Reporting petroleum Reserves & Resources

Transcription

1 Reporting petroleum Reserves & Resources Mr. Tom Andersen, Resource Assessment Team Norwegian Petroleum Directorate Workshop on Reporting of Petroleum Resourses, Reserves and CO₂ Injection Projects April, Bangkok, Thailand

2 Outline National reporting of reserves Classification Reporting process Evaluation and use of data Q & A 23-Apr-15 2

3 National reporting of reserves Why How Method

4 Reporting to Governments, basis for National policies Governments need information on The full resource base of the country Discovered and undiscovered Production forecasts Investments and costs forecasts Environmental aspects of petroleum activity National Energy policy National Finance policy National Environment policy Labour and working policy

5 Macro-economic indicators for the petroleum sector 213 Facts 214

6 Historical and forecasted investments (exploration costs not included) (Source: Norwegian Petroleum Directorate / Ministry of Petroleum and Energy) Facts 214

7 Legal basis for reporting to the authorities Petroleum Act Petroleum Act Regulations to the Petroleum Act Guidelines to the Petroleum Act and associated regulations 23-Apr-15 7 Regulation (Royal Decree) on Petroleum activities Section 5a Reporting to the National Budget process Reporting to the National Budget process shall be submitted to the Ministry and to the Norwegian Petroleum Directorate. The reporting shall include economical company data, projects, resource volumes and prognoses of production, costs and environmental emissions as specified by the recipient. Thematic Guideline Resource Classification Guidelines for reporting

8 The NPD classification of petroleum

9 Principles of the NPD classification Project based Project maturity Prospect Discovery Field development Production In production IOR Development Production Only Recoverable quantities are classified 23-Apr-15 9

10 The NPD resource classification

11 11 Resource categories compared with general project development

12 NPD classification, alternative view Class Project category Discovered quantities Historic prod. Sold and delivered Reserves Contingent resources 1 2 F/A 3 F/A 4 F/A 5 F/A 6 7 F/A In production Under development Decided for development In planning phase Recovery likely, but undecided Recovery not very likely Not evaluated Undiscovered quantities Undiscovered resources 8 9 Prospects Leads and plays Apr-15 F = First, A = Additional

13 Publishing The NPD discloses a detailed workbook on by early March. Reserves and resources per categories, also distributed by main offshore areas. Reserves per field and resources per discovery are tabulated, also available in our fact pages. 13

14 14 Norway s total petroleum resources and uncertainties in the estimates per

15 Resource overview as of 31 December 214 Expected total recoverable quantities Produced: 6.4 bill Sm 3 o.e Remaining proven: 4.9 bill Sm 3 o.e. Undiscovered: 2.8 bill Sm 3 o.e. ( bill Sm 3 o.e) fields in production 18 fields shut down 9 fields under development 92 discoveries under evaluation Appr. 16 IOR projects Identified appr. 15 project possibilities for IOR Expected total recoverable = ~14.1 bill Sm 3 o.e. Uncertainty range: P9 P bill Sm 3 o.e. 15

16 Reporting according to International Standards Since 21 NPD has tested ways of mapping our National resources to the UNFC platform. The 212 Pilot study presented in Geneva was done in collaboration with Statoil Last year the mapping was done by the PRMS bridging document. The method and results are presented in a paper ECE.ENERGY.GE _e.pdf

17 Who does the work? A permanent team within NPD are responsible for the reporting and resource account 17 members in total A very experienced group 17

18 18 Robustness of estimates

19 Sources of data Discovered resources Reports from the operating company on behalf of the Production Licence Total quantities per project According to NPD classification Expected status (maturity) at year end NPD can change the maturity of a project NPD could have other estimates than the companies. Undiscovered resources NPD exploration geologists Knowledge about Prospects, Plays and Basins Geostatistical approach (GeoX)

20 The Operators reports to the NPD on behalf of the licensees REPORTING Idemitsu NORWEGIAN MINISTRY OF FINANCE 2

21 Information on reporting from NPD homepage 23-Apr-15 21

22 General guidelines Reporting file RNB215

23 Challenges with reporting vs classification guideline Classification Guideline More theoretic and basic, and gives the fundament for use Not Carved in Stone, but a more comprehensive process to update than the reporting guideline Ongoing work to incorporate some of the practicality in the reporting guideline into the Classification guideline Reporting guideline A practical approach Many small and a few large «projects» on producing fields How detailed should the reports be? Find a common understanding of how to report comparable projects across fields and reporting companies Annual updates, based on experienced problem areas, and discussion with the companies 23

24 Projects that normally should be included in reserves (RC 1-3) Well projects that have a high probability of implementation, where the following conditions are met: Wells can be drilled from an available drilling facility Wells can be drilled with available technology Wells that are a part of a long range plan for future activity within approved drainage areas Well maintenance (assumed as necessary optimisation). 4D Seismic. Improved sweep with optimised drainage. Integrated operations. Optimise the production facility / remove bottle necks. The likelihood of implementation should take into account: Economy Technical feasibility Availability of infrastructure

25 Projects in fields to be classified as contingent resources New recovery method or significant expansion of existing recovery method that will provide additional reserves and improve recovery factor at implementation (RC-attribute A) Projects to produce new segments/parts of the reservoir not included in PDO. If project adds in-place volumes to the field: RC-attribute F. New wells, not reported as reserves.

26 Challenges Modification and upgrade of infrastructure In cases where there is uncertainty as to the scope of the upgrade, a continuation of the current functionality is reported as basis, while improvements of functionality is reported in a higher resource category Gas caps and blow-down projects Gas from projects in fields where production schedule has not been determined and that without significant investment will be produced and sold, should be reported in the RC3 (as reserves). It is assumed that downstream infrastructure is in place. Lifetime for projects when should the profiles stop Resources should not be limited by the license period nor the design life of the infrastructure When the production is not economical/profitable, when viewed in a broad context.

27 Reporting structure Standardized reporting format Common electronic storage Data checking and temporary storage Final storage in NPD s Data Base SAMBA Samba 23-Apr-15 27

28 1) Prior to reporting: The Reporting Process Improvements are made to Reporting File and Guidelines Project Lists Communication with reporting companies regarding changes from the year before and Resource Classification Shipment of Reporting File, Guidelines and Letter to companies Companies prepares data for the reporting 2) Reporting starts 15 th October Operator Reporting and Data Control NPD - Data Resource Account Basis Scenario Uncertainty Evaluation 3) Report to MPE Operator data NPD-data Uncertainty Evaluation Basic Scenario / Resource Account Draft Report 1,9 4,9 7,9 1,9 13,9 16,9 19,9 22,9 25,9 28,9 1,1 4,1 7,1 1,1 13,1 16,1 19,1 22,1 25,1 28,1 31,1 3,11 6,11 9,11 12,11 15,11 18,11 21,11 24,11 27,11 3,11 3,12 6,12 9,12 12,12 15,12 18,12 21,12 24,12 27,12 3,

29 Types of data to be reported for each project Quantities In-Place and recoverable volumes Low, Base and High estimates Profiles Production sales profiles Oil, Gas, NGL and Condensate, Costs Investments, Operating cost, Tariff expenditures, Decommissioning Environmental data Emissions (CO 2, NOx, nmvoc, CH 4 ) Background data (Water production, Injection profiles) Other data Project attributes for contingent resources, Development concepts, Number of production wells to be drilled, Planned passing of decision gates, etc.. 23-Apr NPD classification have to be used in reporting

30 Reporting project organization within the NPD The Project team checks: That all files have been delivered That the projects are reported in accordance with the project list and guidelines Other NPD teams check: That the data are in accordance with information from licence meetings, reports, etc. That changes from previous reports are explained If the maturity of the project are according to the reported resource category Whether the project are in line with our expectations to this project, or if necessary create a NPD-data set Reporting of new discoveries

31 Quality of data / Uncertainty / Use

32 Quality CHALLENGES Does the different companies report resources in a similar way? Will the companies share the true resource potential? Are the reports reliable SOLUTIONS Good, and easy to understand Guidelines Involve the companies in reporting procedures, discuss problem areas Communication about the Nations need for good data to do the right measures. No fiscal consequences Insight in the licence documentation All companies in the licence involved 32

33 33 Norway s total petroleum resources and uncertainties in the estimates per

34 The Norwegian Resource accounts Annual figures since Million Sm³ oe Sold and delivered Reserves Contingent resources Undiscovered resources Serie5

35 Reporting of uncertainty The estimates shall be reported with uncertainty to each sales product The range is selectable, but usually a P9 P1 range is presented If stochastic methods are applied, the base estimate should be the mean (expected) value. 35 Example of changes in estimates over time in for discoveries with long lead time from discovery to development

36 Uncertainty in the oil production forecast Uncertainty area Historic production Forecast 213 Forecast 214 3, 14 2,5 Million Sm³ , 1,5 Million bbl/day 6 1, 4 2 Stochastically modelled ,5,

37 Sales gas from Norwegian fields, with uncertainty Stochastically Scenarios Experience (Source: Norwegian Petroleum Directorate / Ministry of Petroleum and Energy)

38 Distribution of oil in place, sold oil and reserves by field 8 6 Remaining resources at planned cessation according to approved plans Remaining oil reserves Produced oil per Million Sm³ oil 2-2 Ekofisk Troll Snorre Eldfisk Valhall Statfjord Heidrun Oseberg Gullfaks Oseberg Sør Balder Grane Gullfaks Sør Njord Brage Tor Goliat Hod Vigdis Ula Alvheim Draugen Edvard Grieg Norne Veslefrikk -4-6

39 Concrete projects to improve recovery from the fields

40 Reserve growth oil, since 25 Million Sm 3 oil Cumulative reserve growth from discoveries in 25 and later Cumulative reserve growth from discoveries before 25 Cumulative reserve growth from original fields Goal for reserve growth Prognosis autumn 24 for reserve growth total Prognosis autumn 24 for reserve growth in existing fields Billion bbl oil

41 Thank you for your attention! Questions?

42 Reporting file for RNB215; MS Excel version REPORTING OF PETROLEUM-RELATED DATA TO THE REVISED NATIONAL BUDGET 215 RNB215 Reporting to the revised national budget for 214 must be submitted to the Norwegian Petroleum Directorate in an electronic format. This is to ensure good data quality, and hopefully also provide both more efficient reporting for the companies and easier processing by the NPD. The reporting file has been prepared in Microsoft Office Excel 27, and contains a number of macros. It is therefore not very robust as regards changes in the layout and formulation. Do not make any changes to the spreadsheet layout and do not change the names of the spreadsheets! If you need to override the file's set limitations, please contact the NPD. The original formatting of the cells can be overwritten when data is pasted in. To avoid this, please use the command "Rediger - lim inn - utvalg" ("Edit - Paste Special - Values") when pasting in text. Do not complete light blue cells Do not complete grey cells, they will be calculated automatically Unshaded cells (white) should normally be completed. Do not complete Do not complete Must/can be completed Note: Cell colour will change depending on the reported data. Guidelines for completing the reporting file may be found on: L2S NPD website RESPONSE FORM All responses from the NPD and any comments from the operating companies shall be given in a special spreadsheet in the file called "Tilbakemeldingsskjema". This is hidden until a response has been received from the NPD. Questions to NPD regarding this report should be forwarded to the address in the table below Area General questions Transmission of data, L2S Questions regarding this file Contact Telephone Bente Jarandsen rnb215@npd.no Magnar Haugvaldstad rnb215@npd.no Tom Andersen rnb215@npd.no Changes since version Spreadsheet Profil 1-15 Date Completed by NPD New and improved consistency controls Description of change Profil 1-15 NPD Project stoppers to be reported as threat for future progress of project 23-Apr-15 42

43 Originally In Place, quantities per deposit/discovery Sheet: Generell info og kommentarer 1) General information: Exempt Section 5a Drop-list Name of field/discovery/pipeline, etc.: Area: Type: OD-ID : Discovery well (for field): Norwegian percentage: 1, % Operator: Date: Contact, NPD: Telephone: address: dd.m m.yyyy Report Issuer: Contact, operator: Telephone: address: Alternative contact: 2) Resource overview Risk distribution. State probability that the outcome w ill be Low (%) Base High (%) greater than or equal to the low /high value: Recoverable resources and reserves in categories lower than 6 shall be reported directly in the applicable profile collection. A total overview of the reported resources can be found in the "Resource Overview" spreadsheet Resource Overview 2a) Originally in place: Name of deposit Discovery well for (Select from list or deposit enter new) (Select from list) All deposits To be reporte d Droplist Description of deposit Oil (million Sm 3 ) Associated liquid (NGL/condensate) (million Sm 3 ) Associated gas (billion Sm 3 ) Free gas (billion Sm 3 ) Low Base High Low Base High Low Base High Low Base High Drop-list Total :,,,,

44 1 Serial Deposits is chosen upon new Attribute 1 Number Low Base High Low Base High Low Base High Low Base High (choose from drop-down menu) technology? (yyyy) (yyyy) (yyyy) (yyyy) Allocated Gassco: Not in use,,,, Free text and change explanations related to the profile collection: Free text and change explanations related to investments: Free text and change explanations related to operating costs: Free text and change explanations related to the environmental data: Joint operating agreement (JOA) item CONTROL AREA Data Period Control Oil Months 1 Oil Proj. Life 2 NGL Months 3 NGL Proj. Life 4 Cond. Months 5 Cond. Proj. Life 6 Gas Months 7 Gas Proj. Life 8 CO2 Proj. Life 9 NOx Proj. Life 1 CO2 Annual 11 NOx Annual 12 Cost Proj. Life 13 Cash flow Cash flow Water injection Water production Production and injection data Gross gas production Natural gas injection in ow n field, exclusive gas lift Pipelines and land facilities Well maintenance 1, 1, Investments mill NOK Prod. wells mobile Operating costs Ordinary,9,9 Prod. wells permanent facilities Preparations 1 Facilit ies mill NOK Total operations and support Start-up date,8,8 Tot Inv 1 production,7 1 Total operations,7 1,6,6 1 1,5,5 1 1,4,4 1 1,3,3 1 To be completed for all projects with import of tariff services,,2,2 1 Early Base Late,1,1 and all projects in RC 3 and 4. Month:,, Please name sources of gas purchase: Please state where services are assumed to be provided Please name the fields that enter into the assumptions below Year: Low Base High Low Base High Gas for gas lift CO2 Gas injection Accumulated sale oil Low estimate Accumulated sale oil Base estimate Accumulated sale oil High estimate Annual sale oil Low estimate Annual sale oil Base estimate Annual sale oil High estimate Sale of petroleum, income profiles and transport profiles Annual sale NGL Annual sale condensate Base estimate Base estimate Accumulated dry gas Low estimate per calendar year Gross calorific value (GCV) Accumulated dry gas Base estimate Accumulated dry gas High estimate per calendar per calendar year Gross year Gross calorific value calorific value (GCV) (GCV) Investments Operating costs Physical Physical Saleable gas Saleable gas Gas purchase Tariff Other income General Concept Investments in Investments in Investments in Other Operating Total Dev. w ells Dev. w ells Investments in Investments in Investments Investments in Investments in Total Total Operational Ordinary Maintenance Well Modifications Subsea Platform Administration HSE Reservoir Business Other Total Logistics Other Cost Total Import of Tariff costs oil Tariff costs Tariff costs Tariff costs Tariff costs Tariff costs Total tariff Shut-dow n Final disposal Area fees Environmental Other general Receipt of gas dry gas rich gas per calendar per gas year per calendar income (explain in price increase studies new subsea new floating new fixed Development investments investments in f rom from mobile dev. w ells dev. w ells related to pipelines land facilities investments in investments preparations operating excl. w ells maintenance -JOA operations services -JOA JOA management development operational operations costs-joa 6.3 operating purchase of operating tariff services transport gas transport processing/ land-based Cost sharing Cost sharing costs costs (removal) taxes costs deliveries deliveries year 4 MJ/Sm3 year -JOA 7 part commentary -JOA 4 facilities facilities facilities investments (modifications facilities permanently drilling f rom from mobile production -JOA 5.1 part -JOA 5.1 part pipelines and -JOA 5 -JOA 6.1 costs -JOA JOA and -JOA and -JOA support and support costs gas costs, incl. -JOA 6.4 part -JOA 6.4 part -JOA 6.4 part treatment -JOA 6.4 part OPEX CAPEX -JOA 6.4 -JOA 8.1 -JOA 8.2 -JOA 9.2 -JOA 9.3 -JOA 9.1 from fields/ from fields/ 4 MJ/Sm3 4 MJ/Sm3 field) -JOA 5.1 part -JOA 5.1 part -JOA 5.1 part -JOA 5.1 part ) -JOA placed drilling facilities permanently drilling drilling not land facilities -JOA maintenance development -JOA JOA 6.5 part -JOA 6.5 part operations -JOA 6.4 part -JOA 6.4 part -JOA 6.4 part discoveries discoveries -JOA 7 part -JOA 5.2 facilities placed drilling facilities distributed by -JOA 5.1 part -JOA JOA Total AY-BH preparation per gas year per gas year facilities -JOA 5.3 part w ell -JOA 6.2 excl. Tariffs Gross Gross -JOA 5.3 part -JOA 5.3 part -JOA 6 (-6.4) calorific value calorific value (GCV) (GCV) Unit : million m3 million m3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 million Sm3 million Sm3 million Sm3 million Sm3 million Sm3 million Sm3 million tonnes million Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 million NOK million NOK % million NOK million NOK million NOK million NOK million NOK million NOK million NOK Quantity Quantity million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK million NOK billion Sm3 billion Sm3 million Sm3 oe billion Sm3 billion Sm3 billion Sm3 million m3 million m3 million Sm3 million Sm3 million litres million litres million tonnes million tonnes million tonnes million tonnes million tonnes 1 tonnes 1 tonnes 1 tonnes 1 tonnes 1 tonnes 1 tonnes 1 tonnes million Sm3 1 tonnes 1 tonnes 1 tonnes 1 tonnes GWh MW Sum:,,,,,,,,,,,,,,,,,,,,,, Accum. Up to and including 212,,,,, Annual 14 Proj. Life 15 Gas Annual 16 Gas Annual 17 Proj. Life 18 Proj. Life 19 Gas Annual 2 Drilling Annual 21 Drilling Annual 22 Drilling Annual 23 Drilling Annual 24 Cash flow Annual 25 Cost Proj. Life 26 CAPE X CAPE X Conce pt and wells cost Gassc o Report ing All numbe rs Nam e of project Row s for annual values after 238 can be displayed/hidden by clicking the "+" and "-" icons dow n at the bottom left. Start-up 27 Proj. Life 28 Proj. Life 29 Proj. Life 3 Proj. Life 31 Annual 32 Annual 33 Tariffs 34 Category 213,,,,,, % 214,,,,,, % 215,, % 216,, % 217,, % 218,, % 219,, % 22,, % 221,, % 222,, % 223,, % 224,, % 225,, % 226,, % 227,, % 228,, % 229,, % 23,, % 231,, % 232,, % 233,, % 234,, % 235,, % 236,, % 237,, % 238,, % 239,, % 24,, % 241,, % 242,, % 243,, % 244,, % 245,, % 246,, % 247,, % 248,, % 249,, % 25,, % 251,, % 252,, % 253,, % 254,, % 255,, % 256,, % 257,, % 258,, % 259,, % 26,, % 261,, % 262,, % 263,, % 264,, % 265,, % 266,, % 267,, % 268,, % 269,, % 27,, % 271,, % 272,, % 273,, % 274,, % 275,, % 276,, % 277,, % 278,, % 279,, % 28,, % 281,, % 282,, % 283,, % 284,, % 285,, % 286,, % 287,, % 288,, % TOTAL,,,,,,,,,,,,,,,,,,,,,, %,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, Check that total monthly data for basis sale of oil (spread sheet Monthly data, 'Månedsdata',) is equal to the yearly value stated for year 215 (cell S41). Check that sum of base oil profile (cell S115) is equal to the associated value for base oil in the table above (cell M26). Check that the total monthly data for basis NGL-sale (spreadsheet Monthly Data, 'Månedsdata',) is equal to the value stated for year 215 (cell U41). Check that sum of NGL profile (cell U115) is equal to the associated NGL value in the table above (cell P26). Check that the total monthly data for sale of condensate (spread sheet Monthly Data, 'Månedsdata',) is equal for the value stated for the year 215 (cell V41). Check that sum of condensate profile (cell V115) is equal to associated condensate value in the table above(cell V26). Check that the total monthly data for saleable gas per calendar year (spread sheet Monthly Data, 'Månedsdata',) is equal to the value stated for the year 215 (cell AB41). Check that accumulated physical delivery of dry gas (base estimate) (X115) is equal to the associated value of base gas in the table above (cell S26). Check that CO2 total emissions (cell CN115) is equal to the individual contributions from fuel gas, flaring, diesel and mobile facilities (cells CO115:CR115). Check that NOx total emissions (cell CS115) is equal to the individual contributions from fuel gas, flaring, diesel and mobile facilities (cells CT115:CW115). Check that the annual CO2 emissions (column CN) are reported in the same period of time as the production (columns S, U, V, and K). Check that the annual NOx emissions (column CS) are reported in the same period of time as the production (columns S,U,V and K). Check that end of production (based on the production profiles S,U,V or K) are not later than the latest entry of Shut-dow n costs -JOA 8.1 (column BW). Check that the value of total annual production and tariff income is greater than total annual relevant costs. ASSUMPTIONS: Oil price: 45 NOK/Sm3, Gas price: 25 NOK/1 Sm3, NGL-price: 5 NOK/tonne Condensate price: 45 NOK/Sm3. Based on the same price assumptions as above, check that the remaining net present value (including future investements, excluding abandonment/ shut dow n, 7 % real rate of discount) is greater than. Gas balance /Gas accounting: Gross gas production + Receipt of gas - Deliveries of gas from main field and associated fields w ith ship-loading point on the facility - Injected natural gas in main field and associated fields as w ell as any deposit excl. gas lift - (Natural gas used for fuel + Natural gas used for flaring )/1. Limit values: +/-,3 bill Sm3, years exceeding this limit (if any) are given in the cell to the right: Saleable gas vs Deliveries of Gas, corrected for Receipt of Gas: Saleable gas per calendar year 4 MJ/Sm3 - Gas purchase per calendar year Check that free text and change explanations related to the profile collection (cell H28) have been used. Only applicable in Profil_1. Check that total sale of gas per gas year = total sale of gas per calendar year. Note if greater deviation than.5 billion Sm3 (shall be.). Check that annual cost per w ell from PERMANENTLY PLACED drilling facilities is not very low (below 5) or very high (above 5) mill NOK. Check that annual cost per w ell from MOBILE drilling facility is not very low (below 1) or very high (above 8) mill NOK. Check that there are no large drilling costs for PERMANENTLY PLACED drilling facilities (above 2 mill NOK) WITHOUT w ells. Check that there are no large drilling costs for MOBILE drilling facilities (above 5 mill NOK) WITHOUT w ells. Check that income data (sales volumes for fields and discoveries, operating income for pipelines etc) and relevant opex data cover same years. Check that both Shut-dow n costs -JOA 8.1 and/or Final disposal (removal) -JOA 8.2 have been reported. Check that Startup date production (area N31:P32) are filled in. Check that project attributes (area AB7:AN25) are filled in. Check of CAPEX pr type of facility in profil coloumns AI, AJ and AK vs development solutions chosen in cell area AC7:AC25. Check that expected CAPEX elements for subsea developments are reported. Check that concept cost are reported for discoveries and that development projects have reported w ell costs. Not in use RNB215 Only applicable in Profil_1. Check that information regarding service provider for tariffs are completed in cell area $BO$32:$BU$32 Message Annual oil production Any comments Annual dry gas production Calculation area,, 999, 999,,,,, 999, 999,,,,, 999, 999,,,,, 999, 999,,,,, 999, 999,, 999, 999 2,,, , 999,,,,,,,,, 1,,,, Project type developed? conditional Tariffs Other costs Assumptions for environmental emissions/discharges and other data Consumption of natural gas and diesel CO 2 - discharge Deliveries of gas from main field and associated fields w ith ship-loading point on the facility Deliveries of oil/ngl/ condensate from main field and associated fields w ith ship-loading point on the facility Injected natural gas in main field and associated fields as w ell as any deposit excl. gas lift Total gas lift in main field and associated fields Injected CO2 in main field and associated fields as w ell as deposit Discharge of produced w ater from main field and associated fields Injected w ater in main field and associated fields Natural gas used for fuel Natural gas used for flaring Diesel consumption subject to CO2 tax (in accordance w ith CO2 tax legislation) Diesel consumption not subject to CO2 tax (mobile facility) CO2 total CO2 contribution fuel gas CO2 contribution flaring CO2 contribution diesel (in accordance w ith CO2 tax legislation) CO2 contribution from mobile facilities CO2 NOx total 1,2 1,,8,6,4,2 NOx NOx,, contribution from fuel gas Projected emissions NO X - discharge NOx CO2 contribution from flaring NOx contribution from diesel (in accordance w ith CO2 tax legislation) NOx 1,2 1,,8,6,4,2 contribution from mobile facilities NOx Emissions nmvoc from cold venting and fugitive emissions Emissions CH4 from cold venting and fugitive emissions nmvoc & CH 4 - discharge Oil, NGL, etc. total loaded/stored Emissions nmvoc storage Emissions nmvoc loading Emissions CH4 storage Emissions CH4 loading Power from shore Annual pow er consumption Maximum pow er usage (Peak) Profil_1-15 Projects RNB215 which are included in the profile, included resource data and information Production and injection Sale of petroleum, income and transport Fields for explanations, plots and information Investments Operating costs Tariff costs Other costs Environment data, assumptions and emissions All activity, incl 3 rd party Power from shore Information Information Information Information Information Deposits: Profil_2 Hide Profil_2 no Project attributes required for all projects in RC 3, 4 and 5 - fields and discoveries Project overview incl. recoverable resources Gas resources/reserves shall be stated with actual gross calorific value excluding fuel and flare gas. Project Developmen Need for Project Technology Technology Technology Time Year for Year for Year for Year for Comments: type: t new power stopper: usage: areas: status: criticality: the decision to the decision to the decision to the decision to E.g. realisation assumptions, w hich conditions the realisation of the project is contingent upon, new technology and technology development requirements, specification if technology touches upon several areas, cause of delay if Chose from solution: generation: Most important Is the project Within w hich What is the Is the initialize concretize continuation implement relevant. pull-dow n Complete Indicate how cause for the based on areas w ill status as realisation of (feasibility (concept (concept (detailed menu. w hen the the project w ill project not conventional new regards the project studies) studies) choice, engineering category get supply of being realized methods or technology be technological time-critical, preliminary PDO if Utbygg pow er or suffering w ill new used or development and, if so, engineering relevant) Oil NGL Gas (net deliverable) Condensate under the significant technology be developed? for projects w hat kind of phase) Category (million Sm 3 ) (million tonnes) (billion Sm 3 ) (million Sm 3 ) attribute delay. used or w hich are time- DG DG1 DG2 DG3 criticality? Consistency checks In general: White cells should be filled in when relevant Grey cells should not be filled in, will be 44 calculated automatic or are irrelevant

45 RC 1 5 Recoverable resources Sheets: Profil_1-15 Project overview incl. recoverable resources Gas resources/reserves shall be stated with actual gross calorific value excludin Project overview incl. recoverable resources Name of project Project Developm Need for Project Technolog Technolog Technolog Time Year for Year for Year for Year for type: ent new power stopper: y usage: y areas: y status: criticality: the decision the decision the decision the decision Chose from solution: generation Most Is the Within What is the Is the to to to to pull-down Complete : important project which areas status as realisation initialize concretize continuation implement menu. when the Indicate cause for based on will new regards of the (feasibility (concept (concept (detailed category how the the project conventiona technology technologic project timecritical, and, preliminary PDO if studies) studies) choice, engineering Categ Oil NGL Gas (net deliverable) Utbygg project will not being l methods be used or al under the get supply realized or or will new developed? developme if so, what engineering relevant) Categ Oil ory NGL Gas Serial (net deliverable) Condensate (million Sm 3 ) (million attribute of power tonnes) suffering technology (billion nt for kind of timecriticality? DG DG1 DG2 DG3 Sm 3 ) phase) ory (million Sm 3 ) (million tonnes) (billion Sm 3 ) (million Sm 3 ) Project significant be used or projects Categ Attribut Numb type is delay. developed? which are Serial Deposits chosen conditional Categ Attribut Numb (choose from drop-down upon new project ory e 1 er Low Base oryhigh Low Base High LowerBase High Low Base High menu) technology? (yyyy) (yyyy) (yyyy) (yyyy) 3 Name of Comments: E.g. realisation assumptions, which conditions the realisation of the project is contingent upon, new technology and technology development requirements, specification if technology touches upon several areas, cause of delay if relevant. Condensate (million Sm 3 ) e 1 Low Base High Low Base High Low Base High Low Base High Drop-list Deposits (choose from drop-down menu) Drop-list Allocated Gassco: RC_-3,,,, Project attributes required for all projects in RC 3, 4 and 5 - fields and discoveries Project type: Chose from pull-down menu. Developm ent solution: Complete when the category Utbygg under the attribute Project type is chosen Need for new power generation : Indicate how the project will get supply of power Project stopper: Most important cause for the project not being realized or suffering significant delay. Technolog y usage: Is the project based on conventiona l methods or will new technology be used or developed? Drop-list Technolog y areas: Within which areas will new technology be used or developed? Technolog y status: What is the status as regards technologic al developme nt for projects which are conditional upon new technology? Time criticality: Is the realisation of the project timecritical, and, if so, what kind of timecriticality? Year for the decision to initialize (feasibility studies) 45 DG Year for the decision to concretize (concept studies) DG1 Year for the decision to continuation (concept choice, preliminary engineering phase) DG2 Year for the decision to implement (detailed engineering PDO if relevant) DG3 (yyyy) (yyyy) (yyyy) (yyyy) Comments: E.g. realisation assumptions, which conditions the realisation o development requirements, specification if technology touches