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Out of Gas:
An Empirical Analysis of the Fiscal
Regime for Exploration in India
Anupama Sen
JUNE 2014
IAEE INTERNATIONAL CONFERENCE, NYC
Senior Research Fellow, Oxford Institute for
Energy Studies, United Kingdom
1. Natural Gas in India
2. Conceptual Literature on Resource Taxation
3. Empirical Literature
4. Method
5. Analysis
6. Results
7. Observations & Conclusions
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Outline
• Gas forms 11% of India’s primary energy consumption • Relatively ‘young’ but growing sector
• India’s gas reserves – 0.7% of world reserves
– Range of estimates
– Mostly offshore
• Consumption • 60 Bcma (20-30% LNG)
• 70% used in power generation, fertiliser industry, household use, transportation
• Policy on gas • Substitute for coal, naphtha, fuel oil
• Security of supply / mitigating energy shortages
• Environment
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1. Natural Gas in India
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Electricity
Other Energy Industry Own Use
Manufacturing Industries
and Construction
Transport Residential Other
Total CO2 Emissions from Fuel
Combustion
OECD 4,007 558 1,423 2,699 797 1,408 10,096
UK 2,873 519 822 1,919 1,325 1,643 7,776
USA 7,448 845 1,893 5,229 1,038 1,897 17,312
India 748 52 342 138 64 108 1,388
China 2,659 205 1,734 382 225 416 5,395
Brazil 230 129 585 852 87 194 1,989
Africa 414 39 138 215 56 104 910
Middle East 2,715 786 1,577 1,651 623 829 7,559
Per Capita Emissions by Sector, 2010 (kg of CO2 per capita)
Source: IEA (2008)
Potential for gas in electricity and transportation
• Prices for domestically produced gas are controlled • To keep prices to consuming sectors low
• Prices are set according to the fiscal regime governing a producing field • The fiscal regime has evolved over time; thus multiple pricing mechanisms
• India’s 1999 liberalised upstream fiscal regime • Prices based on an ‘S curve’ formula with a cap and ceiling
• SP = $2.5 + (CP – 25) 0.15+ C
• Five year reviews
• Formula rendered redundant by high oil price – Ceiling of $60/bbl breached very early on
– Review of pricing currently underway; proposals to link it to Henry Hub, NBP and Japan LNG
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Pricing
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India Gas Price vs International Benchmarks
Source: BP Statistical Review; Govt of India
Henry Hub
India LNG Imports
• Liberalised regime launched in 1999 • New Exploration Licensing Policy
• Based on a Production Sharing Contract (PSC)
• Hybrid system (royalty + taxes on ‘rent’)
• Main features 1. Royalty
• 10%, 5% for first 7 years
2. Cost recovery • Opex, capex & royalty up to 100% pa
3. Profit Sharing • Based on a R-factor, or the ratio of cumulative income to cumulative capital
expenditure.
• Two tranches, 1.5 and 3.5. Shares in-between worked out using an extrapolation formula Z = a + [(b-a)*(X-1.5)/2]
4. Corporate Income Tax • 30-40%
5. Minimum Alternate Tax • 18.5% of ‘book profits’ if IT payable is < 18.5% of ‘book profits’
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Fiscal Regime for Gas
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Gross Production
Total Profit Oil
Cost Recovery
Taxable Income
Contractor Take
Royalty
Government
Share
Government Take Tax
(+) (+)
(-)
(-)
(+)
(+)
(-)
Contractor Share
Graphical Illustration of PSC Regime
• Production • Large initial increase (2009) followed by dramatic decline in production; currently a
third of original targets
• Driven by private sector
• NOC production has remained stagnant
• No significant new discoveries since 2004
• Investments • Down from $4.7Bn in 2007 to $1.6 Bn in 2013
• Arbitration & delays • Companies accused of gold plating in the R Factor
• Alleged loss of revenues to exchequer
• Proposed Policy Solution • Replace the PSC regime with a simple Revenue Sharing Contract (RSC) Regime
• Eliminate royalty, cost recovery and profit sharing (R Factor)
• Companies simply share a percentage of their revenues from day 1 of production
• Production slabs pre-specified by the government. Percentage revenue shares biddable by companies at the time of the auction rounds
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Performance of India’s Fiscal Regime
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Drop in Production Increase in Consumption & Imports
Source: BP Statistical Review, PPAC India (2013/14)
Performance …(contd)
What to Tax - The Base
• Net income / rent / liberal regimes – Pure rent = surplus or financial return
not required to motivate economic
behaviour
– Supply price of investment = costs of
capital and operation plus risk premium.
Lower supply price, higher rent. Risk
premium affected by policy
– Zero marginal fiscal take
– Requires information on production
volumes, costs, prices, investments
• Gross income / proprietorial
regimes – Positive marginal rent, reservation
ground rent, and excess profits
– Information on prices and volumes only
• Mommer (1999), Baunsgaard
(2001), Hotelling (1931)
How to Tax - The Instruments
• Net Income /rent – Resource Rent Taxes (R Factor, Rate-
of-Return), Progressive Profits Taxes, Corporate Income Tax, VAT
• Gross Income – Royalties, Bonuses, Fixed Fees,
Minimum Work Programs
• Other – Government equal partner
Government/NOC equity participation, Brown Tax (
– Most systems use a ‘hybrid’ or combinations of both elements
2. Conceptual Literature on Resource Taxation
Royalties Corporate
Income Tax
Resource Rent
Tax
Brown Tax
Production
Sharing
Royalty rate =
cost oil cap
Tax rate =
government
profit share
Paid Equity Tax rate =
equity share
Carried Interest Tax rate =
equity share
Target real rate
of return =
interest rate
Concessional
Equity
Tax rate = share
of initial
concessional
investment
Tax rate =
equity share
Target rate of
return =
interest rate
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Source: Baunsgaard (2001)
Equivalencies in Fiscal System Design
• Desirable features of a fiscal system (Nakhle, 2008) – Efficiency
– Neutrality
– Equity
– Sharing of fiscal risk
– Simplicity
– Stability of fiscal terms and of revenues
• Trade-offs between features – Neutrality trades off with efficiency and with revenue generation
– Neutrality trades off with simplicity
– Equity trades off with simplicity and efficiency
– Stability trades off with fiscal risk sharing
• Selection of instruments is contingent upon the government’s objectives in fiscal system design
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Desirable Features & Tradeoffs
• PSC regime analogous to rate-of-return system; RSC regime to price cap system
– PSC (RoR) necessitates information on volumes, costs, prices and investment
– RSC (Price Cap) necessitates information only on volumes and prices
• Under a price cap type system, the government will most likely need to accept a lower overall expected level of taxation and lower take but stable (yet lower) revenues
– Conversely, investors face greater risks in sinking investments into difficult (offshore) areas
• In utilities and resource taxation price cap systems almost always revert towards rate-of-return (Tapia, 2012; Helm, 2010; Liston, 1993)
– The setting of appropriate caps ultimately necessitates information on cost functions
– Governments may therefore be compelled to intervene ex post
– There is a case for incorporating RoR elements into fiscal design ex ante
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Analogies with Price Cap versus RoR Regulation
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Static Models: Discounted cash flow models using
data on production, costs & prices
under a high, medium and low case
scenario. Fiscal terms used to
compute economic measures. One or
more of these are held constant to
observe the effect of changes in the
others. Results anchored to initial
conditions employed. Restrictions on
graphical representation of
multidimensional data.
Key Studies:
• Goldworthy and Zakharova (2010)
• Johnston (2003)
• Dongkun and Yan (2010)
• Daniel and McPherson (2010)
• Nakhle (2008)
• Tordo (2007)
• Al-Attair and Alomair (2005)
• Dharmadji and Parlindungan
(2002)
• Iledare (2001)
System Measures:
• AETR, IRR, sensitivity analysis
• AGR/ERR, savings index, take stat
• Government take, front loading
index
• METR, AETR, NPV
• NPV, IRR, take
• NPV, IRR, take
• E&P costs
• Contractor take, IRR, NPV
• Prices, production, NPV, take
Meta Models: A cash flow model of the system
constructed and parameters of the
system are defined and bound
through design intervals based on
historical data or reasonable
assumptions combined with the given
parameters in the fiscal system.
Parameters of the system sampled
from the design space and evaluated
in the cash flow model. The results of
the model and system parameters
are then analysed and a linear model
is constructed from the generated
data.
• Kemp and Stephen (2011)
• Hong and Kaiser(2010)
• Adenikinju and Oderinde (2009)
• Iledare and Kaiser (2006)
• Kaiser and Pulsipher (2004)
• Prod, costs, invest., tax revenues
• NPV, IRR, GT, CT
• NPC, IRR GT CT
• NPV, IRR, GT CT
• NPV, IRR, GT, CT
3. Empirical Literature
•
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4. Method
Static Analysis
•
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Meta Modelling
• Static DCF model constructed for India’s PSC regime
• Inputs
– Price
– Fiscal terms: royalty, cost recovery ceiling, corporate income tax, minimum
alternate tax, share of profits from production to the government at the lower and
upper tranches of the R-Factor investment multiple, and the contractor and
government discount rates
• Inputs are applied to a real (representative) offshore gas field in India
• We obtain a set of economic measures
– Present value of cash flows to the contractor and government (NPGc, NPVg), the
internal rate of return (IRR) and the discounted contractor and government take
(NPVct, NPVgt)
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5. Analysis
Parameter Name Measures
Recoverable Reserves 11 tcf
Field Life 33 years
Total Capex $14.78 bn
Full Cycle Opex $0.76 /Bcf
DCF Model Inputs and Project Parameters
Key Project Parameters
Inputs (Fiscal Terms)
Inputs Units Varnames Numbers
Price $/MMBtu P 4.20
Royalty Rate % Roy 5, 10
Cost Recovery Ceiling % CR 80
Corporate Income Tax % CIT 34
Minimum Alternate Tax % MAT 18.5
Government Profit Share
at Lower R Factor (<1.5)
% IM1 0.3
Government Profit Share
at Higher R Factor (>3.5)
% IM2 0.8
Contractor Discount Rate % Dc 15
Government Discount
Rate
% Dg 12
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Set of Economic Measures
Economic Measures Results
NPVc $ 1,213 Mn
NPVg $ 3,298 Mn
IRR 22%
NPVct 27%
NPVgt 73%
DCF Model Results
• Assumption variables
• P, Roy, CR, CIT, IM1, IM2, Dc, Dg.
• Forecast variables
• NPVc, NPVg, IRR, NPVct, NPVgt.
• A design space is constructed for each assumption variable
• Based on reasonable assumptions or historical data (fit to
distribution)
• 100, 500 and 1000 trial simulations of the assumption
variables
• Obtain corresponding forecast variables
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The Meta Model – (1)
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Parameter Design Space
Price LN (3.05, 16.75)
Royalty Rate U (0.05, 0.20)
Cost Recovery Ceiling U (0.10, 1.00)
Corporate Income Tax U (0.30, 0.40)
Government Profit Share at Lower
R Factor (<1.5)
U (0.10, 0.90)
Government Profit Share at Higher
R Factor (>3.5)
U (0.10, 0.90)
Contractor Discount Rate U (0.12, 0.40)
Government Discount Rate U (0.07, 0.12)
Design Space for Meta Model
• Dependent variables:
• NPVc, NPVg, IRR, NPVct, NPVgt
• Independent variables:
• P, Roy, CR, CIT, IM1, IM2, Dc, Dg
• The dataset generated mimics time-series data. We test for
stationarity
• We are interested in the relative influence (elasticity relationships) of
indepvars upon the depvar.
• We estimate the following equation for depvars NPVc, NPVg, IRR, NPVct,
NPVgt:
• L.φ (f, F) = k+ βL.P+ βL.Roy+ βL.CR+ βL.CIT+ βL.IM1+ βL.IM2+βL.Dc+ βL.Dg +ε
• We test for serial correlation and use robust standard errors.
• The coefficients stabilise at around 500 trials
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The Meta Model – (2)
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Same procedure for Revenue Sharing Contract (RSC)
Inputs Units Varnames Numbers
Price $/MMBtu P 4.20
Corporate Income Tax % CIT 34
Minimum Alternate Tax % MAT 18.5
Revenue Share at Tranche ‘A’ % RA 9
Revenue Share at Tranche ‘B’ % RB 13
Revenue Share at Tranche ‘C’ % RC 16
Revenue Share at Tranche ‘D’ % RD 25
Contractor Discount Rate % Dc 15
Government Discount Rate % Dg 12
Inputs (Fiscal Terms)
Parameter Name Measures
Recoverable Reserves 11 tcf
Field Life 33 years
Total Capex $14.78 bn
Total Opex $8.8 bn
Production
Slabs (Bcf)
Govt Revenue
Share
A 0 - 73 9%
B 74 - 1,825 13%
C 1,826 - 2,920 6%
D > 2,921 25%
Key Project Parameters Production Slabs
Source: Kelkar Committee Report, 2013
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Economic Measures Results
NPVc $ 5,047 Mn
NPVg $ 6,053 Mn
IRR 91%
dCT 54.53%
dGT 45.47%
Set of Economic Measures
Parameter Design Space
Price LN (3.05, 16.75)
Corporate Income Tax U (0.30, 0.40)
Revenue Share at Tranche ‘A’ U (0.01, 0.50)
Revenue Share at Tranche ‘B’ U (0.01, 0.50)
Revenue Share at Tranche ‘C’ U (0.01, 0.50)
Revenue Share at Tranche ‘D’ U (0.01, 0.50)
Contractor Discount Rate U (0.12, 0.40)
Government Discount Rate U (0.07, 0.12)
Design Space for Meta Model
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φ (f, F) = k+ βL.P+ βL.Roy+ βL.CR+ βL.CIT+ βL.IM1+ βL.IM2+ βL.Dc+ βL.Dg +ε
Trials k βL.P βL.Roy βL.CR βL.CIT βL.IM1 βL.IM2 βL.Dc βL.Dg R2 Adj R2 F Stat DW
L.NPVC 100
500 1000
2.21(4.73)
0.52(1.42) 2.31(1.0)
0.15(0.03)+
0.14(0.01) +
0.10(0.01) +
-0.03(0.52)
-0.20(0.18) -0.27(0.11) *
0.25(0.37)
0.01(0.13) 0.33(0.09) +
-2.51(2.22)
0.34(0.87) -0.35(0.57)
-0.67(0.35)
-0.68(0.13) +
-0.48(0.08) +
0.51(0.37)
0.04(0.13) -0.11(0.08)
-2.43(0.62)+
-2.88(0.20) +
-2.37(0.14) +
0.77(1.46)#
-0.63(0.44) -0.05(0.29)
0.53
0.58 0.53
0.43
0.57 0.53
6.15+
45.17+
75.86 +
2.5
1.9 2.0
L.NPVG 100
500
1000
6.51(0.96)
6.36(0.38)
7.24(0.34)
0.13(0.01) +
0.12(0.003) +
0.10(0.002) +
0.08(0.11)
0.15(0.05)*
0.07(0.04) #
-0.13(0.07) *
-0.15(0.03) +
-0.05(0.03) #
0.27(0.49)
0.61(0.22) +
0.59(0.18) +
0.38(0.08) +
0.27(0.03) +
0.31(0.01) +
-0.01(0.07)
-0.001(0.03)
0.0001(0.03)
-0.15(0.14)
-0.03(0.05)
0.004(0.05)
-1.85(0.29) +
-2.17(0.12) +
-1.85(0.10) +
0.83
0.78
0.73
0.82
0.77
0.73
55.44+
214.02+
333.58+
2.0
1.9
2.0
L.IRR 100
500
1000
-3.51(5.24)
-4.50(1.61)
-2.50(1.19)
0.20(0.10) +
0.19(0.01) +
0.13(0.01) +
-0.12(0.57)
-0.10(0.21)
-0.32(0.14) *
0.54(0.41)
0.20(0.14)
0.63(0.11) +
-2.53(2.46)
0.84(0.94)
-0.11(0.68)
-0.22(0.38)
-0.32(0.15)*
-0.07(0.10)
0.45(0.41)
0.04(0.15)
-0.14(0.10)
0.15(0.69)
-0.28(0.23)
0.26(0.17)
0.59(1.62)
-0.83(0.51)
-0.08(0.35)
0.59
0.52
0.50
0.52
0.51
0.49
8.21+
35.41+
66.39 +
2.4
1.8
2.0
L.NPVGT 100 500
1000
0.05(0.14) 0.20(0.06)
0.12(0.04)
-0.001(0.001) +
-0.004(0.0005) +
-0.002(0.002) +
0.03(0.02) 0.01(0.01)
0.02(0.01) +
-0.01(0.01) -0.02(0.01) +
-0.02(0.003) +
-0.03(0.07) 0.01(0.03)
0.03(0.02)
0.03(0.01) #
0.05(0.01) +
0.04(0.003) +
-0.001(0.01) -0.003(0.01)
-0.002(0.003)
0.09(0.02) +
0.08(0.01) +
0.07(0.01) +
-0.05(0.04) 0.01(0.02)
-0.02(0.01)*
0.33 0.38
0.31
0.28 0.37
0.30
5.69+
37.02+
55.65+
2.4 2.0
1.9
L.NPVCT 100
500 1000
-6.55(3.85)
-6.90(1.08) -5.58(0.71)
0.05(0.02)*
0.05(0.01) +
0.03(0.004) +
-0.14(0.42)
-0.32(0.14)*
-0.34(0.08) +
0.32(0.30)
0.15(0.10)
0.39(0.06) +
-2.89(1.81)
-0.45(0.66) -0.73(0.40) #
-1.15(0.28) +
-0.99(0.10) +
-0.90(0.06) +
0.48(0.30)
0.05(0.10) -0.002(0.003)
-2.59(0.51) +
-2.86(0.15) +
0.07(0.01) +
2.18(1.19) #
1.43(0.34) +
-0.02(0.01) #
0.51
0.65 0.31
0.42
0.64 0.30
5.94+
61.08+
55.65+
2.5
2.0 1.9
Results from all simulations-PSC Regime
+Significant at 1%, *Significant at 5%, # Significant at 10%, Standard errors in parentheses
6. Results
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L. φ (f, F) = k+ βL.P+ βL.Roy+ βL.CR+ βL.CIT+ βL.IM1+ βL.IM2+ βL.Dc+
βL.Dg+ε
L.NPVC L.NPVG L.IRR L.NPVGT L.NPVCT
k 0.52
(1.42)
6.36
(0.38)
-4.50
(1.61)
0.20
(0.06)
-6.90
(1.08) βL.P 0.14**
(0.01)
0.12**
(0.003)
0.19**
(0.01)
-0.004**
(0.0005)
0.05**
(0.01) βL.Roy -0.20
(0.18)
0.15*
(0.05)
-0.10
(0.21)
0.01
(0.01)
-0.32*
(0.14) βL.CR 0.01
(0.13)
-0.15**
(0.03)
0.20
(0.14)
-0.02**
(0.01)
0.15
(0.10) βL.CIT 0.34
(0.87)
0.61**
(0.22)
0.84
(0.94)
0.01
(0.03)
-0.45
(0.66) βL.IM1
-0.68**
(0.13)
0.27 **
(0.03)
-0.32*
(0.15)
0.05 **
(0.01)
-0.99**
(0.10) βL.IM2 0.04
(0.13)
-0.001
(0.03)
0.04
(0.15)
-0.003
(0.01)
0.05
(0.10) βL.Dc -2.88**
(0.20)
-0.03
(0.05)
-0.28
(0.23)
0.08**
(0.01)
-2.86**
(0.15) βL.Dg -0.63
(0.44)
-2.17**
(0.12)
-0.83
(0.51)
0.01
(0.02)
1.43**
(0.34) R2 0.58 0.78 0.52 0.38 0.65 Adj R2 0.57 0.77 0.51 0.37 0.64 F Stat 45.17** 214.02** 35.41** 37.02** 61.08** Durbin Watson 1.9 1.9 1.8 2.0 2.0 Trials 500 500 500 500 500
**Significant at 1%, *Significant at 5%, Standard errors in parentheses
Results – PSC Regime
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Results – RSC Regime
φ (f, F) = k+ βL.P+ βL.RA+ βL.RB + βL.RC + βL.RD+ βL.CIT+ βL.Dc+ βL.Dg +ε
L.NPVC L.NPVG L.NPVGT L.NPVCT
k 3.55
(0.14)
7.24
(0.05)
0.23
(0.06)
-3.46
(0.19)
βL.P
-0.014
(0.01)
0.01
(0.01)
4.42E-05
(0.01)
-0.02
(0.02)
βL.RA 0.011
(0.01)
-0.003
(0.004)
-0.003
(0.004)
0.01
(0.01)
βL.RB -0.25**
(0.01)
0.27**
(0.004)
0.10**
(0.0040
-0.42**
(0.01)
βL.RC -0.01
(0.01)
0.003
(0.001)
-0.0004
(0.006)
-0.01
(0.01)
βL.RD -0.001
(0.01)
-0.004
(0.004)
-0.003
(0.004)
0.001
(0.01)
βL.CIT -0.30**
(0.08)
0.45**
(0.04)
0.16**
(0.04)
-0.60**
(0.12)
βL.Dc -2.32**
(0.02)
0.01
(0.01)
0.44**
(0.01)
-1.88**
(0.03)
βL.Dg -2.32**
(0.02)
-1.15**
(0.02)
-0.20**
(0.02)
0.97**
(0.06)
R2 0.97 0.94 0.87 0.93
Adj R2 0.97 0.94 0.97 0.93
F Stat 1816.7** 1015.650** 414.46** 776.67**
Durbin Watson 2.0 2.0 1.93 2.0
Trials 500 500 500 500 **Significant at 1%, *Significant at 5%, Standard errors in parentheses
• Variables that have significant effects across all economic indicators:
PSC Regime
– Price
– Share of profits to the government at the lower tranche of the R factor
(‘trigger tranche’)
• Coefficients larger than price
• Variables that have significant effects across all economic indicators:
RSC Regime
– Share of revenues to the government at the first production slab (‘trigger
slab’)
– Corporate income tax
– Government discount rate
• ‘Trigger tranche’/ ‘trigger slab’ reflect rate-of-return characteristics
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7. Observation & Conclusions
• The results for trigger tranche/trigger slabs in the PSC/RSC system are indicative of rate-of-return influences on the fiscal system – With a RSC, it could deter investment in difficult (offshore) areas as there is
less traction in the system to offset investor risk
• The government’s objective in fiscal design appears contrary in the RSC: it desires higher production and higher (and earlier) revenues, but there is not enough traction to offset the higher risks that come with it
• Alternatively, it could explicitly incorporate the rate-of-return element into fiscal system design – This could be done through retaining the PSC, but adding an element of
cost uplift, for instance
– It could also be done through designing a rate-of-return based tax combined with corporate income tax and/or royalties, instead of a RSC
• Areas for further work; RoR systems; testing functional relationships further
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Observations & Conclusions (2)
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End
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NPVc
NPVg
IRR
NPVct
NPVgt
PSC Regime Price
Trigger tranche
(large)
Discount rate (c)
Price
Trigger tranche
Royalty
Cost recovery
Corporate
income tax
Discount rate (g)
Price
Trigger tranche
Price (negligible)
Trigger tranche
(large)
Royalty
Discount rates
Price
Trigger tranche
Cost recovery
Discount rate (g)
(all negligible)
RSC Regime Trigger slab
Corporate
income tax
Discount rates
Trigger slab
Corporate
income tax
Discount rate (g)
No significant
results
Trigger slab
Corporate
income tax
Discount rates
Trigger slab
Corporate
income tax
Discount rates
Significant Variables Compared
Variable ADF Stats (at levels) Order of Integration
NPVC -22.50+ I(0)
NPVG -23.36+ I(0)
NPVGT -22.47+ I(0)
NPVCT -22.47+ I(0)
P -23.25+ I(0)
Roy -20.92+ I(0)
CR -22.02+ I(0)
CIT -23.28+ I(0)
IM1 -20.82+ I(0)
IM2 -22.76+ I(0)
Dc -22.64+ I(0)
Dg -21.97+ I(0)
Critical Value at 1% -3.443228
Critical Value at 5% -2.867112
Critical Value at 10% -2.569800
IAEE INTERNATIONAL CONFERENCE, NYC
Stationarity Tests
+Significant at 1%
PSC Regime
IAEE INTERNATIONAL CONFERENCE, NYC
Variable ADF Stats (at levels) Order of Integration
NPVC -24.37+ I(0)
NPVG -22.13+ I(0)
NPVGT -23.45+ I(0)
NPVCT -23.45+ I(0)
P -23.25+ I(0)
RA -19.50+ I(0)
RB -22.29+ I(0)
RC -21.20+ I(0)
RD -23.56+ I(0)
CIT -21.65+ I(0)
Dc -24.63+ I(0)
Dg -22.85+ I(0)
Critical Value at 1% -3.443228
Critical Value at 5% -2.867112
Critical Value at 10% -2.569800
RSC Regime
+Significant at 1%