USER GUIDE FOR THE COMMON DAILY DRILLING REPORT SYSTEM (CDRS) Report number: OD-95-30

USER GUIDE FOR THE COMMON DAILY DRILLING REPORT SYSTEM (CDRS) Report number: OD-95-30

Petroleum Safety Authority (PSA) Page 2 of 63 CONTENT: 1. DAILY DRILLING REPORT SYSTEM (CDRS) INTRODUCTION...4 2. DRILLING PROGRAM...4 2.1 PROGRAM part I - Basic well...5 2.2 PROGRAM part II - Estimated/planned well...8 2.2.1 PROGRAM PART II a) - Planned mud type...8 2.2.2 PROGRAM part II b) - Estimated/planned mud/pore pressure...9 2.2.3 PROGRAM part II c) - Estimated fracture gradient...9 2.2.4 PROGRAM part II d) - Planned casing string...9 2.2.5 PROGRAM part II e) - Planned phase...10 2.2.6 PROGRAM part II f) - Planned directional...11 2.2.7 PROGRAM part II g) Registration number...11 2.3 PROGRAM part III - Prognozed zonation...11 3. DAILY REPORT...12 3.1 REPORT part I - Basic information...12 3.1.1 REPORT part I a) - Well classification...12 3.1.2 REPORT part I b) - Operator...13 3.1.3 REPORT part I c) - Contractor...13 3.1.4 REPORT part I d) - Rig...13 3.2 REPORT part II - Status...13 3.3 REPORT part III - Mud/pore pressure...15 3.4 REPORT part IV - Present operation...16 3.5 REPORT part V - Survey...16 3.6 REPORT part VI - Operation/mode...17 3.6.1 Legal values for main operation and sub operation...18 3.6.1.1 MOVING...18 3.6.1.2 DRILLING...20 3.6.1.3 FORMATION EVAL...21 3.6.1.4 COMPLETION...22 3.6.1.5 WORKOVER...24 3.6.1.6 PLUG & ABANDON...25 3.6.1.7 INTERRUPTION...26 3.6.2 Legal values for sub modes...27 3.6.2.1 Example of using sub modes...28 3.7 REPORT part VII - Log...29 3.8 REPORT part VIII - Core...29 3.9 REPORT part IX - Well test...30 3.10 REPORT part X - RFT test...32 3.11 REPORT part XI - Weather...32 3.12 REPORT part XII - Remarks...35 3.13 REPORT part XIII - Lithology...35 3.14 REPORT part XIV - Equipment fail...35 3.14.1 Legal values for main and sub equipment system...36 3.14.1.1 DRILLFLOOR EQU/SYST...36 3.14.1.2 HOISTING EQUIPMENT...37 3.14.1.3 PIPE HANDLING EQU/SYST...37 3.14.1.4 MUD AND BULK SYSTEMS...38 3.14.1.5 WELL CONTROL EQU/SYST...38 3.14.1.6 DRILLSTRING/DOWNHOLE EQU...39 3.14.1.7 SERVICE EQU/SYST...39 3.14.1.8 MATERIAL HANDLING SYSTEM...40 3.14.1.9 MISCELLANEOUS EQU/SYST...40 3.15 REPORT part XV - Kick...41 3.16 REPORT part XVI - Preliminary zonation...42

Petroleum Safety Authority (PSA) Page 3 of 63 3.17 REPORT part XVII - Perforation intervals...43 4. CDRS TRANSACTION FILE...44 4.1 Transaction file layout...44 4.1.1 Well reference layout...44 4.1.2 Field separator and continuation indicator...44 4.1.3 Date format...45 4.2 Start of file...45 4.2.1 PROGRAM Part I - Basic Well...45 4.2.2 PROGRAM Part II - Estimated/planned well...46 4.2.2.1 PROGRAM Part II a) - Planned mud type...46 4.2.2.2 PROGRAM Part II b) - Estimated/planned mud/pore pressure...46 4.2.2.3 PROGRAM Part II c) - Estimated fracture gradient...46 4.2.2.4 PROGRAM Part II d) - Planned casing string...46 4.2.2.5 PROGRAM Part II e) - Planned phase...46 4.2.2.6 PROGRAM Part II f) - Planned directional...47 4.2.2.7 PROGRAM Part II g Registration number...47 4.2.3 PROGRAM part III - Prognozed zonation...47 4.2.4 REPORT part I - Basic information...47 4.2.4.1 REPORT part I a) - Well classification...47 4.2.4.2 REPORT part I b) - Operator...47 4.2.4.3 REPORT part I c) - Contractor...47 4.2.4.4 REPORT part I d) - Rig...48 4.2.5 REPORT Part II - Status...49 4.2.6 REPORT Part III - Mud/pore pressure...49 4.2.7 REPORT Part IV - Present operation...50 4.2.8 REPORT Part V - Survey...50 4.2.9 REPORT Part VI - Operation/mode...50 4.2.10 REPORT Part VII - Log...51 4.2.11 REPORT Part VIII - Core...51 4.2.12 REPORT Part IX - Well test...52 4.2.13 REPORT Part X - RFT test...53 4.2.14 REPORT Part XI - Weather...54 4.2.15 REPORT Part XII - Remarks...54 4.2.16 REPORT Part XIII - Lithology...54 4.2.17 REPORT Part XIV - Equipment fail...55 4.2.18 REPORT PART XV - Kick...56 4.2.19 REPORT part XVI - Preliminary zonation...56 4.2.20 REPORT part XVII - Perforation intervals...57 4.3 End of file...57 4.4 Example of a completed transaction file...58 5. COMMUNICATION...60 6. APPENDIX A: OPERATION CODES...61 7. APPENDIX B: EQUIPMENT CLASSIFICATION...62 8. CHANGES OF THE CDRS REPORT SYSTEM...63 8.1 New tables...63 8.2 Separated tables/values...63 8.3 New data fields...63 8.4 New sub operations...63

Petroleum Safety Authority (PSA) Page 4 of 63 1. DAILY DRILLING REPORT SYSTEM (CDRS) introduction The Petroleum Safety Authority (PSA) will as a rule require ongoing activities to be reported on a daily basis (weekdays) to the drilling data base of the PSA, before 1200 noon. Reports shall be in accordance with the format described in this CDRS user's guide 1. The CDRS is a EDP-system that covers information from wells drilled on the Norwegian continental shelf. All wells spudded after 1.4.84 is included in the database and the system consists of two parts: - Data-entry part to be used by all operators - Central database part to be used by the PSA This manual covers necessary information related to the data-entry part: - Program and report parts: Description of each part included in the drilling report and legal values to be used (chapter 2 and 3). - Transaction file: Layout of each part (chapter 4). - Communication: How to transmit the transaction file to the PSA (chapter 5). Note that the CDRS is based on the SI-system except for the casing and hole diameters which is given in inches. 2. DRILLING PROGRAM Before a new well is spudded and every time there are changes in the previous drilling program, a new drilling program must be reported separately to PSA. In addition the CDRS drilling program part shall cover the following parts: - PROGRAM part I: Basic well data - PROGRAM part II: Estimated/planned well - PROGRAM part III: Prognozed zonation 1 cf. Guidelines to the regulation concerning drilling and well activities and geological data collection in the petroleum activities Re. Section 12

Petroleum Safety Authority (PSA) Page 5 of 63 2.1 PROGRAM part I - Basic well Field name Length Format [Units] Remarks WFIELD 4 9999 WBLOCK 2 99 WPLATF 1 A WNO 2 99 Well name 2 WHIST1 3 AAA WTRACK 2 T9 WHIST2 2 AA PDTVD 7 99999,9 [meter] PDMD 7 99999,9 [meter] WDLAT 7 99999,9 [meter] LATITUDE: 9 999999,99 - Ladeg Format: 99 - Lamin Format: 99 - Lasec Format: 99,99 LONGTITUDE: 9 999999,99 - Lodeg Format: 99 - Lomin Format: 99 - Losec Format: 99,99 TEXT 74 A x 74 Description: / WFIELD gives field identification. South of 62nd parallel: Official format Transaction format IE.1: 17/10-5 001710 05 Exploration well IE.2: 17/10-A-5 001710A05 Production well North of 62nd parallel. Fields north of the 62nd parallel are designated by a four - digit number. The first two digits show the latitude, and the second two the longitude at the lower left corner of the field. The block and well numbering system is the same both north and south of the 62nd parallel. Official format Transaction format IE.3: 7016/10-5 701610 05 Exploration well IE.4: 7016/10-A-5 701610A05 Production well / WBLOCK gives block identification. Official format Transaction format IE.1: 17/10-5 001710 05 Exploration well IE.2: 17/10-A-5 001710A05 Production well 2 The well name should be equivalent to NPD's official well name. The well identification are assigned by the NPD.

Petroleum Safety Authority (PSA) Page 6 of 63 / WPLATF gives platform identification. - Production wells: Write field, block, platform identification code and well number. - A - P for platform - U for shallow boreholes - T for test production well Official format Transaction format IE.2: 9/11-A-5 001710A05 IE.4: 7016/10-A-5 701610A05 The platform identification code shall only be used when drilling from a fixed installation. / WNO gives well number identification. South of 62nd parallel: Official format Transaction format IE.1: 17/10-5 001710 05 Exploration well IE.2: 17/10-A-5 001710A05 Production well North of 62nd parallel: Official format Transaction format IE.3: 7016/10-5 701610 05 Exploration well IE.4: 7016/10-A-5 701610A05 Production well / WHIST1 gives well history and well configuration. - Exploration wells: - A, B, C, D,... for side drilling (new wells) Official format Transaction format IE.1: 17/10-5 A 001710 05A IE.2: 7016/10-5 A 701610 05A - S for an inclined exploration well (if the side drilling is done form an inclined well, the S shall not be used) Official format Transaction format IE.3: 17/10-5 S 001710 05S IE.4: 7016/10-5 S 701610 05S - R for re-entered exploration well and times re-entred (blank,1,2,...). Official format Transaction format IE.5: 17/10-5 R 001710 05R IE.6: 7016/10-5 AR 701610 05AR IE.7: 7016/10-5 AR2 701610 05AR2

Petroleum Safety Authority (PSA) Page 7 of 63 - Production wells: - A, B, C, D,... for side drilling (new wells) Official format Transaction format IE.8: 9/11-A-5 A 001710A05A IE.9: 7016/10-A-5 A 701610A05A / WTRACK gives the well track number.: (Well track numbers are assigned by the operator). - Well track number - first well track in a well is not to be given a number. Then next well track is designated T2, T3 etc. Official format Transaction format IE.1 a): 17/10-5 001710 05 Exploration well IE.1 b): 17/10-5 T2 001710 05 T2 Exploration well IE.2 a): 9/11-A-5 000911A05 Production well IE.2 b): 9/11-A-5 T2 000911A05 T2 Production well / WHIST2 gives well history. (Well history are assigned by the Norwegian Petroleum Directorate (NPD)). - Exploration wells: - X for a well that is junked Official format Transaction format IE.1: 17/10-5 R2X 001710 05R 2X IE.2: 7016/10-5 R2X 701610 05R 2X - Production wells: - X for a well that is junked Official format Transaction format IE.3: 9/11-A-5 X 000911A05 X IE.4: 7016/10-A-5 X 701610A05 X - H for subsea completed well (used only for development wells) Official format Transaction format IE.5: 9/11-A-5 H 000911A05 H IE.6: 7016/10-A-5 H 701610A05 H IE.7: 0031/02-B-25 AH 003102B25A H

Petroleum Safety Authority (PSA) Page 8 of 63 / PDTVD gives planned true vertical depth (RKB). The planned vertical depth (TVD) shall be given in metres. One decimal can be given. / PDMD gives planned measured depth (RKB). Planned measured depth (MD) is only to be given when the well is planned to be drilled directional. The planned measured depth has to be given in metres. One decimal can be given. / WDLAT gives water depth. Water depth has to be reported as LAT ( Lowest Astronomical Tide ), and it has to be given in metres. One decimal can be given. LATITUDE: - Ladeg gives latitude degrees. - Lamin gives latitude minutes. - Lasec gives latitude seconds. Latitude seconds can be given with two decimals. LONGTITUDE: - Lodeg gives longitude degrees. - Lomin gives longitude minutes. - Losec gives longitude seconds. Longitude seconds can be given with two decimals. / TEXT gives general planned/estimated freetext data. Freetext data may be written in this field. Freetext data should contain information's concerning type of wellhead system, use of TGB/PGB, possibilities of shallow gas, boulders and/or other relevant information. Variable freetext length. 2.2 PROGRAM part II - Estimated/planned well This program part is seperated into five parts: a) Planned mud type b) Estimated/Planned mud/pore pressure c) Estimated fracture gradient d) Planned casing string e) Planned phase f) Planned directional 2.2.1 PROGRAM PART II a) - Planned mud type Field name Length Format [Units] Remarks WELL 16 ref. 2.1 PDTVD 7 99999,9 [meter] PDMD 7 99999,9 [meter] MTYPE 15 A15 Description: / PDTVD gives estimated/planned true vertical depth (RKB). Give estimated true vertical depth every time there are changes in the parameters. The estimated/planned true vertical depth has to be given in metres. One decimal can be given. / PDMD gives estimated/planned measured depth (RKB). Give estimated measured depth every time there are changes in parameters.the estimated/planned measured depth has to be given in metres. One decimal can be given. / MTYPE gives type of mud. The type of drilling mud planned to be used in the borehole has to be specified.

Petroleum Safety Authority (PSA) Page 9 of 63 2.2.2 PROGRAM part II b) - Estimated/planned mud/pore pressure Field name Length Format [Units] Remarks WELL 16 ref. 2.1 PDTVD 7 99999,9 [meter] ref. 2.2.1 PDMD 7 99999,9 [meter] ref. 2.2.1 PPRESS 4 9,99 [g/cm³] MWEIGHT 4 9,99 [g/cm³] Description: / PPRESS gives estimated pore pressure. Give sufficient pore pressure data to draw the curve of anticipated pore pressures. Data have to be given in eqv. mud weight - relative density. Two decimals can be given. Linear development are described by the endpoints. / MWEIGHT gives planned mud weight. Give sufficient mud weight data to describe the curve of planned mud weights. Data have to be given in relative density. Two decimals can be given. Linear development are described by the endpoints. 2.2.3 PROGRAM part II c) - Estimated fracture gradient Field name Length Format [Units] Remarks WELL 16 ref. 2.1 PDTVD 7 99999,9 [meter] ref. 2.2.1 PDMD 7 99999,9 [meter] ref. 2.2.1 FGRAD 4 9,99 [g/cm³] Description: / FGRAD gives estimated fracture gradient. Give sufficient fracture gradient data to describe the curve of anticipated fracture gradients. Data have to be given in equivalent mud weight - relative density. Two decimals can be given. Linear development are described by the endpoints. 2.2.4 PROGRAM part II d) - Planned casing string Field name Length Format [Units] Remarks WELL 16 ref. 2.1 PDTVD 7 99999,9 [meter] ref. 2.2.1 PDMD 7 99999,9 [meter] ref. 2.2.1 COD 6 99,999 [inch] CWEIGHT 6 999,99 [kg/m] CGRADE 10 A10 CTHREADS 10 A10 FROMDAY 3 999 TODAY 3 999 Description: / COD gives outer diameter of the casing. Give planned nominal outer diameter of the casing for every casing string. If the casing string is made up of two or more sections, with respect to diameter, then establish new depth line(s) at the transition point(s) to indicate the start of every new section, and give the relevant new data concerning the diameter. The outer diameter has to be given in inches, tree decimal can be given.

Petroleum Safety Authority (PSA) Page 10 of 63 /CWEIGHT gives weight of the casing. Has to be given in kg/m. Can be given with two decimals. IE.1: 105.16 IE.2: 78.56 If the casing string is made up of two or more sections, with respect to the weight, then establish new depth line(s) at the transition point(s) to indicate the start of every new section, and give the relevant new data concerning the weight. / CGRADE gives grade of the casing. - IE.1: N80 - IE.2: P110 If grade is not standardised by API, use the asterisk <*>. - IE.3: N80* - IE.4: P110* If the casing string is made up of two or more sections, with respect to the grade, then establish new depth line(s) at the transition point(s) to indicate the start of every new section, and give the relevant new data concerning the grade. / CTHREADS gives threads of the casing. If the casing string is made up of two or more sections, with respect to the threads then establish new depth line(s) at the change point(s) to indicate the start of every new section, and give the relevant new data concerning the threads. / FROMDAY gives from day Give the day number the casing shall be set. / TODAY gives to day Give the day number the casing is finish cemented. 2.2.5 PROGRAM part II e) - Planned phase Field name Length Format [Units] Remarks WELL 16 ref. 2.1 PDTVD 7 99999,9 [meter] ref. 2.2.1 PDMD 7 99999,9 [meter] ref. 2.2.1 PHASE 6 99,999 [inch] Description: / PHASE gives hole diameter of the phase. Write the planned hole diameter every time a new phase starts. The hole diameter has to be given in inches, tree decimal can be given.

Petroleum Safety Authority (PSA) Page 11 of 63 2.2.6 PROGRAM part II f) - Planned directional Field name Length Format [Units] Remarks WELL 16 ref. 2.1 DTVD 7 99999,9 [meter] DMD 7 99999,9 [meter] AZIMUTH 6 999,99 [degree] INCL 6 999,99 [degree] Description: / DTVD gives planned true vertical depth (RKB). Every time new azimuth and/or inclination data is given, then also give TVD. Has to be given in metres. One decimal can be given. / DMD gives planned measured depth (RKB). Every time new azimuth and/or inclination data is given, then also give MD. Has to be given in metres. One decimal can be given. /AZIMUTH gives the planned azimuth. The planned azimuth has to be given in degrees ( 0-360 ) with two decimals. / INCL gives planned inclination. The measured inclination has to be given with two decimals. 2.2.7 PROGRAM part II g) Registration number Field name Length Format [Units] Remarks WELL 16 ref. 2.1 RNUMBER 10 A10 Description: / RNUMBER gives the registration number given by the NPD 2.3 PROGRAM part III - Prognozed zonation (Data from Drilling program ) Field name Length Format [Units] Remarks WELL 16 ref. 2.1 FORMATION 74 A74 DEPTH_MD 7 99999,9 [meter] DEPTH_TVD 7 99999,9 [meter] Description: /FORMATION Formation/zone top for each formation/zone in the well. The Operators established formation/zone codes shall be used. /DEPTH_MD Top of formation/zone in meters MD. /DEPTH_TVD Top of formation/zone in meters TVD.

Petroleum Safety Authority (PSA) Page 12 of 63 3. DAILY REPORT When a new well is spudded a daily report must be reported. Note that REPORT part II, IV, VI and XI must always be present in a daily drilling report. The CDRS daily report part covers the following parts: - REPORT part I: Basic information - REPORT part II: Status - REPORT part III: Mud/pore pressure - REPORT part IV: Present operation - REPORT part V: Survey - REPORT part VI: Operation/mode - REPORT part VII: Log - REPORT part VIII: Core - REPORT part IX: Test - REPORT part X: RFT test - REPORT part XI: Weather - REPORT part XII: Remarks - REPORT part XIII: Lithology - REPORT part XIV: Equipment fail - REPORT part XV: Kick - REPORT part XVI: Preliminary zonation - REPORT part XVII: Perforation intervals 3.1 REPORT part I - Basic information This report part is seperated into four parts: a) Well classification b) Operator c) Contractor d) Rig 3.1.1 REPORT part I a) - Well classification Field name Length Format Remarks WELL 16 ref. 2.1 WCLASS 20 A20 Description: / WCLASS gives well classification. Specify whether the purpose of the well is: WILDCAT APPRAISAL PRODUCTION INJECTION OBSERVATION Wildcat well is the first well drilled to explore a new, clearly defined geological unit, delimited by rock types by way of structural or stratigraphic boundaries. Appraisal well is a well drilled to establish the extent and the size of a petoleum deposit. Producion well is a well used for production of petroleum. Injection well is a well used for injection of gas, water or other medium. Observation well is a well used to map or monitor well parameters.

Petroleum Safety Authority (PSA) Page 13 of 63 3.1.2 REPORT part I b) - Operator Field name Length Format Remarks WELL 16 ref. 2.1 OPERATOR 20 A20 Description: / OPERATOR gives name of operator. 3.1.3 REPORT part I c) - Contractor Field name Length Format Remarks WELL 16 ref. 2.1 CONTRACTOR 20 A20 Description: / CONTRACTOR gives name of drilling contractor. 3.1.4 REPORT part I d) - Rig Field name Length Format [Units] Remarks WELL 16 ref. 2.1 RIG 20 A20 RIGHEAD 5 999,9 [degree] AIRGAP 5 99,99 [meter] WHELEVAT 6 9999,9 [meter] Description: / RIGHEAD gives rig heading. Give rig heading in relation to geographical north. 0 deg. and 360 deg. is geographical north. One decimal can be given. /AIRGAP gives elevation of RKB above sea level Airgap elevation RKB, has to be given in metres. /WHELEVAT gives WH elevation above sea level Give wellhead elevation above sea level, has to be given in metres 3.2 REPORT part II - Status Sidetracks will be splitt into two separate groups, which are: Sidetrack for a new prospect and sidetrack for technical reasons. In case of a technical sidetrack, the "REPORT part I - Status" should be sent in (only the fields relevant for the example are shown): IE Well Rdate Ddmd Tvd Tst Kpmd Mpbd 1 000102 03 950101 2000,0 1875,0 2 000102 03 950102 2000,0 1875,0 1500,0 3 000102 03 950103 2000,0 1875,0 4 000102 03 950104 2000,0 1875,0 Y 4 000102 03 T2 950104 1500,0 1350,0 1450,0 4 000102 03 T2 940105 2000,0 1875,0

Petroleum Safety Authority (PSA) Page 14 of 63 Field name Length Format [Units] Remarks WELL 16 ref. 2.1 RDATE 6 999999 DDMD 7 99999,9 [meter] MPBD 7 99999,9 [meter] PHASE 7 99,999 [inch] PCMD 7 99999,9 [meter] PHOLE 1 A PHSIZE 6 99,999 [inch] PHTVD 7 99999,9 [meter] TST 1 A KPMD 7 99999,9 [meter] FSLM 4 9,99 [g/cm³] FSMD 7 99999,9 [meter] CSDIM 6 99,999 [inch] CSMD 7 99999,9 [meter] TESTTYPE 3 AAA TVD 7 99999,9 [meter] Description: / RDATE gives present date. Dateformat year,month and day with leading zeroes. / DDMD gives measured depth (RKB) at end of report. The measured length to the total drilled depth (TD) has to be given in metres at end of report. Can be given with one decimal. / MPBD gives measured plug back depth (RKB). The measured length to the top of the last plug has to be given at the end of the report. If the well is not being plugged back at the present, then type CR (carriage return). The length has to be given in metres. Can be given with one decimal. / PHASE gives size of the present phase. Write size of the present phase. If phase changed during the 12 first hours of the 24 hours report, write size of the new phase. If the phase did not change, or changed during the last 12 hours of the 24 hours report, then type CR. Then the system will use last reported phase also for this report. Size has to be given in inches, tree decimals can be given. / PCMD gives measured depth (RKB) where phase changed. When phase is changing size, the relevant measured depth (MD), to the transition point has to be given. The operator must define when phase is changing. Has to be given in metres. Can be given with one decimal. / PHOLE are you drilling a pilot hole? Are you drilling pilot a hole in this phase? If yes, type Y (yes). If not, type blank. / PHSIZE gives size of the pilot hole. Size has to be given in inches, tree decimals can be given. / PHTVD gives planned TVD of the pilot hole. The planned true vertical depth (RKB) has to be given in metres. One decimal can be given. / TST are you performing a technical sidetrack? Are you performing a technical sidetrack? If yes, then type Y (yes) If not, type blank.

Petroleum Safety Authority (PSA) Page 15 of 63 / KPMD gives measured depth (MD) to the kickoff point. The measured depth to the kickoff point for the sidetrack has to be given in metres. One decimal may be given. / FSLM gives measured formation strength. LOT and FIT has to be reported as a gradient. Data has to be given in equivalent mud weight - r.d. Two decimals can be given. / FSMD gives depth where formation strength is measured. The measured depth (MD) where LOT and FIT was measured (RKB) has to be given. Has to be given in metres, and one decimal. / CSDIM gives the outer diameter of the last casing. The outer diameter has to be given in inches, tree decimals can be given. / CSMD gives measured depth (RKB) to the last casing shoe. The measured depth (MD) to the last casing shoe has to be given in metres, and with one decimal. /TESTTYPE gives the name of the test. Give the test type LOT or FIT. The result has to be given in the datafield FSLM. / TVD gives the true vertical depth (RKB) The true vertical depth has to be reported in metres. One decimal can be given. 3.3 REPORT part III - Mud/pore pressure Field name Length Format [Units] Remarks WELL 16 ref. 2.1 BOP 7 9999,99 [bar] DMD 7 99999,9 [meter] PPRESS 4 9,99 [g/cm³] MUDT 15 A15 MWEIGHT 4 9,99 [g/cm³] VISC 6 9999,9 [mpa.s.] YP 6 9999,9 [Pa.] TVD 7 99999,9 [meter] ref. 3.2 RDATE 6 999999 ref. 3.2 Description: / BOP gives pressure rating of BOP stack. The pressure rating of the BOP has to be reported in bar. / DMD gives measured depth (RKB). Measured depth (MD) must always be given when mud/pore pressure data is entered into this report part. This apply to both pore pressure, mud type and weight, viscosity and yield point. Has to be reported in metres. One decimal can be given. / PPRESS gives pore pressure. The pore pressure has to be reported in eqv. mud weight - r.d. Two decimal can be given. / MUDT gives type of drilling fluid used. Specify what type of drilling fluid that is being used in this borehole. /MWEIGHT gives drilling/completion fluid weight. The drilling/completion fluid weight has to be reported in r.d. Two decimal can be given. / VISC gives the viscosity of the mud. The drilling/completion fluid viscosity has to be reported in mpa.s. mpa.s = milli Pascal second (milli = 0.001). One decimal can be given. / YP gives the yield point of the mud. The yield point of the drilling/completion fluid has to be reported in Pa. One decimal can be given.

Petroleum Safety Authority (PSA) Page 16 of 63 3.4 REPORT part IV - Present operation Field name Length Format [Units] Remarks WELL 16 ref. 2.1 RDATE 6 999999 TIME 5 99:99 REMARKS 74 A x 74 Description: / RDATE gives date Note that the date given here must always be the next date after the report date given in REPORT part II - Status. / TIME gives time of present operation. Present operation is the actual operation carried out at the time the report is sent onshore. Give time of this operation. Hours and minutes have to be written like for example: 05:30 / REMARKS gives brief description of the present operation. Present operation is the actual operation carried out at the time the report is sent onshore. Give a brief description of this operation. Variable freetext length. 3.5 REPORT part V - Survey Field name Length Format [Units] Remarks WELL 16 ref. 2.1 SSM 1 A DMD 7 99999,9 [meter] AZIMUTH 9 999,99 [degree] INCL 6 999,99 [degree] TVD 7 99999,9 [meter] ref. 3.2 RDATE 6 999999 ref. 3.2 Description: / SSM single shot measurement? If the directional survey was performed by use of a single shot, then this has to be confirmed by typing Y (yes). If not, type blank. / DMD gives measured depth (RKB). Give the measured depth (MD) where the directional survey is taken. All types of directional surveys measuring azimuth and/or inclination have to be reported. One decimal can be given. / AZIMUTH gives the measured azimuth. The measured azimuth must be given in degrees ( 0-360 ) with two decimals. / INCL gives the measured inclination. The measured inclination has to be given with two decimals. If the inclination should be measured two times at the same depth, and with different results, the last reported inclination mesurement will be considered valid.

Petroleum Safety Authority (PSA) Page 17 of 63 3.6 REPORT part VI - Operation/mode Field name Length Format [Units] Remarks WELL 16 ref. 2.1 RDATE 6 999999 ref. 3.2 STOP 5 99:99 DMD 7 99999,9 [meter] SUPERIOR 5 A5 MAINOP 15 A15 SUBOP 15 A15 SUBMODE1 6 A6 SUBMODE2 6 A6 SUBMODE3 6 A6 MAINMODE 4 A4 START 5 99:99 REMARKS 74 A x 74 Description: / STOP gives time when the actual operation stopped. Give time when the operation stopped. The "start" time will always be equal to the previous "stop" time, and the system will fill it in automatically. The first start time in the report shall always be 00:00 hours. Stop time has to be written like: IE1: 07:15 IE2: 15:30 / DMD gives relevant measured depth (RKB). Give the relevant measured depth (MD) of the actual operation. As a rule, the sub operation will most likely determine the depth. See the list of legal sub operation depths. Also see the list for the main operation depths. These depths has to be given in metres and one decimal can be given. /SUPERIOR gives the type of equipment To be able to differentiate between drilling and well activites performed by use of different new drilling equipment and techniques, a superior code to the "main operation" has been introduced. The following codes shall be used: Code: FIXED SNUB COIL Description: If the traditional type of equipment is used like the platforms permanently installed fixed rig and equipment. For all main operations performed by use of hydraulic workover units or similar units that are not permanently installed on the platform, for instance snubbing units etc. For all operations performed by use of coiled tubing units. / MAINOP gives the main operation. An operation will always best be described when using two keywords. One for the main operation, and one for the sub operation. When for example running in hole with a new bit, and the purpose is to drill new formation, the MAIN OPERATION will be DRILLING, and the sub operation will be trip. See the list of legal main operations. Be sure to use the correct abbreviations. Each main operation also need a sub operation.

Petroleum Safety Authority (PSA) Page 18 of 63 / SUBOP gives the sub operation. An operation will always best be described when using two keywords. One for the main operation, and one for the sub operation. When for example running in hole with new bit, and the purpose is to drill new formation, the main operation will be drilling, and the SUB OPERATION will be TRIP. Each main operation has a certain number of legal sub operations. See the list of legal sub operations Be sure to use the correct abbreviations. / SUBMODE1 gives the sub mode(s). The sub mode(s) will describe the result of the sub operation. Often the result will be better described when using more than one mode. It is allowed to use as many as three sub modes, but if using more than one, they have to be written in the same chronological order as in the list of legal sub modes. See the list of legal sub modes. / MAINMODE gives the main mode. The main mode will describe the result of the main operation. Following keywords are legal: 'OK', 'FAIL' / START gives time when the actual operation started. Give time when the operation started. The first start time in the report shall always be 00:00 hours. / REMARKS gives a brief description. Some of the operations and/or modes may need some freetext explanation. Variable freetext length. 3.6.1 Legal values for main operation and sub operation Main operations MOVING DRILLING FORMATION EVAL COMPLETION WORKOVER PLUG & ABANDON INTERRUPTION 3.6.1.1 MOVING Legal sub operations for MOVING: TRANSIT DEPTH: 0 ANCHOR DEPTH: 0 SKID DEPTH: 0 JACK DEPTH: 0 POSITION DEPTH: 0 TRANSIT DEPTH: 0 Rig transit time between last anchor retrieved at previous location and arriving at present location. Transit time for jackups begins when barge is afloat and tow lines are ready for tow. Transit time ends when rig is ready to start anchoring or jacking up on a new location. ANCHOR DEPTH: 0 All time associated with running and retrieving anchors, adjusting initial anchor tensions and testing anchors. Upon abandoning the well, all time after BOP and subsea equipment are retrieved is included until last anchor is bolstered and rig is ready to leave location. SKID DEPTH: 0 Time spent on skidding the rig in place on the location or from slot to slot on a fixed installation.

Petroleum Safety Authority (PSA) Page 19 of 63 JACK DEPTH: 0 Time spent to jack up or down. POSITION DEPTH: 0 Time spent to position the rig. Includes preloading and unloading in case of a jack-up rig.

Petroleum Safety Authority (PSA) Page 20 of 63 3.6.1.2 DRILLING Legal sub operations for DRILLING: DRIVE DEPTH: TD at end of period DRILL DEPTH: TD at end of period HOLE OPEN DEPTH: Max. depth UNDERREAM DEPTH: Max. depth TRIP DEPTH: Bit depth at end of sequence CASING DEPTH: Casing shoe BOP/WELLHEAD EQ DEPTH: 0 or MD where relevant PRESS DETECTION DEPTH: 0 or MD where relevant CIRC/COND DEPTH: Relevant depth REAM DEPTH: Bottom of reamed section SURVEY DEPTH: Survey depth BOP ACTIVITIES DEPTH: 0 or relevant depth MILL DEPTH: Relevant depth + WAIT DEPTH: 0 or relevant depth RIG UP/DOWN DEPTH: 0 + OTHER DEPTH: 0 or relevant depth DRIVE DEPTH: TD at end of period Jetting or driving conductor pipe DRILL DEPTH: TD at end of period Rotating on bottom and routine connection time while drilling. Also use for side tracking if purpose is to reach a new geological or reservoir objective. HOLE OPEN DEPTH: Max. depth Rotating and routine connection time while enlarging a pilot hole etc., with a larger bit and/or hole opener. Also use for side tracking, if purpose is to reach a new geological or reservoir objective. UNDERREAM DEPTH: Max. depth Rotating and routine connection time while enlarging a pilot hole etc. with an undreamed. Does not include time to ream to bottom due to fill, ream core hole or ream tight spot. Includes side tracking if purpose is to reach a new geological or reservoir objective. TRIP DEPTH: Bit depth at end of sequence Time spent to run and pull drill string, slug pipe, change BHA, pick up or lay down drill pipe and collars during routine drilling, hole opening or under reaming. Includes wiper trips, short trips and trips to change bit etc. CASING DEPTH: Casing shoe Time to rig up, make up csg hanger and seal assemblies, run csg or liner, pump cement, pressure test csg, run temperature surveys or other to locate cement top or evaluate cement quality, lay down running string, well conditioning prior to running csg, drilling of cement, float and shoe. Also includes time to squeeze, grout and waiting on cement. BOP/WELLHEAD EQ DEPTH: 0 or MD where relevant Time used to install/remove, run/pull and test guide bases, BOP's, risers, wear bushings and other equipment for either initial installation or as subsequently required. Includes testing on the surface only. Does not include recovery operations associated with plugging and abandoning (cf. main operation PLUG & ABANDON). PRESS DETECTION DEPTH: 0 or MD where relevant Includes time spent on all types of gas checks, flow checks, wireline formation testing (FIT) or packer tests to determine or confirm pore pressure, short trips and circulating bottoms up to confirm sufficient mud weight for trip margin.

Petroleum Safety Authority (PSA) Page 21 of 63 CIRC/COND DEPTH: Relevant depth Time spent on routine circulating and conditioning, to raise mud weight based on positive indications of abnormal pressure. Excludes time to weigh up due to hole instability or while circulating out an influx (cf. main operation INTERRUPTION). Includes all routine mud and hole circulating and conditioning and short trips during long bit runs. REAM DEPTH: Bottom of reamed section Rotating and routine connection time while reaming to correct a key seat, dog leg or the effect of an under gauged bit or coring. Also includes reaming as a result of excessive fill or tight hole conditions. SURVEY DEPTH: Survey depth Time spent to run routine directional surveys like Totco, single shot, multi shot, MWD and dipmeter logs run specifically to determine hole direction and deviation. Includes any required circulation and/or trip time associated with the survey. BOP ACTIVITIES DEPTH: 0 or relevant depth Time spent on BOP and hang off drills, review of kick procedures, testing of BOP's after installation on the wellhead, open hole pressure integrity tests (PIT), and other safety or training procedures which require rig time. MILL DEPTH: Relevant depth Time spent on milling operations. Includes all time spent to perpare and carry out the milling operations untill the operation has proven successful. WAIT DEPTH: 0 or relevant depth Waiting on cement (WOC), and all other drilling related waiting. RIG UP/DOWN DEPTH: 0 Prepare and rig up/down snubbing and coil tubing equipment, including pressure testing. OTHER DEPTH: 0 or relevant depth All drilling related operations that are not specifically covered by one of the sub operations listed under main operation DRILLING. The amount of time consumed by this sub operation should be less then 1% of operation DRILLING sum total. 3.6.1.3 FORMATION EVAL Legal sub operations for FORMATION EVALUATION: TRIP DEPTH: Bit depth at end of period CIRC/COND DEPTH: Relevant depth CORE DEPTH: Max. core depth LOG DEPTH: Max. log depth RFT/FIT DEPTH: Max. RFT/FIT depth CIRC SAMPLES DEPTH: Relevant depth DST DEPTH: Top perforating depth PROD TEST DEPTH: Top perforating depth WAIT DEPTH: 0 or relevant depth RIG UP/DOWN DEPTH: 0 + OTHER DEPTH: 0 or relevant depth TRIP DEPTH: Bit depth at end of period All trip time associated with operations such as circulating and conditioning, coring, logging, RFT, FIT, DST and production testing. CIRC/COND DEPTH: Relevant depth Time spent on well conditioning prior to, during and after all formation evaluation operations. CORE DEPTH: Max. core depth Time spent on cutting the core, laying the core down, and servicing the core barrel.

Petroleum Safety Authority (PSA) Page 22 of 63 LOG DEPTH: Max. log depth Time spent during wireline logging surveys, velocity surveys, sidewall core, thermo, caliper etc. Includes time to rig up and rig down as well as actual logging time. RFT/FIT DEPTH: Max. RFT/FIT depth Includes all time for wireline formation interval tests, RFT/FIT that are conducted primarily to determine fluid content/formation pressure. Tests run specifically to determine pore pressure are not included (cf. main operation DRILLING). CIRC SAMPLES DEPTH: Relevant depth. Routine circulating when purpose is to recover samples. DST DEPTH: Top perforating depth Total time spent on drill stem tests, DST, including perforating, flow testing, shut in/build up periods, squeezing, wireline work, sampling and any abandonment work specifically required by the drill stem test. PROD TEST DEPTH: Top perforating depth Total time spent on production tests, including perforating, flow testing, shut in/build up periods, squeezing, wireline work, sampling and any abandonment work specifically required by the production test. WAIT DEPTH: 0 or relevant depth All waiting related to formation evaluation. RIG UP/DOWN DEPTH: 0 Prepare and rig up/down snubbing and coil tubing equipment, including pressure testing. OTHER DEPTH: 0 or relevant depth All formation evaluation related operations that are not covered by one of the sub operations listed under main operation FORMATION EVALUATION. The amount of time consumed by this sub operation should be less then 1% of operation FORMATION EVALUATION sum total. 3.6.1.4 COMPLETION Legal sub operations for COMPLETION: BOP/WELLHEAD EQ DEPTH: 0 or sea floor WIRE LINE DEPTH: 0 or depth of wl tool CIRC/COND DEPTH: 0 or measured depth PERFORATE DEPTH: 0 or depth of tool/top perforations STIMULATE DEPTH: 0 or top of perforations FLOW DEPTH: Top of perforations SAND CONTROL DEPTH: 0 or top of perforations TEST SCSSSV DEPTH: Depth of safety valve COMPL STRING DEPTH: 0 or depth of tail pipe/tubing MILL DEPTH: Relevant depth + WAIT DEPTH: 0 or measured depth RIG UP/DOWN DEPTH: 0 + OTHER DEPTH: 0 or measured depth BOP/WELLHEAD EQ DEPTH: 0 or sea floor Time spent on running/installing/testing/removing/retrieving BOPs, risers, spools, wellhead plugs and valves, X-mas trees etc. Includes diving in sub sea completion's. Does not include equipment fitted to the X-mas tree or tieback riser for wire line (use sub operation 'WIRE LINE') or stimulation (use sub operation STIMULATE) purposes. WIRE LINE DEPTH: 0 or depth of wire line tool Covers time spent on rigging up/down and testing of wire line equipment (wl riser, wl BOP, lubricator etc.) plus the actual running/landing/testing/pulling of wire line tools. Includes log runs that are not adequately covered by sub operation LOG (cf. main operation FORMATION EVALUATION).

Petroleum Safety Authority (PSA) Page 23 of 63 CIRC/COND DEPTH: 0 or measured depth Use when mud or auxiliary high output pumps are being run to circulate/condition/displace drilling/completion/workover fluid. Also use for planned killing of well. PERFORATE DEPTH: 0 or depth of tool/top perfs Covers time spent on rigging up/down and testing of wire line equipment plus the actual running/firing/ pulling of perforating guns/detonating bar. Does not include initial flow/clean up of well (use sub operation FLOW). STIMULATE DEPTH: 0 or top of perforations Covers time spent on installation/testing/removal of equipment/surface lines for fracturing and/or acidizing purposes plus the actual carrying out of operations. Includes "mini-fracs" to determine formation/design parameters. Does not include initial flow/clean up of well (use sub operation FLOW). FLOW DEPTH: Top of perforations Covers initial flow/clean up/flow test/build up of well after perforating/stimulating/temporary artificial lift. SAND CONTROL DEPTH: Top of perforations Covers the various methods and placement techniques of sand control, e.g. gravel packing. TEST SCSSSV DEPTH: Depth of safety valve Use when tubing retrievable and/or wire line set surface controlled sub sea safety valves (SCSSSV's) are tested independently of the running procedure (cf. sub operation 'WIRE LINE'). COMPL STRING DEPTH: 0 or depth of tailpipe/tbg The making up/testing/running/landing/pulling of the completion string /tailpipe and/or production tubing. Includes setting and testing of production packer(s) run in conjunction with the string. MILL DEPTH: Relevant depth Time spent on milling operations. Includes all time spent to perpare and carry out the milling operations untill the operation has proven successful. WAIT DEPTH: 0 or relevant depth Waiting induced by/being part of completion operations. RIG UP/DOWN DEPTH: 0 Prepare and rig up/down snubbing and coil tubing equipment, including pressure testing. OTHER DEPTH: 0 or relevant depth Use for sub operations that are not adequately covered by the legal ones listed. Restricted use, please!

Petroleum Safety Authority (PSA) Page 24 of 63 3.6.1.5 WORKOVER Legal sub operations for WORKOVER: BOP/WELLHEAD EQ DEPTH: 0 or sea floor WIRE LINE DEPTH: 0 or depth of wl tool CIRC/COND DEPTH: 0 or measured depth PERFORATE DEPTH: 0 or depth of tool/top perforations STIMULATE DEPTH: 0 or top of perforations FLOW DEPTH: Top of perforations SAND CONTROL DEPTH: 0 or top of perforations TEST SCSSSV DEPTH: Depth of safety valve COMPL STRING DEPTH: 0 or depth of tail pipe/tubing MILL DEPTH: Relevant depth + WAIT DEPTH: 0 or measured depth RIG UP/DOWN DEPTH: 0 + OTHER DEPTH: 0 or measured depth BOP/WELLHEAD EQ DEPTH: 0 or sea floor Time spent on running/installing/testing/removing/retrieving BOPs, risers, spools, wellhead plugs and valves, X-mas trees etc. Includes diving in sub sea completion's. Does not include equipment fitted to the X-mas tree or tieback riser for wire line (use sub operation 'WIRE LINE') or stimulation (use sub operation STIMULATE) purposes. WIRE LINE DEPTH: 0 or depth of wire line tool Covers time spent on rigging up/down and testing of wire line equipment (wl riser, wl BOP, lubricator etc.) plus the actual running/landing/testing/pulling of wire line tools. Includes log runs that are not adequately covered by sub operation LOG (cf. main operation FORMATION EVALUATION). CIRC/COND DEPTH: 0 or measured depth Use when mud or auxiliary high output pumps are being run to circulate/condition/displace drilling/completion/workover fluid. Also use for planned killing of well. PERFORATE DEPTH: 0 or depth of tool/top perfs Covers time spent on rigging up/down and testing of wire line equipment plus the actual running/firing/ pulling of perforating guns/detonating bar. Does not include initial flow/clean up of well (use sub operation FLOW). STIMULATE DEPTH: 0 or top of perforations Covers time spent on installation/testing/removal of equipment/surface lines for fracturing and/or acidizing purposes plus the actual carrying out of operations. Includes "mini-fracs" to determine formation/design parameters. Does not include initial flow/clean up of well (use sub operation FLOW). FLOW DEPTH: Top of perforations Covers initial flow/clean up/flow test/build up of well after perforating/stimulating/temporary artificial lift. SAND CONTROL DEPTH: Top of perforations Covers the various methods and placement techniques of sand control, e.g. gravel packing. TEST SCSSSV DEPTH: Depth of safety valve Use when tubing retrievable and/or wire line set surface controlled sub sea safety valves (SCSSSV's) are tested independently of the running procedure (cf. sub operation 'WIRE LINE'). COMPL STRING DEPTH: 0 or depth of tailpipe/tbg The making up/testing/running/landing/pulling of the completion string /tailpipe and/or production tubing. Includes setting and testing of production packer(s) run in conjunction with the string. MILL DEPTH: Relevant depth Time spent on milling operations. Includes all time spent to perpare and carry out the milling operations untill the operation has proven successful. WAIT DEPTH: 0 or relevant depth Waiting induced by/being part of workover/recompletion operations.

Petroleum Safety Authority (PSA) Page 25 of 63 RIG UP/DOWN DEPTH: 0 Prepare and rig up/down snubbing and coil tubing equipment, including pressure testing. OTHER DEPTH: 0 or relevant depth Use for sub operations that are not adequately covered by the legal ones listed. Restricted use, please! 3.6.1.6 PLUG & ABANDON Legal sub operations for PLUG & ABANDON: TRIP DEPTH: Bit depth at end of period CIRC/COND DEPTH: 0 or relevant depth PERFORATE DEPTH: 0 or relevant depth CEMENT PLUG DEPTH: Top of plug MECHANICAL PLUG DEPTH: Top of plug SQUEEZE DEPTH: Perf. or relevant depth CUT DEPTH: 0 or relevant depth EQUIP RECOVERY DEPTH: 0 or relevant depth MILL DEPTH: Relevant depth + WAIT DEPTH: 0 or relevant depth RIG UP/DOWN DEPTH: 0 + OTHER DEPTH: 0 or relevant depth TRIP DEPTH: Bit depth at end of period Trip time in connection with conditioning of hole and mud prior to P&A. Includes also trip time associated with setting of plugs and squeezing, as well as trip time associated with running of cutting/recovery tools, and trips to locate the plugs. CIRC/COND DEPTH: 0 or relevant depth Time required to condition hole and mud prior to and during plugging and abandoning of well. PERFORATE DEPTH: 0 or relevant depth Time required to rig up/down and test the necessary wire line equipment and to perform the operation of perforating. CEMENT PLUG DEPTH: Top of plug Time used to pump cement and set abandonment plugs. Includes time to reverse out cement and to test the plugs. MECHANICAL PLUG DEPTH: Top of plug Time to run, set and test mechanical plugs. SQUEEZE DEPTH: Perf. or relevant depth Time to squeeze casing shoes and/or annulus areas. CUT DEPTH: 0 or relevant depth Time needed to cut the casings. EQUIP RECOVERY DEPTH: 0 or relevant depth Time needed to recover casing, tools, conductor housings, subsea wellheads, BOP, guide bases, etc. MILL DEPTH: Relevant depth Time spent on milling operations. Includes all time spent to perpare and carry out the milling operations untill the operation has proven successful. WAIT DEPTH: 0 or relevant depth Waiting on cement (WOC), and all other plug and abandoning related waiting. RIG UP/DOWN DEPTH: 0 Prepare and rig up/down snubbing and coil tubing equipment, including pressure testing.

Petroleum Safety Authority (PSA) Page 26 of 63 OTHER DEPTH: 0 or relevant depth All P&A related operations that are not specifically covered by one of the sub operations listed under main main operation PLUG & ABANDON. The amount of time consumed by this sub operation should be less then 1% of operation PLUG & ABANDON sum total. 3.6.1.7 INTERRUPTION Legal sub operations for INTERRUPTION: MAINTAIN DEPTH: 0 or relevant depth * REPAIR DEPTH: 0 or relevant depth * FISH DEPTH: Top of fish WELL CONTROL DEPTH: Bit depth LOST CIRC DEPTH: Bit depth SIDETRACK DEPTH: Kick off point MILL DEPTH: Relevant depth + WOW DEPTH: 0 or relevant depth * WAIT DEPTH: 0 or relevant depth RIG UP/DOWN DEPTH: 0 + OTHER DEPTH: 0 or relevant depth MAINTAIN DEPTH: 0 or relevant depth Includes all time spent on maintaining the drilling rig and its associated equipment, e.g. cutting and slipping of the drill line. Also includes all maintenance work in connection with casing and wellhead, drill string, completion string, formation evaluation equipment and surface/subsea BOP equipment. REPAIR DEPTH: 0 or relevant depth Time spent on repairing the drilling rig and its associated equipment, third party equipment also included. Also includes all repair work in connection with casing and wellhead, drill string, completion string, formation evaluation equipment and surface/subsea BOP equipment. FISH DEPTH: Top of fish All work resulting from an object falling in the hole, sticking of equipment which is run in the hole to drill, core, test, log, survey, case or cement. Includes trips, jarring, unscrewing, milling, wash over etc., until normal resumption of work or a decision is made to abandon the well. WELL CONTROL 3 DEPTH: Bit depth Total time spent to control and remove formation fluids which have entered the well bore, including circulating the formation fluids, changing mud weight to control the influx, mixing or conditioning drilling fluids, and hole conditioning required because of the fluid entry. Includes all trips required to regain control of the well, as well as all steps to terminate the well if required. LOST CIRC DEPTH: Bit depth All time spent to regain circulation. Includes mixing and spotting of plugs, trips, squeezes and waiting related to the lost circulation operation. SIDETRACK DEPTH: Kick off point Only technical sidetracks are to be reported under this sub operation. Includes all time spent to perpare and carry out sidetrack operation untill the kick off has proven successful. Then operations shall be reported under the main operation DRILLING. MILL DEPTH: Relevant depth Time spent on milling operations. Includes all time spent to perpare and carry out the milling operations untill the operation has proven successful. WOW DEPTH: 0 or relevant depth Waiting on weather (WOW) 3 Kick data shall also be reported separately. Ref 3.15 REPORT part XV - Kick

Petroleum Safety Authority (PSA) Page 27 of 63 WAIT DEPTH: 0 or relevant depth Time spent on all other waiting during INTERRUPTION operations. RIG UP/DOWN DEPTH: 0 Prepare and rig up/down snubbing and coil tubing equipment, including pressure testing. OTHER DEPTH: 0 or relevant depth All INTERRUPTION related operations that are not specifically covered by one of the sub operations listed under main operation INTERRUPTION. The amount of time consumed by this sub operation should be less then 1% of operation INTERRUPTION sum total. 3.6.2 Legal values for sub modes Legal sub modes: INJURY NUMBER I O FAIL NUMBER II Operation failed KICK NUMBER III C LOSS NUMBER IV Circ lost to formation M LOSS NUMBER V Circ lost due to plugging etc. STUCK NUMBER VI E FAIL NUMBER VII Equipment failed HANG NUMBER VIII OK NUMBER IX INJURY NUMBER I Personnel injury in connection with drilling and/or drilling related operations. O FAIL NUMBER II Operation failed to achieve objective. KICK 4 NUMBER III Formation fluid invading the well bore. C LOSS NUMBER IV Circulation lost to the formation. M LOSS NUMBER V Circulation impossible due to plugging or failure of equipment. STUCK NUMBER VI Equipment got stuck in the hole. E FAIL NUMBER VII Equipment failure occurred. HANG NUMBER VIII Operations had to be aborted due to a hang off operation. OK NUMBER IX Operation achieved objective. 4 Kick data shall also be reported separately. Ref 3.15 REPORT part XV - Kick