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Business Risks

The following is a discussion on key items that can be considered potential risk factors relating to the business of INPEX CORPORATION, its subsidiaries and affiliates (the “Group”). From the standpoint of information disclosure to investors and shareholders, we proactively disclose matters that are not necessarily the business risks but that can be considered to have important effects on the investment decisions of investors. The following discussion does not completely cover all business risks relating to the Group’s businesses.
Unless stated otherwise, forward-looking statements in the discussion are the judgment of the Group as of June 29, 2016 and are subject to change after such date due to various factors, including changes in social and economic circumstances.

1. CHARACTERISTICS OF AND RISKS ASSOCIATED WITH THE OIL AND NATURAL GAS DEVELOPMENT BUSINESS

(1) Risk of failure in exploration, development or production

Payment of compensation is ordinarily necessary to acquire participating interests. Also, surveying and exploratory drilling expenses (exploration expenses) become necessary at the time of exploration activities for the purpose of discovering resources. When resources are discovered, it is necessary to further invest in substantial development expenses according to various conditions, including the size of the recoverable reserves, development costs and details of agreements with oil-producing countries (including gas-producing countries; hereinafter the same shall apply).

There is, however, no guarantee of discovering resources on a scale that makes development and production feasible. The probability of such discoveries is considerably low despite various technological advances in recent years, and even when resources are discovered the scale of the reserves does not necessarily make commercial production feasible. For this reason, the Group conservatively recognizes expenses related to exploration investment in our consolidated financial statements. The Group maintains financial soundness by booking 100% as expenses in the case of concession agreements (including mining rights awarded in Japan as well as permits, licenses and leases awarded overseas) and by booking 100% of exploration project investment as allowances in the case of production sharing agreements. In addition, if there are impossibilities of recovery of investment in a development project, we also book the corresponding amount of investment in the development project as allowances while considering the recovery possibility of each project.

To increase recoverable reserve and production volumes, the Group plans to always take an interest in promising properties and plans to continue exploration investment. At the same time, we plan to invest in development projects, including the acquisition of interests in discovered undeveloped fields and producing fields, so as to maintain an overall balance between assets at the exploration, development, and production stages.

Although exploration and development (including the acquisition of interests) are necessary to secure the reserves essential to the Group’s future sustainable business development, each type of investment involves technological and economic risks, and failed exploration or development could have an adverse effect on the results of the Group’s operations.

(2) Crude oil, condensate, LPG and natural gas reserves
  1. Proved reserves
  2. INPEX CORPORATION (the “Company”) commissioned DeGolyer and MacNaughton, an independent petroleum engineering consultant in the United States, to assess the main proved reserves of the Group of which projects with a significant amount of future development investment might materially affect future performance. An assessment of other projects was undertaken by the Company. The definition of proved reserves is based on the U.S. Securities and Exchange Commission’s (SEC) Regulation S-X, Rule 4-10(a), which is widely known among U.S. investors. Regardless of whether the deterministic approach or probabilistic approach is used in evaluation, proved oil and gas reserves are estimated quantities that geological and engineering data demonstrate with reasonable certainty to be recoverable from known reservoirs under existing economic and operating conditions, from the date of evaluation through to the expiration date of the agreement granting operating rights (or in the event of evidence with a reasonable certainty of agreement, extension through to the expiration of the projected extension period). For definition as“proved reserves,”operators must have a reasonable degree of certainty that the recovery of hydrocarbons has commenced or that the project will commence within an acceptable period of time. This definition is widely regarded as being conservative. Nevertheless, the strictness of the definition does not imply any guarantee of the production of total reserves during a future production period. In this context, when probabilistic methods are employed, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the sum of estimated proved reserves.

    For further details on proved reserves of crude oil, condensate, LPG and natural gas held by the Group, including affiliates accounted for under the equity method, please see the section “Oil and Gas Reserves and Production Volume ” on P. 84 of our Annual Report 2016.

  3. Probable reserves and possible reserves
  4. In addition to the assessment of proved reserves based on the SEC standards, the Company commissioned DeGolyer and MacNaughton to assess its probable reserves and the possible reserves of which projects with a significant amount of future development investment might materially affect the future performance, similar to proved reserves. An assessment of other projects was undertaken by the Company, based on the Petroleum Resources Management System 2007 (PRMS) published by four organizations: the Society of Petroleum Engineers (SPE), the World Petroleum Congress (WPC), the American Association of Petroleum Geologists (AAPG), and the Society of Petroleum Evaluation Engineers (SPEE). Probable reserves, as defined by PRMS guidelines established by the four organizations, are reserves of oil and gas volumes outside proved reserves that are less likely to be recovered than proved reserves but more certain to be recovered than possible reserves based on analyses of geological and engineering data. In this context, when probabilistic methods are employed, there should be at least a 50% probability that the quantities actually recovered will equal or exceed the sum of estimated proved and probable reserves. In addition, possible reserves are also defined in accordance with PRMS guidelines as reserves of oil and gas volumes which are not categorized as proved reserves or probable reserves and which are less likely to be recovered than probable reserves based on analyses of geological and engineering data. In this case, it is unlikely that the actual quantity of oil and gas recovered will exceed the sum of proved reserves, probable reserves and possible reserves. Furthermore, when probabilistic methods are employed to calculate possible reserves, there should be at least a 10% probability that the quantities recovered will equal or exceed the sum of proved reserves, probable reserves and possible reserves. Probable reserves and possible reserves can be upgraded to proved reserves after the addition of new technical data or when uncertainty has been reduced due to clarification of economic conditions or operational conditions. Nevertheless, probable reserves and possible reserves do not offer a guarantee of the production of total reserves during a future production period with the same certainty as proved reserves.

    For further details on probable reserves and possible reserves of crude oil, condensate, LPG and natural gas held by the Group, including affiliates accounted for under the equity method, please see the section “Oil and Gas Reserves and Production Volume” on P. 84 of our Annual Report 2016.

  5. Possibility of changes in reserves
  6. A reserve evaluation depends on the available geological and engineering data from oil and gas reservoirs, the maturity of development plans and a considerable number of assumptions, factors and variables including economic conditions as of the date such an estimate is made. Reserves may be revised in the future on the basis of geological and engineering data as well as development plans and information relating to changes in economic and other conditions made newly available through progress in production and operations. As a result, there is a possibility that reserves will be restated upwards or downwards. As to the reserves under a PSC, not only production, but also oil and gas prices, investments, recovery of investments due to contractual conditions and remuneration fees may affect the economic entitlement. This may cause reserves to increase or decrease. In this way, the assessed value of reserves could fluctuate because of various data, assumptions and changes of definition.

(3) In the oil and natural gas development business the period from exploration to sales is highly capital intensive and funds cannot be recovered for a long time

Considerable time and expense is required for exploration activities. Even when promising resources are discovered through exploration, substantial expenses including production facility construction costs, and an extended period of time, are necessary at the development stage leading up to production.

For this reason, a long period of 10 years or more is required from the time of exploration and development investment until the recovery of funds through production and sales. In particular, the large-scale Ichthys LNG and other projects being pursued by the Company requires a very large amount of investment, and the financing of these projects could be impacted by changes in the economic and financial environment. Following the discovery of resources, a delay in the development schedule or the loss of the economic viability of the properties during the development process leading up to production and the commencement of sales could have an adverse effect on the Group’s operational results. Such delays or losses may occur due to changes in the business environment including a delay in the acquisition or modification of government approvals, the occurrence of unanticipated problems related to geological conditions, fluctuations in the price of oil or gas, fluctuations in foreign exchange rates, or escalating prices of equipment and materials. In the case of LNG projects, such delays or losses may occur due to an inability to complete such procedural requirements as FID owing to the lack of any long-term contractual agreement with prospective purchasers with respect to production.

(4) Operatorship

In the oil and natural gas development business, companies frequently form business partnerships for the purpose of the dispersion of risk and financial burden. In such partnerships, one of the companies becomes the operator, which performs the actual work and bears the responsibility for operations on behalf of the partners. The companies other than the operator, as non-operators, participate in the business by providing a predetermined amount of funds and either carefully examining the exploration and development plan devised and implemented by the operator, or participating in some operations.

The integration of INPEX CORPORATION and Teikoku Oil Co., Ltd., was completed on October 1, 2008. The resultant company possesses abundant operational capabilities thanks to the integration of the former two companies’ know-how based on extensive operation experience in exploration, development and production both within Japan and overseas as well as their high level proprietary technologies.

The Group intends to actively pursue operator projects, focusing on the large-scale Ichthys LNG and other projects taking into consideration the effective application of business resources as well as the balance between operator and nonoperator projects, based on the Group’s technical capability, which has been considerably enhanced by the above-stated business integration. Although the Company lacks operator experience in LNG development projects, it has significant expertise as an operator in the development and production of crude oil and natural gas both in Japan and overseas as well as a wealth of know-how and knowledge accumulated over many years as a participant in LNG and other projects in such countries as Indonesia and Australia. In addition, we believe that by utilizing the services of specialized subcontractors and highly experienced external consultants, a practice similar to foreign oil companies including the majors, it will be possible to execute business appropriately as an operator including LNG projects.

Engaging in project coordination as an operator will contribute to the expansion of opportunities of block and acreage acquisition through enhancement of technical capabilities and greater presence in oil-producing countries and the industry. At the same time, there exist risks such as constraints on the recruitment of personnel who have specialized operational skills and an increase in financial burden. Inability to adequately cope with such risks could have an adverse effect on the Group’s results of operations.

(5) Project partners

In the oil and natural gas development business, as previously mentioned, several companies often engage in joint business for the purpose of dispersion of risk and financial burden. In such cases, the partners generally enter into a joint operating agreement among themselves to decide on the decision-making procedure for execution of the joint business, or to decide on an operator that conducts business on their behalf. A company that is a partner in one property in which the Group is engaged in joint business may become a competitor in the acquisition of other participating interests, even though the relationship with the partner may be good.

In undertaking the joint business, participants in principle bear a financial burden in proportion to their interest share. Any inability by a joint business partner to fulfill this financial burden may adversely affect the project.

(6) Disaster and accident risks

Oil and natural gas development entails the risk that operational accidents and disasters may occur in the process of exploration, development, production and transportation. Should such an accident, disaster or other such incident occur, there is the risk that costs will be incurred, excluding compensation covered by insurance, due to facility damage, as well as the risk of a major accident or disaster involving loss of life. In addition, a cost burden for recovery or opportunity loss from the interruption of operations could occur. For the domestic natural gas business, the Company has continued to procure as source gas natural gas regasified from imported LNG since January 2010. Furthermore, the Company has procured imported LNG as source gas in connection with its Naoetsu LNG Terminal from August 2013. An inability to procure natural gas regasified from imported LNG and other imported gas as source gas due to troubles concerning suppliers or the Company’s Naoetsu LNG Terminal may interfere with the Company’s ability to supply to its customers. This could in turn have an adverse effect on the Company’s domestic natural gas business.

With regard to environmental problems, there is a possibility of soil contamination, air pollution, and freshwater and seawater pollution. The Group has established a “Health, Safety and Environment Policy,” and as a matter of course abides by the environmental laws, regulations, and standards of the countries in which we operate and give due consideration to the environment in the conduct of business, based on our independent guidelines. In the event of an operating accident or disaster which impacts the environment, there is the possibility of incurring a response or cost burden for recovery from that incident, of incurring obligation of payment for procedural costs, compensation or other cost related to the start of civil, criminal or government procedures, or of incurring loss from the interruption of operations. Furthermore, in the event of changes to or the strengthening of the environmental laws, regulations, and standards (including support measures for the promotion of new, renewable energies) of the countries in which we operate, it may be necessary for the Group to devise additional measures, and an associated cost burden could occur.

Although the Group maintains accident insurance in the natural conduct of its operations, should such an accident or disaster be attributable to willful misconduct or negligence on the part of the Group, the occurrence of a cost burden could have an adverse effect on financial results. Also, such accident or trouble would result in receiving administrative punishment or result in damage to the Group’s credibility and reputation as an oil and natural gas development company, and could therefore have an adverse effect on future business activities.

(7) Risk in Relation to Mine Abandonment

The Group books in its accounts, as an asset retirement obligation, the estimated present value of costs related to mine abandonment that will become necessary after finishing operation and production in oil and gas production facilities and the like in accordance with agreements with the authorities of oil-producing countries, applicable laws and regulations and the like. If it is later found that the estimated present value of those costs falls short due to a change in the procedures used for mine abandonment, a rise in expenses for procuring drilling materials and equipment or any other reason, the Group will be required to increase the amount of that asset retirement obligation, which could adversely affect the financial condition and results of operations of the Group.

2. EFFECTS OF FLUCTUATIONS IN CRUDE OIL PRICES, NATURAL GAS PRICES, FOREIGN EXCHANGE AND INTEREST RATES ON FINANCIAL RESULTS

(1) Effects of fluctuations in crude oil prices and natural gas prices on financial results

A large percentage of crude oil prices and natural gas prices in overseas businesses are determined by international market conditions. In addition, those prices fluctuate significantly in response to the influence of a variety of factors including global or local supply and demand as well as trends and conditions in the global economy and financial markets. The vast majority of these factors are beyond the control of the Company. In this regard, INPEX is not in a position to accurately predict movements in future crude oil and natural gas prices. The Group’s sales and profits are subject to the effects of such price fluctuations. Such effects are highly complex and are caused by the following factors.

  1. Although a majority of natural gas selling prices in overseas businesses are linked to crude oil prices, they are not in direct proportion to crude oil prices.
  2. Because sales and profits are determined on the basis of crude oil prices and natural gas prices at the time sales are booked, actual crude oil transaction prices and the average oil price during the accounting period do not necessarily correspond.

For the domestic natural gas businesses, the Company has continued to purchase as source gas natural gas regasified from imported LNG as a raw material in addition to natural gas produced in Japan since January 2010. The price of the Company’s natural gas sold in Japan is comprised of a fixed price portion as well as a portion that reflects fluctuations in the price of imported LNG. In addition to the direct impact of trends in the market prices of LNG and competing energy sources on that portion that reflects fluctuations in the price of imported LNG, contract negotiations held each fiscal year with end purchasers could have an indirect effect on the fixed price portion.

Also, should the recovery of an amount invested in a business asset held by the Group be no longer expected—due to a decrease in profitability associated with changes in the business environment on the basis of changes in future market conditions—since the Group would reduce that business asset’s book value to reflect the level of recoverability and the amount of that reduction would be deemed impairment loss, there is the possibility that there could be an adverse effect on the Group’s results of operations.

(2) The effect of fluctuations in exchange rates on financial results

As most of the Group’s business consists of E&P conducted overseas, associated revenues (sales) and expenditures (costs) are denominated in foreign currencies (primarily in U.S. dollars), and profit and loss is subject to the effects of the foreign exchange market. In the event of appreciation in the value of the yen, yendenominated sales and profits decrease. Conversely, in the event of depreciation in the value of the yen, yen-denominated sales and profits increase.

On the other hand, when borrowing necessary funds, the Company borrows in foreign currencies. In the event of appreciation in the value of the yen, a foreign exchange gain on foreign-currency denominated borrowings is recorded as a result of fiscal year-end conversion; in the event of depreciation in the value of the yen, a foreign exchange loss is incurred. For this reason, the exchange risk associated with the above business is diminished and the impact of fluctuations in exchange rates on profit and loss tends to be mitigated. Moreover, although the Company is taking measures to reduce a portion of the risks associated with movements in foreign currency exchange rates, these measures by no means cover all possible risks. As a result, the impact of fluctuations in foreign currency exchange rates cannot be completely eliminated.

(3) The effect of fluctuations in interest rates on financial results

The Group raises some of the funds necessary for exploration and development operations through borrowing. Much of these borrowings are with variable-rates, long term borrowings based on the U.S. dollar six-month LIBOR rate. Accordingly, the Company’s profits are subject to the influence of fluctuations in U.S. dollar interest rates. Furthermore, although the Group has devised methods to reduce a portion of interest rate risk, these methods do not cover all risks of interest rate fluctuation incurred by our Group and do not entirely remove the effect of fluctuations in interest rates.

3. OVERSEAS BUSINESS ACTIVITIES AND COUNTRY RISK

The Group engages in a large number of oil and natural gas development projects overseas. Because the Group’s business activities, including the acquisition of participating interests, are conducted on the basis of contracts with the governments of oil-producing countries and other entities, steps taken by oil-producing countries to further tighten controls applicable to home country natural resources, suspension of operation due to conflicts and other factors, and other such changes in the political, economic, and social circumstances in such oil-producing countries or neighboring countries (including government involvement, stage of economic development, economic growth rate, capital reinvestment, resource allocation, restriction of economic activities by global community, government control of foreign exchange or foreign remittances, and the balance of international payments), the application of OPEC production ceilings in OPEC member countries and changes in the legal system and taxation system of those countries (including the establishment or abolition of laws or regulations and changes in their interpretation or enforcement) as well as lawsuits could have a significant impact on the Group’s business or results unless the impact is compensated by insurance.

Additionally, against the background of rising development costs and other changes in the business environment, the progress of oil and gas projects, and the need to address environmental issues, the governments of oil-producing countries may seek to renegotiate the fiscal conditions including conditions of existing oil contracts related to participating interests. In the event that the fiscal conditions of contracts were to be renegotiated, this could have an adverse effect on the Group’s business performance.

4. DEPENDENCE ON SPECIFIC GEOGRAPHICAL AREAS OR PROPERTIES

(1) Production volume

The Group engages in stable production of crude oil and natural gas in the Offshore Mahakam Block (Indonesia), the ADMA Block (United Arab Emirates), the Minami Nagaoka Gas Field (Japan) and so on. Through a process of business integration, the Group had established a wide ranging, diversified yet balanced portfolio that encompassed the Asia-Oceania regions (particularly Japan, Indonesia, and Australia), the Middle East and Africa, Eurasia including Caspian Sea area and the Americas. For the year ended March 31, 2016 however, the Middle East and Africa regions accounted for about 48% and the Asia and Oceania regions accounted for about 36% of the Group’s production volume, making up the vast majority of the Group’s operations.

Looking ahead, the Group will endeavor to further enhance the balance of its asset portfolio on a regional basis. However, the Group currently relies heavily on specific geographical areas and properties for its production volume, and the occurrence in these properties of an operational problem or difficulty could have an adverse effect on the Group’s operational results.

(2) Contract expiration dates in principal business areas

Expiration dates are customarily stipulated in the agreements related to participating interests, which are prerequisites for the Group’s overseas business activities. Should an agreement in which an expiration date is stipulated not be extended, re- extended or renewed, or should the terms and conditions be less favorable (including a reduction in the proportion of the Group’s interest) than those existing at the time of extension, re- extension or renewal, there could be an adverse effect on the Group’s results. For example, although the initial contract expiration date in the production sharing contract for the Offshore Mahakam Block of Indonesia—the Group’s principal geographical business area—was March 30, 1997, an extension was approved in 1991, and the current expiration date is December 31, 2017. On the basis of the concession agreement for the ADMA Block, the concession expiration date is March 8, 2018. (However, the expiration date for the Upper Zakum Oil Field has been extended to December 31, 2041.) The Group’s policy is to make efforts together with partners to extend, re- extend or renew these agreements. With regard to the Offshore Makaham Block, the Group signed a basic agreement, covering aspects such as the basic concept for participation in the block from 2018 onward, with project operator Total E&P Indonesie and Indonesia’s state-owned oil corporation PT Pertamina in December 2015 and officially entered into that agreement in January 2016. Should, however, the existing agreement not be extended, re-extended or renewed as a result of agreement negotiations based on the aforementioned January 2016 agreement, or should the terms and conditions be less favorable (including a reduction in the proportion of the Group’s interest) than those existing at the time of extension, re- extension or renewal, these could have an adverse effect on the Group’s results. Even should the agreements stipulating expiration dates be extended, re-extended or renewed, we anticipate that the remaining recoverable reserves at that time will have decreased due to production developments. Although the Group is striving to acquire interests that can substitute these properties, failure to acquire participating interests in oil and gas fields to fully substitute for these properties could have an adverse effect on the Group’s results. In addition, the period for exploration in oil and gas fields currently under exploration is fixed by contracts, and in the case of fields where oil and/or gas reserves are found that are deemed to be commercialized, and the Company is unable to decide on the transition to the development stage by the expiration of the current contract, efforts will be made through negotiations with the government of the oil- or gas- producing country in question to have the periods extended. However, there remains the possibility that such negotiations may not be successfully concluded, in which event the Company would be forced to withdraw from operations in the oil or gas field concerned. Also, as a rule, when there has been a major breach of contract on the part of one party, it is customary for the other party to have the right to cancel the agreement before the expiration date. The agreements for properties in these principal geographical business areas contain similar provisions. The Group has never experienced early cancellation of an agreement due to breach of contract, and we do not anticipate such an occurrence in the future. Nevertheless, a major breach of contract on the part of a party to an agreement could result in cancellation of an agreement before the expiration date.

And in the over seas natural gas development and production activities, in many cases we are selling and supplying gas based on long-term sales and supply contracts in which expiration dates are stipulated. We plan to make efforts with partners to extend or re-extend the expiration date before the deadline stipulated in these contracts. Nevertheless, inability to extend the contracts, or the occurrence of cases in which extension is made but sales and supply volumes are reduced, could have an adverse effect on the Group’s business or results.

5. PRODUCTION SHARING CONTRACTS

(1) Details of production sharing contracts

The Group has entered into production sharing contracts with countries including Indonesia and Caspian Sea area, and therefore holds numerous participating interests in those regions.

Production sharing contracts are agreements by which one or several oil and natural gas development companies serve as contractors that undertake at their own expense exploration and development work on behalf of the governments of oil producing countries or national oil companies and receive production from the projects as cost recovery and compensation. That is to say, when exploration and development work results in the production of oil or natural gas, the contractors recover the exploration and development costs they incurred by means of a share in the production. The remaining production (crude oil and gas) is shared among the oil-producing country or national oil company and the contractors according to fixed allocation ratios. (The contactors’ share of production after cost recovery is called “profit oil and gas.” In the case of natural gas, sales are conducted by Indonesia and the contractors receive cost recovery and profit gas in the form of cash.) On the other hand, in cases when exploration fails and expected production is not realized, the contractors are not to recover their invested funds.

(2) Accounting treatment of production sharing contracts

When a company in the Group owns participating interests under production sharing contracts, as mentioned above, in the role of contractor it invests technology and funds in the exploration and development of the property, recovers the invested costs from the production produced, and receives a share of the remaining production after recovery of invested costs as compensation.

Costs invested on the basis of production sharing contracts are recorded on the balance sheet as assets for which future recovery is anticipated under the item “Recoverable accounts under production sharing.” After the start of production, recovered costs on the basis of those agreements are deducted from this balance sheet item.

As production received under production sharing contracts is divided into the cost recovery portion and the compensation portion, the method of calculating cost of sales is also distinctive. That is to say, the full amount of production received is temporarily charged to cost of sales as the cost of received production, and subsequently the amount of the compensation portion is calculated and this amount is booked as an adjustment item to cost of sales (“Free of charge production allocated”). Consequently, only the cost recovery portion of production after deduction of the compensation portion is booked as cost of sales.

6. RELATIONSHIP WITH THE JAPANESE GOVERNMENT

(1) The Company’s relationship with the Japanese government

Although the government of Japan (the Minister of Economy, Trade and Industry) holds 18.94% of the Company’s common shares issued and a Class A Stock as of June 29, 2016, the Company autonomously exercises business judgment as a private corporation. There is no relationship of control, such as through the dispatch of officers or other means between the Company and the Japanese government. Moreover, we believe that no such relationship will develop in the future. Furthermore, there is no concurrent posting or secondment to the Company of officers or employees from the Japanese government.

(2) Ownership and sale of the Company’s shares by the Japanese government (the Minister of Economy, Trade and Industry)

The Ministry of Economy, Trade and Industry (METI) holds 18.94% of the Company’s common shares issued. METI succeeded to the shares that had been held by Japan National Oil Corporation (JNOC) following the dissolution of JNOC on April 1, 2005. With regard to the liquidation and disposition of the oil and gas upstream assets owned by JNOC, the Policy Regarding the Disposal of Oil and Gas Development-Related Assets Held by Japan National Oil Corporation (hereinafter, the “Report”) was announced on March 18, 2003 by the Japan National Oil Corporation Asset Evaluation and Liquidation Deliberation Subcommittee of the Advisory Committee on Energy and Natural Resources, an advisory body of the Ministry of Economy, Trade and Industry. The Report describes the importance of appropriate timing in selling the shares on the market, taking into consideration enterprise value growth. In addition, METI may, in accordance with the Supplementary Provision Article 13 (1) 2 of the “Special Measures Act for Reconstruction Finance Keeping After the Great East Japan Earthquake” (“the Reconstruction Finance Keeping Act“ (provisional translation, the same shall apply hereinaf ter)) enacted December 2, 2011, sell off the Company’s shares in Japan or overseas after examining the possibility of disposal of the said shares based on a review of the holdings from the perspective of energy policy. This could have an impact on the market price of the Company’s shares.

METI also holds one share of the Company’s Class A Stock. As the holder of a Class A Stock, METI possesses veto rights over certain resolutions of the Company’s general shareholders’ meetings and meetings of the Board of Directors. For details on the Class A Stock, please refer to “8. CLASS A STOCK” below.

7. TREATMENT OF SHARES OF THE GROUP’S PROJECT COMPANY OWNED BY JAPANESE GOVERNMENT AND JOGMEC

(1)Treatment of shares of the Group’s project company previously owned by Japan National Oil Corporation (JNOC)

In the aforementioned Report, INPEX CORPORATION (prior to the integration with Teikoku Oil; reorganized on October 1, 2008) was identified as a company that should comprise part of a core company, and is expected to play a role in efficient realization of a stable supply of energy for Japan through the involvement by a national flagship company. In response to the Report, the Company (also, the Group since our acquirement of Teikoku Oil on October 1, 2008) has sought to promote efficient realization of a stable supply of energy for Japan while taking advantage of synergy with the efforts of active resource diplomacy on the part of the Japanese government, and has aimed to maximize shareholder value by engaging in highly transparent and efficient business operations.

As a result, with regard to the integration by means of transfer of shares held by JNOC proposed in the Report, INPEX CORPORATION and JNOC concluded the Basic Agreement Concerning the Integration of Assets Held by JNOC into INPEX CORPORATION of February 5, 2004 (hereinafter the “Basic Agreement”) and a memorandum of understanding related to Basic Agreement (hereinafter “MOU”). On March 29, 2004, INPEX CORPORATION and JNOC entered into related contracts including the Basic Contract Concerning the Integration of Assets Held by JNOC into INPEX CORPORATION (hereinafter the “Basic Contract”), achieving the agreement on the details including the treatment of the project companies subject to the integration and shareholding ratios.

In 2004 INPEX CORPORATION accomplished the integration of Japan Oil Development Co., Ltd. (JODCO), INPEX Java Ltd. (disposal was completed on September 30, 2010) and INPEX ABK, Ltd. which are three of four companies covered by the Basic Agreement. Although INPEX Southwest Caspian Sea Ltd. (hereinafter “INPEX Southwest Caspian”) would become a wholly owned subsidiary of INPEX CORPORATION by means of a share exchange and the procedures were undertaken, the share exchange contract was invalidated owing to failure to accomplish the terms and conditions of the share exchange contract and the planned share exchange was cancelled. Following the dissolution of JNOC on April 1, 2005, the Minister of Economy, Trade and Industry succeeded to the INPEX Southwest Caspian shares held by JNOC. The Company continues to study the possibility to acquire the shares. However, the METI’s future treatment of these shares is undecided and, depending on the result of review in accordance with the Reconstruction Finance Keeping Act, acquisition of INPEX Southwest Caspian shares could be unavailable.

The treatment of Sakhalin Oil and Gas Development Co., Ltd. (hereinafter “SODECO”), INPEX Offshore North Campos, Ltd., INPEX Nor th Makassar, Ltd. (liquidation proceedings completed on December 19, 2008), INPEX Masela, Ltd., and INPEX North Caspian Sea, Ltd. was agreed between INPEX CORPORATION and JNOC in the MOU of February 5, 2004. Regarding the treatment of shares of SODECO, refer to the section “(2) Treatment of the shares of Sakhalin Oil and Gas Development (SODECO) owned by the Japanese government” below. With regard to the transfer to INPEX CORPORATION of the shares in the above project companies other than SODECO, it was decided that the shares are to be transferred for cash compensation as soon as prerequisites such as the consent of the oil-producing country and joint venture partners and the possibility of appropriate asset evaluations are in place. However, the transfer of shares held by JNOC in the above companies has not been decided and the shares in the above project companies were succeeded to by the Japan Oil Gas and Metals National Corporation (hereinafter “JOGMEC”) on the dissolution of JNOC on April 1, 2005, except shares related to INPEX North Makassar, Ltd., to which the Minister of Economy, Trade and Industry succeeded. JOGMEC states in its “medium-term objective” and “medium-term plan” that the shares succeeded to from JNOC will be disposed of at an appropriate time and in an appropriate manner, but the timing and manner of the disposal for the shares held by JOGMEC have not been decided, and it is possible that the Company will be unable to acquire the shares.

(2) Treatment of the shares of Sakhalin Oil and Gas Development (SODECO) owned by the Japanese government

The Japanese government (the Minister of Economy, Trade and Industry) owns 50% of the shares of SODECO. SODECO was established in 1995 to engage in an oil and natural gas exploration and development project located on the northeast continental shelf off Sakhalin Island. SODECO owns a 30.0% interest in the Sakhalin-1 Project, of which ExxonMobil of the United States is the operator. In October 2005, Phase 1 of this project started with the goal of advanced production of oil and natural gas. Furthermore, there is a plan for additional development operations (Phase 2) for the purpose of the fullscale production of natural gas. The Company holds 6.08% of SODECO shares issued and outstanding.

In the previously mentioned Report, SODECO, along with INPEX CORPORATION and JODCO, has been identified as a company that should comprise part of a core company in Japan’s oil and natural gas upstream industry in the future.

In accordance with the Report, it is assumed that privatesector shareholders, including INPEX CORPORATION, will acquire shares of SODECO issued and outstanding to which the Minister of Economy, Trade and Industry succeeded and that were previously held by JNOC (50.0%). The Company plans to hold a maximum of 33% of the SODECO shares to become its largest shareholder. In the event that the consent of SODECO’s joint-venture par tners, the relevant Russian government entity, or other parties is necessary for the acquisition of the shares, obtaining the consent is a prerequisite for acquisition. In addition, it will be necessary to reach agreement on the shareholder composition for SODECO, the share transfer price, and other matters.

In the event that the additional acquisition of the SODECO shares is realized, the Group will hold a substantial ownership interest in oil and natural gas assets in Russia, as well as in Asia and Oceania, the Middle East, Caspian Sea area, and other regions, and we expect the acquisition to contribute to the achievement of a more balanced overseas asset portfolio for the Group.

However, at this time it is undecided whether agreement concerning acquisition of the shares with the Minister of Economy, Trade and Industry will be reached as anticipated and will be realized. Also, even in the event that the acquisition is realized, the conditions and time of acquisition are undecided and, depending on the result of review in accordance with the Reconstruction Finance Keeping Act, the acquisition by the Company could be unavailable.

8. CLASS A STOCK

(1) Overview of the classified share
  1. Reason for the introduction
  2. The Company was established as the holding company through a stock transfer between INPEX CORPORATION and Teikoku Oil Co., Ltd. on April 3, 2006. Along with this, a classified share originally issued by INPEX CORPORATION (prior to the merger) was transferred and at the same time the Company issued a classified share with the same effect (hereinafter the “Class A Stock”) to the Minister of Economy, Trade and Industry. The classified share originally issued by INPEX CORPORATION was the minimally required and a highly transparent measure to eliminate the possibility of management control by foreign capital while not unreasonably impeding the efficiency and flexibility of management based on the concept in the Report discussed in the above section 7. “TREATMENT OF SHARES OF THE GROUP’S PROJECT COMPANY OWNED BY JAPANESE GOVERNMENT AND JOGMEC.” INPEX CORPORATION is identified as a company that should comprise part of a core company for Japan’s oil and gas upstream industry and is expected to play a role in efficient realization of a stable supply of energy for Japan as a national flagship company. On the basis of the concept of the Report, following a speculative acquisition or an attempt at management controlled by foreign capital, Class A Stock is designed and issued to be highly transparent while not unreasonably impeding the efficiency and flexibility of management and to keep the effects of any such speculative acquisition to the necessary minimum. At the same time, Class A Stock maintains the Company’s role in the efficient implementation of a stable supply of energy for Japan as a core business, so that management is not conducted in a way contradictory to that role and no negative impact is felt.

  3. Shareholders’ meeting resolutions, dividends, distribution of residual assets, and redemption
  4. Unless otherwise provided by laws or ordinances, the Class A Stock does not have any voting rights at the Company’s general shareholders’ meetings. With regard to cash dividends paid and the distribution of residual assets, the Company concluded a stock split at a ratio of 1:400 of common stock with October 1, 2013, as the effective date. For Class A Stock (unlisted) no stock split was conducted. The Articles of Incorporation specify that dividends of Class A Stock are equivalent to dividends of a common stock prior to the stock split. The Class A Stock will be redeemed by resolution of the Board of Directors of the Company if the holder of the Class A Stock requests redemption or if the Class A Stock is transferred to a party other than the government of Japan or an independent administrative body that is fully funded by the government of Japan.

  5. Veto rights in the Articles of Incorporation
  6. The Articles of Incorporation of the Company provide that an approval resolution of the meeting of the holder of the Class A Stock is necessary in addition to resolutions of the Company’s general shareholders’ meetings and resolutions of meetings of the Board of Directors for the decisions on certain important matters such as the appointment or removal of Directors, disposition of material assets, changes to the Articles of Incorporation, business integration, capital reduction or company dissolution in connection with the business of the Company. Accordingly, the Minister of Economy, Trade and Industry, as the holder of the Class A Stock, has veto rights over these important matters.

  7. Criteria for the exercise of veto rights provided in the criteria for the exercise of the Class A Stock holder’s voting rights
  8. Criteria concerning the exercise of the veto rights have been established in a Ministry of Economy, Trade and Industry Notice (No. 220, 2008) (hereinafter the “Notice”). The criteria stipulate the exercise of veto rights only in the following specific cases.

    • When resolutions pertaining to appointment or removal of Directors and integration are not voted down and it is judged that the probability is high that the Company will engage in management inconsistent with the role that a core company should perform for efficient realization of a stable supply of energy to Japan.
    • With regard to decisions related to the disposal of all or part of significant assets, when resolutions pertaining to disposition of material assets are not voted down and the objects of disposition are oil and natural gas exploration or production rights or rights similar thereto or shares or ownership interest in the Company’s subsidiary whose principal assets are said rights and it is judged that the probability is high that the Company will engage in management inconsistent with the role that a core company should perform for efficient realization of a stable supply of energy to Japan.
    • When resolutions pertaining to amendments to the Company’s Articles of Incorporation relating to changes in the Company’s business objectives, reduction in the amount of capital, or dissolution are not voted down and it is judged that the probability is high that the Company will engage in management inconsistent with the role that a core company should perform for efficient realization of a stable supply of energy to Japan.
    • When resolutions pertaining to amendments to the Articles of Incorporation granting voting rights to any shares other than the common shares of the Company are not voted down and could have an effect on the exercise of the voting rights of the Class A Stock.

    It is provided that the above criteria shall not be limited in the event that the Notice is changed in the light of energy policy.

(2) Risk in connection with the Class A Stock

Following a speculative acquisition or an attempt at management controlled by foreign capital, Class A Stock is designed and issued to be highly transparent while not unreasonably impeding the efficiency and flexibility of management and to keep the effects of any such speculative acquisition to the necessary minimum. At the same time, Class A Stock maintains the Company’s role in the efficient implementation of a stable supply of energy for Japan as a core business, so that management is not conducted in a way contradictory to that role and no negative impact is felt. Nevertheless, the anticipated risks in connection with the Class A Stock include the following.

  1. Possibility of conflict of interest between national policy and the Company and its common shareholders
  2. It is conceivable that the Minister of Economy, Trade and Industry could exercise the veto rights in accordance with the above criteria provided in the Notice. As the said criteria have been provided from the standpoint of efficient realization of a stable supply of energy to Japan, it is possible that the exercise of the veto rights by the Minister of Economy, Trade and Industry could conflict with the interest of other shareholders who hold the Company’s common shares. Also, it is possible that the said criteria could be changed in the light of energy policy.

  3. Impact of the exercise of veto rights on the price of shares of common stock
  4. As mentioned above, as the holder of the Class A Stock has the veto rights over certain important matters in connection with the business of the Company, the actual exercise of the veto rights over a certain matter could have an impact on the price of the Company’s shares of common stock.

  5. Impact on the Company’s degree of freedom in business and business judgment
  6. As the Minister of Economy, Trade and Industry holds the Class A Stock with the previously mentioned veto rights, the Company needs a resolution of the meeting of the holder of the Class A Stock concerning the above matters. For this reason, the Company’s degree of freedom in management in those matters could be restricted by the judgment of the Minister of Economy, Trade and Industry. Also, attendant on the need for a resolution of the meeting of the holder of the Class A Stock concerning the above matters, a certain period of time is required for procedures such as the convening and holding of meetings and resolutions and for the processing of formal objections, if necessary.

9. CONCURRENTLY SERVING OUTSIDE DIRECTORS

The Board of Directors of the Company is composed of 14 members, five of whom are outside directors.

The four outside directors have many years of management experience in the Company’s business and are able to offer objective, professional advice regarding operations. For this reason, they were asked to join the Board of Directors to contribute to the development of the Company’s business.

The four outside directors concurrently serve as director or advisors of Japan Petroleum Exploration Co., Ltd., Mitsubishi Corporation, Mitsui Oil Exploration Co., Ltd. and JX Holdings, Inc. (hereinafter “shareholder corporations”), respectively.

At the same time, however, the shareholder corporations are involved in businesses that overlap with those of the Company. The Company therefore recognizes that it must pay particular attention to corporate governance to avoid conflicts of interest in connection with competition and other matters.

To this end, all Company directors, including the four outside directors described above, are required to sign a written undertaking to carry out their duties as officers of the Company appropriately and with the highest regard for the importance of such matters as their obligations in connection with noncompetitive practices under the Japanese Companies Act, the proper manner for dealing with conflict of interest, and confidentiality.

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