Eldfisk, Norway, Commercial Asset Valuation and Forecast to 2026

Eldfisk, Norway, Commercial Asset Valuation and Forecast to 2026

http://www.reportsandreports.com/market-reports/eldfisk-norway-commercial-asset-valuation-and-forecast-to-2026/


GlobalData

Norway Market Research

The Eldfisk field is located in Norway block 2/7. It lies at water depth of 70-75 meters and is southwest of Stavanger. It was discovered in 1970. It is situated in the oldest Ekofisk field complex of the Norwegian North Sea.
 
Eldfisk field produce crude oil, natural gas and natural gas liquids. It is a high quality product with API of 37.3 degrees and is sweet due to low sulphur content. The estimated remaining recoverable reserves of the field are 290.85 Billion barrels of oil equivalent.

The field is operated by Conoco Phillips Skandinavia AS (35.11%). The remaining equity partners are Eni Norge AS, Statoil Petroleum AS, Petoro AS and Total E&P Norge AS.

Eldfisk has produced about 579 million barrels of crude oil, 1.36 TCF of natural gas and about 27 million barrels of natural gas liquids till 2009. The field produced 17.98 million barrels of crude oil, 17,327 MMCF of natural gas and 0.39 million barrels of natural gas liquids in the year 2009. The estimated field life is till 2026.The peak production was around 36.95 million barrels of oil and 1.08 million barrels of natural gas liquids in 1980. The natural gas production reached its peak production in 1988 with 80,293 MMCF of natural gas.

The Eldfisk field is expected to generate gross revenues of $26.02 Billion during its remaining life (starting 1/1/2010) and is expected to yield an IRR of around 11.33%.

Scope

• The report provides detailed information on oil and gas production, infrastructure, reserves, geology, operator and equity partners and the latest fiscal terms applicable to the asset and provides its fair value (Remaining Net Present Value) based on remaining reserves, forecast production, capital and operational costs, fiscal regime and commodity prices.
• The report also provides additional valuation parameters like Internal Rate of Return (IRR), Profitability Index (PI), Pay Back (discounted and undiscounted), Entitlement Production (EP) and Working Interest (WI) to enhance your decision making process.
• This report provides detailed sensitivity analysis of the remaining NPV with changes in the commodity prices, discount rate, production and key fiscal terms.
• Detailed cash flows over the life of the asset are included in the report. These cash flows cover a wide range of calculations related to various payments to the government/licensing authority.
• Interactive Excel models can be used to derive custom valuations, sensitivities and cash flows based on the specific inputs by the user in the model. These custom inputs vary from production data, cost information, price information and fiscal terms information.

Reasons to buy

• Make well informed investment decisions based on detailed operational analysis and cash flow forecasts
• Estimate the fair value of your future investment under different economic and fiscal conditions
• Value a prospective investment target through a comprehensive analysis using focused forecasting and valuation methodologies.
• Supporting interactive excel model will enhance your decision making capability in a more rapid and time sensitive manner
• Evaluate how the changes in the country’s fiscal policies impact the cash flows and the present value of the asset

1 Table of Contents 2
1.1 List of Tables 3
1.2 List of Figures 3
2 Eldfisk, Norway, Introduction 4
3 Eldfisk, Norway, Geology and Formations 6
4 Eldfisk, Norway, Equity Partners 8
5 Eldfisk, Norway, Crude Oil Reserves 9
6 Eldfisk, Norway, Key Fiscal Terms 9
6.1 Royalty 9
6.2 Fees 9
6.3 Special Petroleum Tax 9
6.4 Taxation 9
6.5 Carbondioxide Tax 9
6.6 Deductions and Depreciation 10
7 Eldfisk, Norway, Infrastructure 11
7.1 Upstream Infrastructure 11
7.2 Midstream Infrastructure 11
8 Eldfisk, Norway, Development Plan 12
9 Eldfisk, Norway, Crude Oil Production 13
10 Eldfisk, Norway, Field Economics 17
10.1 Eldfisk, Economic Assumptions 17
10.1.1 Forecast Commodity Prices 17
10.1.2 Inflation 17
10.1.3 Discount Rate and Representation of Cash Flows 17
10.1.4 Sensitivity 17
10.1.5 Access to the Economic Model 17
10.2 Eldfisk, Norway, Cash Flow Analysis 18
10.3 Eldfisk, Norway,, Remaining PV Sensitivity Analysis 19
10.3.1 Remaining NPV Sensitivity to Discount Rates 19
10.3.2 Remaining NPV Sensitivity to Change in Commodity Prices and Production 20
10.3.3 Remaining NPV Sensitivity to Special Petroleum Tax and Production Rate 21
11 Eldfisk, Norway, Summary Cash Flows 22
11.1 Eldfisk, Norway, Front End Load Due To Fiscal Policy 23
11.2 Eldfisk, Norway, Tax Liability 25
12 Appendix 26
12.1 Methodology 26
12.2 Coverage 26
12.3 Secondary Research 26
12.4 Primary Research 26
12.5 E&PForecasts 27
12.6 CapitalCosts 27
12.7 Exploration and Appraisal (E&A) Costs 27
12.8 Operating Costs 27
12.9 Expert Panel Validation 28
12.10 About GlobalData
12.11 Contact Us
12.12 Disclaimer

1.1 List of Tables

Table 1: Eldfisk, Norway, Key Asset Data, 2010 4
Table 2: Eldfisk, Norway, Field Reserves, January 2010 9
Table 3: Eldfisk, Norway, Historic and Forecast Production, Thousand Barrels, 1979-2026 15
Table 4: Eldfisk, Norway, Commodity Price Assumptions, 2010-2025 17
Table 5: Eldfisk, Norway, Commodity Price Assumptions, 2010-2025 17
Table 6: Eldfisk, Norway, Project Analysis Metrics, 2010 18
Table 7: Eldfisk, Norway, Remaining PV Sensitivity Analysis Over Discount Rate Vs. Commodity Price Change, in Million Dollars 19
Table 8: Eldfisk, Norway, Remaining PV Sensitivity Analysis over Commodity Price Change Vs Production Rate, in Million Dollars 20
Table 9: Eldfisk, Norway, Remaining PV Sensitivity Analysis at 10% Discount Rate over Special Petroleum Tax Change Vs Production Rate, in Million Dollars 21
Table 10: Eldfisk, Norway, Asset Summary Cash Flows, 000’$, 1975-2026 22
Table 11: Eldfisk, Norway, Front End Load, 000’$, 1979-2026 23
Table 12: Eldfisk, Norway, Tax Liability Estimations, 000’$,1979-2026 25

1.2 List of Figures

Figure 1: Eldfisk, Norway, Location of Eldfisk in Ekofisk Area 5
Figure 2: Eldfisk, Norway, Geology Formations 6
Figure 3: Eldfisk, Norway, Geology Formations 7
Figure 4: Eldfisk, Norway, Current Equity Details, 2010 8
Figure 5: Eldfisk, Norway, Infrastructure Block Diagram 11
Figure 6: Eldfisk, Norway, Crude Oil, Historic Production and Forecast, 1979-2026 13
Figure 7: Eldfisk, Norway, Natural Gas, Historic Production and Forecast, 1979-2025 13
Figure 8: Eldfisk, Norway, Natural Gas Liquids, Historic Production and Forecast, 1979-2013 15
Figure 9: Eldfisk, Norway, Gross Revenue Versus Tax Cash Flow Analysis, 1979-2026 18
Figure 10: Eldfisk, Norway, Remaining PV Sensitivity Analysis Over Discount Rate Vs. Commodity Price Change, in Million Dollars 19
Figure 11: Eldfisk, Norway, Remaining PV Sensitivity Analysis over Change in Production Vs. Commodity Price Change, in Million Dollars 20
Figure 12: Eldfisk, Norway, Remaining PV Sensitivity Analysis Over Special Petroleum Tax Change Vs. Production Rate, in Million Dollars 21

Ekofisk Field, Norway, Commercial Asset Valuation and Forecast to 2027

Ekofisk Field, Norway, Commercial Asset Valuation and Forecast to 2027

http://www.reportsandreports.com/market-reports/ekofisk-field-norway-commercial-asset-valuation-and-forecast-to/

GlobalData

Norway Market Research 

Ekofisk is an oil field located in the southern part of the North Sea in the block 2/4 – production license 018, awarded in the year 1965. The sea depth in the area is between 70-75 meters. It is one of the largest fields in the basin. ConocoPhillips Scandinavia AS is the operator of the field. Ekofisk’s test production was started in 1971 after eighteen months of the initial discovery, by the means of a discovery well and three appraisal wells tied to the jack-up facility Gulftide.

The two major equity partners of the Ekofisk field are ConocoPhillips Scandinavia AS and Total E&P Norge AS with 35.11% and 39.90% stake respectively. The other partners are the Eni Norge AS, 12.39%, Petoro AS 5%, and Statoil with 7.6% stake.

The Ekofisk field was discovered in 1969. ConocoPhillips got the development approval in March 1972 and the field came on stream in June 1971. The produced liquid is a light, low sulfur North Sea crude oil with an API of 38o. The price of the Ekofisk crude oil is at par with the Brent Blend.

The Ekofisk field produced an estimated average of 66.2 million barrels of oil equivalent (MMboe) during 2009. The peak production was recorded in the year 2002 where the production was 127.2 million barrels of oil equivalent.

The life of the Ekofisk field is expected to be around 57 years with complete abandonment during 2027. The field is expected to generate $61.6 billion in revenues (undiscounted) during its remaining life (starting January 1, 2010) and is expected to yield an IRR of around 10.5%.

Scope

• The report provides detailed information on oil and gas production, infrastructure, reserves, geology, operator and equity partners and the latest fiscal terms applicable to the asset and provides its fair value (Remaining Net Present Value) based on remaining reserves, forecast production, capital and operational costs, fiscal regime and commodity prices.
• The report also provides additional valuation parameters like Internal Rate of Return (IRR), Profitability Index (PI), Pay Back (discounted and undiscounted), Entitlement Production (EP) and Working Interest (WI) to enhance your decision making process.
• This report provides detailed sensitivity analysis of the remaining NPV with changes in the commodity prices, discount rate, production and key fiscal terms.
• Detailed cash flows over the life of the asset are included in the report. These cash flows cover a wide range of calculations related to various payments to the government/licensing authority.
• Interactive Excel models can be used to derive custom valuations, sensitivities and cash flows based on the specific inputs by the user in the model. These custom inputs vary from production data, cost information, price information and fiscal terms information.

Reasons to buy

• Make well informed investment decisions based on detailed operational analysis and cash flow forecasts
• Estimate the fair value of your future investment under different economic and fiscal conditions
• Value a prospective investment target through a comprehensive analysis using focused forecasting and valuation methodologies.
• Supporting interactive excel model will enhance your decision making capability in a more rapid and time sensitive manner
• Evaluate how the changes in the country’s fiscal policies impact the cash flows and the present value of the asset

  1 Table of contents 2

1.1 List of Tables 4
1.2 List of Figures 4

2 Ekofisk Field, Norway, Introduction 5

3 Ekofisk Field, Norway, Geology, Geography and Formations 7

4 Ekofisk Field, Norway, Equity Details 9

5 Ekofisk Field, Norway, Crude Oil and Natural Gas Reserves 10

6 Norway, Fiscal System 10
6.1 Norway Petroleum Fiscal Environment 10
6.1.1 Governing Law 10
6.1.2 Licensing Authority 10
6.1.3 State Participation 10
6.1.4 Contract Type 10
6.2 License Terms 11
6.2.1 Exploration License (EL) Duration 11
6.2.2 Relinquishment during Exploration 11
6.2.3 Exploration obligation 11
6.2.4 Production Rights, Area & Duration 11
6.3 Key Fiscal Terms 11
6.3.1 Royalty 11
6.3.2 Fees 11
6.3.3 Special Petroleum Tax 11
6.3.4 Taxation 12
6.3.5 Carbon Dioxide Tax 12
6.3.6 Deductions and Depreciation 12

7 Ekofisk Field, Norway, Infrastructure 12
7.1 Upstream Infrastructure 12
7.2 Midstream Infrastructure 12
7.2.1 Ekofisk Pipelines 12

8 Ekofisk Field, Development Plan, Investment and Expenditure 15

9 Ekofisk Field, Norway, Oil and Gas Production 15

10 Ekofisk Field, Norway, Field Economics 17
10.1 Ekofisk Field, Norway, Economic Assumptions 17
10.1.1 Forecast Commodity Prices 17
10.1.2 Inflation 18
10.1.3 Discount Rate and Representation of Cash Flows 18
10.1.4 Sensitivity 18
10.1.5 Access to the Economic Model 18
10.2 Ekofisk Field, Norway, Cash Flow Analysis 18
10.3 Ekofisk Field, Norway, Remaining PV Sensitivity Analysis 20
10.3.1 Remaining NPV Sensitivity to Discount Rate and Commodity Price 20
10.3.2 Remaining NPV Sensitivity to Changes in Commodity Prices and Production Rates 21

11 Ekofisk Field, Norway, Summary Cash Flows 23
11.1 Ekofisk Field, Norway, Front End Load Due To Fiscal Policy 25
11.2 Ekofisk Field, Norway, Tax Liability 28

12 Appendix 30
12.1 Methodology 30
12.2 Coverage 30
12.3 Secondary Research 30
12.4 Primary Research 30
12.5 E&P Forecasts 31
12.6 Capital Costs 31
12.7 Exploration and Appraisal (E&A) Costs 31
12.8 Operating Costs 32
12.9 Expert Panel Validation 32
12.10 About GlobalData
12.11 Contact Us
12.12 Disclaimer

1.1 List of Tables

Table 1: Ekofisk Field, Norway, Key Asset Data, 2010 5
Table 2: Ekofisk Field, Norway, Reserves, 2010 10
Table 3: Ekofisk Field, Norway, Historic and Forecast Production, Thousand Barrels, 1971-2027 16
Table 4: Ekofisk Field, Norway, Commodity Price Assumptions, 2010-2025 18
Table 5: Ekofisk Field, Norway, Project Analysis Metrics, 2010 19
Table 6: Ekofisk Field, Norway, Remaining PV Sensitivity Analysis Over Discount Rate Vs. Commodity Price Change, in Billion Dollars, 2010 20
Table 7: Ekofisk Field, Norway, Remaining PV Sensitivity Analysis over Commodity Price Change Vs Production Rate, in Billion Dollars, 2010 21
Table 8: Ekofisk Field, Norway, Remaining PV Sensitivity Analysis over Commodity Price Change Vs Production Rate, in Billion Dollars, 2010 22
Table 9: Ekofisk, Norway, Remaining PV Sensitivity Analysis at 10% Discount Rate over Income Tax Change Vs Production Rate, in Million Dollars, 2010 22
Table 10: Ekofisk Field, Norway, Asset Summary Cash Flows, Thousand $, 1971-2027 23
Table 11: Ekofisk Field, Norway, Front End Load, Thousand $, 1971-2027 25
Table 12: Ekofisk Field, Norway, Tax Liability Estimations, Thousand $, 1971-2027 28

1.2 List of Figures
Figure 1: Ekofisk Field, Norway, Location, 2010 6
Figure 2: Ekofisk Field, Norway, Geological Details showing Lithology, Source Rock and Reservoir of the Murzuq Basin, 2010 7
Figure 3: Ekofisk Field, Norway, Top Structure Map of Ekofisk Formation of the Ekofisk Field 8
Figure 4: Ekofisk Field, Norway, Equity Details, 2010 9
Figure 5: Ekofisk Field, Norway, Oil and Gas Pipeline Layout for Ekofisk 13
Figure 6: Ekofisk Field, Norway, Infrastructure Diagram 14
Figure 7: Ekofisk Field, Norway, Historic Production and Forecast, 1971-2027 15
Figure 8: Ekofisk Field, Norway, Historic Production and Forecast, 1971-2027 16
Figure 9: Ekofisk Field, Norway, Gross Revenue Versus Tax Cash Flow Analysis, 2002-2025 18
Figure 10: Ekofisk Field, Norway, Remaining PV Sensitivity Analysis Over Discount Rate Vs. Commodity Price Change, in Billion Dollars, 2010 20
Figure 11: Ekofisk Field, Norway, Remaining PV Sensitivity Analysis over Change in Production Rate Vs. Commodity Price Change, in Billion Dollars, 2010 21

Brage, Norway, Commercial Asset Valuation and Forecast to 2015

Brage, Norway, Commercial Asset Valuation and Forecast to 2015

http://www.reportsandreports.com/market-reports/brage-norway-commercial-asset-valuation-and-forecast-to-2015/ 

GlobalData

Norway Market Research 

Brage Field is located in the northern North Sea in Norway. Brage is an oil field which lies approximately 13 kilometers to the east of Oseberg. The field reservoir is at an average depth of 140 meters below the seabed. The field is located in the block 31/4, extending into 31/7 and 30/6.

Statoil ASA is the operator of the field with 32.70% equity stake. The other equity partners of the field are Petoro A/S, Altinex ASA, Talisman Energy Inc., VNG Norge AS and Spring Energy Norway AS. Brage was discovered in 1980. The field was discovered in the well 31/4-3. The basic engineering activities began in 1990. The field came operational in 1993. Brage is expected to hold recoverable reserves of 56.6 million standard cubic meters of oil, 3.7 standard billion cubic meters of gas and 1.2 million tons of NGL as on December 2009.

Brage field produces crude oil and natural gas. The crude is of 33.70 degrees API and 0.37% of sulphur. The field produced about 10.55 million barrels of oil, 4,668.57 million cubic feet of gas and 6.764.58 barrels of equivalent of NGL in 2009.

The field life of Brage is expected to be around 23 years with complete estimated abandonment during 2014-2015. The field is expected to generate $4.09 billion in revenue (undiscounted) during 2010-2015 and is expected to yield an IRR of around 11.06%.

Scope

• The report provides detailed information on oil and gas production, infrastructure, reserves, geology, operator and equity partners and the latest fiscal terms applicable to the asset and provides its fair value (Remaining Net Present Value) based on remaining reserves, forecast production, capital and operational costs, fiscal regime and commodity prices.
• The report also provides additional valuation parameters like Internal Rate of Return (IRR), Profitability Index (PI), Pay Back (discounted and undiscounted), Entitlement Production (EP) and Working Interest (WI) to enhance your decision making process.
• This report provides detailed sensitivity analysis of the remaining NPV with changes in the commodity prices, discount rate, production and key fiscal terms.
• Detailed cash flows over the life of the asset are included in the report. These cash flows cover a wide range of calculations related to various payments to the government/licensing authority.
• Interactive Excel models can be used to derive custom valuations, sensitivities and cash flows based on the specific inputs by the user in the model. These custom inputs vary from production data, cost information, price information and fiscal terms information.

Reasons to buy

• Make well informed investment decisions based on detailed operational analysis and cash flow forecasts
• Estimate the fair value of your future investment under different economic and fiscal conditions
• Value a prospective investment target through a comprehensive analysis using focused forecasting and valuation methodologies.
• Supporting interactive excel model will enhance your decision making capability in a more rapid and time sensitive manner
• Evaluate how the changes in the country’s fiscal policies impact the cash flows and the present value of the asset

1 Table of Contents 3

1.1 List of Tables 4
1.2 List of Figures 4

2 Brage, Norway, Introduction 5

3 Brage, Norway, Geology and Formation 6

4 Brage, Norway, Equity Partners 8

5 Brage, Norway, Crude Oil Reserves 9

6 Brage, Norway, Key Fiscal Terms 9
6.1 Royalty 9
6.2 Fees 9
6.3 Special Petroleum Tax 9
6.4 Taxation 9
6.5 Carbon Dioxide Tax 10
6.6 Deductions and Depreciation 10

7 Brage, Norway, Infrastructure 10
7.1 Upstream Infrastructure 10
7.1.1 Wells 10
7.1.2 Platform 11
7.2 Midstream Infrastructure 11

8 Brage, Norway, Development Plan 11

9 Brage, Norway, Crude Oil, Natural Gas and NGL Production 11

10 Brage, Norway, Field Economics 15
10.1 Brage, Norway, Economic Assumptions 15
10.1.1 Forecast Commodity Prices 15
10.1.2 Inflation 15
10.1.3 Discount Rate and Representation of Cash Flows 15
10.1.4 Sensitivity 15
10.1.5 Access to the Economic Model 15
10.2 Brage, Norway, Cash Flow Analysis 16
10.3 Brage, Norway, Remaining PV Sensitivity Analysis 17
10.3.1 Remaining NPV Sensitivity to Discount Rates 17
10.3.2 Remaining NPV Sensitivity to Change in Commodity Prices and Production 18
10.3.3 Remaining NPV Sensitivity to Income Tax and Production Rate 19

11 Brage, Norway, Summary Cash Flows 20
11.1 Brage, Norway, Front End Load Due To Fiscal Policy 21
11.2 Brage, Norway, Tax Liability 22

12 Appendix 23
12.1 Methodology 23
12.2 Coverage 23
12.3 Secondary Research 23
12.4 Primary Research 23
12.5 Capital Costs 24
12.6 Exploration and Appraisal (E&A) Costs 24
12.7 Operating Costs 24
12.8 Expert Panel Validation 24
12.9 About GlobalData
12.10 Contact Us
12.11 Disclaimer

1.1 List of Tables
Table 1: Brage, Norway, Key Asset Data, 2010 5
Table 2: Brage, Norway, Current Equity Details, 2010 8
Table 3: Brage, Norway, Field Reserves, January 2010 9
Table 4: Brage, Norway, Crude Oil, Natural Gas and NGL Production, 1993-2015 14
Table 5: Brage, Norway, Commodity Price Assumptions, 1993-2015 15
Table 6: Brage, Norway, Project Analysis Metrics, 2010 16
Table 7: Brage, Norway, Remaining PV Sensitivity Analysis Over Discount Rate Vs. Commodity Price Change, in Million Dollars 17
Table 8: Brage, Norway, Remaining PV Sensitivity Analysis Over Change in Production Vs. Commodity Price Change, in Million Dollars 18
Table 9: Brage, Norway, Remaining PV Sensitivity Analysis at 10% Discount Rate over Income Tax Change Vs Production Rate, in Million Dollars 19
Table 10: Brage, Norway, Asset Summary Cash Flows, Thousand USD, 2001-2015 20
Table 11: Brage, Norway, Front End Load, Thousand USD, 2001-2015 21
Table 12: Brage, Norway, Tax Liability Estimations, Thousands USD, 2004-2029 22

1.2 List of Figures

Figure 1: Brage, Norway, Location Map 6
Figure 2: Brage, Norway, Geological Formation of the Brage Field 7
Figure 3: Brage, Norway, Current Equity Details, 2010 8
Figure 4: Brage, Norway, Installations at the Brage Field 10
Figure 5: Brage, Norway, Crude Oil Historic Production and Forecast, 1993-2015 11
Figure 6: Brage, Norway, Natural Gas Historic Production and Forecast, 1993-2015 12
Figure 7: Brage, Norway, NGL Historic Production and Forecast, 1993-2015 14
Figure 8: Brage, Norway, Gross Revenue Versus Tax Cash Flow Analysis, 1993-2015 16
Figure 9: Brage, Norway, Remaining PV Sensitivity Analysis Over Discount Rate Vs. Commodity Price Change, in Million Dollars 17
Figure 10: Brage, Norway, Remaining PV Sensitivity Analysis Over Change in Production Vs. Commodity Price Change, in Million Dollars 18
Figure 11: Brage, Norway, Remaining PV Sensitivity Analysis at 10% Discount Rate over Income Tax Change Vs Production Rate, in Million Dollars 19

Asgard, Norway, Commercial Asset Valuation and Forecast to 2024

Asgard, Norway, Commercial Asset Valuation and Forecast to 2024

http://www.reportsandreports.com/market-reports/asgard-norway-commercial-asset-valuation-and-forecast-to-2024/

GlobalData

Norway Market Research


The field is located in the Halten Bank of Norwegian Sea about 200km from mid-Norway and 50km south of Statoil's Heidrun field. The water depth is in the range of 240-300m. It is a major development in the Halten Bank area which serves as the production hub for that area.

Statoil acts as the operator of the field with 34.57% equity share. The field produces Asgard Blend crude oil which is light (48.9° API), low sulphur (0.12% mass) crude oil.

The field comprises the Midgard, Smorbukk and Smorbukk South deposits, which were discovered in the years 1981, 1984 and 1985 respectively. Midgard is a gas and condensate field and located in blocks 6507/11 and 6407/2. The other two deposits containing oil, gas and condensate are located in block 6506/11. These three deposits were unitized into one production license in the year 1995.

The field contains approximately 735 million barrels of oil-in place and 8.2 (trillion cubic feet) tcf of gas-in place reserves. The estimated recoverable reserves as of 31/12/2009 are 710 million barrels of oil and 6.6 tcf of gas. The field life of Asgard is expected to be around 26 years with complete abandonment during 2024. The field is expected to generate $44.8 billion in revenues (undiscounted) during its remaining life (starting 1/1/2010) and is expected to yield an IRR of around 16.03%.
Scope

• The report provides detailed information on oil and gas production, infrastructure, reserves, geology, operator and equity partners and the latest fiscal terms applicable to the asset and provides its fair value (Remaining Net Present Value) based on remaining reserves, forecast production, capital and operational costs, fiscal regime and commodity prices.
• The report also provides additional valuation parameters like Internal Rate of Return (IRR), Profitability Index (PI), Pay Back (discounted and undiscounted), Entitlement Production (EP) and Working Interest (WI) to enhance your decision making process.
• This report provides detailed sensitivity analysis of the remaining NPV with changes in the commodity prices, discount rate, production and key fiscal terms.
• Detailed cash flows over the life of the asset are included in the report. These cash flows cover a wide range of calculations related to various payments to the government/licensing authority.
• Interactive Excel models can be used to derive custom valuations, sensitivities and cash flows based on the specific inputs by the user in the model. These custom inputs vary from production data, cost information, price information and fiscal terms information.

Reasons to buy

• Make well informed investment decisions based on detailed operational analysis and cash flow forecasts
• Estimate the fair value of your future investment under different economic and fiscal conditions
• Value a prospective investment target through a comprehensive analysis using focused forecasting and valuation methodologies.
• Supporting interactive excel model will enhance your decision making capability in a more rapid and time sensitive manner
• Evaluate how the changes in the country’s fiscal policies impact the cash flows and the present value of the asset

1 Table of contents 2

1.1 List of Tables 4
1.2 List of Figures 4

2 Asgard, Norway, Introduction 5

3 Asgard, Norway, Geology and Formations 7

4 Asgard, Norway, Equity Details 8

5 Asgard, Norway, Crude Oil Reserves 8

6 Asgard, Norway, Fiscal System 9
6.1 Contract Type 9
6.2 State Participation 9
6.3 Royalty 9
6.4 Fees 9
6.5 Special Petroleum Tax 9
6.6 Taxation 9

7 Asgard, Norway, Infrastructure 10
7.1 Floating Production Storage Offloading (FPSO) 10
7.2 Semisubmersible 10
7.3 Storage Vessel (FSO- Floating Storage Offloading) 10
7.4 Pipe-Line 11
7.5 Export Riser Base (ERB) 11
7.6 Shuttle Tankers 11

8 Asgard, Norway, Development Plan 12
8.1 Capital and Operating costs 12
8.2 Phases of Development 12
8.3 Plans for Development 12
9 Asgard, Norway, Crude Oil Production 12

9.1 Full Crude Oil and Gas Production Forecasting for the Field Life from 1999 to 2024 13

10 Asgard, Norway, Economics 14
10.1 Asgard, Norway, Economic Assumptions 14
10.1.1 Forecast Commodity Prices 14
10.1.2 Inflation 14
10.1.3 Discount Rate and Representation of Cash Flows 14
10.1.4 Sensitivity 14
10.1.5 Access to the Economic Model 14
10.2 Asgard, Norway, Cash Flow Analysis 15
10.3 Asgard, Norway, Remaining PV Sensitivity Analysis 16
10.3.1 Remaining NPV Sensitivity to Discount Rates 16
10.3.2 Remaining NPV Sensitivity to Change in Commodity Prices and Production 17
10.3.3 Remaining NPV Sensitivity to Income Tax and Production Rate 18

11 Asgard, Norway, Summary Cash Flows 19
11.1 Asgard, Norway, Front End Load Estimations 20
11.2 Asgard, Norway, Tax Liability 21

12 Appendix 22
12.1 Methodology 22
12.2 Coverage 22
12.3 Secondary Research 22
12.4 Primary Research 22
12.5 E&P Forecasts 23
12.6 Capital Costs 23
12.7 Exploration and Appraisal (E&A) Costs 23
12.8 Operating Costs 23
12.9 Expert Panel Validation 24
12.10 About GlobalData
12.11 Contact Us
12.12 Disclaimer

1.1 List of Tables
Table 1: Asgard, Norway, Key Asset Data, 2010 5
Table 2: Asgard, Norway, Canada, Reserves Classification, 2010 8
Table 3: Asgard, Norway, Crude Oil and Gas Production, 1999-2024 13
Table 4: Asgard, Norway, Commodity Price Assumptions, 2010-2024 14
Table 5: Asgard, Norway, Project Analysis Metrics, 2010 15
Table 6: Asgard, Norway , Remaining PV Sensitivity Analysis Over Discount Rate Vs. Commodity Price Change, in Billion Dollars, 2010 16
Table 7: Asgard, Norway, Remaining PV Sensitivity Analysis over Commodity Price Change Vs Production Rate, in Billion Dollars, 2010 17
Table 8: Asgard, Norway , Remaining PV Sensitivity Analysis at 10% Discount Rate over Income Tax Change Vs Production Rate, in Billion Dollars, 2010 18
Table 9: Asgard, Norway, Asset Summary Cash Flows, Thousand USD, 1997-2024 19
Table 10: Asgard, Norway, Front End Load, Thousand USD, 1999-2016 20
Table 11: Asgard, Norway, Tax Liability Estimations, Thousands USD,1999-2024 21

1.2 List of Figures

Figure 1: Asgard, Norway , Location, 2010 6
Figure 2: Asgard, Norway , Schematic field layout, 2010 6
Figure 3: Asgard, Norway , Equity Partners and Their Equity Stakes, 2010 8
Figure 4: Asgard, Norway , Infrastructure, 2010 10
Figure 5: Asgard, Norway , Oil Historic Production and Forecast, 1999-2020 12
Figure 6: Asgard, Norway , Gas Historic Production and Forecast, 2000-2024 13
Figure 7: Asgard, Norway , Gross Revenue Versus Tax Cash Flow Analysis, 2010 15
Figure 8: Asgard, Norway , Remaining PV Sensitivity Analysis Over Discount Rate Vs. Commodity Price Change, in Billion Dollars, 2010 16
Figure 9: Asgard, Norway, Remaining PV Sensitivity Analysis over Change in Production Vs. Commodity Price Change, in Billion Dollars, 2010 17
Figure 10: Asgard, Norway , Remaining PV Sensitivity Analysis Over Income Tax Change Vs. Production Rate, in Billion Dollars, 2010 18

BP Sustainability Case Study Now Available at ReportsandReports

BP Sustainability Case Study Now Available at ReportsandReports

Dallas, TX: ReportsandReports announce it will carry BP Sustainability Case Study Market Research Report in its Store.

Browse complete Report on: http://www.reportsandreports.com/market-reports/bp-sustainability-case-study/

Introduction

Sustainable development is increasingly important in the modern energy industry. The way that BP and other oil and gas companies respond to urgent and complex sustainability issues will be crucial to future energy supply. This brief gives an in-depth analysis of how BP are responding that those issues and outlines scenarios for their corporate strategy to 2030.

Scope

• Providing you with an in-depth analysis of BP's sustainability efforts and potential impact of sustainable development on BP by the year 2030.
• Develops scenario analysis under three possible future paradigms; business as usual, weak sustainability and strong sustainability.
• Discover which impacts the Gulf of Mexico oil spill has on BP's sustainability credibility.
• Find out how BP can target new markets of 1.5 to 2 billion people.

Highlights

BP has long been a leader in sustainability but is being overtaken by other businesses which are committed to sustainability and integrate sustainability throughout their core business practices. Tony Hayward as new CEO since 2007 had significant impact on BP's sustainability efforts.

A credible public commitment to sustainability which is grounded in the company's core values is a key factor in communicating BP's sustainability efforts. Rebranding as Beyond Petroleum has had long-lasting effect but delivering different messages to different stakeholders could give rise to claims of green washing.

Under our scenario analysis, you will see how BP becomes a sustainable energy provider. We developed business strategies for weak sustainability, where BP's sum of manufactured, environmental, human and social capital is stable. BP undergoes a paradigm shift in the strong sustainability scenario, allowing it to access 1.5 to 2 billion consumers.

Reasons to Purchase

• Use this report to evaluate BP's strengths and weaknesses with regards to sustainable development.
• See how an international oil and gas company can be the first sustainable energy company.
• Compare with other oil and gas companies strategies to understand best practice in the industry.

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Table Of Contents

DATAMONITOR VIEW

CATALYST

SUMMARY

KEY FINDINGS

SUSTAINABILITY PERCEPTION

Company vision and mission

Public

Sustainability indices

Awards

Industry bodies, voluntary initiatives and standardization contributions

NGOs

ASSESSMENT OF CURRENT SUSTAINABILITY EFFORTS

Environment

Greenhouse gas emissions

Air pollutant emissions

Energy use

Other energy sources

Flared gas

Biodiversity

Fresh water use

Discharges to water

Waste water

Water use

Waste

Hazardous waste

Process safety

Oil spills

Social

Product responsibility and product stewardship

Human rights and security

Human rights in the supply chain

Workforce participation and employee engagement

Workforce health, injury and illness incidents

Workforce diversity and inclusion

Training and development

Non-retaliation and grievance system

Community impacts and engagement

Micro-financing

Indigenous peoples and involuntary resettlement

Local hiring practices and supply chain development

Economic

Preventing corruption

Preventing corruption in the supply chain

Transparency of payments to host governments

Public advocacy and lobbying

Legal proceedings

BP sustainability reporting

Single, common leadership framework

Code of conduct

Alignment of incentives with values

Sustainable supply chain management

Stakeholder communication

Climate change

Transparency and credibility

Ability to communicate strong commitment to sustainability

Integration of sustainability into the organization

Significant changes in business behavior

Country and site sustainability and environmental reporting

Unconventional oil

Alternative energy

Cutting of employee numbers

SWOT ANALYSIS

SCENARIOS TO 2030

BP's situation in March 2010

Oil and gas interests

Petrochemical assets

Refineries

BP Alternative Energy

Targetneutral

Sustainability and the oil and gas industry

Paradigms for the scenario analysis

Assumptions for scenario analysis

Energy security

Other assumptions

2030 sustainability scenarios

BP in 2030 - business-as-usual scenario

BP in 2030 - weak sustainability scenario

BP by 2030 - strong sustainability scenario

CONCLUSION AND RECOMMENDATIONS

APPENDIX

General overview of BP

History

Mergers and acquisitions

Subsidiaries, jointly controlled entities and associates

Sustainability challenges

BP memberships in organizations

Further reading

Ask the analyst

Datamonitor consulting

Disclaimer

List of Tables

Table 1: Awards 2009

Table 2: BP group greenhouse gas emissions (excluding TNK BP), 2005-09

Table 3: Estimated TNK-BP greenhouse gas emissions, including direct, indirect, CO2, CH4, N2O, 2005-08

Table 4: Primary energy use (million GJ), 2001-09

Table 5: Discharges to water (tonnes), 2002-09

Table 6: Waste water discharged (m³), 2005-09

Table 7: BP SWOT analysis

Table 8: BP Alternative Energy business

Table 9: Assumptions until 2030

Table 10: BP's products and services

Table 11: BP's main brands

Table 12: BP's reporting business segments

Table 13: BP's mergers/acquisitions and divestments, 1950-2010

Table 14: 100% BP-owned subsidiaries, 2009

Table 15: 75% BP-owned subsidiaries, 2009

Table 16: Jointly controlled entities (14-60% BP ownership), 2009

Table 17: Associates (24-50% BP ownership), 2009

Table 18: Associates (24-50% BP ownership), 2009

Table 19: Sustainability challenges in the oil and gas industry

Table 20: BP memberships

List of Figures

Figure 1: Public perception of BP's sustainable business practices

Figure 2: Oil and gas production stacked on top of direct greenhouse gas emissions, 2005-2009

Figure 3: BP group emissions to air, 1999-2009

Figure 4: Primary energy use versus oil and natural gas production, 2005-09

Figure 5: Flaring of hydrocarbons (thousand tonnes) 2001-2009

Figure 6: Total water withdrawal, 2003-09

Figure 7: Potable water use, 2003-09

Figure 8: Hazardous waste, 2006-09

Figure 9: Governance flow

Figure 10: US primary energy production and consumption, 2008

Figure 11: US primary energy sources, 2008

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