Information meeting RNB2015

Transcription

1 Information meeting RNB215 RNB September 214

2 Agenda Kl Introduction (Bente Jarandsen) Regulations, Time schedule, Guidelines, L2S, RNB 214 experience, project list Kl Kl Kl Kl Kl Kl Kl Kl RNB reporting news, changes from RNB 214 (Tom Andersen) Resource classification and reporting of resources (Tom Andersen) Gas reporting (Kjartan Teigen) Cost and income reporting incl tariffs (Tove Francke) Reporting of environmental data (Bente Jarandsen) Gassco Lunch The Reporting file how it works

3 Introduction Bente Jarandsen

4 The purpose of the reporting The reporting for the RNB contributes basic data for the Government s oil and environmental policy, the state and national budget The petroleum activities account for a substantial percentage of Norway s gross domestic product and total export. These forecasts are important, and great emphasis is therefore placed on ensuring that high-quality reporting is provided within the stated deadlines. NPD quality- assures the reported data prepares it`s own estimates based on its own assumption prepares overall forecasts

5 Legal basis for reporting to the authorities Petroleum Act Regulations to the Petroleum Act Guidelines to the Petroleum Act and associated regulations Petroleum Act 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 9/4/214 5

6 General guidelines Reporting file RNB215

7 RNB 215 file 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 Profil 1-15 Date Completed by NPD NPD New and improved consistency controls Description of change Project stoppers to be reported as threat for future progress of project

8 RNB215 Time schedule 1 st September: Necessary material for the reporting process (project list, reporting file and guidelines) was made available to the operators. 4 th September: Information meeting. 15 th October: Deadline for submitting the reporting files. 3 th October: Feed-back from the NPD on the RNB-submission. 5 th November: 2nd submission if requested. 11 th November: 2nd feed-back from the NPD on the RNB-submission. 14 th November: 3rd submission if requested. If there are major changes based on decisions made in the Management Committee after submission, the NPD should be informed and an updated reporting file should be submitted within 15 th December.

9 Quality! Saves time for both the companies and for the authorities Gives confidence to the data Ensures a good basis for decision making both within the companies and with the authorities Consistency checks 9

10 Transmission of data to NPD License 2 Share (L2S)

11 Improvements

12 RNB 214 Statistics 12

13 Improvements How to avoid a lot of files returned on October 3 th? Use supporting materials Use the file properly Check numbers that we can check through other sources Check transitions from history to forecast, explain if not obvious If in doubt, contact us. Missing data Provide data, best assumptions are better than nothing

14 Areas for improvements s14

15 Project lists

16 Submitted from the NPD Project list based on projects reported to RNB214 Changes that have been made; Changed resource category for fields that have changed PDO- or production status. Added new discoveries. RC 6 Added discoveries in re-licensed area and licenses with a new operator. Expected from the operators; Update resource category related to project decisions Reporting of discontinued projects Description of new projects Fill in information in al columns final RC RNB 215

17 Project lists - Process Reporting according to the project lists There will be an individual process regarding the few unresolved items Still possible to change projects, please involve us. Project lists were uploaded to L2S late June and we got feedback in August. The lists were then returned with comments on September 1 rd. Goal is a final version October 1 st

18 New features RNB215

19 Overview changes since RNB214 Project attributes Definition of project stoppers and text boxes Consistency checks New and upgraded checks Further clarification on classification of future wells No changes in requests for data in RNB215.

20 Project attributes Project stopper Context change: Earlier : The reason for the project not beeing sanctioned? Now: What could stop or significantly delay the project? New boxes with help text When entering a cell in some columns A box showing the full text in pull-down menu Hints

21 Consistency checks Goal: Improved quality Oct 15th report Changed error tolerance recourses and sales numbers Differences should normally be zero. Expanded some checks to also test file totals Result of check only shown in Profil_1 Removed some errors Will probably trigger more need for corrections and explanations Included 6 new checks on items with multiple feedbacks to operators Project attributes filled in for all projects RC3-5 Development solution matches CAPEX-items Subsea developments will normally need investments on host facility and pipelines Expected production start up with uncertainty Concept costs for discoveries and wells in development projects Negative figures in file totals (Profil_Total).

22 Consistency checks The same procedure as last year. After Oct 1 st a message will pop up, when closing the file, if there is triggered consistency checks in the file not accounted for.

23 Resource classification and reporting of resources

24 Main principles for the resource classification Only recoverable petroleum volumes should be classified. Recoverable volumes related to a project. Projects should be classified based on maturation (resource category).

25 Resource categories compared with general project development RC8, 9 RC7 RC5 RC4 RC3, RC2 RC+1

26 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. The likelihood of implementation should take into account: Economy Technical feasibility Availability of infrastructure Improved sweep with optimised drainage. Integrated operations. Optimise the production facility / remove bottle necks.

27 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.

28 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.

29 Originally In Place, quantities per deposit/discovery Sheet: Generell info og kommentarer ) General information: Exempt Section 5a Drop-list ame of field/discovery/pipeline, etc.: Area: Type: OD-ID : iscovery well (for field): orwegian percentage: 1, % perator: ate: ontact, NPD: elephone: -mail address: dd.m m.yyyy Report Issuer: Contact, operator: Telephone: address: Alternative contact: ) Resource overview Risk distribution. State probability that the outcome w ill be Low (%) Base High (%) greater than or equal to the low /high value: ecoverable 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 n the "Resource Overview" spreadsheet Resource Overview a) Originally in place: Name of deposit (Select from list or enter new) Discovery well for deposit (Select from list) Description of deposit Oil (million Sm 3 ) Associated liquid (NGL/condensate) (million Sm 3 ) Associated gas (billion Sm 3 ) Free gas (billion Sm 3 ) All deposits To be reported Drop-list Low Base High Low Base High Low Base High Low Base High Drop-list otal :,,,,

30 RK 6 8 Recoverable resources Sheet: Generell info og kommentarer Recoverable resources in Categories 6 and 7 Name of project Resource Category Drop-list Resource Category Attribute 1 Serial Number Deposit Droplist Year for the decision to initialize (feasibility studies) DG (yyyy) Oil (million Sm 3 ) NGL (million tonnes) Gas (net deliverable) (billion Sm 3 ) Condensate (million Sm 3 ) Low Base High Low Base High Low Base High Low Base High Not evaluated discoveries 7F Possible meassures to improve recovery 7A Resources where recovery is not very likely 6 Recoverable resources in Resource Category 8 Information regarding undiscovered resources and exploration plans NGL (million tonnes) Oil (million Sm 3 ) Gas (billion Sm 3 ) Condensate (million Low Base High Low Base High Low Base High TOTAL RC6,,,, TOTAL RC7,,,,, Resource estimates (risked) all prospects: Name of prospects included in the resource estimate: Number of mapped prospects that can be linked to the field: Number of prospects drilled in 213 Name of prospects drilled in 213 Resource growth from exploration in 213 (million Sm 3 oe) Number of prospects drilled in 214 Name of prospects drilled in 214 Resource growth from exploration in 214 (million Sm 3 oe) Number of prospects planned for drilling in 215 Name of prospects planned to be drilled in 215 Expected resource growth from exploration in 215 (risked) (million Sm 3 oe) Number of planned exploration wells to be drilled from mobile facilities in 215: Number of planned prospects for drilling in the period Expected resource growth (risked) for the period (million Sm 3 oe) Number of planned exploration wells to be drilled from mobile facilities Comments:

31 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 oject overview incl. recoverable resources Name of project Name of project Categ ory 3 Categ Categ ory Attribut Serial Numb Oil (million Sm 3 ) NGL (million tonnes) Gas (net deliverable) (billion Sm 3 ) Condensate (million Sm 3 ) Deposits (choose from drop-down menu) Project Developm Need for Project Technolog Technolog Technolog Time Year for Year for Year for ory e 1 er Low Base High Low Base High type: Low ent new Base power stopper: High y usage: y Low areas: y status: Base criticality: High the decision the decision the decision Chose from solution: generation Most Is the Within What is the Is the to to to Drop-list pull-down Complete : important project which areas status as realisation initialize concretize continuation menu. when the Indicate cause for based on will new regards of the (feasibility (concept (concept category how the the project conventiona technology technologic project timecritical, studies) studies) choice, Utbygg project will not being l methods be used or al and, preliminary Categ Oil NGL Gas (net deliverable) Condensate under the get supply realized or or will new developed? developme if so, what engineering attribute of power suffering technology nt for kind of timecriticality? phase) ory (million Sm 3 ) (million tonnes) (billion Sm 3 ) (million Sm 3 ) Project significant be used or projects DG DG1 DG2 DG3 Serial Deposits type is delay. developed? which are chosen conditional Attribut Numb (choose from drop-down upon new e 1 er Low Base High Low Base High Low Base High Low Base High menu) technology? (yyyy) (yyyy) (yyyy) (yyyy) Year for Comments: the decision E.g. realisation assumptions, w to development requirements, sp implement (detailed engineering PDO if relevant) Drop-list Project attributes required for all projects in RC 3, 4 and 5 - fields and discoveries cated Gassco: RC_-3,,,, 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. Drop-list Technolog y usage: Is the project based on conventiona l methods or will new technology be used or developed? 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? 35 Time criticality: Is the realisation of the project timecritical, and, if so, what kind of timecriticality? Year for the decision to initialize (feasibility studies) 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 assumptio development requiremen

32 Reporting of resources Use the commentary boxes in the reporting file Changes from last years reporting should be explained as short and concise as possible, example: Reduced STOOIP based on new mapping Increased volumes based on positive well results Well postponed due to rig availability etc. Please state, if possible, references to documents where the changes are further explained.

33 Profile sheets Production and sales products

34 Profil_2 Conce pt and wells cost Gassc o Report ing All numbe rs Information 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 timecriticality? DG DG1 DG2 DG3 Project type developed? conditional Nam e of Serial Deposits is chosen upon new project Category 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: Annual oil production Annual dry gas production 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: 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 I nv 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 1 Production and injection data Sale of petroleum, income profiles and transport profiles Investments Operating costs Tariffs Other costs Assumptions for environmental emissions/discharges and other data Consumption of natural gas and diesel CO 2 - discharge NO X - discharge nmvoc & CH 4 - discharge Power from shore Water Water Gross Natural gas Gas for gas CO2 Accumulated Accumulated Accumulated Annual sale Annual sale Annual sale Annual sale Annual sale Accumulated Accumulated Accumulated 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 Deliveries of Deliveries of Injected Total gas lift in Injected CO2 Discharge of Injected Natural gas Natural gas Diesel Diesel CO2 total CO2 CO2 CO2 CO2 NOx total NOx NOx NOx NOx Emissions Emissions Oil, NGL, etc. Emissions Emissions Emissions Emissions Annual pow er Maximum injection production gas injection in lift Gas injection sale oil sale oil sale oil oil oil oil NGL condensate dry gas dry gas dry 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 gas from main oil/ngl/ natural gas in main field and in main field produced w ater in main used for fuel used for consumption consumption contribution contribution contribution contribution contribution contribution contribution contribution nmvoc CH4 total nmvoc nmvoc CH4 CH4 consumption pow er usage production ow n field, Low estimate Base estimate High estimate Low estimate Base estimate High estimate Base estimate Base estimate Low estimate Base estimate High estimate 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 field and condensate main field and associated and w ater from field and flaring subject to not subject to fuel gas flaring diesel (in from mobile from fuel gas from flaring from diesel (in from mobile from cold from cold loaded/stored storage loading storage loading (Peak) Row s for annual values after 238 can be displayed/hidden exclusive gas per calendar per calendar per calendar 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 associated from main field associated fields associated main field and associated CO2 tax (in CO2 tax accordance facilities accordance facilities venting and venting and by clicking the "+" and "-" lift year Gross year Gross year Gross discoveries discoveries -JOA 7 part -JOA 5.2 facilities placed drilling facilities distributed by -JOA 5.1 part -JOA JOA Total AY-BH preparation fields w ith and fields as w ell fields as w ell associated fields accordance (mobile w ith CO2 tax w ith CO2 tax fugitive fugitive icons dow n at the bottom left. calorific value calorific value calorific value per gas year per gas year facilities -JOA 5.3 part w ell -JOA 6.2 excl. Tariffs ship-loading associated as any as deposit fields w ith CO2 tax facility) legislation) legislation) emissions emissions (GCV) (GCV) (GCV) Gross Gross -JOA 5.3 part -JOA 5.3 part -JOA 6 (-6.4) point on the fields w ith deposit excl. legislation) calorific value calorific value facility ship-loading gas lift (GCV) (GCV) point on the facility Joint operating agreement (JOA) item 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,,,,, 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,,,,,,,,,,,,,,,,,,,,,, %,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 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 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 Information Information Information Information Start-up 27 Proj. Life 28 Proj. Life 29 Proj. Life 3 Proj. Life 31 Annual 32 Annual 33 Tariffs 34 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. Hide Profil_2 Check that information regarding service provider for tariffs are completed in cell area $BO$32:$BU$32 Message Any comments Calculation area,, 999, 999,,,,, 999, 999,,,,, 999, 999,,,,, 999, 999,,,,, 999, 999,, 999, 999 2,,, , 999,,,,,,,,, 1,,,, Deposits: 1,2 1,,8,6,4,2 NOx Projected emissions CO2,, ,2 1,,8,6,4,2 Profil_1-15 RNB215 Projects which are included in the profile, include 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 CO2 NOx Power from shore Consistency checks In general: White cells should be filled in when relevant Grey cells should not be filled in, will be calculated automatic or are irrelevant 38

35 In general: What should be reported data types Production start-up, including uncertainty, RC 2-5 Information related to purchase of gas, tariffs and environmental assumptions. Explanations (free-text) to the profiles changes, assumptions Profiles; Production, sales and other incomes. Costs (Capex, Opex, Tariffs, Other costs). Environmental assumptions and emissions (RC -5). Consistency checks.

36 Consistency checks control of the relationship between some data in the file 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 Annual 14 flow Cash Proj. Life 15 flow Gas Annual 16 Gas Annual 17 Information Proj. Life 18 Information Proj. Life 19 Gas Annual 2 Drilling Annual 21 Drilling Annual 22 Drilling Annual 23 Drilling Annual 24 Cash Annual 25 flow Cost Proj. Life 26 Information Start-up 27 Information Proj. Life 28 CAPE Proj. Life 29 X CAPE Proj. Life 3 X Conce Proj. Life 31 pt and wells cost Gassc Annual 32 o Report ing All Annual 33 numbe rs Information Tariffs 34 Message Check that total monthly data for basis sale of oil (spread sheet Monthly Deviation betw een monthly and yearly data. Check reported data, 'Månedsdata',) is equal to the yearly value stated for year 215 (cell figures or provide comments. S41). Check that sum of base oil profile (cell S115) is equal to the associated Deviation betw een stated oil resources and total basis oil value for base oil in the table above (cell M26). profile. Please check reported figures or provide comments. 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 Production data has been reported after last year of CO2- period of time as the production (columns S, U, V, and K). discarges, correct poss. mistake or provide comments. Check that the annual NOx emissions (column CS) are reported in the same Production data has been reported after last year of NOxdischarges, correct poss. mistake or provide comments. 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 Need to comment on development concept/improved (cell H28) have been used. recovery or progress in cell H28. 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 Check 215, for possibly incomplete data, please comment/ income for pipelines etc) and relevant opex data cover same years. correct. 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. Please fill inn Startup date production, cell area N31:P32. 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 Any comments Calculation area 3, 3,, 1 1, 3, 3, 3 1,, 999, 999,,,,, 999, 999,,,,, 999, 999,,,,, 999, 999,, 999, , 1,, , 999, 1,,, 1,,,,, 1,,,, 4 Example: Reported oil sale in 215 in profile for RK2F Consistency? Monthly data Resources CO 2 -emissions NO X -emissions Comments Missing OPEX Start-up w/uncertainty What should be done Correct mistakes If not; comment the reason why the reporting is correct

37 Production profiles RC 1 RC 5 sales profiles The projects total lifetime (can be in different categories). For the following year, monthly values (on separate sheet). Only Norwegian part of boundary field. RC 5 No uncertainty profiles requested. Input of uncertainty for start-up mandatory.

38 Profiles, production and sales Free text and change explanations related to the profile collection: Annual oil production Write good explanations Month: Year: Start-up date production Early Base Late Fill in for RC 2-5 1,6 1,4 1,2 1,,8,6,4,2, Low Base High 1,,9,8,7,6,5,4,3,2,1, 214 Production and injection data Sale of petroleum, inco Row s for annual values after 238 can be displayed/hidden by clicking the "+" and "-" icons dow n at the bottom left. Joint operating agreement (JOA) item Water injection Water production Gross gas production Natural gas injection in ow n field, exclusive gas lift Production data 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 Annual sale NGL Base estimate Annual sale condensate Base estimate 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 Sum:,,,,,,, 6,3,, 6,3,,, Accum. Up to and including 212,,, 213,,, 214 1, 1, 1, 1, 215 2,5 1,5 Fill in relevant white cells Sales product condensate/oil Sales data, incl uncertainty 216 3,8 1, ,8 1, 218 5,5, ,,5 22 6,3,3 221, 222, 223, 224,

39 Uncertainty in the oil profiles (RC 1-4) Accumulated uncertainty high and low estimate. Compliance with low and high estimate for recoverable reserves/resources. Yearly uncertainty low and high estimate for the next 5 years. Will be used for; Aggregated production for the Norwegian Continental Shelf. Normally a larger range of uncertainty than for accumulated uncertainty.

40 Details after lunch

41 Gas Kjartan H. Teigen 4 September 214

42 Comments related to delivery of gas to other fields / discoveries In the sheet Generell info og kommentarer Please state transmissions of gas to other fields / discoveries. Please state if the gas is exchanged as payment for a service or if it is sold. 2c) Explanation of changes and comments Detailed explanation of any changes in the resource estimates in relation to the previous RNB reporting, as well as explanations concerning changes in the project that will have consequences as regards changes in production profiles, costs and environmental discharges/emissions. Please state any transfer of gas to other fields/discoveries for injection or other use. Please state if the gas is given away as payment for a service or if it is sold.

43 Gas reporting 18 profiles The reporting of gas is split in four; 1. Production and injection in own field 2. Physical deliveries, transport, sale and purchase of gas 3. Basis for calculation of the environment emissions 4. Reporting to Gassco

44 Production and injection data Row s for annual values after 234 can be displayed/hidden by clicking the "+" and "-" icons dow n at the bottom left. Water injection Water production Production and injection data Gross gas production Natural gas injection in ow n field, exclusive gas lift Gas for gas lift CO2 Gas injection This should be filled in! Joint operating agreement (JOA) item Unit : million m3 million m3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 Sum:,,,,,, Accum. Up to and including Gross gas production Natural gas injection in own field, exclusive gas lift Gas for gas lift CO2 Gas injection

45 Physical deliveries, transport, purchase and sales of gas Accumulated dry gas Low estimate per calendar year Gross calorific value (GCV) Accumulated dry gas Base estimate per calendar year Gross calorific value (GCV) Accumulated dry gas High estimate per calendar year Gross calorific value (GCV) Physical dry gas deliveries from fields/ discoveries per gas year Gross calorific value (GCV) Physical rich gas deliveries from fields/ discoveries per gas year Gross calorific value (GCV) Saleable gas per calendar year 4 MJ/Sm3 Saleable gas per gas year 4 MJ/Sm3 Gas purchase per calendar year 4 MJ/Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3 billion Sm3,,,,,,,,,,,,,, Please name sources of gas purchase: When purchasing gas, all source fields should be reported in cells AA32 in the profile sheet. Purchase and sales profiles in 4 MJ/Sm³ Range of uncertainty should be reported for RC 1-4 Physical deliveries -All fields/discoveries that deliver gas should report physical dry gas deliveries -Fields that deliver rich gas from the field should report rich gas

46 Calendar year own field Flare Gas purchase per calendar year 4 MJ/Sm3 Fuel Accumulated dry gas Low estimate per calendar year Gross calorific value (GCV) Accumulated dry gas Base estimate per calendar year Gross calorific value (GCV) Accumulated dry gas High estimate per calendar year Gross calorific value (GCV) Gross gas production Natural gas injection in own field, exclusive gas lift Gas for gas lift CO2 Gas injection Saleable gas per calendar year 4 MJ/Sm3 5

47 Gas year (1 October to 1 October) Physical rich gas deliveries from fields/ discoveries per gas year Gross calorific value (GCV) Physical dry gas deliveries from fields/ discoveries per gas year Gross calorific value (GCV) Everybody that deliver gas should fill in this! Saleable gas per calendar year 4 MJ/Sm3 Saleable gas per gas year 4 MJ/Sm3 51

48 For emissions calculations Own field plus environments calendar year Flare Receipt of gas Fuel Deliveries of gas from main field and associated fields with ship-loading point on the facility Injected CO2 in main field and associated fields as well as deposit Gross gas production Injected natural gas in main field and associated fields as well as any deposit excl. gas lift Total gas lift in main field and associated fields Check 16: Gross + Receive- Injection - Fuel - Flare = Gas deliveries

49 Coordination with the reporting to Gassco The NPD has a cooperation with Gassco which means that the sheets Gassco main data collection process are included in the reporting file. Gassco provides guidelines to the operators. The operators should send these sheets to Gassco, ref request from Gassco. All projects where it is possible that the operators will apply for transportation rights in Gassled, should be reported to Gassco.

50 Some key messages This should be reported; Gross gas production (Column K) Accumulated dry gas Base estimate per calendar year Gross calorific value (GCV) (Column X) Physical dry gas deliveries from fields/discoveries per gas year Gross calorific value (GCV) (Column Z) If the field/discovery does not deliver physical dry gas from the facility, but only raw gas, a dry gas volume should still be calculated. This dry gas volume is expected to be delivered at the sales point. The sales gas profile per calendar year and per gas year must add up to the same volume, but the production schedule can be different (Column AB and AC) The accumulated dry gas Base estimate per calender year GCV (Column X) and physical dry gas deliveries from fields/discoveries per gas year GCV (Column Z) must also add up to the same volume. Fill in the comments columns Explain changes Describe development solution Include source field if purchase of gas Comments related to gas transferred to another field/discovery

51 Cost and income Tove Francke

52 Cost and income reporting The reporting is based on the Joint Operating Agreement. But: Sometimes the NPD asks for a more detailed information compared to the JOA in other cases the NPD ask for less detailed information regarding costs related to Exploration, Exploration drilling and testing, and Field evaluation, this data is collected by the NPD though Statistic Norway

53 The profile sheets The reporting in the profile-sheets is split in four parts: Investments costs Operating costs Tariff costs Other costs Tariff income in reported in a separate sheet Tariffinntekter

54 Development Investments Development investments concern the development of new resources and shall be reported separately for 5 categories : Subsea facilities Floating facilities Fixed facilities (excluding subsea facilities / pipelines) Investment in pipelines and land facilities Other development investments Note that Development Investments shall be reported exclusive of concept studies done before such an investment is made

55 Development Investments and Project attributes For all projects in RC 3, 4 and 5, both fields and discoveries, project attributes in the profile sheets must be reported Among the attributes are Development solutions Chosen Development solution in the attribute list must comply with what is reported as Development Investments

56 Development Investment and number of development wells Dev. wells from permanently placed drilling facilities Dev. wells from mobile drilling facilities Investments in dev. wells from permanently placed drilling facilities -JOA 5.3 part Investments in dev. wells from mobile drilling facilities -JOA 5.3 part Quantity Quantity million NOK million NOK Wells drilled from fixed and mobile facilities must be differentiated. The number of wells and the costs associated with development wells must correspond per year. If the wells are not completed within the calendar year, number of wells may be reported as a decimal figure

57 Development wells New wells include all wellbores that receive their own designation in accordance with the NPD s rules for naming wells and wellbores: "Wells - Designation of wells and wellbores ". Wells and wellbores are included regardless of the well s purpose (production, injection, observation and disposal).pilots and observation wells drilled in order to establish an efficient wellbore, should not be reported under the number of development wells. Exploration wells (wildcat and appraisal wells) shall NOT be included. Each branch in a multilateral well counts as a separate wellbore.

58 Development Investment in pipelines and land facilities Investments in pipelines -JOA 5.1 part Investments in land facilities -JOA 5.1 part Total investments in pipelines and land facilities -JOA 5.1 part million NOK million NOK million NOK Include in-field pipeline costs and export pipeline cost. Include land facilities owned by the joint venture or equivalent

59 Operating Investments vs. Other development investments Operating Investments includes a variety of investment types, see the JOA 5.2 As regards discoveries, modifications on a host related to tie-in of a subsea development must be reported as other development investments

60 Operating Costs Operational preparations -JOA 6.1 Ordinary operating costs -JOA Maintenance excl. wells -JOA Well maintenance -JOA Modifications -JOA million NOK million NOK million NOK million NOK million NOK All maintenance activities, excl. wells, related to an offshore facility, land plant and associated pipes are to be reported as Operating Cost here, not as Operating Investment Well maintenance are all types of costs that are related to down-hole work up to the choke, and which do not form part of a drilling project.

61 Tariff costs Tariff costs shall only be reported for projects in RC 3-4 that have such costs Tariff costs also include direct payment of operating costs or direct payment of investment costs. Tariff costs in RC -2 shall not be reported unless they comprise of payments related to import of tariff services The tariff costs associated with the projects in RC -2 will be accounted for when the fields report income from third-party processing, and pipelines and terminals provide estimates of their income. The NPD incorporates and allocates this income as costs for the relevant fields as part of the comparison of the figures associated with National Budget Reporting.

62 Tariff income Tariff income shall only be reported for projects in RC 1-2 that have such income. The income flows are to be stated in separate columns Tariff revenues also comprise a possible reimbursement of operating costs and/or investment costs as a result of cost sharing agreements with associated fields..

63 Other costs BW BX BY BZ CA 33 Shut-down costs -JOA 8.1 Final disposal (removal) -JOA 8.2 Other costs Area fees -JOA 9.2 Environmental taxes -JOA 9.3 Other general costs -JOA million NOK million NOK million NOK million NOK million NOK Costs associated with shutdown and final disposal shall be reported. The time schedule for the activity must be practically possible to carry out and reflect projects that can extend the lifetime of the field!

64 General reminders Only cost profiles for projects in resource category -5 are to be reported As far as possible, report complete profiles for each profile collection on fields Report profiles for the field covering the full expected lifetime, irrespective of the length of the license period. If a project has reached a decision in the license, what is reported to the NPD in the RNB must be in accordance with the license s Recommended Budget 214 (as per 1 october) Changes in relation to the reporting as of October 1 that follow from budget consideration in the MC s shall be submitted to the NPD as early as possible and no later than 15 December Cost and income profiles for 213 must show final cost numbers and in 213- NOK, whereas cost and income profiles for 214 and forward must be in 214- NOK. Use the comment boxes to explain and describe significant changes compared with the previous RNB reporting large changes in this year s profiles regarding discoveries in RC 4 and 5 the operator is asked to briefly describe the concept reported

65 Environmental data Bente Jarandsen 5 September 213

66 Emissions forecast - environmental Emissions from fields in production and approved developments shall be reported. Note that the discharge/emission should be reported on the field where they take place. Boundary fields/discoveries should report total discharge/emission if these take place on the Norwegian shelf. For reserves, RC 1-3, the forecasts shall reflect emissions/discharges based on use of current technology and the effect of emission/discharge reduction measures adopted by the license. Projects in the planning phase (RC 4 and 5) Should report own emission data if the development solution will lead to total increased emission. Link these emissions to the power demand. New power generations, existing power generation or power from shore. Should not report own emissions if the development solution is tie-in to an existing infrastructure and this do not increase the power demand on the hostinstallation. Environmental data shall not be reported for RC 7 and 8.

67 Environmental data Assumptions for environmental emissions/discharges and other data Receipt of gas 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 billion Sm3 billion Sm3 million Sm3 oe billion Sm3 billion Sm3 billion Sm3 million m3 million m3 Consumption of natural gas and diesel 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) million Sm3 million Sm3 million litres million litres

68 Environmental data CO 2 - discharge NO X - discharge CO2 total CO2 contribution fuel gas CO2 contribution flaring CO2 contribution diesel (in accordance w ith CO2 tax legislation) CO2 contribution from mobile facilities NOx total NOx contribution from fuel gas NOx contribution from flaring NOx contribution from diesel (in accordance w ith CO2 tax legislation) NOx contribution from mobile facilities million tonnes million tonnes million tonnes million tonnes million tonnes 1 tonnes 1 tonnes 1 tonnes 1 tonnes 1 tonnes nmvoc & CH 4 - discharge Power from shore Emissions nmvoc from cold venting and fugitive emissions Emissions CH4 from cold venting and fugitive emissions Oil, NGL, etc. total loaded/stored Emissions nmvoc storage Emissions nmvoc loading Emissions CH4 storage Emissions CH4 loading Annual pow er consumption Maximum pow er usage (Peak) 1 tonnes 1 tonnes million Sm3 1 tonnes 1 tonnes 1 tonnes 1 tonnes GWh MW

69 Important to note! Describe changes from RNB214 Check historical data against forecast level. Please explain discontinuities. 74

70 Gassco

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