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Cambodia December 2004
1
General aspects of petroleum fiscal regimes
Dr. Alfred KjemperudThe Bridge Group AS
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Opening Statements
• The fiscal arrangement is the Government’s most important tool for managing petroleum resources
• It is mandatory for all managers and technical personnel in the Government and industry to understand the basics of fiscal arrangements
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Government Options
• Value of National Resources -Determining Factors
– The resource base– The market – oil price– Terms and regulations
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Costs
Income
Time
Pre-license Exploration Development Production AbandonmentProduction
Rehab.
Government
Activities and cash flow
Con
trac
t sig
ning
PDO
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The role of the authorities
– Definition of policy– Setting of terms– Promotion– Licensing– Monitoring and supervision– Adjustment of terms as required– Managing the impact
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Petroleum Fiscal Regimes• Covers :
– Legislative issues– Tax issues– Contractual issues
• There are more fiscal systems in the world than there are countries due to:– Negotiation of Terms– Numerous vintages
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Legal/Contractual FrameworkThe Constitution
The fundation which is the basis for all other regulationsThe Law
E.g. tax lawPetroleum Law and Legislation
Not all countries have a separate petroleum law. If that is the case the contract has to cover all aspects
Nigeria: Petroleum Act, 1969Production sharing Contract
Concessionary agreement in countries using that system
Nigeria: Model Contract 1999Joint Operating Agreements
Between partners in a field (can also be the state company)
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Economic Rent• The Classic Definition by Economists
– The produce of the earth derives from labour and capital
– The produce is divided between:• Labourers (Wages)• Owners of Capital (Profit)• Owners of Land (Rent)
– Rent = Value – Cost– Rent = Gross Revenue –Total Cost
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Resource RentAllocation of revenues from Production
After Johnston (1995)
•Bonuses•Royalties•Prod. Sharing•Taxes•Gov. Participation
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Regressive - Progressive
Regressive Progressive
Bonuses Royalties Profit TaxProduction Sharing
Gov
ernm
ent R
isk
The non profit based government takes are regressive i.e. the lower profitability the higher effective tax
Before cost recovery Cost recovery phasesPr
e disc
overy
Post
disco
very
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Regressive system
85 %
0 %
20 %
40 %
60 %
80 %
100 %
Applica
tion f
eeSigna
ture bon
usDisc
overy
bonu
s
Produc
tion fe
e/Roy
alty
Produc
tion Sha
ring
Income T
ax
Specia
l Petro
leum Tax
Repatria
tion Tax
Individual taxesCummulative taxation
Regressive Progressive
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Progressive system
85 %
0 %
20 %
40 %
60 %
80 %
100 %
Applica
tion f
eeSigna
ture bon
usDisc
overy
bonu
s
Produc
tion fe
e/Roy
alty
Produc
tion Sha
ring
Income T
ax
Specia
l Petro
leum Tax
Repatria
tion Tax
Individual taxesCummulative taxation
Regressive Progressive
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Rent vs. Risk• The Profit Margin for the Oil
Companies must be large enough to accommodate failures – A majority of the exploration possibilities are
unsuccessful
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Risk- & Non Risk-Takers• Fiscal Terms must account for the
large Risk in the Oil Business
– Oil Companies are High Risk TakersCompanies can reduce risk by
diversification
– Governments are Low Risk Takers Governments can reduce risk by introducing a Regressive tax system (Bonuses and Royalties)
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Poor GoodGeological Promise
Gov
ernm
ent T
ake
Low
High
High interest from Oil CompaniesPotential for higher Government take
Low interest from Oil CompaniesLow potential for any Government take
Optimized Fiscal Terms
Global Exploration Market
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Value of Discovery after TaxIllustrated as Field Size
A 25 million bbl field in Ireland gives the same profit after tax for the oil company as a 144 million bbl field in Indonesia
The Importance of Fiscal Regimes
117
46
75
45
144
25
99104 104
40
63
49
94
0
20
40
60
80
100
120
140
160
Angola
Camero
onChin
aGab
onInd
iaInd
ones
iaIre
land
Malays
iaNige
riaNorw
ayPhil
ippine
sViet
nam
Bangla
desh
MM
BB
L
Necessary Field Size to match low esttax regime (Ireland)Reference Field Size (25 MMBBL)
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Petroleum Fiscal Systems
• Two Families– Concessionary system
• Allows private ownership to mineral resources
– Contractual systems• The State retains ownership to mineral
resources
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Fiscal Systems Classification
Petroleum Fiscal Arrangements
Concessionary Systems Contractual Systems
Service Agreements Production Sharing Agreements
Indonesian Type Peruvian TypePure Service Risk Service
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Systems around the WorldAustralia Pakistan (On) Bangladesh Mongolia PhilippinesBrunei PNG Cambodia MyanmarKorea, South Thailand China Pakistan (Off)New Zealand Timor Gap B India Timor Gap A
Indonesia VietnamLaos NepalMalaysia Sri LankaAzerbaijan RussiaGeorgia TurkmenistanKazakstan UzbekistanKyrghystan
Argentina Falkland Is. Belize Nicaragua Brazil HondurasBolivia Paraguay Cuba Panama Chile PanamaColombia T&T (On) Guatemala T&T (Off) Ecuador PeruCosta Rica Guyana Uruguay Haiti
Jamaica VenezuelaAbu Dhabi Neutral Zone Bahrain Oman IranAjman Sharjah Iraq Qatar Kuwait (OSA)Dubai Turkey Joran Syria Saudi ArabiaFujairah Libya YemenCanadaUnited States
Concessions (R/T System) PSC SC
North America
Far East
Former Soviet Union
Latin America
Middle East
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Systems around the World
C. Afracan Rep. Namibia Algeria Liberia Chad Niger Angola LibyaCongo (K.) Senegal Benin MadagascarMadagascar Seychelles Cameroon MozambiqueMalawi Somalia Congo (Br.) NigeriaMali South Africa Cote D'Ivoire SudanMorocco Tunisia (Old) Egypt TanzaniaGhana Eq. Guinea Togo
Ethiopia Tunisia (New)Gabon UgandaGambia ZambiaKenya
Australia Italy AlbaniaBulgaria Netherlands MaltaCzech Republic Norway PolandDenmark Poland TurkeyFrance PortugalGreece RomaniaHungary SpainIreland UK
R/T System PSC SC
Africa
Europe
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Concessionary System• Oil company have exclusive right to explore and produce
at its own risk and expense• Oil Company Owns production• Oil Company often pays Royalty and Surface rental to
Government• Oil Company Pays Taxes on profit• Oil Company owns equipment • Oil company has right to export hydrocarbons
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Royalty/Tax SystemConsession Flow Chart
Contractor GovernmentGross 100
Royalty 1010 %
Net Revenues90
35 Deductions Capex, Opex,
etc.
Taxable Income
55
-27.50 Tax 27.5050 %
27.50Net Income
after tax 37.50
63 % Share 38 %28 % Profit Margin42 % Take 58 %
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Production SharingContract
• The Contractor gets a share of production usually in kind
• The Contractor never holds title to oil• The Contractor share the risk with the
Government
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Generic PSC SystemPSC Flow Chart
Contractor GovernmentGross Revenues
100
Royalty 00 %
Net Revenues100
35.0 Cost Recovery35 %
Total Profit oil65
26 Profit oil sharing 3940 %
Taxable26.00
0.0 Tax 00 %
61.0 Gross Cash Flow 39.0
26.0 Net Cash Flow
61.0 % Share 39 %26 % Profit Margin40 % Take 60 %
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Risk Service Contract
• The Contractor share the risk with the Government
• The Contractor gets a share of Profits usually as money
• The Contractor never holds title to oil
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Elements in a PSC• Work Commitment• Bonus Payment• Royalties• Cost Recovery (Cost Oil)• Profit Oil• Government participation• Domestic Market Obligation• Ring fencing
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Work Commitments• Acquisition of Seismic Data
– Shooting, where and when– Processing– Kilometres or Minimum Expenditure
• Drilling Obligations– Number of Wells , where and when– Stratigraphic interval– Minimum Expenditure
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Bonuses• Signature Bonus
– Paid upon contract signing• Discovery Bonus
– Paid upon first discovery• Production Bonus
– Paid when production reaches a specified level
• Bonuses makes a fiscal regime regressive and are unpopular with oil companies
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Royalties
• Calculated from Gross Revenue• Can cause premature abandonment• Ranges from zero to 20%• Sliding scale (Example.)
• First Step Up to 5.000 bopd 5%• Second Step 5.001-10.000 bopd 10%• Third Step Above 10.000 bopd 15%
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Special Royalty Schemes• The Philippines have a negative Royalty up to
7,5% (Philippine Participation Incentive Allowance - FPIA)
• New Zealand have a hybrid system 5% Royalty or 20 % Accounting Profits Royalty
• Rate Royalty $/bbl (Columbia, Russia)
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Negative Royalty SchemePhilippine RSC Flow Chart
Contractor GovernmentGross Revenues
100
FPIA 7.57.5 %
Net Revenues92.5
32.4 Cost Recovery35 %
Revenues for sharing60.13
24.1 Profit share 36.140 %
Taxable24.1
Tax paid by Gov.0.0 0 % 0.07.5 FPIA (% of Gross)
31.6 Service Fee
32.4 Cost Recovery
63.9 Entitlement 36.146.7 % Take 53.3 %
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Cost Oil (Cost Recovery)• Cost Oil usually has an upper limit • Cost oil normally includes:
– Unrecovered costs carried over from previous years
– Operating costs– Expensed capital costs– Current year DD&A ( Depreciation, Depletion & Amortisation)
– Interest on Financing– Investment Credit (Uplift)– Abandonment cost recovery fund
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Cost Recovery
Cruel Unusual Low EndTypical
Upper EndTypical
Rare Concessions+ a few PSCs
0 20 40 60 80 100
Range of Cost Recovery Limits (%)
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Profit Oil• Profit oil = Net revenue - Cost recovery
– Net revenue = Gross revenue - Royalties
• Profit oil is analogue to taxable income in a concessionary system and Service fee in a service agreement
• Profit oil is split between Government and Contractor
• Profit oil is usually, but not always taxed
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Profit oil Sharing Triggers
• Production– Daily rate– Absolute volume
• Rate of return (ROR)• R-factors
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Triggers
R-factor based From To Gov.Share
0.0 1.0 2.5 %1.0 1.5 5.0 %1.5 2.0 7.5 %2.0 2.5 10.0 %2.5 3.0 12.5 %3.0 4.0 15.0 %4.0 > 20.0 %
ROR based, %From To Gov.Share0.0% 12.5% 30.0 %12.5% 17.5% 40.0 %17.5% 22.5% 50.0 %22.5% 27.5% 60.0 %27.5% 30.0% 70.0 %30.0% 35.0% 80.0 %35.0% > 90.0 %
Prod. Based; 1000 bopdFrom To Gov.Share
0 5 20.0 %5 10 30.0 %10 20 40.0 %20 30 50.0 %30 50 60.0 %50 100 70.0 %
100 > 80.0 %
Prod. Based; Million bblFrom To Gov.Share
0 1 20.0 %1 5 30.0 %5 20 40.0 %20 100 50.0 %
100 200 60.0 %200 200 60.0 %200 > 60.0 %
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R-Factor
• Objective– Sharing between the Government and the contrator is
based on Profitability• Design
– Both revenue and cost are included in the calculation
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Different R- Factors
• Cumulative revenues/Cumulative cost
• Cumulative Revenue-Cumulative Opex/cumulative Capex
• Cumulative Revenue – Cumulative Profit Share/Cumulative Investments + Cumulative Opex
• Cumulative net income/Cumulative Costs
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Peruvian onshore
R-Factor ************ROYALTY RATE ************* ≤ $15/bbl $25/bbl ≥ $35/bbl 0.0 < R < 1.0 19% 23% 27% 1.0 ≥ R < 1.5 24% 29% 32% 1.5 ≥ R < 2.0 30% 35% 37% 2.0 ≥ R 36% 39% 42%
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Domestic Market Obligations (DMO)• A certain volume of oil to be sold to the Government
• Discounted Price• Local Currency. Predetermined exchange rate
• Example - Indonesian DMO – Production: 1 MMBBL– Oil price: 20 USD/BBL– Discount: 2 USD/BBL– Contractor’s profit oil: 28.8462% of total production– DMO: 25% of Contractors profit oil
• 1MMBBL*(20USD/BBL-2USD/BBL)*25%*28.8462%= 1,298 MMUSD• 1,298MMUSD/20USD/BBL=0.0649 MMBBL= 6.49% of total production ( Pure volume
calculation: 28.8462%*25%=7.21%)
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Direct State Participation• Free Ride
– Have access to all information• Can choose the goodies
– Does not pay for pre-license exploration– Does not pay for R&D
• Carried interest– The State can be carried through:
• Exploration• Exploration +Development
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The Importance of Tax Holidays
0.0
5.0
10.0
15.0
20.0
25.0
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20
Years
MM
BB
L
Production curve (100 %)
Protected by 5y tax holiday (62 %)
A 5 years tax holiday represents 25% of project time, but 62 % of produced volume (Undiscounted)
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Poor GoodGeological Promise
Gov
ernm
ent T
ake
Low
High
High interest from Oil CompaniesPotential for higher Government take
Low interest from Oil CompaniesLow potential for any Government take
Optimized Fiscal Terms
Global Exploration Market