Your SlideShare is downloading. ×

Relatório de reservas da OGX

2,078
views

Published on

Published in: Business, Technology

0 Comments
0 Likes
Statistics
Notes
  • Be the first to comment

  • Be the first to like this

No Downloads
Views
Total Views
2,078
On Slideshare
0
From Embeds
0
Number of Embeds
7
Actions
Shares
0
Downloads
3
Comments
0
Likes
0
Embeds 0
No embeds

Report content
Flagged as inappropriate Flag as inappropriate
Flag as inappropriate

Select your reason for flagging this presentation as inappropriate.

Cancel
No notes for slide

Transcript

  • 1. 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.
  • 2. DeGolyer and MacNaughton 5001 Spring Valley Road 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
  • 3. DeGolyer and MacNaughton 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
  • 4. DeGolyer and MacNaughton 5001 Spring Valley Road 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 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.
  • 5. 2 DeGolyer and MacNaughton 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.
  • 6. 3 DeGolyer and MacNaughton 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.
  • 7. 4 DeGolyer and MacNaughton 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
  • 8. 5 DeGolyer and MacNaughton 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
  • 9. 6 DeGolyer and MacNaughton 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.
  • 10. 7 DeGolyer and MacNaughton 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
  • 11. 8 DeGolyer and MacNaughton 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.
  • 12. 9 DeGolyer and MacNaughton 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
  • 13. 10 DeGolyer and MacNaughton 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
  • 14. 11 DeGolyer and MacNaughton 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.
  • 15. 12 DeGolyer and MacNaughton 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.
  • 16. 13 DeGolyer and MacNaughton 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.
  • 17. TABLE 1 SUMMARY of GROSS and NET OIL RESERVES as of JUNE 30, 2013 for the TUBARÃO MARTELO FIELD 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.
  • 18. TABLE 2 PROJECTION of PROVED-plus-PROBABLE RESERVES and FUTURE NET REVENUE as of JUNE 30, 2013 of the TUBARÃO MARTELO FIELD in BRAZIL attributable to OGX PETRÓLEO E GÁS PARTICIPAÇÕES S.A. 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
  • 19. TABLE 3 PROJECTION of PROVED-plus-PROBABLE-plus-POSSIBLE RESERVES and FUTURE NET REVENUE as of JUNE 30, 2013 of the TUBARÃO MARTELO FIELD in BRAZIL attributable to OGX PETRÓLEO E GÁS PARTICIPAÇÕES S.A. 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