OGX Petróleo e Gás Participações S.A. (Bovespa: OGXP3), Brazil’s largest private oil and natural gas exploration company, announces its third quarter results for 2012.
GTU Process Plant View
|Key Financial Metrics||3Q 2012||YTD 2012|
|Revenues (R$ mm)||150.7||150.7|
|EBITDA – Pro forma¹ (R$ mm)||(51.6)||(305.1)|
|Net Profit (Loss) (R$ mm)||(343.6)||(887.1)|
|Realized oil price per barrel (US$)²||95||95|
|CAPEX (R$ mm)||(1,115)||(3,186)|
|Production volume (kboepd)||9.3||9.7 ³|
|¹ Considers OGX Campos|
|² Refers to the cargo booked as revenues (delivered on July 26, 2012)|
|³ Production volume from January 31, 2012 to September 30, 2012|
Luiz Carneiro, Chief Executive Officer of OGX, said: “OGX reached a new and important milestone in the third quarter, posting revenues from the sale of approximately 800,000 barrels for the first time since the company began commercial production. We are pleased to note that we have achieved this milestone, and, besides that we obtained an 80% success rate in our exploratory and appraisal campaign since the beginning of the year.”
“Production is progressing well and is on schedule in the Campos Basin, and a third production well in the Tubarão Azul Field will be connected in the coming weeks. In exploration, we began drilling new prospects in the Campos Basin where we continue to have strong expectations for our activities. In addition, we are continuing to develop the Tubarão Martelo Field, in the Campos Basin, and the Gavião Real Field project in the Parnaíba Basin where we expect to begin commercial gas production in early 2013. We expect to invest about US$1.2 billion towards capital expenditures in 2013 to continue delivering on our potential in both exploration and production,” Carneiro continued.
OGX’s production activities are progressing according to schedule.
OGX continued its successful exploratory campaign in the third quarter.
Besides the increased focus on its production campaign, OGX has interesting prospects to be drilled in the coming months.
Drilling of exploratory wells
|Cozumel||BM-C-37||209-270 mmboe||70%||146-189 mmboe||4Q12|
|Tulum||BM-C-37||194-280 mmboe||70%||136-196 mmboe||4Q12|
|Cancun||BM-C-37||184-294 mmboe||70%||129-206 mmboe||1Q13|
|Viedma||BM-C-38||245-313 mmboe||70%||172-219 mmboe||1Q13|
|Cotopaxi||BM-C-38||30-40 mmboe||70%||21-28 mmboe||1Q13|
|Total||-||861-1,196 mm boe||70%||603-837 mm boe||-|
With the end of the exploratory concession periods for the Campos and Santos Basins approaching, the Company is gradually downsizing its rig fleet to accommodate a transition from the exploration campaign to the production phase in these basins, resulting in a reduction of its capex for 2013.
OGX spent US$588 million in the third quarter. Compared to the previous quarter, the Company had a slight increase given expenditures in its onshore operations (GTU final assembly and two additional rigs) and in the development of Tubarão Martelo and Tubarão Azul fields. The Company has begun to optimize and rationalize its expenses, mainly in exploration, while it moves towards the development phase. At the end of September, the Company returned one of its offshore rigs, which should impact the exploration capex in the first quarter of 2013.
OGX maintains a solid cash position of approximately US$2.5 billion. Considering the fourth quarter operations, OGX expects to end 2012 with a cash position of approximately US$1.8–1.9 billion.
Tubarão Azul Field Development
Since commencing production on January 31, the Tubarão Azul Field has produced more than 2.5 million barrels of oil and delivered four shipments. Average daily production in the nine months of production from January 31 to October 31 was 9.7 kboepd, and, this quarter alone, average daily production was 9.3 kboepd. FPSO OSX-1 continues to perform very well, with an average operating efficiency of 98.5% since first oil.
The OGX-26HP well was reconnected to FPSO OSX-1 during the first week of August, after having been closed for slightly over a month to allow for the replacement of the centrifugal submersible pump. Since then, the two production wells, OGX-26HP and OGX-68HP, have again been producing in line with expectations with stable flows rates of above 5.0 kboepd on average per well.
The third production well in the field, TBAZ-1HP, is under completion and will begin connection to FPSO OSX-1 in the coming weeks. It is expected to come on-stream at the beginning of December.
The average daily production in October amongst all wells in the Tubarao Azul Field was 10.3 kboepd, which is in line with previous months.
In July, OGX made the final shipment delivery of approximately 800,000 barrels under the Company’s first sales contract with Shell, marking the commencement of the Company’s revenues generation after the declaration of commerciality in the Tubarão Azul Field, resulting in sales revenues of R$150.7 million.
On October 15, following the declaration of commerciality and the conclusion of the Extended Well Test (EWT), the fourth shipment of approximately 800,000 barrels was delivered to Reliance Industries Ltd., one of the world's largest refineries and India's largest private company.
The table below shows the pro-forma OSX-1 EBITDA after the delivery of the first shipments:
|Operation Period||51 days||27 days||98 days||80 days|
Production related to the shipments -
in barrels (bbls)
|% EBITDA / Net Revenue||47.81%||41.48%||17.31%||40.76%||35.37%|
|EBITDA / barrel - (R$/barrel)||103.07||94.11||33.03||85.17||72.98|
1 Sales occurred during the Extended Well Test and before the declaration of commerciality - not accounted in Results and recorded as a reduction of "Fixed Assets"
2 Sale occurred after the Extended Well Test and declaration of commerciality - recorded as net revenues
3 Sale occurred after the Extended Well Test and declaration of commerciality - recorded as net revenues. Net figure of expenses associated with the sale of freight costs
As shown in the table above, the delivery of the third cargo presented an EBITDA / barrel relatively lower than the first and second cargos due to: i) lower production during the 98-day production period resulting from the need to close the OGX-26HP well for just over a month to allow for the replacement of the centrifugal submersible pump; ii) lower revenue (discount already applied) resulting from a decrease in oil prices (Brent) from USD 122 per barrel at the time of the first cargo to USD 95 per barrel at the time of the third cargo; iii) an increase in costs resulting from currency fluctuations upon the devaluation of the exchange rate by 14% rate from March 28 to July 26; and iv) an increase in logistics costs (boats and fuel) resulting from the IBAMA requirement to use support boats, which did not exist at the time of the first and second cargos.
In the fourth cargo, with production of the two wells stabilized and a better realized oil price, profitability of the operation improved.
The following table demonstrates the effective daily rates (in USD) of each of the costs associated with the FPSO OSX-1 operation:
Daily Cost (USD '000)
Tubarão Martelo Field Development
Following the declaration of commerciality of the field and OGX’s submission of a Development Plan, ANP granted the Company authorization to begin drilling the production wells in this field. OGX is now concluding the drilling and completing the 3 horizontal production wells (TBMT-2HP, TBMT-4HP and TBMT-6HP). We expect these wells to be connected to FPSO OSX-3, which is scheduled to arrive by 3Q13. The Tubarão Martelo Field is scheduled to come on-stream by 4Q13.
It is important to note that during last week we are performing a production test of the TBMT-2HP well and so far the results within expectations.
Campos Basin Exploration Campaign
On October 5, OGX obtained environmental authorization from IBAMA to begin drilling in the BM-C-37 and BM-C-38 blocks. This authorization will allow the Company to advance its exploratory campaign in this very promising region, where it plans to apply the expertise of its technical team and two of its rigs to continue drilling wildcat and appraisal wells.
Below we highlight results obtained in the third quarter:
Villarrica: We have concluded drilling the wildcat well in the accumulation, OGX-87, and identified 8 meters of net pay in the Maastrichtian section and 2 meters in the Paleocene section.
Fuji: We have finished drilling the fourth appraisal well of the accumulation, OGX-90D, where we discovered 2 meters of net pay in the Albian section.
Cozumel: We have commenced drilling the wildcat well of the accumulation, OGX-99, which is still in progress.
Development of the Gavião Real and Gavião Azul fields
Development of Gavião Real Field project is on schedule and has progressed substantially in recent months, with two rigs focused on production development. The drilling of all 16 production wells planned for this phase of the project has already been concluded, of which 11 have already been completed and the remaining 5 are in the process of completion and connection to the GTU. We also concluded the drilling of the first water disposal well, GVR-15D, which will work in conjunction with the second disposal well (GVR-16D), in drilling progress.
The 11 wells already completed have been tested with open choke (3/4") and showed average flow rates of 400,000 - 500,000 m3/day each.
In addition, at the end of September, we obtained the Operating License from the Environmental and Natural Resources Secretary of the State of Maranhão (SEMA/MA) authorizing production of natural gas in the Gavião Real and Gavião Azul fields.
The project is in its final stages as described by the current activities at the site: i) mechanical and instrument assembly, electrical wiring and instrumentation; ii) test of control networks in the clusters and the GTU; iii) pipelines in place; iv) construction of the administrative buildings with offices, workshop and laboratories, all in pre-fabricated metallic structures; and v) leakage tests in the tanks in final phase.
Natural gas production at the Gavião Real Field will begin in the fourth quarter of this year, with the commissioning of the GTU and the MPX Parnaíba Thermoelectric Complex turbines. Commercial generation of power will begin in 2013.
Parnaíba Basin Exploratory Campaign
After the discovery of the Bom Jesus accumulation last year, identified through the OGX-34 well, the Company drilled appraisal wells to test the extent of this accumulation. In addition to the drilling and well test of the OGX-88 well in July, we also concluded the drilling of another two appraisal wells in the region in 3Q12, OGX-91D and OGX-95, both of which contained discoveries of hydrocarbons in the Carboniferous section of 23 and 4 meters of net pay, respectively. After the evaluation of the results from the wells, OGX submitted the Discovery Evaluation Plan (PAD) for the region to the ANP, which has already been approved.
We have initiated the drilling of five new prospects in this basin – Santa Maria (OGX-92), Rio Corda (OGX-93), Peritoró (OGX-96), Basílios (OGX-97) and Norte California (OGX-98). The OGX-92 and OGX-93 wells were concluded in the Fazenda Santa Maria and Rio Corda prospects; however, neither well showed indications of hydrocarbons. Currently, 3 exploratory wells are still in progress - the first exploratory well in the PN-T-50 block in the Peritoró prospect, OGX-96, OGX-97 in the Basílios prospect and OGX-98 in the Norte California prospect.
In the quarter, we finished drilling the OGX-89D appraisal well of the Natal accumulation, where we discovered 7 meters of net pay in the Santonian section, proving the extension of the accumulation.
We also concluded the drilling of the OGX-85 well, where we have confirmed microbiolite limestone with presence of gas and light oil, identified in sandstone and volcanic rocks, as reported to the ANP. The Company is still analyzing the economic viability of this discovery.
Finally, we are currently drilling the OGX-94DA well, in the Curitiba accumulation, where we have already discovered 32 meters of net pay in the Santonian/Campanian section. The drilling is still in progress aiming for the Albian section and we expect to have more information in the coming weeks.
Going forward, OGX will go through the assessment of the full set of data from the Santos Basin to define the ring fence of potential fields and the development plan for the area.
In September, we returned the BM-S-29 exploratory block, in which OGX had a 100% stake, to the ANP. After the conclusion of the Discovery Evaluation Plan (PAD) period for this area, the Company decided not to continue its development.
Espírito Santo Basin
Although we did not drill in this basin in 3Q12, we plan to resume our exploration campaign before the end of the exploration period in October 2014 with drilling in the southern blocks of the basin (BM-ES-39, BM-ES-40 and BM-ES-41), considered a new and promising area for oil and natural gas.
Also, in October, we returned the BM-ES-38 exploratory block, in which OGX had a 50% stake, to the ANP after having analyzed the results obtained in the block.
This quarter, OGX finalized the acquisition of 2D and 3D seismic data in the Lower Magdalena Valley Basin (VIM-5 block), and plans to commence drilling the first exploration well in Colombia in 2013. Also, in October, we participated in Colombia’s 2012 ANH Round, and had the winning bid for another block in the Lower Magdalena Valley Basin, VIM-19, only waiting for ANH’s confirmation.
OTHER OGX HIGHLIGHTS
Exploration and Development Equipment
In accordance with our plan to gradually return our drilling rigs as a part of our transition to a production-focused campaign in the Campos and Santos Basins, in September, we returned the Ocean Ambassador rig upon completion of the drilling of the TMBT-4HP well and the expiration of our contract with Diamond Offshore.
Operator A Qualification
In October, OGX obtained qualification of Operator A from the ANP, allowing the Company to operate blocks located in deepwaters and ultra-deepwaters, in addition to shallow waters and onshore, where Operator B already operates.
Controlling Shareholder Put Option
On October 24, OGX’s controlling shareholder, Eike Batista, granted the Company the right to demand his subscription of up to US$1.0 billion new common shares of OGX at a price of R$6.30 per share (the “Option”). The Option, which expires after April 30, 2014, is conditional upon the Company’s additional capital requirement and the absence of more favorable alternatives, which will be determined by the majority of the independent board members on the Company´s Board of Directors.
The option reflects Mr. Batista’s confidence in the technical expertise and quality assets of the Company, as well as the new opportunities that the oil and gas industry offers to OGX.
OGX closed 3Q12 with 382 employees and 6,111 third party service providers responsible for conducting all administrative, exploration and oil production activities, up approximately 6% over the same period of the previous year. In addition to our strategy of contracting internationally respected suppliers to conduct operating activities, we maintain a high-performance, streamlined structure focused on managerial excellence. Our team is composed of professionals with broad experience in the oil and gas sector, in addition to young professionals with great potential, educated at the country’s leading universities.
OGX has several important events planned for the coming months, including:
The financial and operational data below is presented on a consolidated basis, in accordance with the International Financial Reporting Standards (IFRS) issued by the International Accounting Standards Board - IASB and, in reais (R$), except where otherwise indicated.
Cost of goods sold (COGS) 1
|General and administrative expenses||(158,611)||(179,653)||21,042||(41,462)||(71,820)||30,358|
|Depreciation (part of COGS)||(14,665)||(3,039)||(11,626)||(11,574)||(1,210)||(10,364)|
|Amortization (part of COGS)||(7,337)||(4,170)||(3,167)||(3,798)||(1,692)||(2,106)|
|Net financial results||(106,916)||212,579||(319,495)||(67,159)||1,234||(68,393)|
|(-) Income tax||389,151||30,625||358,526||157,900||(35,779)||193,679|
|Net profit (loss) for the year- Pro forma||(900,170)||(177,298)||(722,872)||(343,619)||(25,978)||(317,641)|
|OGX Campos Merger||13,102||-||13,102||-||-||-|
|Net profit (loss) for the year- Book value||(887,068)||(177,298)||(709,770)||(343,619)||(25,978)||(317,641)|
|Non controlling interests||(21,306)||(17,167)||(4,139)||(288)||(8,488)||8,200|
1 This balance does not include parts of COGS related to depreciation, amortization and royalties that are disclosed in specific lines of the table above
|BALANCE SHEET||Sep 30, 2012||Dec 31, 2011||Sep 30, 2012||Dec 31, 2011|
|ASSETS||LIABILITIES AND EQUITY|
|Current assets||Current Liabilities|
|Cash and cash equivalents||5,058,579||5,367,451||Trade payables||755,296||431,931|
Taxes, contributions and profit sharing payable
|Escrow deposits||14,758||39,039||Salaries and payroll charges||44,701||54,507|
|Taxes and contributions recoverable||65,464||78,137||Loans and financings||138,738||22,301|
|Derivative financial instruments||25,295||8,879||Accounts payable to related parties||109,055||96,692|
|Oil inventories||105,448||-||Other accounts payable||16,299||87,807|
|Loans and financings||7,908,034||4,750,113|
|Noncurrent Assets||Shareholders’ Equity|
|Taxes and contributions recoverable||154,321||278,810||Capital reserves||185,242||274,109|
|Deferred income taxes and social contributions||673,306||282,693||Earnings reserves||97,737||-|
|Credits with related parties||176,278||139,386||Currency translation adjustments||42,086||19,588|
|Retained earnings (deficit)||(1,168,308)||(289,444)|
|Portion attributed to controlling shareholders||7,977,891||8,814,560|
|Intangible assets||1,508,756||1,512,724||Portion attributed to non-controlling interests||44,666||54,473|
|Total Assets||17,165,727||14,350,197||Total Shareholders’ Equity||17,165,727||14,350,197|
|Balance as of December 31, 2011:||6,172,783|
|Espirito Santo Basin||47,842|
|Pará Maranhão Basin||45,910|
|(+) Borrowing costs||123,261|
|(+) Asset retirement obligation||103,047|
|(-) Gross margin EWT||(79,644)|
|(-) Write off Dry/Subcommercial wells||(460,235)|
|Balance as of September 30, 2012||9,019,065|
|LOANS AND FINANCING|
|Balance as of December 31, 2011:||(4,772,414)|
|(-) New fundings||(2,537,689)|
|(-) Accrued interests||(403,775)|
|(-) Currency exchange||(695,957)|
|(+) Interest paid||336,315|
|(+) Funding costs||39,032|
(-) Amortization of funding costs
|Balance as of September 30, 2012||(8,046,772)|
We ended 3Q12 with net losses YTD of R$887.1 million, largely without an impact on cash. This net loss is chiefly due to: (a) expenditures with the exploratory campaign of R$172.6 million; (b) general and administrative expenses of R$158.6 million; (c) expenses of R$460.2 million relative to dry wells and sub-commercial areas that represent accounting effects; (d) foreign exchange variation expenses, chiefly unrealized, of R$366.1 million; (e) net financial expenses of R$106.9 million; and (f) the cost of oil sold after the end of the extended well test (EWT) at R$124.6 million. These impacts were partially offset by: (g) net revenue of R$150.7 million from oil sales after the conclusion of the EWT; and (h) the positive impact of income tax and social contribution, the majority of which is deferred, of R$389.1 million.
Exploration expenses increased R$47.4 million year-on-year. This variation was primarily the result of the intensification of seismic campaigns in the Parnaíba Basin and Colombia.
General and Administrative Expenses
General and administrative expenses decreased R$21 million year-on-year, driven by the R$10 million reduction in expenses with profit sharing.
Dry and Sub-commercial Wells
In 3Q12, the Company posted an expense of R$460.2 million with dry wells and sub-commercial areas. Of this amount, R$213.2 million account for previously capitalized expenses in the BM-S-29 block, which was returned in August of 2012. The remaining balance refers to dry or sub-commercial wells.
Foreign Exchange Expense
In 3Q12, the Company posted net foreign exchange expenses of R$366.1 million, compared to a net expense of R$4.2 million in 3Q11, for an increase of R$361.9 million.
This foreign exchange expense is almost entirely non-cash and due to a net foreign exchange exposure of US$2.1 billion. Despite the loss in U.S. dollars exceeding income, the Company opted not to contract hedge instruments for this non-cash exposure as it plans to settle this dollar-denominated liability through revenue from oil sales to be booked in the same currency, production of which began on January 31, 2012. Thus, the net foreign exchange exposure will be protected by a natural hedge to be generated by oil sales.
The R$106.9 million financial expense in 3Q12 is explained by: (a) the un-capitalized interest on financing of R$302.9 million, partially offset by (b) gains on financial investments of R$194.7 million; and (c) other net financial income of R$1.3 million.
Cost of Products Sold
The R$124.6 million cost of goods sold incurred with the oil sales after the EWT is broken down as: (a) expenses with leasing of R$52.7 million; (b) O&M services of R$28.1 million; (c) logistics of R$27.8 million; (d) royalties of R$14.8 million; and (e) others of R$1.2 million.
Net Sales Revenue
The Company’s sales in 3Q12 total R$324.7 (until October total R$493.8 million). Of this total, R$150.7 million earned after the EWT with the sale of a shipment of 789,800 barrels to Shell booked as net sales revenue. Sales prior to the conclusion of the EWT of R$174 million for 794,200 barrels were booked as a reduction in property, plant and equipment.
We ended 3Q12 with a solid cash position of R$5.1 billion (equal to US$2.5 billion).
Cash and Cash Equivalents
Cash and cash equivalents totaled R$5.1 billion on September 30, 2012, down R$308.9 million over the balance on December 31, 2012. This decrease is chiefly due to: (a) CAPEX of R$3.2 billion, partially offset by (b) fundraising in 1Q12 of R$2.5 billion; (c) EBITDA from FPSO OSX-1 of R$105.7 million; and (d) restitution of withholding income tax on financial applications of R$156 million.
Property, Plant and Equipment (CAPEX)
Property, plant and equipment represented by capital expenditures during the exploration and development phases include expenses related to drilling campaigns and acquisition of E&P equipment. From December 31, 2011 to September 30, 2012, this balance increased by R$2.8 billion.
Loans and Financing
The R$3.3 billion increase in the balance of loans and financing between December 31, 2011 and September 30, 2012 is due to the transactions listed in the loans and financing table in the appendix.
Friday, November 9 at 12 P.M. (Brasília Time Zone); 9:00 A.M. (EST)
Telephone (Brazil): +55 11 4688-6341 or +55 11 2104-8901
Telephone Toll-free (US): +1 855 281-6021
Telephone (US): + 1 786 924-6977
Webcast in Portuguese: www.ccall.com.br/ogx/3t12.htm
Webcast in English: www.ccall.com.br/ogx/3q12.htm
Audio will be available three hours after the conference call on the IR
The conference call will be conducted in English with simultaneous translation to Portuguese.
OGX Petróleo e Gás SA is focused on oil and natural gas exploration and production and is conducting the largest private-sector exploratory campaign in Brazil. OGX has a diversified, high-potential portfolio, comprised of 28 exploratory blocks in the Campos, Santos, Espírito Santo, Pará-Maranhão and Parnaíba Basins in Brazil, and 4 exploratory blocks in Colombia, in the Lower Magdalena Valley and the Cesar-Ranchería basins. The total extension area is of approximately 5,675 km² in sea and approximately 36,700 km² on land, with 24,500 km² in Brazil and 12,200 km² in Colombia. OGX relies upon an experienced management team and holds a solid cash position, with approximately US$2.5 billion in cash (as of September 2012) to fund its E&P investments and new opportunities. In June of 2008, the company went public raising R$6.7 billion, which at the time was the largest amount ever raised in a Brazilian IPO. OGX is a member of the EBX Group, an industrial group founded and under the leadership of Brazilian entrepreneur Eike F. Batista, who has a proven track record in developing new ventures in the natural resources and infrastructure sectors. For more information, please visit: www.ogx.com.br/ri
This document contains Company-related statements and information that reflect the current vision and/or expectations the Company and its management have regarding its business plan. These include, among others, all forward-looking statements that involve forecasts and projections, indicate or imply results, performance or future achievements, and may contain words such as “believe,” “foresee,” “expect,” “consider,” “is likely to result in” or other words or expressions of similar meaning. Such statements are subject to a series of expressive risks, uncertainty and premises. Please be advised that several important factors can cause the actual results to diverge materially from the plans, objectives, expectations, estimations, and intentions expressed in this document. In no event shall the Company or the members of its board, directors, assigns or employees be liable to any third party (including investors) for investment decisions or acts or business carried out based on the information and statements that appear in this presentation, or for indirect damage, lost profit or related issues. The Company does not intend to provide to potential shareholders with a revision of the statements or an analysis of the differences between the statements and the actual results. You are urged to carefully review OGX's offering circular, including the risk factors included therein. This presentation does not purport to be all-inclusive or to contain all the information that a prospective investor may desire in evaluating OGX. Each investor must conduct and rely on its own evaluation, including of the associated risks, in making an investment decision.
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