091 39,008
2025 4,621 0 103.00 - 475,963 47,813 270,000 0 0 120 53,730 104,300 31,453
2026 4,265 0 103.00 - 439,295 44,133 295,000 0 0 120 34,014 66,028 18,024
2027 3,921 0 103.00 - 403,863 40,575 205,000 0 0 120 53,777 104,391 25,796
2028 3,603 0 103.00 - 371,109 37,286 230,000 0 0 120 35,259 68,444 15,310
2029 3,304 0 103.00 - 340,312 34,194 205,000 0 0 120 34,339 66,659 13,497
2030 3,034 0 103.00 - 312,502 31,400 230,000 0 0 120 17,334 33,648 6,167
2031 2,796 0 103.00 - 287,988 28,940 205,000 0 0 120 18,336 35,592 5,905
2032 2,601 0 103.00 - 267,903 26,921 230,000 0 0 120 3,693 7,169 1,077
2033 2,383 0 103.00 - 245,449 24,670 205,000 0 0 120 5,324 10,335 1,405
2034 0 0 - - 0 0 113,000 0 0 0 0 (113,000) (13,906)
2035 0 0 - - 0 0 0 0 0 0 0 0 0
2036 0 0 - - 0 0 0 0 0 0 0 0 0
2037 0 0 - - 0 0 0 0 0 0 0 0 0
Total 108,482 0 11,173,646 1,166,734 5,335,190 921,700 26,404 2,520 741,895 2,979,203 1,387,403
After Corporation Tax
Present Worth (M U.S.$) at:
8 Percent 1,614,473
Notes: 12 Percent 1,192,500
1. Explanation of abbreviations – Special Participation Fee (SPF). Contribution for the Worker’s Social Contribution Fund (PIS). Contribution for the Social Security Funding (COFINS). 15 Percent 949,623
2. OGX has represented that PIS and COFINS liabilities are not applicable to this project. 18 Percent 754,317
3. Probable and possible reserves and the values associated with probable and possible reserves have not been risk adjusted to make them comparable to proved reserves. 20 Percent 645,336

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