Indonesia's proven oil reserves at the end of 2018 amounted to 3.2 billion barrels, with production at 39.5 million tonnes per annum. With respect to gas, Indonesia's proven gas reserves at the end of 2018 were 97.5 trillion cubic feet, with production amounting to 62.9 million tonnes per annum.2
Oil and gas business activities in Indonesia are divided into the upstream sector (exploration and exploitation) and the downstream sector (processing, transportation, storage, and trading).
In 2017, Indonesian President Joko 'Jokowi' Widodo issued a regulation3 classifying a number of upstream oil and gas projects as national strategic projects in an effort to increase Indonesian oil and gas production. Classifying these as national strategic projects allows the government, through the Coordinating Ministry for Economic Affairs, to make sure these projects can be put on stream immediately by expediting the infrastructure required for the projects and the issuance of regulations for their implementation. The national strategic upstream oil and gas projects are:
|No.||Project name||Operator||Onstream schedule||Expected production|
|1.||Abadi Field Project||Inpex Masela, Ltd||2027||10.5 million tonnes of gas per annum|
|2.||Indonesia Deepwater Development||PT Chevron Pacific Indonesia||2024||1.120 million standard cubic feet of gas per day and 40,000 barrels of oil per day|
|3.||Jambaran-Tiung Biru Field||PT Pertamina EP Cepu||2021||190 million standard cubic feet of gas per day|
|4.||Tangguh Train-3||BP Berau BV||2020||3.8 million tonnes of LNG per annum|
The Indonesian oil and gas industry, like the global industry, has experienced significant difficulties due to the collapse of global oil prices. While oil prices are beginning to return to more normal levels, the government still faces the problem of a lack of new reserve discoveries. Part of this is because of the overall struggles of the global industry, but it would also be difficult to ignore the role of domestic regulatory and bureaucratic issues, specifically for foreign investors. To attract new business players to the upstream oil and gas industry, President Jokowi, through the Minister of Energy and Mineral Resources (MEMR), has attempted to clarify and simplify the regulatory regime of the oil and gas industry. These efforts include the issuance of tax incentives and facilities, the revocation of exploration permit requirements, and the relaxation of restricted positions for expatriate employment, as discussed in greater detail below.
In general, upstream oil and gas business activities by oil companies are based on a contract, known as a production sharing contract (PSC), between the government, (through the Special Task Force for Upstream Oil and Gas Business Activities (SKK Migas), and the oil company as a PSC contractor. Up until 2017, there was only one form of PSC, with a cost-recovery mechanism, called a cost recovery PSC. In January 2017, the MEMR introduced a new PSC scheme based on a gross production split without a cost-recovery mechanism, called the gross split PSC.
Other major recent developments include:
- MEMR Regulation No. 15 of 2018 regarding Post-Operation Activities in Upstream Oil and Gas Business Activities (MEMR Reg 15/2018), which requires PSC contractors to carry out post-operation activities and deposit funds for post-operation activities in a joint account of SKK Migas and the PSC contractor;
- MEMR Regulation No. 42 of 2018 regarding the Priority to Use Crude Oil for Meeting Domestic Needs (MEMR Reg 42/2018), which requires PSC contractors to prioritise offering their crude oil portion to Pertamina, an Indonesian state-owned oil and natural gas corporation, before exporting the crude; and
- Government Regulation No. 1 of 2019 on Export Proceeds from Exploitation, Management and/or Processing Activities of Natural Resources (GR 1/2019), which requires foreign exchange proceeds derived from the export of natural resources, including oil and gas, to be placed in a special account in an Indonesian foreign exchange bank.
The above developments have become an issue for existing PSC contractors whose PSCs do not provide these requirements and indeed specifically allow funds from oil and gas sales to be held and retained abroad.
II LEGAL AND REGULATORY FRAMEWORK
i Domestic oil and gas legislation
Main legislation specific to upstream oil and gas, including summary of key provisions
The upstream oil and gas sector in Indonesia is mainly regulated by Law No. 22 of 2001 regarding Oil and Natural Gas (the Oil and Gas Law). Further provisions are regulated under Government Regulation No. 35 of 2004 regarding Upstream Oil and Natural Gas Business Activities, as amended most recently by Government Regulation No. 55 of 2009 (GR 35/2004).
In general, the Oil and Gas Law grants the government the exclusive right to oil and gas exploration and exploitation, and requires all private companies that wish to explore and exploit oil and gas resources to enter into cooperation contracts with the government through SKK Migas. Such cooperation contracts most often take the form of a PSC.
There are currently two types of PSCs used for Indonesian upstream oil and gas business activities. Before 2017, all PSCs contained a cost recovery scheme, where PSC contractors could obtain reimbursement of their operating costs through the production of oil and gas. In mid-January 2017, the government introduced gross split PSCs with no cost recovery arrangements. Under a gross split PSC, the government allowed PSC contractors a higher production split than that allowed under the cost recovery scheme but all costs had to be borne by the PSC contractors.
The key provisions of the Oil and Gas Law include the following: (1) the government's entitlement to oil and gas resources up to the delivery point; (2) SKK Migas' control over the management of oil and gas operations;4 (3) all capital and risks of oil and gas operations are to be borne by PSC contractors; (4) one company can only hold one oil and gas working area; (5) the term of a PSC is 30 years, which can be extended a maximum of 20 years; and (6) PSC contractors are obligated to provide 25 per cent of their production share to fulfil domestic demands.
Regulatory agencies with responsibility for upstream oil and gas
The regulators' powers
The MEMR, through the Directorate General of Oil and Gas (DGOG), oversees affairs in the energy and mineral resources sector, including supervision of the implementation of oil and gas business activities, preparation of policies for the upstream oil and gas business sector, determination of cost-recoverable and non-cost-recoverable activities in the upstream oil and gas business, and issuance of approvals related to upstream oil and gas activities, such as the first plan of development (POD), the transfer of participating interests, and direct and indirect change of control of the entities holding a PSC.
With the issuance of the Presidential Regulation No. 9 of 2013 regarding Management of Upstream Oil and Gas Activities, as amended by Presidential Regulation No. 36 of 2018, the upstream sector is managed and supervised by SKK Migas. In general, SKK Migas has the right to organise the management of upstream oil and gas activities, to the extent the management is in accordance with the relevant PSC. The Head of SKK Migas reports directly to the President. In performing its duties, SKK Migas is supervised by a supervisory committee, consisting of the MEMR, a Deputy MEMR, a Deputy Minister of Finance (MOF) and the Head of the Capital Investment Coordinating Board.
Currently, a draft oil and gas law is being finalised by the House of Representatives. One of the anticipated changes in the new law includes the establishment of a Specific Oil and Gas Business Entity (BUK Migas), which will take over the current authorities of SKK Migas and also manage downstream oil and gas activities.
PSC contractors' activities are subject to audit by the government. The auditing authority rests with the Agency for Finance and Development Supervision (BPKP). Based on GR No. 60 of 2008 regarding the government's internal management system, the BPKP has the authority to audit the state treasury as part of an internal government audit. These audits include state revenue and expenses including the allocation of cost-recovery costs under the state budget. With respect to the audit of income tax obligations, a joint audit will be conducted by BPKP, SKK Migas, and the Directorate General of Taxation, based on MOF Regulation No. 34/PMK.03/2018 regarding Implementing Guidelines for Joint Audits of the Implementation of Cooperation Contracts in the Form of Production Sharing with Recovery of Operating Costs in the Upstream Oil and Gas Business.
While Indonesia does not recognise foreign court decisions, international arbitration awards can be enforced in Indonesia through mechanisms provided in Law No. 30 of 1999 regarding Arbitration and Alternative Dispute Resolution. In general, Indonesia has bound itself to enforce foreign arbitral awards if (1) the award is rendered by a tribunal in a country bound by the 1958 New York Convention on the Recognition and Enforcement of Foreign Arbitral Awards (the Convention) or a bilateral treaty with Indonesia; (2) the dispute is commercial in nature, as that term is understood under Indonesian law and the Convention; and (3) the award does not contravene Indonesian law or notions of public order or policy.
International treaties and other multinational agreements are binding upon Indonesia after ratification, which may be done by way of a law to be approved by the House of Representatives, or by way of a presidential regulation to be further implemented by a ministerial regulation, which will be notified to the House of Representatives. All regulations and decrees issued afterwards must not deviate from the provisions of the international treaty or the national regulation enacted in light thereof. Therefore, once an international treaty is binding upon the government, regulatory policy or activity shall develop in accordance with the international treaty. Indonesia is a party to, among others, the United Nations Convention on the Law of the Sea (UNCLOS), the 1987 Montreal Protocol, and the International Convention on Civil Liability for Oil Pollution Damage and the protocols and amendments thereof.
Indonesia has entered into many bilateral tax treaties with other countries to avoid the imposition of double taxation in both countries. As of 2019, Indonesia has 66 double tax treaties with contracting states including Australia, France, Japan, Malaysia, Singapore, the United Arab Emirates and the United States.
The right to explore oil and gas is provided by the execution of cooperation contracts, generally based on a production sharing scheme through a PSC between the government, through SKK Migas, and the company that wins the right to the working area covered by the PSC. Pursuant to MEMR Regulation No. 35 of 2008 regarding Procedures for the Stipulation and Tender of Oil and Gas Working Areas, a working area can be offered either through a direct offer or a tender. In a direct offer, a company that performs a technical assessment through a joint study with the DGOG will receive the right to match the highest bidder of the tender round. Most new working areas are awarded through a tender process.
A PSC is granted for 30 years, typically comprising six plus four years of exploration and 20 years of exploitation. A PSC that has entered into the exploitation phase shall be subject to cost recovery. The production output of the traditional cost recovery PSC is subject to a first tranche petroleum (FTP) requirement where 10 per cent of oil and gas production shall be given to the government first and the remaining portion will be distributed between the PSC contractor and the government based on the production split proportions set out in each PSC, cost recovery and certain taxes.
In 2017, MEMR Regulation No. 8 of 2017 regarding gross split PSCs, as amended by MEMR Regulation of 52 of 2017, introduced a gross split production sharing scheme through a gross split PSC. The gross split is agreed through negotiations with SKK Migas, and the production output is split at gross without FTP or cost recovery, stipulated at the beginning of a field's development and subject to fluctuation depending on certain variables and progress components.
In general, GR 35/2004 provides that a PSC should at least contain the following provisions: state revenues, the working area and its relinquishment, obligatory funding expenses, the transfer of ownership of oil and gas production, the contract period and contract extension requirements, settlement of disputes, the obligation to supply crude oil or natural gas (or both) for domestic needs, post-mining operation obligations, occupational health and safety, environmental management, the transfer of rights and obligations, reporting requirements, field development plans, preferential utilisation of domestic goods and services, the development of the surrounding community and a guarantee of the rights of nearby traditional communities and the prioritisation of the use of Indonesian workers.
Below is a table summarising brief key differences between cost recovery and gross split PSCs.
|Description||Cost recovery PSCs||Gross split PSCs|
|Production sharing split||Depending on each PSC, typically 65:35 between the government and the PSC contractor for oil, and 60:40 between the government and the PSC contractor for gas||57:43 between the government and the PSC contractor for oil, and 52:48 between the government and the PSC contractor for gas, both of which can be increased based on:
|Approvals required||Approvals are provided for work programmes and budgets (WP&B) and the POD, and the Authorisation for Expenditure (AFE)||Approvals are provided for the POD.|
|Recovery of costs||All allowable current costs as well as amortised exploration and capital costs||None.|
|Procurement of goods and services||Regulated under the prevailing working guidelines issued by SKK Migas||Managed independently by each PSC contractor, not based on SKK Migas working guidelines.|
|• PricewaterhouseCoopers, Oil and Gas in Indonesia, Investment and Taxation Guide (May 2018, 9th edition).|
The continuation of operations following the expiration of the term of a relevant PSC is regulated under MEMR Regulation No. 23 of 2018 regarding the Management of Oil and Gas Working Areas with Expiring PSCs, as most recently amended by MEMR Regulation No. 3 of 2019. This regulation provides that upon the expiry of a PSC, a PSC may either be taken over by Pertamina, extended, jointly operated by Pertamina and the PSC contractor, or tendered to the public.
IV PRODUCTION RESTRICTIONS
Oil and gas production remains owned by the state until its possession is delivered at the point of export or other delivery point. Once it reaches the point of export or other delivery point, the PSC contractor is entitled to any production of oil and gas based on the production split as regulated under the PSC.
The PSC contractor can take its share of the oil and gas production in kind. For oil production, the PSC contractor may take its oil production share in kind and sell it with the option not to commingle the sale with the government's share of oil production. For gas production, in practice, the PSC contractor's and the government's share of production are sold jointly.
Exports of oil and gas are subject to the fulfilment of the Domestic Market Obligation (DMO) and the initial domestic offering under MEMR Reg 42/2018. This regulation requires PSC contractors or their affiliates to offer their crude oil portion to Pertamina or holders of the crude oil processing licence, or both, through a negotiation process on a business-to-business arrangement no later than three months before commencing the export recommendation period for the PSC contractor's entire portion of crude oil. Through the negotiation process, Pertamina may directly appoint a PSC contractor for the purchase of the crude oil, which may be made in the form of a long-term contract with a term not to exceed 12 months.
In January 2019, the government issued GR 1/2019. This regulation requires foreign exchange proceeds derived from the export of natural resources, including oil and gas, to be placed in the Indonesian financial system through a special account in an Indonesian foreign exchange bank, which must be licensed by the Financial Services Authority. The Indonesian branch offices of overseas banks do not satisfy this requirement. The placement of the export proceeds in a special account must be carried out no later than the end of the third month after the registration of export declaration. The funds in the special account can only be utilised by the PSC contractor for certain payments, such as customs, loans, imports, profits or dividends, and other purposes permitted by the Indonesian Investment Law (namely Law No. 25 of 2007 regarding Capital Investment).
A PSC contractor is required to fulfil the DMO by supplying oil or gas, or both, to meet domestic needs. The participation of the PSC contractor is determined on a prorated basis in accordance with its share of total oil and gas production. Typically, the amount of the PSC contractor's participation is 25 per cent of the oil and gas production, subject to stipulation by the MEMR. In the past, there was no DMO requirement related to gas production. A DMO requirement for gas was introduced in PSCs that were signed after the issuance of the Oil and Gas Law.
The value of oil to determine the sharing of production and for tax purposes must be not less than the Indonesian crude price (ICP). With respect to gas, the relevant gas sales contract is based on negotiations on a field-by-field basis between SKK Migas, buyers and individual producers. There is a requirement that the determination of gas prices by a PSC contractor must follow the considerations provided under MEMR Regulation No. 6 of 2016 regarding Provisions and Procedures for Determining the Allocation, Utilisation and Price of Gas, namely the economics of a particular gas field, domestic and international gas prices, and the added value of the domestic utilisation of gas. After determining the gas price, it must be submitted to the MEMR, through SKK Migas, for approval.
V ASSIGNMENTS OF INTERESTS
PSCs contain different approval requirements for the transfer of participating interests, depending on when they were entered into. For a transfer to an affiliated company, some PSCs do not require any approval. For a transfer to a non-affiliated company, PSCs require either the approval of the MEMR, the MEMR and SKK Migas, or the MEMR through SKK Migas. As noted, the different approval requirements depend on the generation of the signed PSC.
For the sake of unification, the MEMR issued MEMR Regulation No. 48 of 2017 regarding Business Supervision in the Energy and Mineral Resources Sectors (MEMR Reg 48/2017), which requires prior approval from the MEMR, through SKK Migas, to transfer a participating interest to affiliated or non-affiliated companies. In practice, the government currently refers to the transfer of participating interest approval requirements in MEMR Reg 48/2017 rather than those set forth in individual PSCs.
It is to be noted that GR 35/2004 and MEMR Reg 48/2017 prohibit a PSC contractor from transferring its majority participating interest to a non-affiliated party within the first three years of the PSC contractor's exploration period.
A change of control through the transfer of a majority of the shares of a PSC contractor, on the other hand, does not always require the approval of the MEMR (through SKK Migas). A change of control can take one of two forms, namely a direct change of control and an indirect change of control. MEMR Reg 48/2017 defines 'direct control' as the direct ownership by a parent company being one level above through the ownership of a majority of the shares having voting rights. It is commonly understood that 'indirect control' means transfer of shares by a parent company beyond one level above that owns a majority of the shares with voting rights in a PSC contractor.
Only PSCs signed in 2008 and later require approval for a direct and indirect change of control, either from the MEMR, through SKK Migas, or from both the MEMR and SKK Migas. MEMR Reg 48/2017 requires the prior approval of the MEMR, through SKK Migas, for a direct change of control and notification to the MEMR, through SKK Migas, for an indirect change of control, which is typically given after the transaction has been completed. In practice, the government currently refers to MEMR Reg 48/2017 and not PSCs for the approval and notification requirement for direct and indirect changes of control.
The government does not have a right of first refusal or preferential purchase rights upon a transfer of a participating interest or a change of control. Other than imposing a final tax to be paid out of the consideration for any transfer of a participating interest or change of control (i.e., 5 per cent for a transfer during the exploration stage and 7 per cent for a transfer during the exploitation stage), the government does not impose any other requirements with respect to the consideration for any transfer of a participating interest or a change of control. Therefore, the consideration can be agreed between the parties in the transfer documentation.
A PSC contractor is required, under MEMR Regulation No. 37 of 2016 regarding the Requirement to Offer a 10 per cent Participating Interest in an Oil and Gas Block (MEMR Reg 37/2016), to offer through SKK Migas a 10 per cent participating interest to a regionally owned business entity (BUMD) or state-owned business entity (BUMN) after the first commercial discovery. In essence, MEMR Reg 37/2016 regulates that following the first approval of a POD, SKK Migas will notify the governor of the relevant working area. Within a period of one year, the governor must prepare a BUMD and submit a letter to SKK Migas indicating the appointment of the BUMD. SKK Migas will deliver the letter to the relevant PSC contractor requesting it to start the offer process to the BUMD. If the BUMD rejects the PSC contractor's offer (or if the governor does not submit the letter to SKK Migas), the PSC contractor must offer the 10 per cent participating interest to a BUMN. There is no regulation that establishes the purchase price or the valuation method for the 10 per cent participating interest.
Taxes that are applicable to PSCs include income tax, value added tax, import duties, regional taxes and other levies. Each PSC may stipulate whether the tax laws and regulations applicable at the time the PSC was executed shall apply or whether the PSC shall follow changes to tax laws and regulations that are issued over time. Currently, the income tax rate is 25 per cent. VAT has a rate of 10 per cent, which is imposed on the provision of services and may be reimbursed with respect to cost recovery PSCs. Branch profits tax (BPT), which is assessed on the after-tax profits of a PSC contractor's permanent establishment (i.e., a foreign entity as discussed below), also applies and has a rate of 20 per cent, subject to reduction under an applicable tax treaty. If the PSC contractor is a business entity (i.e., an Indonesian entity as discussed below), the BPT is not applicable; however, its disbursements of dividends are subject to a withholding tax of 20 per cent, from which an exemption can be obtained if (1) the dividend is derived from retained earnings of the business entity, or (2) the recipient of the dividend is a legal entity holding at least 25 per cent of the shares in the business entity. In addition, PSC contractors are required to pay non-tax state revenues such as exploration and exploitation fees and bonuses, including signing bonuses and production bonuses, which vary depending on the PSC.
Currently, tax arrangements for cost recovery PSCs are regulated under Government Regulation No. 79 of 2010, as amended by Government Regulation No. 27 of 2017 (GR 79/2010). Tax arrangements applicable for gross split PSCs are regulated under Government Regulation No. 53 of 2017 regarding Tax Treatment for Upstream Oil and Gas Business Activity through Gross Split PSCs (GR 53/2017).
In general, both GR 79/2010 and GR 53/2017 regulate the taxation of the production sharing income and non-production sharing income of PSC contractors. Both Regulations allow certain tax incentives and tax facilities. The tax facilities under GR 79/2010 and GR 53/2017 are similar. During both the exploration and exploitation stages, there is an exemption from import duty for the import of goods used in the context of petroleum operations, an exemption from VAT or Luxury Goods Sales Tax for certain goods and services used in the context of petroleum operations, a reduction in the Land and Building Tax (PBB) amounting to 100 per cent, which is applicable during the exploration stage, and a reduction of subsurface PBB amounting to 100 per cent, which is applicable during the exploitation stage. Tax facilities in the exploitation stage will be granted by the MOF based on its consideration of project economics. GR 79/2010 provides tax incentives including a DMO holiday (with no time limit specified), a range of tax incentives as long as they are in accordance with the prevailing tax laws and a range of non-tax state revenue incentives including the use of state-owned assets for upstream activities.
VII ENVIRONMENTAL IMPACT AND DECOMMISSIONING
PSC contractors are required to comply with the provisions of occupational health and safety, environmental management, and community development regulations. In the exploration stage, PSC contractors must complete an environmental monitoring and environmental management report (UKL/UPL). In the exploitation stage, PSC contractors must further conduct an environmental assessment (AMDAL), which must be approved by the relevant government authority. PSC contractors are also required to make periodic reports to the relevant government authority regarding their compliance with the UKL/UPL or AMDAL. In addition, Law No. 32 of 2009 regarding Protection and Management of Environment requires PSC contractors to obtain an environmental licence from the Minister of Environment and Forestry. While the DGOG is responsible for supervising the implementation of health, safety and environment (HSE) regulations in the oil and gas sector and imposing sanctions for non-compliance, it designates mining inspection enforcement teams to examine the work safety compliance of oil and gas businesses. If the facilities and techniques satisfy work health and safety standards, the DGOG will issue certifications for installations and equipment. In the event that a company does not comply with applicable HSE rules, it will be subject to various administrative sanctions ranging from warnings to the revocation of its licence.
The Oil and Gas Law highlights post-operation obligations as a means of ensuring environmental management and protection, and GR 35 obligates contractors to allocate funds for post-operation activities. In 2018, the MEMR issued MEMR Reg 15/2018 on abandonment and site restoration activities, or post-operation activities. This Regulation requires PSC contractors to carry out post-operation activities before or on the expiry of the PSC. Post-operation activities include well-plugging, site restoration and managing the disposal of equipment, installations and facilities. These post-operation activities must be initially reported to SKK Migas through the submission of a WP&B (if the PSC is in the exploration stage) or through a POD (if the PSC is in the exploitation stage). PSC contractors are also required to deposit funds for post-operation activities in a joint account between SKK Migas and the PSC contractor in an Indonesian state-owned bank. The deposited funds must be in accordance with the estimated costs in the post-operation activities plan submitted to SKK Migas. Other specific decommissioning obligations include land reclamation and the dismantlement of facilities that are no longer used.
VIII FOREIGN INVESTMENT CONSIDERATIONS
Timing and procedure for establishment of a local entity or branch of a foreign entity.
Under the Oil and Gas Law and GR 35/2004, upstream oil and gas business activities may be carried out by a business entity or a permanent establishment (PE). A business entity is a legal entity established under the laws of Indonesia and operating and domiciled in Indonesia. It may be in the form of a state-owned enterprise, a regional administration-owned company, a cooperative, a small-scale business or a private business entity. A PE is a business entity established and existing outside the territory of Indonesia that engages in activities within the territory of Indonesia and is subject to prevailing Indonesian laws and regulations. An offshore subsidiary holding the participating interest in a PSC is considered a PE.
A business entity can be in the form of a wholly Indonesian-owned company (PMDN) or a partially or wholly foreign-owned company (PMA). Please note that under the Oil and Gas Law, only one PSC may be granted to each company, meaning that one company cannot hold a participating interest in more than one PSC. However, several companies can own participating interests in a single PSC.
Before a PMDN or PMA can be established, it must meet the minimum capital requirements, which are significantly higher for a PMA. The establishment of a PMDN is less complicated; it can freely determine its line of business and may freely modify or change its line of business by simply amending its articles of association. A PMA must comply with foreign ownership requirements by referring to the prevailing negative investment list issued by the government. In the current negative investment list, upstream oil and gas activities are open to 100 per cent foreign ownership. The process for establishing a PMDN and PMA consists of the preparation of a deed of incorporation by a notary, approval of the deed by the Minister of Law and Human Rights, and the issuance of a taxpayer registration number (NPWP). With the establishment of the single-window licensing platform, called the online single submission (OSS) system, through the issuance of Government Regulation No. 24 of 2018 regarding Electronic Integrated Business Licensing Services (GR 24/2018), a PMDN and PMA in the oil and gas sector must be registered in the OSS system to obtain a business identification number (NIB). The establishment process can take a total of three to four weeks.
The establishment of a PE, on the other hand, is significantly simpler. Other than a requirement to obtain an NPWP, it only has to register with the OSS system to obtain an NIB, which is required by common practice despite GR 24/2018 not specifically requiring a PE to do so. In total, the establishment process can take three to four weeks.
ii Capital, labour and content restrictions
In the Indonesian oil and gas sector, capital refers to funds that are disbursed during the operation of the PSC. For cost recovery PSCs, the only restriction on the movement of funds is that a PSC contractor's funds during the implementation of the PSC can only be disbursed to the extent it is in accordance with the yearly WP&B or AFE, or both, approved by SKK Migas. Any excess of funds requires a separate approval from SKK Migas. Gross split PSCs do not contain any restriction on the utilisation of funds during the implementation of PSC operations as the budgets are not approved by SKK Migas.
Bank Indonesia Regulation No. 17/3/PBI/2015 regarding the Mandatory Use of Rupiah (PBI 17/2015) restricts most transactions within the Indonesian territory from being carried out using foreign currency. Bank Indonesia Circular Letter No. 17/11/DKSP was issued as an implementing regulation for PBI 17/2015 and it exempts oil and gas infrastructure projects from the required use of rupiah for transactions. To obtain the exemption, the project owner must seek confirmation from the relevant ministry and obtain a waiver letter from Bank Indonesia.
SKK Migas Working Guideline No. PTK-007/SKKMA0000/2017/S0 (Revision 04) Book Two regarding Guidelines for the Implementation of Goods/Services Procurement requires business players to prioritise local goods, services, technology, and design and engineering, so long as they are of comparable quality, price and availability. Indonesian-made equipment must be purchased if it meets the requirements, even if the cost of the equipment is higher than foreign-made equipment. Local goods must be given preference if their price is within 15 per cent of the lowest tender price and within 7.5 per cent for local services. Goods, services, technology, and design and engineering can be imported if they are not produced domestically. These Guidelines do not apply to gross split PSCs.
PSCs require that PSC contractors give preference to qualified Indonesian personnel and train such personnel for staff positions, including in administration and executive management. The Oil and Gas Law also requires PSC contractors to prioritise Indonesian personnel. PSC contractors may employ expatriates if the expertise is unavailable in Indonesia. In 2018, the government relaxed the restricted positions for expatriates in the oil and gas sector by revoking MEMR Regulation No. 31 of 2013 regarding the Procedures to Utilise Expatriates in Oil and Gas Activities. This is supervised by way of expatriate and local manpower utilisation plans submitted by the PSC operator to SKK Migas for its review and approval.
The relevant anti-corruption laws and regulations in Indonesia consist primarily of the Indonesian Criminal Code, Law No. 11 of 1980 regarding Bribery and Law No. 31 of 1999 regarding the Eradication of Criminal Acts of Corruption (the Corruption Law). The Corruption Law applies to government officials or any other person who commits an illegal act to enrich himself or herself or who favours himself or herself or abuses power, opportunity or facilities, which in either case may harm state finances and the national economy. Any person who accepts or makes any gift in kind or payment in view of a government official's position or authority is guilty of an act of criminal corruption, whether or not a loss is suffered by the state as a result.
Despite having laws and regulations for the prevention of corruption in Indonesia, anti-corruption efforts have proven difficult to implement. Historically, major corruption cases have resulted in the issuance of new regulations, in the hope they would eradicate corruption practices in the future. One example of this involves Pertamina, which in the past served as both regulator and operator, prompting the issuance of the Oil and Gas Law to end Pertamina's regulatory rights.
Research by the professional services firm Ernst & Young found that the highest risk of corruption was among vendors that provide goods and services to PSC contractors, during the procurement process and related to permitting and licensing.5 In 2013, the head of SKK Migas was arrested for taking bribes from a Singaporean oil company as part of a tender. Also, the complicated procedures for obtaining the numerous exploration licences required have created an environment conducive to bribery, corruption and extortion. In February 2018, the MEMR issued regulations to revoke past regulations related to licensing and simplify the number of exploration licences required.
A recent major corruption case has caused some legal uncertainty, in particular as to the line between bad business decisions and graft. In June 2019, the former president director of Pertamina was sentenced to eight years in prison for her involvement in alleged graft related to Pertamina's investment in an Australian block, which ultimately resulted in losses to the company and caused state losses amounting to 568 billion rupiah. Some observers say there was a lack of legal evidence to prove graft and that the losses may simply have resulted from a bad investment. This begs the question as to the extent that bad business decisions in the oil and gas industry can be criminally charged.
IX CURRENT DEVELOPMENTS
A draft of a new oil and gas law is being prepared by the House of Representatives. This new oil and gas law is widely expected to change the oil and gas regulatory framework, with the proposed changes including the establishment of BUK Migas to replace SKK Migas, increased privileges for Pertamina in acquiring work areas, contracts and licensing mechanisms in the upstream sector, the prescribed maximum period for exploration activities, and an obligation to dedicate production to the domestic market through a safeguarding business entity established by the law.
The largest reserve in almost two decades was recently discovered, in the Sakakemang Block in South Sumatra. According to preliminary estimates, the discovery holds at least 2 trillion cubic feet of recoverable gas resources. As the discovery was made only recently, the relevant block will require further exploration and evaluation before actual production can begin, in about 10 to 15 years.
In 2018, Pertamina, through its subsidiaries, took over several expiring PSCs from PSC contractors, including the East Kalimantan and Attaka PSC from Chevron Indonesia Company, the Rokan PSC from PT Chevron Pacific Indonesia and the Mahakam PSC from Total E&P Indonesie. In 2019, the Corridor PSC in South Sumatra was granted an extension, in which ConocoPhillips (Grissik) Ltd, Talisman Corridor Ltd (Repsol), and Pertamina Hulu Energi Corridor will have the right to the Corridor PSC until 2043, with the PSC adjusted from a cost recovery PSC to a gross split PSC.
Also recently, the government announced the results of the first phase of oil and gas working area tenders for 2019. Three exploration blocks (Anambas, West Ganal and West Kaimana), and two production blocks (Selat Panjang and West Kampar) were tendered. For the second phase, three exploration blocks (Kutai, Bone and West Ganal) and one production block (West Kampar) were tendered. The third phase of oil and gas working area tenders for 2019 is now open and will be closed on 25 October 2019. For the third phase, four blocks (East Gebang, West Tanjung I, Belayan I and Cendrawasih VIII) were tendered.
1 Darrell R Johnson is senior of counsel and Fransiscus Rodyanto is a partner at SSEK Legal Consultants.
2 BP Statistical Review of World Energy 2019, 68th Edition.
3 Presidential Regulation No. 58 of 2017 regarding Amendment to Presidential Regulation No. 3 of 2016 regarding Acceleration of the Implementation of National Strategic Projects (16 June 2017).
4 Initially, the government through the Oil and Gas Law granted the authority over the management of upstream oil and gas operations to the Implementing Body of Upstream Oil and Gas Activities (BP Migas). However, a Constitutional Court Decision in 2012 disbanded BP Migas by declaring that its authority was unconstitutional. Afterward, the authority was transferred to a newly established entity, SKK Migas, through the issuance of Presidential Regulation No. 9 of 2013 regarding Management of Upstream Oil and Gas Activities, as amended by Presidential Regulation No. 36 of 2018.