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Home My WebLink About207-158 9 ECEl Mw STATE OF ALASKA ' AL :A OIL AND GAS CONSERVATION CON. JSION iUl. 1 5 2015 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing 17- ACAGEGCShutdow n I-- Performed Performed Suspend r Perforate r Other Stimulate r Alter Casing iii, Change Apprc�v�cl Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: s r,K f/ ie 2.Operator Name 4.Well Class Before Work 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1 Exploratory r 207-158 3.Address 6.API Number P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 1'" 50-029-21837-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513,25512 KRU 30-02A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11 Present Well Condition Summary: Total Depth measured 13181 feet Plugs(measured) 9928 true vertical 6545 feet Junk(measured) none Effective Depth measured 13181 feet Packer(measured) 6207, 9812, 9891 true vertical 6545 feet (true vertical) 4163,6369,6421 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 5896 9.625 5931 4002' PRODUCTION 10359 7 10392 6571 LINER A BOTTON 2008 2 375 11173 6592 SCANNEV Perforation depth. Measured depth 10347-11169, 11182-12100, 12134-13147 True Vertical Depth. 6571-6592,6592-6575,6575-6547 Tubing(size,grade,MD,and TVD) 3.5", L-80, 9886' MD/6420'TVD and 3.5", J-55, 9963' MD/6468'TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 6207 MD and 4163 TVD PACKER-BAKER FHL PACKER @ 9812 MD and 6369 ND PACKER-AVA RHS PACKER @ 9891 MD and 6421 ND NO SSSV 12.Stimulation or cement squeeze summary. Intervals treated(measured): no stimulation or cement squeeze summary Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work Daily Report of Well Operations 17 Exploratory r Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WWJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 315-334 Contact Diana Guzman @ 265-6318 Email Diana.Guzman@conocophillips.com Printed Name Diana Guzman Title Sr. Wells Engineer Signature Phone 265-6318 Date ?Takt...3C— J 1 V11 11-1( LO, VTL q/3/i5— Form 10-404 Revised 5/2015 i 7 ' Submit E final Only RBDMS.J 1 JUL 1 7 2015 KUP PROD 30-02A COt1QCOPi1illiP S o_ Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/OWl Field Name Wellbore Status II ncl 7) MD(ftKB) Act Bce(ftKB) 0„,., yM,, 500292183701 KUPARUK RIVER UNIT PROD 95.77 12,933.69 13,181.0 .-- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig ReleaDate 30-02A,7/132015 11;46:42 AM SSSV:TRDP 150 12/19/2013 Last WO: 6/8/2015 34.981se 8/30/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..... • HANGER;33.0 4 °7 ----Last Tag:SLM 1,544.0 6/28/2015 Rev Reason:WORKOVER,TAG,GLV C/O, smsmith 7/9/2015 PULL PLUG/CATCHER/BALL&ROD w u lCasing Strings•� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread I _ CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread a...SURFACE 9 5/8 8.921 35.0 5,930.5 4,002.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULan(I...Grade Top Thread PRODUCTION 7 6.276 33.0 10,392.0 6,571.3 26.00 J-55 BUTT CONDUCTOR;36.0-115.0 a Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(L..Grade Tap Thread LINER ATOP 23/8 1.992 10,331.8 11,172.6 6,591.8 4.44 L-80 STL (off AL2-01) Liner Details GAS LIFT;3.428.7 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 10,331.8 Casing Description 6,571.7 91.04 DEPLOY ALUMINUM DEPLOYMENT SLEEVE 1.000 OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread GAS LIFT:5,284.4 LINER A BOTTOM I 23/81 1.992 11,172.61 13,181.01 6,545.41 4.441 L-80 I STL I Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 11,172.6 6,591.8 89.17 DEPLOY BTT DEPLOYMENT SLEEVE 1.000 0.500 SURFACE;35.0-5,930.5--• . 12,099.9 6,574.8 89.79 0-RING BTT 0-RING SUB 12,133.5 6,575.1 89.57 DEPLOY BTT DEPLOYMENT SLEEVE 2.250 GAS LIFT:6,101.0 a' 13,147.3 6,546.5 91.90 0-RING BTT 0-RING SUB 1.000 Tubing Strings Tubing Description I String Ma...l ID(in) !Top(ftKB) I Set Depth(ft..1Set Depth(TVD))...IWt(lb/ft) (Grade (Top Connection TUBING-WO 2015- 31/2 2.992 33.0 6,183.81 4,149.3 9.30 L-80 EUE 8rd UPPER 3 1/2" LOCATOR;6,157.7 Completion Details SETTING SLEEVE:6,155.5 Nominal ID SEAL ASSY;6,158.9 mw Top(ftKB) Top(TVD)(1 d.(6) Top 1051 7) Item Des Com (In) 33.0 33.0 0.00'HANGER CAMERON CXS TUBING HANGER 2.992 aw 6,157.7 4,134.2 54.50 LOCATOR BAKER GBH-22 LOCATOR 2.992 DBE;8,172.9al 6 la 6,158.9 4,134.8 54.50 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 2.990 KC Tubing Description String Ma...ID(in) Top(ftKB) -Set Set Depth( et Depth(ft.. (TVD)(...Wt(lb/ft) Grade Top Connection Ali TUBING-WO 2015-ISOLATION PACKER 1 31/2! 2.9921 6,155.5 9,807.31 6,365.91 9.301 L-B0 !Top PACKER;6207.0 Completion Details LOCATOR;9,784.6 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (In) 6,155.5 4,132.9 54.50 SETTING BAKER HRD-E LINER SETTING SLEEVE 5250 SLEEVE 6,172.9 4,143.0 54.50 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 SEAL ASSY;9,785.6, PBR;9,788.8 6,207.0 4,162.8 54.52 PACKER BAKER 598-287 PREMIER PACKER 2.870 9,784.6 6,351.1 49.39 LOCATOR BAKER GBH-22 LOCATOR 2.990 PACKER;9,811.7 9,785.6 6,351.7 49.38 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY 2.990 Tubing Description 1String Ma...1 ID(in) !Top(ftKB) I Set Depth(ft..1Set Depth(TVD)(...1 Wt(Ib/ft) (Grade (Top Connection - TUBING-WO 2015- 31/2 2.992 9,788.6 9,885.7 6,417.1 9.30 L-80 8rd NIPPLE;9,865.1 STACKER PACKER Completion Details r Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) Tail Pipe;8,877.1 9,788.6 6,353.7 49.37 PBR BAKER 80-40 PBR 4.000 PBR;9,878.0 9,811.7 6,368.8 49.29 PACKER BAKER 47B2 FHL RETRIEVABLE PACKER 2.930 MULE SHOE:9.885.1 9,865.1 6,403.6 49.16 NIPPLE CAMCO DS NIPPLE 2.812 PACKER;9,891.1- 9,876.6 6,411.2 49.13 LOCATOR LOCATOR 2.992 9,877.1' 6,411.5 49.13 Tail Pipe Mule Shoe Pup Joint 2.992 NIPPLE;9,928.4 - 9,885.1 6,416.7 49.11.MULE SHOE MULE SHOE 2.992 ' Tubing Description 'String Ma...103(in) 'Top(ftKB) 'Set Depth(ft..I Set Depth(TVD)I...IWt(Ib/fl) 'Grade 'Top Connection ` - , TUBING-ORIGINAL 31/2 2.992 9,878.0 9,963.21 6,4683 9.30 J-55 EUEBrdABMOD Completion Details SOS;9,962.4L71 I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (In) 9,676.0 6,412.1 49.12 PBR AVA PBR 3.000 9,691.1 6,420.7 49.09 PACKER AVA RHS PACKER 3.000 LINER Al2-01;9,939.9-11,471.0 9,928.4 6,445.2' 48.62 NIPPLE CAMCO D NIPPLE NO GO 2.750 WINDOW;70,060.0-10,065.0 4 9,9624 6,467.8 48.09 SOS BAKER#3500 SHEAR OUT SUB 2.992 Perforations&Slots Shot Dens Top(TVD) Mei(TVD) (shots/! _... -_ Top(ftKB) Btm(ftKB) (ftKB) (BKB) Zone Date t) Type Com __ 10,347.0 11,169.0 6,571.4 6,591.7 A-1,30-02A 3/15/2008 32.0 SLOTS Slotted Tubing _.�., 11,182.0 12,100.0 6,591.9 6,574.8 A-1,30.02A 3/10/2008 32.0 SLOTS Slotted Tubing PRODUCTION;33.0-10,392.0-. 12,134.0 13,147.0 6,575.1 6,546.5 A-1,30-02A 3/10/2008 32.0 SLOTS Slotted Tubing SLOTS;10,347.0-11,169.0- _.....1 i. - Mandrel Inserts LINER ATOP (oft] St AL2-01);10,331.8-11,172.8ati SLOTS;71,782.0-72,700.0N TeTop(TVD) Valve Latch Port Size TRO Run Top(8KB) (ftKB) Make Model OD(in) Sen/ Type Type (in) (psi) Run Date Corn 1 3,428.8 2,496.9 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,288.0 6/15/2015 SN: 259A GO1 2 5,284.4 3,617.7 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,285.0 6/27/2015 SN: 253A GO1 SLOTS;72,734.0-13,747.0 LINER A BOTTOM:11,172.8- 13,181.0 KUP PROD 30-02A ConocoPhillips OF 1 Alaska,Inc. Osnocc.PhIllps 30-02A,7/13/2015 11:46:44 AM vertical schematic(actual) Annotation Last Mod By End Date -- - - Rev Reason:SIDETRACKED 4/1/2008 smsmith 7/9/2015 HANGER,33.0 117 Mandrel Inserts I • : 5- ali J en Top(TVD( Valve Latch Port Siae TRO Run f N Top(MB) (i9KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com S 6,101.0 4,101.2 CAMCO MMG 1 1/2 GAS LIFT OV RKP 0.250 0.0 6/27/2015 SN: 103A CONDUCTOR;36.0-115.0 G01 Notes:General&Safety End Date Annotation 4/13/2008 NOTE:MULTI-LATERAL WELL 30-02A,AL1,AL2,AL2-01 GAS LIFT;3,428.7 1 1/18/2011 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;5,284.4 SURFACE;35.0-5,930.5-4 GAS LIFT;6,101.0 LOCATOR;6,157.7 SETTING SLEEVE;6,155.5 SEAL ASSY;6,158.9 1 g SBE;6,172.9 emmi .30 ai L PACKER;6,207.0 U LOCATOR;9,784.6 SEAL ASSY;9,785.6, MEW PBR;9,788.6 .11Mr_ PACKER;9,811.7 - - NIPPLE;9,865.1 I. a Tail Pipe,9,877.1, ((� PBR;9,878.0 1(i 1 MULE SHOE;9,885.1 PACKER;9,891.1 a In NIPPLE;9,928.4 97. 1 SOS;9,962.4 4 - LINER AL2-01;9,939,9-11,471.0 WINDOW;10,060.0-10,065.0 PRODUCTION;33.0-10,392.0-. SLOTS;10,347.0-11,169.0 ,4!L LINER ATOP (of AL2-01);10,331.8-11,172.6 SLOTS;11,182.0-12,100.0 ri SLOTS;12,134.0-13,147.0 - y. IJ T i LINER A BOTTOM;11,172.6- ii 13,181.0 30-02A PRE-RIG WELL WORK DATE SUMMARY 3/13/2015 (PRE-RWO) FUNCTION LDS ALL OK, T POT PASSED, T PPPOT PASSED, IC POT PASSED, IC PPPOT PASSED 3/14/2015 (PRE-RWO) : MIT-OA PASSED TO 1800 PSI. 4/17/2015 MADE 2 ATTEMPTS TO PULL ST#1 @ 9836' RKB. UNSUCCESSFUL. COULD NOT KOT TO LOCATE. PULLING TOOL HAD HEAVY SCALE. PULLED 1" BK-GLV'S FROM ST#3 @ 7846' RKB & ST#1 @ 3508' RKB. 4/18/2015 ATEMPTED SETTING 1" BK-DGLV IN ST# 1 @ 3508' RKB. UNABLE TO SET DOWN W/ KOT. SET 1" DGLV'S W/BTM INTERGAL LATCH IN ST# 1 @ 3508' RKB &ST#3 @ 7846' RKB. 4/19/2015 RAN TBG PUNCH. 1.56" PUNCHER INTERVAL=9830'-9834' RKB LDFN DUE TO 35+ MPH WINDS. 4/20/2015 RAN STRING SHOT, SHOOTING 8' INTERVAL-9856'-9864' RKB. RAN 2.62" CHEM CUTTER. CUT TBG @ 9860' RKB. 5/4/2015 ATTEMPT CLOSURE TEST ON TRSSSV FAILED; UNABLE TO SEE FLOW TUBE MOVEMENT; WITH CONTROL LINE PRESSURE @ ZERO, ABLE TO DRIFT THRU TRSSSV CLEANLY. READY (FLOW TUBE SEIZED). READY FOR CIRC OUT(PRE RIG). 5/11/2015 Circ-out well, 260 bbls S/W,100 bbls dsl, down tbg up IA, u-tubed,job complete Conoco hillips Time Log & Summary Wellview Web Reporting Report Well Name: 30-02 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 6/9/2015 4:00:00 PM Rig Release: 6/16/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/08/2015 24 hr Summary Lower the derrick. Pull the pits away from the sub. Pull the sub off 1C-178. Move the pits from 1C pad to 30 pad. Move the sub from 1C pad to 30 access road. 00:01 03:01 3.00 0 0 MIRU MOVE MOB P Move auxiliary equipment from 1C pad to 30;Taylor camp,welding shop, and electrical shop. Continue prepping pits and sub base for rig move. raise pit module and remove mats from beneath. 03:01 04:31 1.50 0 0 MIRU MOVE MOB P PJSM. Lower the derrick. Connect sow to pits and pull away. 04:31 06:01 1.50 0 0 MIRU MOVE MOB P Raise sub base. Remove mats from beneath. Back off 1C-178 06:01 09:01 3.00 0 0 MIRU MOVE MOB P Move pit module from 1C to 30 access road. 09:01 17:01 8.00 0 0 MIRU MOVE MOB P Move sub base from 1C pad to 10 pad 17:01 19:01 2.00 0 0 MIRU MOVE MOB P Wait on field wide change out. 19:01 00:01 5.00 0 0 MIRU MOVE MOB P Move sub base from 1Q pad to 30 access road. 36/09/2015 Move sub from 30 access road entrance to 30 pad and spot rig over 30-02A. Raise the derrick, spot the pits to the sub, and RU. Rig accepted at 16:00 hours. Load the pits with seawater and RU to kill the well. Pull the BPV and PT lines to the kill tank. 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Shuffle rig mats and mat entire 30 access road to 30 pad. 05:00 06:00 1.00 0 0 MIRU MOVE MOB P Move the sub from 30 access road entrance to 30 pad. Spot herculite for the sub and hang the tree in the cellar. 06:00 09:00 3.00 0 0 MIRU MOVE MOB P Spot the sub over 30-02A 09:00 09:30 0.50 0 0 MIRU MOVE RURD P Spot herculite for the pits. Spot the pits to the sub. Berm around the sub and the pits. 09:30 12:00 2.50 0 0 MIRU MOVE RURD P PJSM. Inspect the derrick prior to raising, raise the derrick, and pin the derrick. 12:00 16:00 4.00 0 0 MIRU MOVE RURD P Finish berming around the rig. Spot the LEPD tank and berm. Pin the cattle chute. RU the rig floor. Bridle down and pin the blocks. MU stand pipe, Kelly hose, and inner connect. Plug in electrical. 16:00 17:30 1.50 0 0 MIRU WELCTI RURD P Accept the rig at 16:00 hours. RU to kill the well. Page 1 0112 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:30 1.00 0 0 MIRU WELCTI SFTY P Hold pre-spud meeting with rig crew. Discuss up coming operations and hazards. 18:30 20:45 2.25 0 0 MIRU WELCTI RURD P Load the pits with seawater(8.36 ppg off the truck). SimOps: Continue to RU in the cellar for the well kill operation. Blow down lines to the kill tank. IA=490 psi and OA=360 psi. Bleed the OA to 0 psi to the bleed trailer. 20:45 22:00 1.25 0 0 MIRU WELCTI.MPSP P RU lubricator and PT to 1000 psi. Pull BPV(tubing=300 psi). RD lubricator 22:00 23:00 1.00 0 0 MIRU WELCTI.SEQP P Fill the line to the tiger tank and PT to 1500 psi. PT mud manifold and interconnect to 3500 psi. 23:00 00:00 1.00 0 0 MIRU WELCTI KLWL P Bleed the tubing and IA to 0 psi. 06/10/2015 Reverse circulate 387 bbls 8.36 ppg seawater at 4 BPM out to the kill tank. Observe the well for flow;tubing= 15 psi and IA= 10 psi, Reverse circulate 109 bbls 8.36 ppg seawater at 4 BPM out to the kill tank. Observe the well for flow; IA still flowing slightly. Circulate 520 bbls of 8.36 ppg seawater at 2 BPM to the pits through the gas buster. Observe the well for flow;tubing=0 psi and IA= 10 psi.Weight the active pit system up to 8.5 ppg seawater. Circulate 376 bbls of 8.5 ppg seawater at 2 BPM to the pits through the gas buster(lost 10 bbls). Observe the well for flow;tubing=4 psi and IA= 10 psi. Weight up the active pit system to 8.7 ppg. Circulate 397 bbls of 8.5 ppg seawater at 2 BPM to the pits through the gas buster(lost 3 bbls). Observe the well for flow;tubing on a slight vac and the IA slightly flowing. 00:00 00:30 0.50 0 0 MIRU WELCTI RURD P Verify line up for the well kill operation. 00:30 02:30 2.00 0 0 MIRU WELCTI KLWL P SITP=28 psi and SICP= 10 psi. Reverse circulate 387 bbls 8.36 ppg seawater at 4 BPM out to the kill tank while holding 80 psi back pressure. Shut down to empty the kill tank. 02:30 03:30 1.00 0 0 MIRU WELCTI.KLWL P Empty the kill tank while monitoring the well. Stabilized pressure IA= 140 psi,tubing=220. Bleed the tubing and IA to 0 psi. 03:30 04:00 0.50 0 0 MIRU WELCTI.RURD T Bring on 290 bbls of seawater into the pits. 04:00 05:00 1.00 0 0 MIRU WELCTI.KLWL T Tubing pressure increased to 15 psi and the IA increased to 10 psi. Reverse circulate 109 bbls at 3 BPM. 05:00 06:00 1.00 0 0 MIRU WELCTI OWFF T Observe the well for flow. IA still flowing slightly. SimOps: Blow down choke manifold and squeeze manifold to the kill tank. 06:00 06:15 0.25 0 0 MIRU WELCTI.RURD T RU to circulate down the tubing and taking returns out the IA through the gas buster to the pits. 06:15 09:15 3.00 0 0 MIRU WELCTI.KLWL T Circulate 520 bbls of 8.36 ppg seawater at 2 BPM= 150 psi on the tubing. Page 2 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 09:30 0.25 0 0 MIRU WELCTL OWFF T Shut down and observe the well for flow. IA still has 10 psi and the tubing 0 psi. 09:30 12:00 2.50 0 0 MIRU WELCTL COND T Weight the active pit system up to 8.5 ppg seawater. 12:00 13:15 1.25 0 0 MIRU WELCTL KLWL T Circulate 8.5 ppg seawater down the tubing taking returns out the IA through gas buster to the pits at 2 BPM= 140 psi on the tubing. 13:15 14:15 1.00 0 0 MIRU WELCTL COND T Fluid weight in the pits fell below 8.5 ppg. Shut down and bring the weight back to 8.5 ppg. SITP=50 psi and SICP=40 psi. 14:15 16:00 1.75 0 0 MIRU WELCTL KLWL T Circulate 8.5 ppg seawater down the tubing taking returns out the IA through gas buster to the pits at 2 BPM = 140 psi on the tubing. FCP = 160 psi. Pumped a total of 376 _ bbls and lost 10 bbls. 16:00 17:30 1.50 0 0 MIRU WELCTL OWFF T Shut down and observe the well for flow. The tubing on a slight vac and the IA slightly flowing. Shut the well: tubing=4 psi, IA= 10 psi, and OA= 20 psi. 17:30 20:00 2.50 0 0 MIRU WELCTL COND T Weight up the active pit system from 8.5 ppg to 8.7 ppg. SimOps: Continue to load the pipe shed with 3-1/2"tubing and monitoring the IA and tubing pressures. 20:00 23:45 3.75 0 0 MIRU WELCTL KLWL T Circulate 8.7 ppg seawater down the tubing taking returns out the IA through gas buster to the pits at 2 BPM= 160 psi on the tubing. FCP =200 psi. Pumped a total of 397 bbls and lost 3 bbls. 23:45 00:00 0.25 0 0 MIRU WELCTL OWFF T Shut down and observe the well for flow. The tubing on a slight vac and the IA slightly flowing. 06/11/2015 Circulate additional 75 bbls of 8.7 ppg seawater. Tubing and IA at 0 psi; open up the tubing and IA and both are static. Install BPV, ND tree, install test dart in to BPV, NU DSA, and NU BOPE. Conducted initial BOPE test to 250/3500 psi: test 2-7/8"x 5"VBR's(lower pipe rams)and 3-1/2"x 6"VBR's(upper pipe rams) with 3-1/2"and 4"test joints;test annular to 250/3500 with 3-1/2"and 4"test joints; conducted CPAI Koomey Draw Down Test. All tested passed. The States right to witness was verbally waived by AOGCC inspector Johnnie Hill on 6/9/15 at 17:30 hours. Conduct Hazard Hunt with crew and all third party personnel. Pull test dart/BPV. BOLDS, pull tubing free at 140K, and pull hanger to the rig floor. POOH laying down 3-1/2"tubing, spooling control line, and removing stainless steel bands. Recovered 31 stainless steel bands(28 stainless steel bands listed on the tally from 1988). 00:00 00:30 0.50 0 0 MIRU WELCTL OWFF T Shut the well and observe the well: tubing=6 psi, IA=6psi, and OA=0 psi. SimOps: Crew change. Page 3 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:15 0.75 0 0 MIRU WELCTL KLWL T Circulate 8.7 ppg seawater down the tubing taking returns out the IA through gas buster to the pits at 2 BPM= 160 psi on the tubing. FCP = 160 psi. Pumped a total of 75 bbls and lost 0 bbls. 01:15 02:00 0.75 0 0 MIRU WELCTL OWFF P Observe the well for flow for 30 minutes. Shut in pressures-Tubing =0 psi, IA=0 psi, and OA=0 psi. Open up the tubing and IA to check for flow and the well is static. 02:00 02:30 0.50 0 0 MIRU WELCTL RURD P Blow down all circulation line and choke manifold. RD circulating equipment. 02:30 03:00 0.50 0 0 MIRU WHDBO SFTY P PJSM for installing BPV and ND of tree. SimOps: Start loading the pipe shed with 4"DP. 03:00 03:15 0.25 0 0 MIRU WHDBO MPSP P Install'HP' BPV per Cameron rep. SimOps: Weight up the 8.5 ppg return fluid to 8.7 ppg. 03:15 04:30 1.25 0 0 MIRU WHDBO NUND P Bleed pressure off the control line and tubing head void. ND the tree, pull tree loose with TD, and set down in the cellar with the bridge crane. Clean and prep wellhead; install test dart into BPV. 04:30 07:30 3.00 0 0 MIRU WHDBO NUND P NU DSA. NU BOPE, obtain RKB's, install riser, and install turnbuckles. 07:30 08:00 0.50 0 0 MIRU WHDBO OTHR P Install mouse hole and charge up the Koomey unit. Clean and clear the floor. 08:00 09:00 1.00 0 0 MIRU WHDBO RURD P RU BOPE testing equipment. PU 3-1/2"doughnut test joint, MU crossover, and 5'in to bottom rams. 09:00 09:30 0.50 0 0 MIRU WHDBO OTHR T Breakout crossover and lay down doughnut test joint. PU 3-1/2"test joint, MU crossover, and 5' in to bottom rams. MU to hanger lift threads and MU TIW with Dart valve. 09:30 10:30 1.00 0 0 MIRU WHDBO RURD P Fill the BOPE and choke manifold with fresh water. Shell test the BOPE to 3500 psi. Page 4 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 16:30 6.00 0 0 MIRU WHDBO BOPE P Conduct initial BOPE test to 250/3500 psi: test 2-7/8"x 5"VBR's (lower pipe rams)and 3-1/2"x 6" VBR's(upper pipe rams)with 3-1/2" and 4"test joint;test annular to 250/3500 with 3-1/2"and 4"test joints. The States right to witness was verbally waived by AOGCC inspector Johnnie Hill on 6/9/15 at 17:30 hours. Tests: #1)Annular with 3-1/2"test joint, 3-1/2" EUE TIW, Chokes 1,2, 3,& 16(Passed) #2)Upper Pipe rams with 3-1/2"test joint, HCR Kill, Chokes 4, 5, &6 (Passed) #3)Lower Pipe rams with 3-1/2"test joint(Passed) #4)Manual Kill, Blind rams, Chokes 7, 8, &9(Passed) #5)Manual Choke, Hydraulic Choke (Passed) #6)Chokes 10& 11 (Passed) #7)Annular with 4"test joint, Dart valve, Chokes 12, 13, & 14(Passed) #8)4"TIW, Upper Pipe rams with 4" test joint, Choke 15(Passed) #9)Top Drive Upper IBOP, HCR Choke(Passed) #10)Top Drive Lower IBOP, Manual Choke(Passed) #11) Lower Pipe rams with 4"test joint(Passed) #12)Outer Test Spool(Passed) #13)Inner Test Spool(Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure= 2950 psi Accumulator Pressure After Closer= 1800 psi Pressure Gain of 200 psi=28 seconds Full System= 128 Seconds Average N2(6 Bottles)=2008 psi 16:30 17:30 1.00 0 0 MIRU WHDBO RURD P Breakout crossovers, lay down 4" test joint, blow down lines, and RD BOPE testing equipment. 17:30 18:30 1.00 0 0 MIRU WHDBO SFTY P Conduct hazard hunt on the rig and pad with crew and all third party hands. Review,document, and addressing findings of the hazard hunt. Page 5 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:15 0.75 0 0 MIRU WHDBOOTHR P PJSM. RUWeatherfordtubing pulling equipment. Change elevators from 4"DP to 3-1/2"tubing. RU SLB control line spooler. 19:15 19:30 0.25 0 0 MIRU WHDBO MPSP P Drain the stack. Check for pressure under BPV, no pressure, and pull test dart/BPV(well static). 19:30 21:00 1.50 0 9,860 COMPZ RPCOM PULL P PJSM. BOLDS, pull tubing free at 140K, pull hanger to the rig floor(PU = 110K, SO=70K), break out crossover, break out 3-1/2" EUE TIW, unscrew landing joint, lay down landing joint, and lay down tubing hanger. Note: CTD wore a groove through the BPV threads on one side(picture in the folder). 21:00 00:00 3.00 9,860 8,056 COMPZ RPCOM PULL P POOH laying down 3-1/2"tubing, spooling control line, and removing stainless steel bands. Strapping and unloading the pipe shed as needed and monitoring the well on the trip tank. Lay down SCSSSV. Recovered 31 stainless steel bands (28 stainless steel bands listed on the tally from 1988). 06/12/2015 Continue POOH laying down 3-1/2"tubing to 2508'. MU, RIH, set storm packer 18'below the casing flange, and PT to 1500 psi. ND the BOP and rack back on stump. ND DSA and remove IA valve from the tubing head. RU Hydratight, ND tubing head(the casing did not grow), RD Hydratight, and remove the tubing head. Pull the pack-off and install new pack-off per. NU new tubing head, DSA, BOPE, and shell test BOPE/flange connections to 250/3500 psi. RIH with storm packer retrieving tool, open equalizing valve, release storm packer, and lay down the storm packer. 00:00 00:15 0.25 8,056 8,056 COMPZ RPCOM SFTY P Crew change. PJSM to RD SLB spooling unit and for POOH laying down 3-1/2"tubing. 00:15 00:45 0.50 8,056 8,056 COMPZ RPCOM RURD P RD SLB control line spooler. 00:45 05:45 5.00 8,056 3,992 COMPZ RPCOM PULL P POOH laying down 167 jts of 3-1/2" tubing and removing GLM's to 3992-ft. Strapping and unloading the pipe shed as needed and monitoring the well on the trip tank. 05:45 06:15 0.50 3,992 3,992 COMPZ RPCOM OTHR P Secure well for lunch break 06:15 06:30 0.25 3,992 3,992 COMPZ RPCOM SFTY P Deliver Nabors Global Safety week T shirts to crew prior to crew shift change. 06:30 09:00 2.50 3,992 2,508 COMPZ RPCOM PULL P Continue to POOH laying down from 3992'for another 34 joints of 3-1/2" tubing and removing GLM's to 2508'. (Leaving 76.5 joints in the hole) Strapping and unloading the pipe shed as needed and monitoring the well on the trip tank. Page 6 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:45 0.75 2,508 2,508 COMPZ WELLPF BHAH P Change elevator from 3-1/2"tubing to 4"DP. PU storm packer, MU crossover from 3-1/2"IF to 3-1/2" EUE 8rd, and MU crossover from 4" HT-40 to 3-1/2"IF. 09:45 10:30 0.75 2,508 0 COMPZ WELLPF MPSP P RIH and set the storm packer 18' (center of element)below the casing flange. PT to 1500 psi for 10 minutes(good test). Lay down joint of DP. 10:30 11:15 0.75 0 0 COMPZ WELLPF OWFF P Pump out the stack. OA pressure is at 0 psi. Open up the OA and monitor to verify OA is static. 11:15 12:00 0.75 0 0 COMPZ WELLPF RURD P Lay down mouse hole and pull the riser. 12:00 13:00 1.00 0 0 COMPZ WELLPF NUND P ND the BOP and rack back on stump. ND DSA and remove IA valve from the tubing head. 13:00 15:00 2.00 0 0 COMPZ WELLPF NUND P RU Hydratight, ND tubing head(the casing did not grow), RD Hydratight, and remove the tubing head. Pull the pack-off, clean up casing flange, and install new pack-off per Cameron rep. 15:00 17:00 2.00 0 0 COMPZ WELLPF NUND P PJSM. NU new tubing head and PT void to 250/5000 psi for 5 minutes each. 17:00 20:00 3.00 0 0 COMPZ WELLPF NUND P PJSM. NU DSA, NU BOPE, break 13-5/8"adapter flange, change out API ring, and tighten all nuts on the BOPE. 20:00 21:00 1.00 0 COMPZ WELLPF BOPE P PJSM. Set test plug. Fill the BOP stack with fresh water. 21:00 21:30 0.50 0 0 COMPZ WELLPF BOPE T Shell test the BOP and flange connections to 250 psi for 5 minutes (good test). Bring the pressure up to 3500 psi and the door seal on the lower rams leaked. 21:30 22:00 0.50 0 0 COMPZ WELLPF BOPE T Tighten up the door on the lower pipe rams. 22:00 22:30 0.50 0 0 COMPZ WELLPF BOPE P Shell test the BOP and flange connections to 250/3500 psi(good test). 22:30 22:45 0.25 0 0 COMPZ WELLPF BOPE P Empty the stack, blow down lines and pull test plug. 22:45 23:00 0.25 0 0 COMPZ WELLPF BHAH P PU and MU storm packer retrieving tool,joint of DP,4"TIW, and DP pup. 23:00 23:30 0.50 0 0 COMPZ WELLPF MPSP P Engage retrieving tool, open up equalizing valve, verify no pressure on the DP, close the annular, release the storm packer,verify no pressure under storm packer, and open the Annular. 23:30 00:00 0.50 0 2,508 COMPZ WELLPF BHAH P Break out TIW and DP pup. Lay down joint of DP, storm packer retrieving tool, and storm packer. Page 7 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/13/2015 24hrsummary POOH laying down remaining 2500'of 3-1/2"tubing and GLM's. Recovered the seal assembly; SLB chemical cut failed to cut the pipe(cut—75%). PU and MU mule shoe joint, nipple assembly, FHL packer assembly with PBR, and test packer assembly. Single in the hole with stacked packer completion with test packer on DP to 9851' RKB. 00:00 00:15 0.25 2,508 2,508 COMPZ RPCOM RURD P RU Weather tubing pulling equipment. Change elevators from 4"DP to 3-1/2"tubing. 00:15 00:30 0.25 2,508 2,508 COMPZ RPCOM SFTY P PJSM on laying down 3-1/2"tubing. 00:30 05:00 4.50 2,508 0 COMPZ RPCOM PULL P POOH laying down remaining 3-1/2" tubing removing GLM's. Recovered the seal assembly; SLB chemical cut failed to cut the pipe(cut—75%). Lay down cut joint and seal assembly 05:00 07:00 2.00 0 0 COMPZ RPCOM RURD P Clean and clear the floor. Set Weatherford equipment off to the side. Load pipe shed with packer assembly, nipple assembly, mule shoe join, and 1 joint of 3-1/2"tubing. Finalize new tally and verify numbers. 07:00 07:30 0.50 0 0 COMPZ RPCOM RURD P PU 1 joint of DP, MU crossover, MU wear ring running tool, and install wear ring. 07:30 09:30 2.00 0 114 COMPZ RPCOM PUTB P PU and MU mule shoe joint, nipple assembly, FHL packer assembly with PBR, and test packer assembly. 09:30 09:45 0.25 114 114 COMPZ RPCOM RURD P Install stripping rubbers and change elevator from 3-1/2"tubing to 4" DP. 09:45 11:45 2.00 114 1,605 COMPZ RPCOM RCST P Single in the hole with stacked packer completion on DP to 1605' RKB(PU =50K, SO=50K). 11:45 13:30 1.75 1,605 1,605 COMPZ RPCOM RURD P Load the pipe shed with remaining joints of DP. Strap and tally DP. 13:30 23:45 10.25 1,605 9,851 COMPZ RPCOM RCST P Continue to single in the hole with stacked packer completion on DP _ from 1605'to 9851 RKB. 23:45 00:00 0.25 9,851 9,851 COMPZ RPCOM CIRC P Circulate to fill DP and establish returns. 06/14/2015 Locate existing PBR and spot 20 bbl 8.7 ppg corrosion inhibited pill followed by 94 bbls of 8.7 ppg seawater. Drop ball&rod with roller stem. Set FHL packer per Baker rep: Pressure up on the DP to 2500 psi(initial shear at 1800 psi)hold for 5 minutes. Bring the pressure up to 3000 psi and hold for 5 minutes. Bleed the tubing pressure to 0 psi. FHL packer set at 9811'ORKB. Pressure up to 1500 psi and pull 20K over to shear PBR. Set test packer and pressure up down the DP to 1500 psi for 10 minutes to test the FHL packer from above(good test). Release test packer, POOH laying down 113 joints of DP to 6281' RKB,set test packer per Baker rep, and PT 7"casing to 3000 psi for 10 minutes(good test). Release test packer and TOOH standing back DP. PU and MU seal assembly, 113 joints of 3-1/2"tubing and Premier isolation packer assembly. TIH, locate top of new PBR, and spot 132 bbls of 8.7 ppg corrosion inhibited seawater followed by 65 bbls of 8.7 ppg seawater. 00:00 00:15 0.25 9,851 9,851 COMPZ RPCOM SEQP P PJSM. PT Kelly hose to 3500 psi (good test). Page 8 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:15 01:30 1.25 9,851 9,872 COMPZ RPCOM RCST P RIH to 9872' RKB(PU = 180K, SO= 100K), locate out on top of existing PBR with 10K down. PU, circulate at 3 BPM, SO, see pressure increase indicating mule shoe joint entering the and verify tag depth. 01:30 02:30 1.00 9,872 9,872 COMPZ RPCOM CRIH P PJSM. Spot 20 bbl 8.7 ppg corrosion inhibited pill at 2-1/2 BPM =245 psi and followed by 94 bbls of 8.7 ppg seawater at 3 BPM=340 psi. 02:30 03:00 0.50 9,872 9,872 COMPZ RPCOM OWFF P Observe the well for flow;well static. 03:00 03:30 0.50 9,872 9,872 COMPZ RPCOM PACK P Drop ball&rod with roller stem. Allow for ball&rod to gravitate to RHC plug body. 03:30 04:00 0.50 9,872 9,872 COMPZ RPCOM PACK P Set FHL packer per Baker rep: Pressure up on the DP to 2500 psi (initial shear at 1800 psi)hold for 5 minutes. Bring the pressure up to 3000 psi and hold for 5 minutes. Bleed the tubing pressure to 0 psi. FHL packer set at 9811'ORKB. Pressure up to 1500 psi and pull 20K over to shear PBR. 04:00 04:15 0.25 9,872 9,745 COMPZ RPCOM MPSP P Lay down 1 joint of DP, screw into DP, PU and set test packer 9710' (center of element). 04:15 04:45 0.50 9,745 9,745 COMPZ RPCOM PRTS P Pressure up down the DP to 1500 psi for 10 minutes to test the FHL packer from above(good test). Release test packer, unscrew TD, and blow down top drive, 04:45 07:30 2.75 9,745 6,281 COMPZ RPCOM PULD P POOH laying down 113 joints of DP from 9745'to 6281' RKB. 07:30 08:15 0.75 6,281 6,281 COMPZ RPCOM PRTS P Set test packer per Baker rep, purge kill line, close upper pipe rams,and PT 7"casing to 3000 psi for 10 minutes(good test). Bleed pressure to 0 psi, release test packer, and blow down lines. 08:15 12:00 3.75 6,281 60 COMPZ RPCOM TRIP P TOOH standing back DP from 6281' to 60' RKB. 12:00 12:45 0.75 60 0 COMPZ RPCOM BHAH P Lay down test packer assembly and inspect seal assembly. 12:45 17:00 4.25 0 3,592 COMPZ RPCOM PUTB P PJSM. MU seal assembly and RIH with 113 joints of 3-1/2"tubing to 3592' RKB 17:00 17:30 0.50 3,592 3,661 COMPZ RPCOM PUTB P PU and MU Premier packer assembly with running tool. 17:30 22:00 4.50 3,661 9,702 COMPZ RPCOM RCST P TIH with Premier isolation packer assembly on DP from 3661'to 9702' RKB. Break circulation at 3 BPM= 260 psi, engage seals(pressure increase observered), locate out at 9778' RKB, mark the pipe, and space out 3'(PU= 195K, SO= 92K). Page 9 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:45 0.75 9,702 9,800 COMPZ RPCOM HOSO P Break circulation at 3 BPM=260 psi,engage seals(pressure increase observered), locate out at 9778' RKB, mark the pipe, and space out 3'(PU = 195K, SO=92K). 22:45 00:00 1.25 9,800 9,777 COMPZ RPCOM CRIH P Pull the seal assembly out of the PBR. Spot 132 bbls of 8.7 ppg corrosion inhibited seawater at 3.5 BPM followed by 65 bbls of 8.7 ppg seawater. 06/15/2015 Pressure up on the DP to 3000 psi to set the Premier packer. Slack off and slowly bring up the pressure to 3800 psi to release the HRD-E running tool. Bleed the DP to 1000 psi, close the upper pipe rams, and PT the IA to 3500 psi for 10 minutes to test the Premier packer from above(good test). Premier packer set at 6207' ORKB. Slip and cut 70'of drilling line. Hold MR on slipping and cutting drilling line. POOH laying down DP and lay down HRD-E running tool. Pull wear ring. PU, MU, and RIH with upper completion per tally on 3-1/2" tubing. Engage seals into SBE, mark the pipe, space out with pups, MU tubing hanger, and MU landing joint. Circulate 200 bbls of 8.7 ppg corrosion inhibited seawater followed by 16 bbls of 8.7 ppg seawater. Land tubing hanger, RILDS, and change out VR plug. 00:00 00:30 0.50 9,777 9,800 COMPZ RPCOM PACK P Engage seals into PBR with 3'space out. Pressure up on the DP to 3000 psi for 5 minutes to set the Premier packer. Slack off 31K and slowly bring up the pressure to 3800 psi to release the HRD-E running tool. 00:30 01:00 0.50 9,800 9,800 COMPZ RPCOM PRTS P Bleed the DP to 1000 psi, close the upper pipe rams, and PT the IA to 3500 psi for 10 minutes to test the Premier packer from above(good test). Bleed the IA to 0 psi, bleed the DP to 0 psi, and open the upper pipe rams. Premier packer set at 6207' ORKB 01:00 01:30 0.50 9,800 6,118 COMPZ RPCOM RURD P PU to confirm HRD-E running tool is released (PU= 120K)and stand back stand#65. Blow down the TD and lines. 01:30 02:00 0.50 6,118 6,118 COMPZ RPCOM SFTY P PJSM for slipping and cutting drilling line. 02:00 03:00 1.00 6,118 6,118 COMPZ RPCOM SLPC P Slip and cut 70'of drilling line. 03:00 03:30 0.50 6,118 6,118 COMPZ RPCOM SVRG P Service draw works,top drive, blocks, and crown. 03:30 04:00 0.50 6,118 6,118 COMPZ RPCOM SFTY P AAR on slipping and cutting drilling line. Discussed what went well and what could be improved on. 04:00 04:30 0.50 6,118 5,670 COMPZ RPCOM PULD P POOH laying down DP from 6118'to 5670' RKB. 04:30 04:45 0.25 5,670 5,828 COMPZ RPCOM TRIP P TIH with 2 stands of DP from the derrick. 04:45 09:30 4.75 5,828 31 COMPZ RPCOM PULD P POOH laying down DP from 5828' to 31' RKB. 09:30 10:00 0.50 31 0 COMPZ RPCOM BHAH P PJSM. Lay down HRD-E running tool. 10:00 10:30 0.50 0 0 COMPZ RPCOM RURD P PU 1 joint of DP, MU wear ring pulling tool, and pull wear ring. Page 10 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 0 156 COMPZ RPCOM PUTB P Verify tubing tally,count joints in the pipe shed, and verify GLM serial numbers. PJSM. MU seal assembly, 1 joint 3-1/2"tubing, GLM with SOV assembly, and 2 joints of 3-1/2"tubing to 156' RKB. 12:00 12:30 0.50 156 156 COMPZ RPCOM SVRG P Crew change and Service draw works. 12:30 19:00 6.50 156 6,151 COMPZ RPCOM PUTB P PJSM. Continue to RIH with 3-1/2" tubing from 156'to 6151' RKB 19:00 20:30 1.50 6,151 6,136 COMPZ RPCOM HOSO P Break circulation at 1 BPM, engage seals(pressure increase observed), locate out at 6183' RKB, mark the pipe, and space out 7'. Lay down joint#193, 192, and 191. 20:30 21:30 1.00 6,136 6,158 COMPZ RPCOM THGR P MU 2.25'and 8.22'space out pups. MU joint#191,tubing hanger, and landing joint with pump in sub. 21:30 23:30 2.00 6,158 6,158 COMPZ RPCOM CRIH P Circulate 200 bbls of 8.7 ppg corrosion inhibited seawater followed by 16 bbls of 8.7 ppg seawater at 3 BPM=245. 23:30 00:00 0.50 6,183 6,183 COMPZ RPCOM THGR P Land tubing hanger, RILDS, and change out VR plug. X6/16/2015 PT the tubing to 3000 psi for 10 minutes(good test), bleed the tubing to 1500 psi, and PT the IA to 2500 psi for 30 minutes(good test). Bleed the IA to 0 psi, bleed the tubing to 0 psi, ramp up the pressure on the IA, and shear the SOV at 2300 psi. Install BPV and pressure up on the IA to 1000 psi to test the BPV from below in the direction of flow(good test). ND the BOPE, install test dart into the BPV, NU tubing head adapter, NU the tree, test void 250/5000 psi, and PT tree to 250/5000 psi. Pull test dart with BPV, pump 86 bbls of diesel freeze protect, allow time for tubing/IA equalize, install BPV, and RDMO. Rig released at 12:00 hours. 00:00 01:30 1.50 6,183 6,183 COMPZ RPCOM PRTS P Line up to pressure test. PT the tubing to 3000 psi for 10 minutes (good test), bleed the tubing to 1500 psi,and PT the IA to 2500 psi for 30 minutes(good test). Bleed the IA to 0 psi, bleed the tubing to 0 psi, ramp up the pressure on the IA, and shear the SOV at 2300 psi. Pump 2 bbls down the IA to verify flow and then pump 2 bbls down the tubing to verify flow. 01:30 02:00 0.50 6,183 0 COMPZ RPCOM OWFF P Monitor the well for flow for 30 minutes;well static. SimOps: Blow down line, RD circulating equipment, and pull landing joint. 02:00 02:45 0.75 0 0 COMPZ WHDBO MPSP P Drain the stack. Install'H' BPV and pressure up on the IA to 1000 psi for 10 minutes(good test)to test the BPV from below in the direction of flow. Bleed pressure to 0 psi. 02:45 04:30 1.75 0 0 COMPZ WHDBO NUND P Pull mouse hole, pull riser, ND BOP, set BOP back on stump, and secure BOP stack for transport Page 11 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:15 0.75 0 0 COMPZ WHDBO NUND P ND DSA, install test dart into BPV, and NU tubing head adapter. 05:15 05:45 0.50 0 0 COMPZ WHDBO PRTS P PT void to 250/5000 psi. 05:45 07:00 1.25 0 0 COMPZ WHDBO NUND P NU tree, break swab valve, and orientate it correctly. Pad operator verified tree position. 07:00 08:00 1.00 0 0 COMPZ WHDBO PRTS P Fill the tree with diesel and PT to 250/5000 psi for 5 minutes. 08:00 08:15 0.25 0 0 COMPZ WHDBO MPSP P Pull test dart with BPV. 08:15 11:00 2.75 0 0 COMPZ WHDBO FRZP P PJSM. RU Little Red Services(LRS) to pump diesel freeze protect. PT lines to 4500 psi. Pump 86 bbls of diesel down the IA and taking return up the tubing at 2 BPM=900 psi. RD LRS. Place the IA and tubing in communication and allow to u-tube/equalize for 30 minutes (tubing= 120 psi, IA= 120 psi, and OA=0 psi). Open up to the cutting and bleed both the tubing and IA to 0 psi. Well static. 11:00 11:30 0.50 0 0 COMPZ WHDBO MPSP P Install'H' BPV per Cameron rep. 11:30 12:00 0.50 0 0 DEMOB MOVE RURD P Secure tree and cellar. Install valves and gauges. Clean and clear the cellar. Final well pressures:tubing= 0 psi, IA=0 psi, and OA=0 psi. *Rig Released at 12:00 hours* Page 12 of 12 '1O-02A POST RIG WELL WORK a DATE SUMMARY POST-RIG WELL WORK 6/27/2015 PULLED BALL & ROD FROM RHC PLUG @ 9865' RKB, PULLED SOV @ 6101' RKB, SET OV© SAME (1/4" PORT), PULLED DV @ 5284' RKB, SET GLV © SAME (3/16" PORT/ 1285 TRO). IN PROGRESS. 6/28/2015 PULLED DV @ 3428' RKB, SET GLV © SAME (3/16" PORT/ 1288 TRO), PULLED RHC PLUG BODY @ 9865' RKB, BAILED 30' SCALE FROM AVA CATCHER ON CA-2 PLUG © 9928' RKB, PULLED 3 1/2 AVA CATCHER PACKED W/SCALE ON CA-2 PLUG @ 9928' RKB. IN PROGRESS. 6/29/2015 BAILED SCALE FORM TOP OF PLUG © 9928' RKB, PULLED EQUALIZING PRONG & PLUG BODY © 9928' RKB, TAG LINER TOP © 9940' RKB RECOVER PACKING POSSIBLE RAG FIBER IN BRUSH, UNABLE TO WORK PAST 2660' SLM WITH GAUGES. IN PROGRESS. 7/3/2015 TAG HYDRATES/ICE @ 2359' SLM; ATTEMPT TO ROCK/FREE UP ICE PLUG (MOVED UP HOLE TO 1544' SLM); PUMP 60 BBLS OF HOT DIESEL DOWN IA @ .25 BBLS PER MIN. (2000 PSI) & RE-TAG ICE PLUG AT SAME. IN PROGRESS (READY FOR CTU PENDING PROCEDURE). .� or 7'y • ,w\`��yj��s� THE STATE Alaska Oil and Gas 4F- �- ofA Conservation Commission ill, _ 333 West Seventh Avenue ter;: 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r`Q 1� Main 907.279.1433 O'S,ALASIC� ,`�c� \U1v Q J Fax 907.276 7542 �C� G www aogcc alaska goy Diana Guzman Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-02A Sundry Number: 315-334 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, "I (.4-41-.-,—_ Cathy P. Foerster Chair DATED this Z day of June, 2015 Encl. STATE OF ALASKA A ,KA OIL AND GAS CONSERVATION COM, 3ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r •Rill Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r -Repair Well p � Re-enter Susp Well r Other: (- 2 Operator Name. 4.Current Well Class. 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. - Exploratory r Development r. 207-158 • 3.Address. Stratigraphic r Service r 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-029-21837-01 • 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F KRU 30-02A . 9.Property Designation(Lease Number): 44310.Field/Pool(s): ADL 25513 t Ass Ia. Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft)• Plugs(measured): Junk(measured). 13181 - 6545 - none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 5896 9.625 5931' 4002' PRODUCTION 10359 7 10392' 6571' RECEIVED LINER A BOTTOM 2008 2 375 11173' 6592' _ MAY 2 7 20th 0✓_c C/ 7/f- Ao CC Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade: Tubing MD(ft): •10347-11169,11182-12100,12134-13147 6571-6592,6592-6575,6575-6547 3.5 J-55 9963 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-AVA RHS PACKER ' MD=9891 TVD=6421 SSSV-CAMCO TRDP SAFETY VALVE - MD=1787 TVD=1585 12.Attachments: Description Summary of Proposal 1 13. Well Class after proposed work. Detailed Operations Program E BOP Sketch r Exploratory r Stratigraphic r Development P' Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work. 6/8/2015 OIL P • WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r- WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Diana Guzman @ 265-6318 Email: Diana.Guzman@conocophillips.com Printed Name Dian Guzman Title: Sr. Wells Engineer Signature (,(,Q_ Phone:266-6318 Date 5/27/ �_s Commission Use Only Sundry Number: �[ Conditions of approval: Notify Commission so that a representative may witness 3Irj –33 C Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: /30 P /-05 f fo 3 5 O 0 p 5 1 /1 kl-hv/ a✓ nrc-ve•1.--7re-r re' i fo 25 06 t)S r Spacing Exception Required? Yes ❑ No Zr Subsequent Form Required: /D—Iic LI-- APPROVED BY Approved by: /9 ),(.1.44'(— COMMISSIONER THE COMMISSION Date: –2--/S-- kit 6,/0 //proved application is valid tor 12 months trom the date of approval. Submit Form and Form 10-403 Revised 5/2015 t ents in pRIGINAL –s�v/7s RBDM JN - 32015 ConocoPhillips RECEIVED Alaska MAY 2 7 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 A.OGCC May 27,2014 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to workover the Kuparuk Well 30- 02(PTD#207-158). Well 30-02 was originally drilled and completed as an A-sand only gas lifted producer in 1988. Well 30-02 was sidetracked with coiled tubing in 2008 when four laterals were drilled. The parent bore perforations were cemented in 2008 prior to CTD. Initial flush production from the sidetrack was almost 1000 BOPD and stabilized in 2011 at around 200 BOPD. Diagnostics were performed on 30-02 after a failing TIFL in March 2014, as well as a failing CMIT TxIA and a failing MIT-T in May 2014. A tubing leak at 6256', corresponding to GLM#2, was detected in May 2014 with a LDL. A baseline pass was logged and then compared to a second pass while injecting down the tubing and taking returns up the IA. A production casing leak point was found the same month with another LDL. A baseline pass was logged and then compared to a second pass while injecting down the IA and taking returns to the formation. The production casing leak was observed at 7240'. Before being SI in April 2014 well 30-02 was producing 180 BOPD. In order to put well 30-02 back into production the existing 3 Y2" completion will be pulled from the pre-rig tubing cut at 9860', the packoffs will be replaced and a premier packer will be stacked above the production casing and tubing leaks,and return the well to service. If you have any questions or require any further information,please contact me at 907-265-6318. Sincerely, Diana G�u ma Wells Engineer CPAI Drilling and Wells E KUP PROD 30-02A ConocoPhillips a Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore APIIUWI Field Name Wellbore Status ncl 5) MD(ftKB) Act Btm(ftKB) ,,,, ,g,p, 500292183701 KUPARUK RIVER UNIT PROD 95.77 12,933.69 13,181.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-02A,6/9/2014 2.38.52 PM SSSV:TRDP 150 12/19/2013 Last WO: 34.98 8/30/1988 Vertical schematic(actual) 'Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag:ELM 9,950.0 8/10/2008 Rev Reason:H2S,GLV C/O,SET PLUG hipshkf 6/5/2014 =YJ = ,n,..mw... 12 , 1.,,ar HANGER;33.0 ., Caasing rings sing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 6250 H-40 WELDED J L Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 5,930.5 4,002.0 36.00 3-55 BTC Casing Description SOD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;386115.0 _ PRODUCTION 7 6.276 33.0 10,392.0 6,571.3 26.00 J-55 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER ATOP (off 23/8 1.992 10,331.8 11,172.6• 6,591.8 4.44 L-80 STL SAFETY VLV;1.766.7 'g°.?,u.. AL2-01) Liner Details Nominal ID J Top(ftKB) Top(ND)(8KB) Top Ind(*) Item Des Com (in) 10,331.8 6,571.7 91.04 DEPLOY ALUMINUM DEPLOYMENT SLEEVE 1.000 GAS LIFT;3.508.1 Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER A BOTTOM 23/8 1.992 11,172.6 13.181.0 6,545.4 4.44 L-80 STL Liner Details Nominal ID Top(ftKB) Top(ND)(kKB) Top Incl 5) Item Des Com (in) • 11,172.6 6,591.8 89.17 DEPLOY BTT DEPLOYMENT SLEEVE 1.000 SURFACE;35.0-5,930.5-- 12099.9 6,574.8 89.79 0-RING .BTT 0-RING SUB 0.500 12133.5 6,575.1 89.57'DEPLOY •BTT DEPLOYMENT SLEEVE 2.250 GAS LIFT;6,255.9 13,147.3 6,546.5 91.90 0-RING BTT O-RING SUB 1.000 Tubing Strings GAS LIFT;7,846.2 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth lit..Set Depth(TVD)(...Wt WO Grade Top Connection TUBING 31/2 2.992 33.0 9.9632 6,468.3 9.30 J-55 EUESrdABMOD GAS LIFT;8,608.1 Completion Details Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal 3.500 ID GAS LIFT;92477 33.0 33.0 0.00 HANGER CIW TUBING HANGER 1,786.7 1,584.8 46.07 SAFETY VLV CAMCO TRDP SAFETY VALVE 2.812 GAS UFT;9.838.2 9.877.5 6,411.7 49.13 LOCATOR LOCATOR 2.992 ill 9,878.1 6412.1 49.12 PBR AVA PBR 3.000 LOCATOR;9,877.5a 9.8912 6,420.7 49.09 PACKER AVA RHS PACKER 3.000 9,928.5 6,445.2 48.62 NIPPLE CAMCO D NIPPLE NO GO 2.750 PBR;9,878.1 ill 9,9624 6,467.8 48.09 SOS BAKER 43500 SHEAR OUT SUB 2.992 PACKER;9,891 2 Perforations&Slots Shot Dens CATCHER;9.925.0 (1911 Top(kKB) Btm(ftKB) Top (MB)D) Bt(ftKB) Zone Date (sllI) Type Com � 10,347.0 11,169.0 6,571.4 6,591.7 A-1,30-02A 3/15/2008 32.0 SLOTS Slotted Tubing NIPPLE;9,928.51 ' 11,182.0 12,100.0 6,591.9 6,574.8 A-1,30-02A 3/10/2008 32.0_SLOTS Slotted Tubing PLUG;9,928.0 12,134.0 13,147.0 6,575.1 6,546.5 A-1,30-02A 3/10/2008 32.0 SLOTS Slotted Tubing Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(kKB) (ftKB) Make Model 00(In) Bern Type Type lin) (psi) Run Date Com 1 3,508.1 2,542.4 MMH FHMO 1 GAS LIFT GLV BK 0.156 1,305.0 3125/2012 sos,9s62.4 2 6,255.9 4,191.1 MMH FHMO 1 GAS LIFT DMY BK- 0.000 0.0 5/23/2014 EXT 3 7,846.2 5,135.1 MMH FHMO 1 GAS LIFT GLV BK 0.188 1,337.0 3/24/2012 4 8,658.1 5,630.8 MMH FHMO 1 GAS LIFT DMY BK 0.000 0.0 5/62014 5 9,247.7 6,005.9 MMH FHMO 1 GAS LIFT DMY BK 0.000 0.0 2/15/1998 LINER AL2-01,9,939.9.11,471.0 6 9,836.2 6,384.8 OTIS LBX 11/2 GAS LIFT 1DMY 1-2 0.000 0.0 5/8/2014 WINDOW;10.060.0-10065.0 Notes:General&Safety End Date Annotation 4/13/2008 NOTE:MULTI-LATERAL WELL 30-02A,AL1,AL2,AL2-01 1/18/2011 NOTE:View Schematic w/Alaska Schematic9.0 t • • • • • PRODUCTION;33.0-10,392.0 SLOTS;10,347.0-n.1 69.0- UNER A TOP (off AL2-01); 10.331.8-11.172.8 SLOTS;11.182.0.12.100.0 ti ! ...SLOTS;12,134.0-13,147.0 ( I LINER A BOTTOM;11,172.6- 13.181.0 30-02 Rig Workover P&R Tbg and Stack Packer (PTD #: 207-158) Current Status: This well is currently shut in and awaiting pre-RWO well work. Scope of Work: • Pull existing 3 'A"completion from pre-rig tbg cut at 9860'. • Packoff replacement. • Recomplete the well with a new 3 'h" completion by stacking a premier packer above the existing production csg and tbg leaks. General Well info: Well Type: Producer MASP: 3085 psi using 0.1 psi/ft gradient(Most recent SBHP=3730 psi on 05/30/14) Reservoir Pressure/TVD: 3730 psi/6452' TVD(11.1 ppg)on 05/30/14 Wellhead type/pressure rating: CIW Gen IV/5M psi TH,5M Csg Hd. BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: MIT-OA passed March 14,2015 Earliest Estimated Start Date: May 3,2015 Production Engineer: Scott Pessetto Workover Engineer: Diana Guzman Work:265-6318 E-mail:Diana.Guzman@conocophillips.com Pre-Rig Work 1. RU DSL and punch tbg at 9830'-9845' 2. RU DSL and cut tbg at 9860' 3. PT tubing and casing packoffs,FT LDS's. 4. Set BPV within 24 hrs of rig arrival. Proposed Procedure: 1. MIRU 2. Pull BPV. Circulate workover fluid. Obtain SITP& SICP, if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug or two-way check,PT to 1000 psi from below if possible.ND tree,NU BOPE& test to si 35-00 p s ' VTC 472-0,5- 4. 7Z0s4. RU to pull 3 '/2", 9.3#, J-55, 8rd EUE AB Mod tubing. Pull the blanking plug and the 3" H-BPV. Verify that the well is static. 5. POOH laying down 3 '/2"tubing spooling up control line. 6. While TIH, set a storm packer at-100' w/tubing hanging below. RU Hydratight equipment. NDBOP & Tbg head,replace tbg head&1C packoffs,NU BOP&test. Pull storm packer. 7. LD remaining 3 '/2"tubing. 8. Load new 3 '/2",9.3#,L-80, 8rd EUE AB Mod tubing into the pipe shed and RIH to just above the tubing cut at 9860'MD. 9. Pump pill of corrosion inhibited seawater. 10. Drop ball and rod,pressure up on tubing to set the Baker FHL packer. 11. Release from packer, PU 1 jt and set the retrievamatic services packer to test the Baker FHL packer from above. 12. Release ES Retrievamatic Services Packer and PU to 6200'to set. 13. Pressure up the workstring to confirm the integrity of the 7"casing at the new Premier Packer setting depth prior RIH. 14. Release ES Retrievamatic Packer and POOH laying down DP. • . 30-02 Rig Workover P&R Tbg and Stack Packer (PTD #: 207-158) 15. MU the premier packer completion and RIH to just above the Baker FHL packer. 16. Pump pill of corrosion inhibited seawater. 17. Pressure up to set the Premier Packer and PT the IA to confirm packer integrity. 18. Finish TIH with the new 3 ''A"completion to just above the new premier packer. 19. Engage seal assembly until fully located and space out. 20. Space out w/pups,MU hanger.Land the hanger,RILDS. 21. PT the tubing to shear the SOV. 22. Pull the landing joint,install BPV or two-way check. PT BPV or two-way check through 1A. 23. ND BOPE. 24. NU and test tree. 25. Freeze protect well w/diesel. 26. Set BPV. 27. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull SOV. 4. Handover to Ops. Kuparuk Producer 30-02A Current Well Schematic ....... Fpril l).3015 by Diana Guzman r _ , 1 lb ,l 16"62.5 ppf H-40 welded condutctor from 36'-115'MD(ID:15.062") 1 ,:. „... < CAMCO TRDP SAFETY VALVE @ 1787'MD(ID:2.812") 111 111 t 9-5/8"36 ppf 1-55 BTC surface casing from 35'-5931'MD(ID:8.921") 4 ! — Tubing leak @ 6256' Casing leak @ 7240' IFMandrel Inserts 111 .apt 11 re Top 11.1a.e latcn y Site TRO Run R Top 10K6ram 1 0006) Y wax 00 0n1 837v Type Type 11 Ono Oro Run D. 1 3.5081 22.542.4 MMHF1080 1 GAS LIFT CLT BK 0.156 1.305.0 312500122 6.2569 4.191.1 MMT F14M0 1 GAS LIFT CMV BK. 0000 0.0 512312014 EXT '3' 7.64 2- 5.13.1 MMT TOMO l'-'6A LIFT OT P3 --0.7881 TS Siff-41177.- 4 86581 5,6308 MMT F141.30 1 GAS UFT DMV BK 0.000 0.0 576I201a 5 9247,7 6.0059 MMT FTMO 1'GAS LIFT CMV BK 0000 00 211571998 6 98362 6384.8 OTIS 'LOX 11/2 GAS LIF/ CMV 12 ..__..0060.....0.0 57812014 1.56"tbg punch 9830'-9845' -. Chem Cut at 9860' < LOCATOR,9,877. <— POR;9.878 < PACKER;9,891. 3-1/2"9.3 ppf J-55 EUE 8rd ABMOD production tubing from 33'-9963'MD(ID:2.992") p;, *CATCHER;9.925. t, ._ < NIPPLE;9,928. PLUG:9,928. tIN) 7 26 ppf J-55 BTC production casing ►.rreradona frau 7_......_ ... from 33'-10392'MD(ID:6.276") It _ 'roar _ _ 1 01 1t 66 Io-- Pae t"4"-17;0 ..no. 65>t♦ '6541)A1.X.....,9 :y15P.WF 3.'.0 410..9 SbLL+d tubny 1118_0 I::100.0 65919 6.5514.8 A1.3P076 3000008 I20 SLOTS Slated Tub, 171318 13.1310 6.5151 6.54631 1.3002A 3f100868 320 56075 5b0•01Wa.9 —+ H 1 4141. I l 1r 10 • KUP PROD PROPOSED COMPLETION 30-02A ConocoPhillips 0; Well Attributes Max Angle&MD TD WellboreAPIiUWI Field Name Wellbore Status Inotl'I MDIIKB) Act etmMKS) cocomipthilog 500292133701 ,KUPARUKRIVERUNIT PROD 95.77 12,93369 13,181.0 ..... Rig Release Date Drdlsne Well Type Well Sub Type ISBGrd(R) Loc Sensitive' Proposed by:Diana Guzman 3,30/1938 30 Development Production 3493 No April 15,2015 t • -Casing Strings ""•'""-�� " 4ANGER.33 ". " 1t'It '>`-:-Casing Description OD tin} ID lin) Top lW(BI Set Depth lhKBi Set Depth IND7... WCLen 11.. Grade Top Thread I I1 UCONDUCTOR 16 15.062 36.0 WELDED 1150 6250H-10 ELDED i Casing Description OD(in) ID(in) Top(11(8) Set Depth(NNE)) Set Depth(ND)_. Wt'Len(I Grade Top Thread I SURFACE 9 5/8 3.921 35 0 5.930 5 4,002.0 36 00 J-55 ETC Casing Description OD(in) ID(in) Top 1111(E) Set Depth Ittl(8) Set Depth(TVD).. WULen II Grade Top Thread _ .1 - PRODUCTION 7 6.276 33.0 10.392 0 6,571 3 26 00 J-55 BUTT CONDUCTOR:36.0.115: Casing Description OD lin) ID fin) Top im(8) Set Depth(RISE) Set Depth(ND)... Wt len(I Grade Top Thread LINER A TOP (off 2 3,8 1.992 10,331.8 11,172.6 5,591.8 4.44 L-80 STL AL2-07 Liner Details Nominal ID Top(WTI) Top 1(VD)INKS) Top 1nc1('1 Item Des Com Yin) 10,331,8 6,571,7 91.04 DEPLOY ALUMINUM DEPLOYMENT SLEEVE '000 GAS UFT:3.427 Casing Description OD(in) ID(in) Top IRKS) Set Depth 114108) Sot Depth(ND) . Wt Len(I Grade Top Thread LINER A BOTTOM 2 3,6 1992 11.172 6 13.131 0 6,5451 4.44 L-80 STL Liner Details Nominal ID Top Ih36) Top(TVD)(RISS) Top Ind(•) Item Des Corn lin) 11.172.6 6,591.8 89.17 DEPLOY BTT DEPLOYMENT SLEEVE 1.000 GAS LIFT:5.271 12.099.9 6.5743 89,79 0-RING BTT 0-RING SUB 0 500 • 12.133,5 6.575.1 89.57 DEPLOY BTT DEPLOYMENT SLEEVE 2 250 13,1473 6.5465 91.90 0-RING BTT0-RINGSUB 1.000 SURFACE:35SM,9225- Tubing Strings TIlitiubing Oe,147 3n String Ma...ID(in) Top IM(8) Set Depth Ih..Set Depth(ND)[.,.WI((btM Grade Top Conneebon GAS LIFT 6.132 'PROPOSED' 3 1/2 2 992 33.4 9.963 2 6.468.3 9 30 L-80 EUEErdABMOD TUBING Proposed Completion Details =?c7,1:ER PACKER:620: Top I1)(8) Item Des Com 334 HANGER CI';:TL.BING HANGER 6.187,2 SBR 6.200.2 PREMIER PACKER 3-12-X T BAKER PREMIER PACKER 9.777 7 PER PBR 9,790.8 FHL PACKER AVA RHS PACKER 9.805.6 NIPPLE 2 813'DS NIPPLE 9.857.1 PB OVERSHOT 3-112'BAKER POOR BOY OVERSHOT PER: r� 9,860.1 12"MULESHOE 1/2-MULESHOE FHL PACKER PI- 3-1/2'TBG STUB DSL PERFORMED A 713 CUT AT 9860.+PRE-R',':O: NIPPLE:S.&356 9.891.7 AVA PACKER AVA RHS PACKER I 9,928.4 NIPPLE CAMCO0NIPPLENOGO 9.962 4 SOS BAKER 03500 SHEAR OUT SUB T Perforations&Slots snot 1,2'MULESHOE.916? Dens Top(TVD) EMT(ND) Ishots't Top(MOPBan OMB) IRKB) ittKB) Zone Dao t) Type Com i 0.347 0 t 21..110609.0 6.571.4 6,591.7 A-1.30-02A 3/15/2003 32.0 SLOTS Slotted Tubing 71,182.0 72.100,0 6.591 9 6,574.8 A-1.30-02A 3;102008 32 0 SLOTS Slotted Tubing AVA PACKER:5.191.7 r'1 le• 12.134.0 13.147 0 6,575.1 6.546.5 A-1.30-02A 3/102003 32.0 SLOTS Slotted Tubing Proposed Gas Lift Design GLM « Depth-ft TVD Depth -ft MD Valve Type NIPPLE:SACS 4,, E 1 2,500 3,427 Dummy 3,600 5,271 Dummy 4,116 6,132 SOV(2000 psi IA to TEG shear) fli LINER AL2-01,5939411.471.0 WINDOW:10.0623.10,065.0 111 144.. Awe- PRODUCTION.33..13,352.• SLOTS:13,347,0.11,t69.0 LINER ATOP (ORAL2GI): �` 10,331.11-11,172.6 SLOTS;SLOTSi 11.133 0-l2 100.0 LLL.....��J to Loepp, Victoria T (DOA) From: Guzman, Diana <Diana.Guzman@conocophillips.com> Sent Wednesday, May 27, 2015 4:35 PM To: Loepp,Victoria T(DOA) Subject 30-02 Sundry- PTD 207-158 Good afternoon Victoria, I just wanted to follow up my phone call. As I mentioned I made a mistake and did not submit a sundry for the 30-02 RWO. Nabors 9ES could potentially move to that well June 3rd at the earliest. I'm so sorry about my mistake and having to ask you and your group to please expedite this sundry. The procedure objectives include: • Pull the existing 3%2" completion from tbg cut at 9860' • Packoff replacement. • Run a new 31/2" completion with a stacked premier packer above the production casing and tubing leaks I just wanted to inform you before you see this submission. If you have any questions please feel free to call me. Thank you so much for your time. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 1 Image Rrojeet Well History File Craver Rage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - L~ Well History File Identifier Organizing (done) o.wo=,a~ miimui m Re,~a~~~eaee oi,uiiuiuiiuu RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Date: ~ ^ Other:: !s/ Project Proofing III IIIIII VIII II III BY: Maria - Date: /s/ ~\ Scannin Pre aration 30 = ~r'~ ~ + ~ = TOTAL PAGES ~~ g p x - =~- ~ ~ (Count does not include cover sheet) ~/~/~ BY: Maria 1 Date: ,~ ~ /s/ Y Y 1 Production Scanning Stage 7 Page Count from Scanned File: ~~ (Count does include cove heet) Page Count Matches Number in Scanning Preparation: ~! r ES NO BY: Maria Date: ,~ ~ ~ ~ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO DIG TAL DATA Diskettes, No. f ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned III IIIIiIIIIII VIII BY: Maria Date: lsl Comments about this file: a , ~e~~ed iuumuiiuiiii 10/6!2005 Well History File Cover Page.doc :~~.1 ~~ ~~ ` ~- 4 v -~ ~~ ~~ x a >}, Y' ...~~* ~,,,. ~. _~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATE R1AL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ConocoPhillips Alaska KRU 30 -02A RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and /or Digital Data contact: Lisa Wright, 907 263 -4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disc David Douglas in lieu of sepia Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519 -6612 CHEVRON /KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file Disk P.O.Box 196247 in lieu of sepia Electronic Anchorage, Alaska 99519 CGM TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 sDislcx/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS go-- l s CAS .NE) NO ,1 2 7 2005 DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071580 Well Name/No. KUPARUK RIV UNIT 30-02A MD 13181 TVD 6545 Completion Date 3/31/2008 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / RES / GR Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED D Asc Directional Survey I R/pt Directional Survey ~D C Pds 16832~ressure ~g 'Pressure Well Cores/Samples Information: 10000 13181 Open 5/23/2008 10000 13181 Open 5/23/2008 9450 9940 Case 9/2/2008 SBHPS, Pres, Temp, CCL, GR 10-Aug-2008 2 Blu 1 9450 9940 Case 9/2/2008 SBHPS, Pres, Temp, CCL, GR 10-Aug-2008 Interval Name Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? Chips Received? `~ N ~ Formation Tops Analysis 1`-/-N' Received? Comments: ~ H ~.,.~ "~`~` ,-~ ~j o„~e.. ~ e-c,~ae~~ ~ Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21837-01-00 Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey Yes v (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments Sampte Set Number Comments ~l /N ~/ N Compliance Reviewed By: __ - _.-_ _ ____ ____ Date: c~ ~ ~ ~__ ti ~ ,., ,... f9 ~ ~, ~ } ~F_.~:> ~~ `j ?(10s ~~~~~~h~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Field: Beluga River Unit 1~ Well Job # Log Description ~~1~~sK~~ .ail :' ,~ ,>~~ NO.4852 ;~,~~~~t~r, Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD 08/28/08 2W-11 12100437 PROD PROFILE E - 08/06/08 1 1 1 F-14 12096521 PROD PROFILE - ~ 08/08/08 1 1 1 Y-05 12096520 LDL / ~ 08/07/08 1 1 30-02A 12097415 SBHP SURVEY ~ "'}- 2 08/10/08 1 1 1 E-114 12096524 INJ PROFILE - 08/10/08 1 1 2A-24 12097417 PROD PROFILE - ~ ~- 08/11/08 1 1 1 G-10A 12097418 PROD PROFILE ~ 08/12/08 1 1 1 L-14 10228963 INJ PROFILE q ~- ~ (~ 08/12/08 1 1 30-17 11966273 SBHP SURVEY ~ 08/15/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r' • • ConocoPhilli s p Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 D y , ~~ ~ V ~~ ~, ~ ~Q Dear Mr. Maunder: Enclosed please find a spreadsheet with a llst of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, '~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 7/30/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1Y-06A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 ~~ ~~ BAKER Hu~NE iNTE+[~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: May 23, 2008 Please find enclosed directional survey data for wells: 30-02A - ~ - ~ ~` ~ 30-02AL 1 PB 1 30-02AL1 30-02AL2 30-02AL2-O1 1R-O1BL1PB1 1R-OlBL1 1R-OlBLl-O1PB1 1R-O1BL1-O1 Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey .file Cc: State of Alaska, AOGCC Christine Mahnken Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 07, 2008 11:29 AM To: 'Hubble, Terrie L' Subject: RE: 30-02A (207-158), et al Terrie, I agree, the changes should not present a problem. Thanks, Tom From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, May 07, 2008 11:16 AM To: Maunder, Thomas E (DOA) Subject: RE: 30-02A (207-158), et al You are correct... I see the error that 1 made. I think you could make a hand correction on this if you would be so kind... 30-02AL2-01 No Change 30-02A~./ No Change 30-02AL1 Well Branch 30-02AL1_ Departs... 30-02AL2 Well Branch 30-02AL2 Departs... Thanks! Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, May 04, 2008 12:20 PM To: Hubble, Terrie L; Stewman, Sondra D Subject: 30-02A (207-158), et al Terrie and Sondra, I am finishing my review of the 407s for the 30-02A redrill and laterals. In block 21where the slotted section is detailed, the same statement regarding the well branch and whether it is accessible or not is made. Shouldn't that statement change depending on what segment is being reported? Thanks in advance, Tom Maunder, PE AOGCC 5/7/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, May 04, 2008 12:20 PM To: 'Hubble, Terrie L'; 'Stewman, Sondra D' Subject: 30-02A (207-158), et al Terrie and Sondra, I am finishing my review of the 407s for the 30-02A redrill and laterals. In block 21where the slotted section is detailed, the same statement regarding the well branch and whether it is accessible or not is made. Shouldn't that statement change depending on what segment is being reported? Thanks in advance, Tom Maunder, PE AOGCC 5/4/2QQ8 Page 1 of 1 Maunder, Thomas E (DOA) From: Eller, J Gary [J.Gary.Eller@conocophillips.com] Sent; Thursday, May 01, 2008 9:09 AM To: Maunder, Thomas E (DOA) Subject: RE: 30-02A.(~t5- 30-02AL(one half) Tom - It is long read, isn't it? And that spaghetti bowl of laterals sure gets a little tough to keep up with. That was supposed to be lateral AL3 (permit #208-036). Basically, we were going to break the AL1 lateral into two shorter segments. But when we couldn't get off the billet at 11,170' MD, we bagged that plan and cancelled the AL3 permit, and ultimately drilled the AL1 lateral more or less as we originally intended. Thanks, and please call if you have any questions. -Gary From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 30, 2008 5:10 PM To: Eller,) Gary Subject: 30-02A (207-158) - 30-02AL(one half? Gary, I have just reviewed the L-O-N-G report for 30-02A, et al. After drilling to TD on the initial penetration, the liner was run in 2 sections and it appears that it was attempted to kickoff at about 11170'. Problems were encountered and another section of liner was run and the AL1 penetration was kicked off at about 10329'. According to the spreadsheet I did when examining the permits, this was the planned KO depth for AL1. What was attempted at 11170'? That depth does not correspond to any KO depths I have for the various laterals. Thanks in advance. Tom Maunder, PE AOGCC 5/1/2008 STATE OF ALASKA - ~~ ALASKA OIL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~E~~I\/Ef APR 2 5 2008 ~iaska flii t~ Gas Cons. CammisSiQtt 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAO,c zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class{~nChOfa(~@ ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aban - 3/31/2008 ~ ~ 12. Permit to Drill Number 207-158 3. Address: c/o P.O. Box 196612, Anchorage, AK 99519-6612 6. Date Spudded 3/3/2008 ~ 13. API Number 50-029-21837-01-00 4a. Location of Well (Governmental Section): Surface: 74 ' F ' 7. Date T.D. Reached 3/10/2008 - 14. Well Name and Number: Kuparuk 30-02A 5 NL, 1855 FWL, SEC. 22, T13N, R09E, UM Top of Productive Horizon: 3298' FSL, 4240' FEL, SEC. 16, T13N, R09E, UM 8. KB (ft above MSL): 59' ~ Ground (ft MSL): 15. Field /Pool(s): , Kuparuk River Unit /Kuparuk Total Depth: 2309' FSL, 1399' FEL, SEC. 17, T13N, R09E, UM 9. Plug Back Depth (MD+TVD) 13181' 6545' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 525491 y- 6022072 Zone- ASP4 10. Total Depth (MD+TVD) 13181' 6545' 16. Property D signation: L~.~SS~L ADL 025512 TPI: x- 519375 y- 6026098 Zone- ASP4 Total Depth: x- 516941 y- 6025103 Zone- ASP4 11. SSSV Depth (MD+TVD) 1787' 1585' 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rioted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1700' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information pe 20 AAC 25.071): MWD DIR / RES / GR /~//NDO~ ~ 10060'MD ~~~ Ss?YD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MO' SETTING DEPTH TVD ' HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2-3/8" 4.44# / 4.6# L-80 10329' 13181' 6572' 6545' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slotted Section NOTE: 3-1/2", 9.3#, J-55 9963' 9891' MD TVD MD TVD 10347 - 11169' 6571' - 6592' Well Branch Well Branch 11182' - 12100' 6592' - 6575' 30-02A 30-02A 25. ACID, Fw.cTURE, CEMENT SQUEEZE, ETC. 12134' - 13147' 6575' - 6546' Departs From Is not Directly DEPTH INTERVAL MD AMOUNT Se KIND OF MATERIAL USED 30-02AL2-01 Accessible Ooen Hole PTD # 207-161 , at 10140' MD 10140' - 10329' 6567' - 6572' (6567' TVD) 26. PRODUCTION TEST Date First Production: Reported on 30-02AL2-01 ~a~`~- ~(,,`~ Method of Operation (Flowing, Gas Lift, etc.): See the 10-407 for 30-02AL2-01 (Dated 04/25/08, PTD 207-161) for Production & Test Data Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~4 ~. ~. .1~ R. None `~~~ m4 Form 10-407 Revised 02/2007 y "~ CoNnNLED ON REVERSE SIDE r _ (~ ~ ,,, 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Kuparuk Al 10139' 6566' None Formation at Total Depth (Name): Kuparuk Al 10139' 6566' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ ~~~ Signed Terrie Hubble Title Drilling Technologist Date Kuparuk 30-02A 207-158 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. onuing engineer: Gary Eller, 529-1979 (Cell) INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITea~ 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only 4 BP AMERICA Page 1 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31 /2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 2/26/2008 ~ 18:00 - 20:00 ~ 2.00 ~ MOB P ~ ~ PRE ~ Make ready to back off well. Notified Kuparuk DSO to SI 20:00 - 21:00 1.00 MOB P PRE 21:00 - 22:30 1.50 MOB P PRE 22:30 - 00:00 1.50 MOB P PRE 2/27/2008 00:00 - 06:00 6.00 MOB P PRE 06:00 - 08:00 2.00 MOB P PRE 08:00 - 09:30 1.50 MOB P PRE 09:30 - 11:00 1.50 MOB N RREP PRE 11:00 - 13:30 2.50 MOB P PRE 13:30 - 15:30 2.00 MOB P PRE 15:30 - 15:45 0.25 MOB P PRE 15:45 - 16:00 0.25 MOB P PRE 16:00 - 00:00 I 8.001 RIGU I P I I PRE 2/28/2008 00:00 - 05:00 5.00 RIGU P PRE 05:00 - 15:00 10.00 BOPSU P PRE 15:00 - 16:30 1.501 BOPSUp P PRE 16:30 - 17:00 0.50 BOPSU P PRE 17:00 - 19:00 2.00 BOPSU P PRE 19:00 - 19:15 0.25 BOPSU P PRE 19:15 - 21:00 1.75 BOPSU P PRE 21:00 - 22:00 ~ 1.00 ~ CLEAN ~ P 22:00 - 00:00 ~ 2.00 i CLEAN I P W EXIT adjacent wells 1 L-20 and 29. Moving camps to 30-02 starting at 2000 hrs. Held PJSM with crew and Pad operator. Shut-in 1 L-29 and 20. Move off well and drive to the edge of the pad. Set down Clean up location Move off location and travel to 30-02 Mobilize rig to 30-02. Spotted ManCamp on Ungu Pad and Office camp spotted on 30-02 Pad. Conducted crew change at 1 O Pad. Nordic and Kupuark Field crew change Travel from 1 O Pad to just south of 3C Pad turnout. SD - Doyon 15 broke down on road due to hinge pin.. Rig on standby waiting on Doyon 15 Rig Repair Mobilize rig Rig on Pad. Prep Pad for moving over well Held PJSM on moving over the well Move rig over well and set down. Wait on wood to level said rig Rig accepted at 16:00 hrs NU BOP's and MPD loop valuing. Leveled rig Doyon 15 and Nordic 3 moving tonight Hauling in associated equipment from 1 L-28 Loaded 290 bbl's biozan in pits. Installed riser Finished NU BOP and thawed out some surface line. RU TT (tiger tank) line and cutting box. BOP test as per AOGCC 250 psi / 4500 psi . Lou Grimaldi wavered witness the BOP test Made ready reel for installation of the sleeves /bushing Nordic electrician is RU the Fairweather muster shack and generator Installed CTRI modular on CCat Loaded the TT line and PT to 3000 psi using diesel. SLB finished up the hardline PJSM Re: Pulling BPV Pull BPV. Recovered ok. No ressure on well under BPV. Re: Filling coil with brine, pumping slack, PT'ing inner reel valve. Pump 5 bbl MEOH spear into coil. Pump 60 bbls of 2% KCL brine into coil. Stab injector. Rig up and reverse slack back. Good indication of wire moving inside coil. Pumped 2.5 bpm at 4300 psi until wire stopped. Cycled pumps up and down until no more wire movement. PT inner reel valve to 4500 psi and chart. PT packoff to 4500 psi. Note -Had rig hands check all nuts on production tree. All nuts tight. Circulate to warm coil 1 last time. Unstab injector. Install hydraulic CT cutter. Cut back pipe to find eline. Cut off a total of 36' of pipe to find end of eline. Install CTC and pull test to 35 klbs. Install Baker UOC. Meg line and check continuity. W EXIT ~ Continue making up Baker UOC and flow sub. Had problems Printed: 4/11/2008 12:40:41 PM ~ ~ BP AMERICA Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 2/1 /2008 Rig Release: 3/31/2008 Rig Number: Date From-To Hours Task. Code NPT Phase. 2/28/2008 22:00 - 00:00 2.00 CLEAN P WEXIT 2/29/2008 00:00 - 00:30 0.50 CLEAN N DFAL WEXIT 00:30 - 00:45 0.25 CLEAN P WEXIT 00:45 - 01:05 0.33 CLEAN P WEXIT 01:05 - 01:30 0.42 CLEAN P WEXIT 01:30 - 03:15 1.75 CLEAN P W EXIT 03:15 - 04:10 0.92 CLEAN N SFAL ~ W EXIT 04:10 - 04:35 I 0.42 I CLEAN I N I DPRB I W EXIT 04:35 - 05:15 I 0.671 CLEAN I N I DPRB I W EXIT 05:15 - 06:30 1.25 ~ CLEAN ~ N ~ DPRB ~ W EXIT 06:30 - 08:15 1.75 CLEAN N DPRB WEXIT 08:15 - 09:15 1.00 CLEAN N DPRB WEXIT 09:15 - 11:00 1.75 CLEAN N DPRB WEXIT 11:00 - 11:25 0.42 CLEAN N DPRB WEXIT 11:25 - 11:44 0.32 CLEAN N DPRB WEXIT 11:44 - 13:25 1.68 CLEAN N DPRB WEXIT 13:25 - 14:00 I 0.581 CLEAN I N I DPRB I WEXIT 14:00 - 14:43 I 0.721 CLEAN I N I DPRB I W EXIT Page 2 of 36 ~ Spud Date: 10/2/1988 End: 3/31 /2008 Description of Operations with first 2 flow subs. Continue to sort out. BHI continuing to sort out problems with CTC. Finally got a good electrical test. PT CTC to 3500 psi. Passed ok. PJSM Re: making up cleanout BHA. Check well for pressure. No pressure on well. Make up BHA #1. 2.7 x 3.0" bicenter bit, straight mud motor, BHI BHA. RIH with BHA #1, circulating at minimum rate. Taking diesel freeze protect returns to the cuttings box, and brine returns to the pits. Pumping 2#/bbl, 8.6 ppg biozan. IAP=O psi, OAP=540 psi. PVT=383 bbls. Bled OA down to 200 psi. Try to tie in with GR log. BHI can't get GR tool working. GR sensor pegged at 300 counts. Could be high formation GR. Switch to CCL sensor. Log tie in pass over GLM at 9248' using CCL. GLM found at 9240'. Expected at 9248'. Add 8'. Note -Collar log available at rig is a CBL log with collars marked on it which are down below the expected cement top. For tie in purposes, the CPAI schematic depth of GLM#5 was used for the tie in. An additional collar log tie in will be made after getting cement cleaned up thru D nipple. 9400', pumps to full rate. Pumping 1.5/1.5/2700 psi. RIH. Pump 10 bbl high vis sweep. Wt check 28 klbs at 9500'. Continue RIH slowly, looking for motor work. 9883', started seeing slight weight. 1 for 1 on the returns. Could be mushy cement. Continue in hole at 10 fpm. Hard motor work_at 9923' (D nipple) with a drill off. Drilled off, and returns went to 1.5/1.2. Stall. PU at 27 klbs clean. New free spin 3350 psi with pill in coil. Continue drilling cmt. Returns 1.5/1.5 ROP=40 fph. Pump pressures are much higher with thick bio pill on the backside. Make a pickup to be sure everything is ok. Clean PU at 24 klbs. Free spin 3970 psi at 1.56 bpm. 1.56/1.54. PU 200', run back to bottom to resume drilling cement. To many stalls at 9929 ft with out WOB and to close to the 2.75" D nipple at 9,921 or 9,928 ft, POOH, open EDC and circulate at max rate POOH Changed out bit to used 2.74" D331 mill. BC bit looked OK some metal shaving on the BHI's CCL tool. RIH to tie-in Started tie-in at 9200 ft down. Logged CCL and no correction Closed EDC RIH to tag TOC Tagged at 9,927.7 ft, Drilling cement at 1.5 / 1.50 bpm Stalled at 9,927.2 ft D Nipple PU and working to get started 9927.13 ft Drilling cement at 0.3fpm / 18 fph Visted by the CAPI VP of HSE Dale Summerline PUH and log lower TT to confirm the jewerly Logged from 9,800 ft to 9,948 ft. -1 ft correction Drilling Cement and pumped 1 5 bbl Op = 1.64 / 1.64 bpm F'Mtetl: a/ll/2008 12:4U:41 F'M • BP AMERICA Page 3 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: i Date ', From - To Hours ~ Task ~ Code NPT i Phase Description of Operations 2/29/2008 14:43 - 15:05 0.37 CLEAN N DPRB WEXIT PUH to 9400 ft to tiein CCL to GR for sidetrack 15:05 - 16:58 1.88 CLEAN N DPRB WEXIT Logging down with GR to 9,927ft. Corrected +0.5 ft and RIH and tagged bottom at 9,961.27 ft Drilled cement to 9.963 ft 16:58 - 18:30 1.53 CLEAN N DPRB WEXIT POOH with open EDC 18:30 - 19:00 0.50 CLEAN N DPRB WEXIT Hold PJSM while POH to discuss BHA swap. Discuss hazards and mitigations. Continue POH. 19:00 - 19:15 0.25 CLEAN N DPRB WEXIT Change out BHA #2, straight motor and D331 mill. Mill recovered at 2.74". 19:15 - 20:00 0.75 STWHIP P WEXIT Change motor AKO to 1.75 deg. Pick up new D331 mill. Stab injector, shallow hole test BHA. 20:00 - 22:00 2.00 STWHIP P WEXIT RIH with BHA #3 to drill pilot section of hole. 22:00 - 22:10 0.17 STWHIP P WEXIT Log tie in pass over GLM at 9248'. Make +1' correction. 22:10 - 23:15 1.08 STWHIP P WEXIT Make reaming passes to remove any possible cement sheath in tubing tail. Make 4 passes, 1 every 90 deg from 9880' to 9963'. Pump 2 high vis sweeps to carry possible debris OOH. Circulate until bottoms up from last sweep. No excess large debris spotted in sweeps, but did get a lot of cement fines. 23:15 - 23:45 0.50 STWHIP P WEXIT Make a GR tie in pass down to tie into the Gamma Ray from the PDC log. Discuss tie in. Confidence of tie in from GR to PDC log is low. The GR is much higher in amplitude on this log vs PDC log. Make +3' correction. 23:45 - 00:00 0.25 STWHIP P WEXIT Call town engineer to discuss. We will make an additional tie in pass with CCL accross the tubing tail detail and correlate that to the collar/GR log that was faxed up showing the tubing jewalry on depth to the PDC log. 3/1/2008 00:00 - 00:15 0.25 STWHIP P WEXIT Log CCL depth down from 9800' to 9963'. Compare to faxed log showing on depth tubing jewalry. Log is on depth. 00:15 - 03:15 3.00 STWHIP P WEXIT Orient to low side. Pumps to full rate. Free spin 3750 psi at 1.6 bpm. Tao at 9962'. Begin milling pilot hole. Rate 1.53/1.54/3650 psi. PVT 376 bbls. IAP=330 psi, OAP=277 psi. DHWOB=2600 lbs. ECD with bio in hole = 11.45 ppg (3800 psi.) Initial ROP= 18 fph. Wt check up = 23 klbs clean. Continue milling. 03:15 - 05:00 1.75 STWHIP P WEXIT Continuing to mill. Pumping a 5 bbl high vis sweep every half hour. Getting good cement back accross the shaker. ROP 10-15 fph. Milling compitent hard cement in the pilot hole. IAP=393 psi, OAP=280 psi. TF = 180 deg. DHWOB=2850 lbs. Milling at 1.55/1.59/4140 psi. PVT = 399 bbls. 05:00 -12:00 7.00 STWHIP P WEXIT Continuing to mill hard cement. 10-15 fph. !ts slow at 10,023 ft, BHA is in some what of a bind. Having some trouble getting past 10,023 ft. Finally worked past. Between 10,033 ft and 10,035.5ft, the ROP increased to 0.5 fpm and then back to 8-10 fph. Compressibility of cement reduced again between 10,035.8 to 10036.1 ft. (Zero motor work). back to hard cement at 10,036.2 ft. Op = 1.53 / 1.53 bpm Pt = 3739 / 3825 psi VP = 374 bbl 12:00 - 14:45 2.75 STWHIP P WEXIT Continuin to mill hard cement. 10-15 fph. Op = 1.53 / 1.53 bpm Pt = 3739 / 3825 psi VP = 374 bbl 14:45 - 15:10 0.42 STWHIP P WEXIT PUH and reamed the pilot hole clean to 9963 ft Printed: 4/11/2008 12:40:41 PM 3~~ l~-~ 3 BP AMERICA Page 4 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To 'Hours Task I Code NPT Phase Description of Operations 3/1/2008 15:10 - 16:40 1.50 STWHIP P WEXIT Milling cement ramp from 10,052 ft to 10,060 ft Op = 1.54 / 1.59 bpm Pt = 3780 / 4028 psi VP = 381 bbl ROP 5-11 fph Stopped at 10,060 ft and WOB won't drill off, the TF is not erratic. 16:40 - 17:00 0.33 STWHIP P WEXIT PU reaming ramp and pilot hole with HS TF 17:00 - 18:00 1.00 STWHIP P WEXIT RIH and log CCL down at 1,000 fph from 9,800 ft 18:00 - 18:40 0.67 STWHIP P WEXIT Back ream top of cement/tubing tail area with high side and 45 deg left and right of high side tool face. 18:40 - 20:15 1.58 STWHIP P WEXIT Run back to 10060'to confirm no debris left in the hole from back reaming. Clean to TD, POOH pumping at full rate. 20:15 - 20:45 0.50 STWHIP P WEXIT PJSM while POH to discuss BHA swap out. Discuss hazards and mitigations. 20:45 - 21:45 1.00 STWHIP P WEXIT Tag up at surface. Check well for flow. No flow observed. Stand back injector. Lay down 1.75 deg adjustable AKO motor and D331 mill. Pickup BHA #4, 2.5 deg fixed AKO WF mud motor and HCC 1 step window mill with brass guide ring. 21:45 - 22:00 0.25 STWHIP P WEXIT Stab injector. RIH, shallow hole test BHA. All working ok. Continue RIH. PVT=361 bbls. IAP=435 psi, OAP=289 psi. Pumping at 0.5 bpm thru an open EDC. 22:00 - 22:30 0.50 STWHIP P WEXIT Pre spud meeting while running in the hole. Held meeting with all hands on night tour. 22:30-23:30 1.00 STWHIP P WEXIT ContinueRlH. 23:30 - 23:45 0.25 STWHIP P WEXIT Log GR tie in pass down from 9600' with pumps off. Make -4' correction. 23:45 - 00:00 0.25 STWHIP P WEXIT Orient to low side tool face. RIH thru tubing tail. Orient to high side tool face. RIH and dry tag at 10063.5'. Pick up 6'. Kick ~~ on pumps to full rate. Free spin is 4000 psi at 1.52 bpm. RIH and tag at 10062.49. Pick up 1'. Flag pipe. Change depth to 10059.0'. 3/2/2008 00:00 - 01:00 1.00 STWHIP P WEXIT PVT=396 bbls. IAP=420 psi, OAP=277 psi. aint new ag on pipe due to BHA length change from pilot hole milling run. Be in time millin se uence. Free spin 1.52/1.52/3955 psi. DHWOB = -140 lbs. 01:00 - 02:00 1.00 STWHIP P WEXIT 10059.1', DHWOB=-80 Ibs, IAP=470 psi, OAP=280 psi. PVT=395 bbls. 1.52/1.53/3850 psi. 02:00 - 03:00 1.00 STWHIP P WEXIT 10059.3', DHWOB= 70 Ibs, IAP=490 psi, OAP=282 psi. _ ~ PVT=394 bbls. 1.52/1.53/3950 psi. 03:00 - 04:00 1.00 STWHIP P WEXIT 10059.5', DHWOB=250 Ibs, IAP=502 psi, OAP=283 psi. (j~y~ ~ PVT=393 bbls. 1.52/1.54/3980 psi. ~ 1_ ~ 04:00 - 05:00 1.00 STWHIP P WEXIT 10059.8', DHW06=1100 Ibs, IAP=510 psi, OAP=284 psi. PVT=392 bbls. 1.53/1.53/4050 psi. ~,`-~~ 05:00 - 07:00 2.00 STWHIP P WEXIT 10060.0', DHWOB=1400 Ibs, IAP=522 psi, OAP=284 psi. PVT=392 bbls. 1.52/1.54/4150 psi. 07:00 - 10:55 3.92 STWHIP P WEXIT Time milling window as per procedure Seeing WOB and motor work at each segment slacked off. At 10061.7 ft seen a 120 psi drop and WOB dropped off at 10061.7 ft which is the bottom of th w' Op = 1.53 / 1.53 bpm at a CTP fo 3850 / 4182 psi BHP = 3890 psi at 11.60 ppg ECD IA/OA 537 / 287 psi Printed: 4/11/2008 12:40:41 PM i • BP AMERICA Page 5 of 36 ~ Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 10/2/1988 Start: 2/1 /2008 End: 3/31 /2008 Rig Release: 3/31/2008 Rig Number: Date From - To Hours ~ Task II Code NPT ' Phase Description of Operations 3/2/2008 107:00 - 10:55 I 3.921 STWHIPI P 10:55 - 11:48 I 0.881 STWHIPI P 11:48 - 12:30 I 0.701 STWHIPI P 12:30 - 13:00 I 0.501 STWHIPI P 13:00 - 13:20 I 0.331 STWHIPI P 13:20 - 14:53 I 1.551 STWHIPI P 14:53 - 15:15 0.37 STWHIP P 15:15 - 15:40 0.42 STWHIP P 15:40 - 16:05 I 0.421 STWHIPI P 16:05 - 16:30 0.42 STWHIP P 16:30 - 18:15 1.75 STWHIP P 18:15 - 18:30 0.25 STWHIP P 18:30 - 19:00 ~ 0.501 STWHIPI P 19:00 - 19:30 I 0.501 STWHIPI P 19:30 - 19:45 I 0.251 STWHIPI P 19:45 - 21:30 1.75 STWHIP P 21:30 - 22:10 0.67 STWHIP P 22:10-23:00 ~ 0.83~STWHIPP 23:00 - 23:30 I 0.501 STWHIPI P WEXIT WOB 1.60 to 2.OOklbf Vp = 391 bbl WEXIT Finished time drill schdule at 10,063.1 ft Drill formation at 6 fph Op 1.52 / 1.52 bpm CTP 4072 psi DHBHP = 3888 psi at 11.60 ppg WEXIT PUH and back ream window area to 9,900 ft RIH with milled TF and cleanout to bottom. Op = 1.52 bpm at 3,933 psi RIH and tagged at 10,067.8 ft WEXIT PUH with milled toolface. Change at 10,052 ft from HS to LS PUH to 9800 ft WEXIT RIH and log for tie-in. Corrected (+6 ft) RIH and tagged the bottom at 10 073 ft corrected. WEXIT PUH and make ready to swap to 9.3ppg flo-pro. Mud swap, sample not conclusive on formation. PUH and tie-in to GR WEXIT Tie-in to GR at 9560 ft and corrected 0.5 ft at 9612 ft WEXIT RIH to reconfirm TD and sample conformation Tagged bottom at 10,069 ft WEXIT Drill formation for putside casing conformation Op =1.50 / 1.51 bpm TF at HS, seeing reactive torque BHP = 4042 psi at 12.04 ppg ECD (Note: 9.3ppg all the way around) WEXIT PUH and have Geologist check samples 50-70% Formation WEXIT POOH to PU crayola WEXIT Hold PJSM while POH to discuss BHA swap. Discuss hazards, plan forward, and mitigations to hazards. WEXIT Check well for flow. No flow observed. OH undeploy BHA. Lay down mill and motor from BHA #4. Mill showed a wear pattern that is somewhat non-typical fora 1 step mill that has produced a good window. The mill gauged 2.72" go, 2.71" ~ no-go, with significant edge wear, some wear on the face, but without the typical swirl pattern at the mill face center. Cuttings indicate that we have exited into the formation. Call town and discuss. WEXIT Hold Safety meeting with night crew that just came on tour from days off. Review Pre tour tech limits notes. Discuss plan forward, hazards of deploying new BHA, and mitigations to hazards. WEXIT Pick up BHA #5, BHI 1.75 deg adjustable AKO mud motor and W F crayola mill. (Used, with a 2.73" OD). Stab on injector. Shallow hole test MWD tools. All check ok. WEXIT RIH with BHA #5. WEXIT Log tie in pass down over GR character at 9500-9600'. Make a -4' correction. Orient low side, run thru the tubing tail slick, orient high side, and run down the pilot hole and ramp slick. Dry tag at 10062.7. Pick up 5'. WEXIT PU dry at 29 klbs. Confirm high side orientation. Kick pumps on to full rate. Free spin 3250 psi at 1.52 bpm. DHWOB = 70 lbs. Pumping at 1.52/1.5/3250, ease down and dress window. First motor work at 10061.85. Ream down slowly and let mill do its thing. Good motor work at 10062.7, 10062.9. WEXIT Difficult to get past 10062.9. Try to time mill down thru it. It is Printed: 4/11/2008 12:40:41 PM BP AMERfCA Page 6 of 36 Operations Summary.. Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To .Hours Task Code' NPT Phase Description of Operations.. 3/2/2008 23:00 - 23:30 0.50 STWHIP P WEXIT grabby and keeps stalling at this depth. Ream thru. Ream down and tag TD at 10070.9'. 23:30 - 00:00 0.50 STWHIP P WEXIT Back ream up thru window at 30 deg L and R of high side. 3/3/2008 00:00 - 01:30 1.50 STWHIP P WEXIT Continue to backream window at high side +/- 30 deg. Dry drift window clean with TF high side. Tag bottom with pumps on. Pump 20 bbl sweep. 01:30 - 03:40 2.17 STWHIP P WEXIT POH following the pressure schedule. Although the well shows no pressure, from this point on the rig will folllow the pressure 3:40 - 04:15 .58 TWHIP P EXIT Note - Caught a bottoms up sample prior to POH. The rig geologist confirms that the sample does contain formation cuttings consistent with the formation we expected to exit in at the window. Tag up at surface. Circulate down the coil and thru the EDC while conducting a safety meeting to discuss pressure undeploying the crayola BHA. This is the first time this Vear that a pressure unde to has been made. Holdin 790 si on wellhead. Review the undeploy proceedure step by step. Make job assignments, and discuss expectations. 04:15 - 06:00 1.75 STWHIP P WEXIT Undeploy BHA #5, crayola mill BHA, using the undeploy proceedure and the circulating loop pressure maintenance system. Holding 790 psi on wellhead. 06:00 - 06:30 0.50 STWHIP P WEXIT Pull BHA out of well. Lost Pulsation damper on MP2. Open manifold and circulate CT. 06:30 - 09:30 3.00 STWHIP N RREP WEXIT Repair Pulsation Damper on MP#1 and (MM2) Mud Manifold Valve # 2 Unable to isolate MP#1, SD circulating CT and repair MM2 09:30 - 09:45 0.25 STWHIP P WEXIT Held PJSM and discussed on howing to manage you time better. Discussed plan forward 09:45 - 10:00 0.25 STWHIP P WEXIT Pull BHA out of well and RD motor. Visually inspect crayola mill - good. 10:00 - 13:00 3.00 DRILL N RREP PROD1 PT the mud manifold valves needed for the MPD that caused the problems early Working to pressure testing MP1 and MP 2 valves Found MM#1 leaking Repair MM1 and PT same 13:00 - 14:15 1.25 DRILL P PROD1 PJSM on BHA handling. PU 2.4 AKO motor with HYC BC bit. Confirmed scribe line. Stabbed injector and RIH 142 ft. 14:15 - 15:10 0.92 DRILL P PROD1 Pressured up on the wellhead to 800 psi.. Closed SSSV and bleed off wellhead presure through the choke. 15:10 - 16:42 1.53 DRILL P PROD1 RIH following pressure schedule 16:42 - 17:30 0.80 DRILL P PROD1 Log tie-in starting at 9568 ft Corrected -4.5 ft 17:30 - 17:45 0.25 DRILL P PROD1 RIH and turned TF to LS at 9963 ft, Turned TF to HS at 10,052 ft. 17:45 - 18:00 0.25 DRILL P PROD1 Ta ed bottom at 10,070 ft. Window clean - PU and start the build section Op = 1.56 / 1.56 bpm at 3,600 psi off bottom Set TF HS to achieve the desired BR of 40 deg /100 ft Vp = 371 bbl DHBHP = 4,059 psi / 12.10 ppg 18:00 - 19:10 1.17 DRILL P PROD1 Drill build section. PVT=372 bbls. Free spin 3580 psi at 1.5 bpm. Drilling at 1.56/1.56/3700 psi. TF=O deg. ROP= 30 fph. ECD=12.06. WHP=O, BHP=4060 psi. IAP=466 psi, OAP=273 Printed: 4/ 71 /2008 12:40:41 I' M • r BP AMERICA Page 7 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From- To Hours Task Code NPT Phase Description of Operations 3/3/2008 18:00 - 19:10 1.17 DRILL P PROD1 psi. DHWOB=2330 lbs. 19:10 - 22:45 3.58 DRILL P PROD1 Started having losses. Drilling at 1.57/1.26/3770 psi. Losses 22:45 - 00:00 ~ 1.25 ~ DRILL ~ P PROD1 3/4/2008 00:00 - 00:35 0.58 DRILL P PROD1 00:35 - 01:05 0.50 DRILL P PROD1 01:05 - 02:30 1.42 DRILL P PROD1 02:30 - 03:05 0.58 DRILL P PRODi 03:05 - 03:45 ~ 0.67 ~ DRILL P ~ ~ PROD1 03:45 - 06:00 2.25 DRILL N HMAN PROD1 06:00 - 07:30 1.50 DRILL P PROD1 07:30 - 11:00 3.50 DRILL P PROD1 11:00 - 13:00 2.00 DRILL P PROD1 13:00 - 13:20 0.33 DRILL N DFAL PROD1 13:20 - 14:20 ~ 1.00 ~ DRILL ~ P ~ ~ PROD1 14:20 - 15:15 0.92 DRILL P PROD1 15:15 - 17:00 1.75 DRILL P PROD1 improved after drilling another 20'. 1 for 1 returns after 1/2 hour. Well is landed. POH for lateral section motor. Discuss with town engineer. Decide to pick up 0.8 deg dogleg to drill as straight a hole as possible near the parent wellbore since this is an extended reach target. Clean PU off bottom at 24 klbs. Clean in build section. Clean thru window and pilot hole. Open EDC and pump following choke schedule while POH. Continue pulling out of the hole while pumping at full rate thru an open EDC. Tag up at surface with BHA. Hold PJSM to discuss pressure undeploying BHA #7, the build section BHA. Review proceedure. Note operational difficulties we had yesterday when we did this same proceedure. Discuss hazards and mitigations to hazards. Make job assignments, and confirm that individuals are comfortable in the tasks. Pressure undeploy BHA #7 following circulating loop proceedure. PJSM: BHA hung up accross stack when being picked up by stickling. Can't go up or down. Heel of motor at tubing hanger profile. Suspect wear pad on motor. (Again) Hold PJSM to discuss plan for getting BHA OOH. Shut SSSV. Bleed lubricator to 0, and monitor well for flow. No flow observed. Break lubricator and pick up with blocks. Turn BHA with a pipe wrench and pick up to rig floor. Lay down MWD BHA, bit and motor. During pressure undeploy found an apparent leak on valve on mud manifold. Pressure tested and it held fine. Suspect an alternate flow path around valve due to the circulating loop or charge pump. Investigate. Held PJSM and discussed Pressure Deploying BHA and assigned task to crew members Pressure Deploy lateral BHA #1 (BHA #7) as per procedures. Worked through procedure the first time using the MPD loop. Made adjustmernt to procedures. Set counter at 71.67 ft RIH following MPD Graph Tie-in at 9560 ft and corrected -3 ft. Trying to close the EDC and failed to do so. Working to confirm the closural of the EDC. Unable to fix problem, need to POOH. Circulated and balance out the wellhead pressure to the required BHP POOH circulating across the top maintaining the correct BHP using the surface pressure. Sorted out EDC problem after a few minutes. RIH with BHA at correct TF Tagged bottom and started drilling. Got a small amount of gas cut mud back. Circulated it to the tiger tank and held 150 psi on the wellhead. Gas cut mud cleaned up fairly quickly. Opened the choke, took returns back to the pits and resumed Printetl: 4/11/2008 12:40:41 PM • BP AMERICq Page 8 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ~'I NPT ~ Phase ~ Description of Operations 3/4/2008 15:15 - 17:00 1.75 DRILL P PROD1 drilling. Drilling at 1.59/1.51/4070 psi. Free spin 3830 psi ~ 1.59 bpm. PVT=304 bbls. Called for a vac truck of new mud to top off pits. DHWOB=1700 lbs. ECD=12.16 ppg. Annulus pressure = 4116 psi. ROP=110 fph. 17:00 - 17:20 0.33 DRILL P PROD1 Saw a loss of returns at 10200'. Drilling at 1.51/1.2. Returns slowly healing. 17:20 - 17:45 0.42 DRILL P PROD1 Wiper trip to window. RIH, tagged up at 10109', and bounced thru. Run back to bottom smooth. 17:45 - 19:15 1.50 DRILL P PROD1 Resume drilling. ROP 70 fph. Drilling at 1.54/1.47/4200 psi. PVT=308 bbls. IAP=376 psi, OAP=271 psi. ECD=12.31 ppg. DHWOB=1200 lbs. 19:15 - 19:50 0.58 DRILL P PROD1 Drill lateral at 1.54/1.49 bpm, 4000 psi, 100 fph ROP, 1.2K DHWOB, 87 deg incl, 90L TF, 12.3 ECD, 450 bbls PVT. Drill to 10494'. 19:50 - 20:10 0.33 DRILL P PROD1 Wiper trip to window. Hole clean. 20:10 - 21:50 1.67 DRILL N RREP PROD1 Troubleshoot leaking pump cap on pump 1. Replace swabs. Orient highside, SD pumps, PU into tubing tail while holding 800 psi WHP on choke. Circ at 0.2 bpm w/ 800 psi WHP at 9950' while completing repairs on mud pump 1. RIH to outside of window. 21:50 - 22:10 0.33 DRILL P PROD1 RIH, MAD Pass from 10070' - 10154' to re-log resistivity. 22:10 - 22:25 0.25 DRILL P PROD1 RIH clean to bottom. 22:25 - 23:20 0.92 DRILL P PROD1 Drill lateral at 1.57/1.53 bpm, 3950 psi, 70-85 fph ROP, 0.8K DHWOB, 85 deg incl, 30L TF, 12.2 ECD, 428 bbls PVT. Drill to 10560'. 23:20 - 00:00 0.67 DRILL P PROD1 Drill A lateral at 1.61/1.57 bpm, 4200 psi, 100 fph ROP, 1.6K DHWOB, 86 deg incl, 60L TF, 12.3 ECD, 427 bbls PVT. Drill to 10625'. 3/5/2008 00:00 - 00:15 0.25 DRILL P PROD1 Drill A lateral at 1.61/1.54 bpm, 4000-4200 psi, 100 fph ROP, 1.3K DHWOB, 87 deg incl, 75L TF, 12.4 ECD, 425 bbls PVT. Drill to 10650'. 00:15 - 00:40 0.42 DRILL P PROD1 Wiper trip to window. Hole clean. 00:40 - 01:30 0.83 DRILL P PROD1 Orient HS, hold 900 psi WHP on choke, S/D pumps, P/U thru window. Log GR tie-in, +6' correction. 01:30 - 02:30 1.00 DRILL P PROD1 RIH clean to bottom. 02:30 - 03:15 0.75 DRILL P PROD1 Drill lateral section at 1.51/1.44 bpm, 4000 psi, 100 fph ROP, 1.3K WOB, 87 deg incl, 90L TF, 12.2 ECD, 403 bbls PVT. Drill to 10730'. Not getting quite the turn we need, averaging 7.4 deg / 100 ft. 03:15 - 04:00 0.75 DRILL P PROD1 Drill lateral at 1.56/1.50 bpm, 4000 psi, 85-100 fph ROP, 1.5K WOB, 88 deg incl, 80L TF, 12.3 ECD, 399 bbls PVT. Drill to 10800'. 04:00 - 04:30 0.50 DRILL P PROD1 Wiper trip to window. Discuss w/ town and decide to POH for higher bend motor. At current turn rate we will not be able to stay in polygon w/ 0.8 deg motor. 04:30 - 06:30 2.00 DRILL P PROD1 POOH following pressure schedule. 06:30 - 08:45 2.25 DRILL N RREP PROD1 Tag up at surface. Close kill HCR and manual valve on tree. Replace leaking 2" Rubber kill like hose with 3" high pressure hose with graylock hardline on each end. PT same to 250 and 4500 lbs. Passed ok. 08:45 - 11:00 2.25 DRILL N RREP PROD1 PT on hose passed, but found leak on mud manifold valve #8. Install a jumper hose around mud manifold to isolate it. Rebuild mud manifold valve #8. PT valve to 250 and 4500 psi. Printed: 4/11/2008 12:40:41 PM BP AMERICA Page 9 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To 'Hours Task Code NPT Phase ~ Description of Operations 3/5/2008 08:45 - 11:00 2.25 DRILL N RREP PROD1 Passed ok. 11:00 - 11:30 0.50 DRILL P PROD1 PJSM Re; Pressure undeploying BHA #7. 11:30 - 14:45 3.25 DRILL P PROD1 Pressure undeploy BHA #7 following the circulating loop undeployment proceedure. Shut down for SLB crew change and resumed after a short safety meeting. 14:45 - 16:15 1.50 BOPSU P PROD1 Perform weekly function test of BOPE. All functioned properly. Perform electrical check out of new BHI BHA on catwalk. 16:15 - 16:40 0.42 DRILL P PROD1 PJSM Re: pressure deploying next lateral section BHA. 16:40 - 18:00 1.33 DRILL P PROD1 Pressure deploy BHA #8, which is the second lateral section BHA on the "A" lateral. Bit is a new hycalog BC bit, Motor bend is 1.1 deg. Full MWD BHA. Deployment made following the new circulating loop deployment proceedure. 18:00 - 18:20 0.33 DRILL P PROD1 Crew Change. Hold PJSM for continuing pressure deployment procedure. 18:20 - 19:45 1.42 DRILL P PROD1 Finish pressure deploying "A" lateral drilling BHA #8. 19:45 - 21:30 1.75 DRILL P PROD1 RIH w/ BHA #8, "A" lateral drilling BHA #2 following pressure schedule. 21:30 - 21:45 0.25 DRILL P PROD1 Tie-in to GR at 9575'. -5' correction. 21:45 - 22:45 1.00 DRILL P PROD1 RIH clean thru window w/ no pumps. RIH to bottom. Hole clean. 22:45 - 00:00 1.25 DRILL P PROD1 Drill "A" lateral at 1.44/1.41 bpm, 3750-3900 psi, 65-85 fph ROP, 1.4K WOB, 90 deg incl, 75L TF, 12.3 ECD, 343 bbls PVT. Drill to 10876'. 3/6/2008 00:00 - 01:00 1.00 DRILL P PROD1 Drill "A" lateral at 1.6/1.5 bpm, 4150 psi, 100 fph ROP, 1 K WOB, 91 deg incl, 60L TF, 12.4 ECD, 343 bbls PVT. Drilled to 10950'. 01:00 - 02:00 1.00 DRILL P PROD1 Wiper trip to window. Hole clean. 02:00 - 03:15 1.25 DRILL P PROD1 Drill lateral at 1.57/1.53 bpm, 4000 psi, 75 fph ROP, 1.4K WOB, 89 deg incl, 120E TF, 12.4 ECD, 337 bbls PVT. Drilled to 11025'. 03:15 - 04:20 1.08 DRILL P PROD1 Drill lateral at 1.57/1.51 bpm, 3800 psi, 75 fph ROP, 1 K WOB, 89 deg incl, 75L TF, 12.4 ECD, 393 bbls PVT. Drilled to 1 10 '. Getting higher than expected doglegs with 1.1 deg motor, averaging 19.5 deg / 100 ft. 04:20 - 05:45 1.42 DRILL P PROD1 Wiper trip to window. RIH to bottom. Hole clean. PVT 438 05:45 - 07:45 2.00 DRILL P PROD1 Drill from 11100' 1.56/1.50/3820/1008 w/ 100-300 psi dill, 1.0-2.Ok wob w/ 12.39 ECD at 89.5 deo at 6532' TVD , 60-120'/hr. Begin planned drop from 11200' and drill to 11250' 07:45 - 08:25 0.67 DRILL P PROD1 Wiper to window was clean PVT 424 08:25 - 08:35 0.17 DRILL P PROD1 Log tie-in down from 10120' to open hole high GR marker at 10103' (mainly to avoid pulling the bit thru the cement ramp window, but also to save time to/from only other tie-in spot at -9500'). Add 5.5' 08:35 - 09:15 0.67 DRILL P PROD1 Wiper back to TD was clean PVT 425 09:15 - 12:30 3.25 DRILL P PROD1 Drill from 11251' 1.57/1.51/3830/1208 w/ 200-300 psi dill, 1.0-2.Ok wob at 12.36 ECD at 85 deg from 6536' TVD at 60-120'/hr. Swap to left at 11380' and drill to 11400' PVT 410 12:30 - 14:10 1.67 DRILL P PROD1 Wiper to window was clean both directions PVT 405 14:10 - 17:50 3.67 DRILL P PROD1 Drill from 11400' 1.56/1.51/3830/45L w/ 100-250 psi dill, 1.0-1.9k wob at 12.30 ECD at 83 deg. Determine we are >10' TVD deeper than planned, so point TF up to get back to plan. Drill to 11550' PVT 390 17:50 - 19:45 1.92 DRILL P PROD1 Wiper to window. Hole clean. Printed: 4/11/2008 72:40:47 PM ~ ~ BP AMERICA Page 10 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date 'From - To Hours Task Code NPT ! Phase Description of Operations 3/6/2008 19:45 - 21:15 1.50 DRILL P PROD1 Drill lateral at 1.56/1.53 bpm, 3970 psi, 60 fph ROP, 1.4K WOB, 95 deg incl, 90L TF, 12.2 ECD, 371 bbls PVT. ROP dropped to 40 fph at 11574'. Drilled to 11605'. 21:15 - 23:30 2.25 DRILL P PROD1 Drill lateral at 1.57/1.53 bpm, 3850 psi, 40 fph ROP, 1 K WOB, 93 deg incl, 75L TF, 12.2 ECD, 362 bbls PVT. Drilled to 11710'. 23:30 - 00:00 0.50 DRILL P PROD1 Wiper trip to window. 3/7/2008 00:00 - 00:45 0.75 DRILL P PROD1 Continue wiper trip to window. Hole clean. 00:45 - 01:00 0.25 DRILL P PROD1 Log tie-in to GR marker at 10103'. +9' correction. 01:00 - 01:50 0.83 DRILL P PROD1 RIH clean to bottom 01:50 - 04:10 2.33 DRILL P PROD1 Drill lateral at 1.59/1.56 bpm, 4100 psi, 60 fph ROP, 1.2K WOB, 92 deg incl, 1208 TF, 12.4 ECD, 300 bbls PVT. Getting some gas back to surface, send returns to tiger tank. Hold 75 psi WHP w/ choke. No indication of crossing projected fault #3. Building at 92 deg incl tot and et back in a zone. Drilled to 11850'. 04:10 - 06:00 1.83 DRILL P PROD1 Wiper trip to window. RIH to bottom. Hole clean. 06:00 - 07:35 1.58 DRILL P PROD1 Drill from 11850' 1.59/1.56/4000/908 w/ 100-200 psi dill, 1.0-1.5k wob w/ 12.60 ECD holding 75 psi whp at 95 deg. Drill to 11875' and get some gas back. Incr whp to 150 psi. Drill ahead w/ 12.9 ECD and take returns to tiger tank 07:35 - 07:50 0.25 DRILL P PROD1 Open choke to full open and drill from 11930' 1.58/1.55/4000/858 w/ 12.58 ECD and take returns back inside after shipping 100 bbls gas cut used mud to tiger tank. That was short lived! Drill to 11937' and started aettinq more nas 07:50 - 08:55 1.08 DRILL P PROD1 Slow wiper up hole during AM call to circ out gas to tiger tank. Incr back ressure to 200 si to tar et 13.0 E D after findin out we are close to MI in'ectors that have hi h in' ressure. Veriif that in'ectors have been SI. Take all used mud to tiger tank Second conference call- Will resume drilling. After crossing next fault will trip for lesser bend motor Will et MI to mix emer enc KWF w/ barite to +/-14.0 old on location in a vac truck Will weight up fresh mud from 9.3# to 9.8# on location so we can drill with open choke Will target 13.0 ppg ECD unless conditions change 08:55 - 09:55 1.00 DRILL P PROD1 Resume drilling 1.59/1.45/4030/908 holding 200-250 psi whp to target 13.0 ECD while swap to fresh 9.3# FloPro mud. See returns from drilling with 12.9 ECD cut from 9.3 ppg to 8.65 ppg and then stabilized at 9.24 ppg. Revise target to 13.1 ECD. Drill to 12000' 09:55 - 11:05 1.17 DRILL P PROD1 Wiper to window while finish swap to new mud was clean. Adjust choke to maintain 13.0 ppg min ECD and were at 475 psi whp at the window and losing -0.20 bpm 11:05 - 12:05 1.00 DRILL P PROD1 Wiper back to TD while offload last of fresh mud into the pits. Hold min 13.0 ECD while RIH. Had one set down at 11750' 12:05 - 13:30 1.42 DRILL P PROD1 Drill from 12000' 1.58/1.50/4000/90L w/ 300 psi induced whp w/ 100-300 psi dill, 0.8-2.0 k wob w/ 13.1 ECD. See returns from bottoms up at 9.15 ppg. Begin weighting up the fresh 9.3 ppg mud to 9.8 ppg Printetl: 4/11/LUUki l"L:4U:41 YM ~ ~ BP AMERICA Page 11 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date .From - To Hours Task Code NPT ~ Phase Description of Operations 3/7/2008 13:30 - 13:55 0.42 DRILL P PROD1 After a period of fast drilling and at 12115' the out density had 13:55 - 15:10 1.25 DRILL P PROD1 15:10 - 15:50 0.67 DRILL P PROD1 15:50 - 17:50 2.00 DRILL P PROD1 17:50 - 18:10 0.33 DRILL P PROD1 18:10 - 18:30 0.33 DRILL P PROD1 18:30 - 20:00 1.50 DRILL P PRODi 20:00 - 21:00 1.00 DRILL P PROD1 21:00 - 21:15 0.25 DRILL P PROD1 21:15 - 23:30 2.25 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 3/8/2008 00:00 - 01:10 1.17 DRILL P PROD1 01:10 - 01:25 0.25 DRILL P PROD1 01:25 - 03:00 1.58 DRILL P PROD1 03:00 - 04:15 1.25 DRILL P PROD1 04:15 - 06:40 2.42 DRILL P PROD1 06:40 - 09:10 2.50 DRILL P PROD1 09:10 - 09:55 0.75 DRILL P PROD1 09:55 - 14:00 4.08 DRILL P PROD1 14:00 - 17:05 3.08 DRILL P PROD1 fallen to 9.15 ppg. Incr whp to 350 psi and maintain 13.3 ECD, then go to 375 psi whp to hold 13.4 ECD. Out density slowly rose while drilling w/ 1.60/1.46/4100/40L. Becoming more difficult to slide. Drilling in fast spurts w/ -5k surface wt to get 1.Ok wob w/ no sign of fault. Will need agitator soon. Drill to 12150' and return density is up to 9.45 ppg w/ 13.45 ECD w/ 1.60/1.48 Wiper to window was clean while maintaining 13.4 ECD Close choke, SD pump and trap 1300 psi whp. Pull thru window, clean. Park at 9950' and monitor downhole pressure for 20 min and was close to stabilizing at 4170 psi or 12.6 ECD. Open EDC POOH circ thru EDC 1.6/3200 while follow pressure schedule for 13.1 ppg mud. Finish wt up of surface system to 9.8 ppg Park at 500' for crew change. Circ 1.0/0.90/2790 w/ 1100 psi whp PJSM for pressure undeploy of BHA #8. Pressure undeploy lateral drilling BHA #8 following the circulating loop MPD undeployment proceedure. UD drilling BHA. M/U BHI MHA. C/O injector pack-offs. PJSM for pressure deploying lateral drilling BHA #9. Pressure deploy lateral drilling BHA #9, which is the third lateral section BHA on the "A" lateral. Bit is a new hycalog BC bit, Motor bend is 0.9 deg. P/U new Agitator. Full MWD BHA. Deployment made following the new circulating loop deployment proceedure. RIH following pressure schedule Continue RIH with Latteral drilling BHA following pressure schedule Tie in to GR ~ 9550 correction + 1' Continue RIH through window to bottom. Drill lateral at 1.57/1.55 bpm, 4470 psi, 68 fph ROP, 1 K WOB, 90 deg incl, 60 L TF, 13.1 ECD, 342 bbls PVT. Holding 220 psi WHP, BHP at 4450 psi. Drilled to 12,185' started petting some ,gas to surface, Increased WHP to 275 psi, sent 34 bbls to tiger tank. In-density of 9.83 ppg, out of 9.56 ppg ECD. Increased to 13.3 ppg with annular press. Out density increased to 9.8ppg. Drill ahead to 12,215' Drill lateral at 1.57/1.5 bpm, 4500 psi, 50-65 fph ROP, 1.1 K WOB, 92 deg incl, 75 L TF, 13.3 ECD w/ 275 psi whp, w/ return density at 9.60 ppg avg. Acts like we are drilling in ankerite at times PVT 301 Wiper to window maintaining 13.4 ECD w/ choke was clean both directions. Had MW near TD at 12285' which was identified as ankerite PVT 281 Drill from 12300' 1.44/1.38/4400/40L-90L w/ 150-200 psi induced whp to give 13.4 ECD=4533 dhp. Drilling in spurts in hard/soft formation w/ 50-150 psi diff and w/ -3.5k surface wt to get 1.44k wob at 91 deg at -6512' TVD Drill ankerite from 12324' w/ 2.44k wob at 5'/hr. Find additional ankerite streaks while drilling to 12450' PVT 261 Wiper to window holding 13.4 ECD was clean both directions. Printed: 4/112UU8 lY:4U:41 PM ~ ~ BP AMERICA Page 12 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task i Code' NPT i Phase Description of Operations - 3/8/2008 14:00 - 17:05 3.08 DRILL P PROD1 MAD pass resistivity anomaly at 12282' and repeated okay PVT 256 17:05 - 18:45 1.67 DRILL P PROD1 Drill from 12450' 1.48/1.44/4400/90L w/ 175 psi induced whp to give 13.4 ECD=4550 psi dhp. Drill w/ 50-150 psi dill, 0.70-1.5k wob w/ -4.3k surface wt at 88 deg at 6507' TVD. Drilled to 12530' 18:45 - 20:30 1.75 DRILL P PROD1 Drill lateral at 1.4/1.4 bpm, 4250 psi, 40 fph ROP, 1 K WOB, 90 deg incl, 150E TF, 13.5 ECD, 256 bbls PVT. Holding 180 psi WHP, BHP at 4550 psi. Drilled to 12,600'. 20:30 - 22:10 1.67 DRILL P PROD1 Wiper trip to window, hole clean. 22:10 - 22:20 0.17 DRILL P PROD1 Tie-in to GR. +9' correction. 22:20 - 23:40 1.33 DRILL P PROD1 RIH clean to bottom. 23:40 - 00:00 0.33 DRILL P PROD1 Drill lateral at 1.4/1.4 bpm, 4250 psi, 40 fph ROP, 1 K WOB, 90 deg incl, 150E TF, 13.5 ECD, 256 bbls PVT. Holding 180 psi WHP, BHP at 4550 psi. Drilled to 12,625'. 3/9/2008 00:00 - 04:00 4.00 DRILL P PROD1 Drill lateral at 1.4/1.4 bpm, 4250 psi, 40 fph ROP, 0.5K WOB, 88 deg incl, 308 TF, 13.4 ECD, 232 bbls PVT. Holding 170 psi WHP, BHP at 4540 psi. C~ 12,730' 1.4/1.4 bpm, 4250 pst, 45 fph, 0.8K WOB, 91 deg incl, 85 R TF, 13.4 ECD, 235 bbls PVT. Holding 225 psi WHP, BHP 4530 psi. Started to have difficulty slidin .Drilled to 12,740' TMD 04:00 - 06:55 2.92 DRILL P PROD1 Wiper trip to window maintaining 13.5 ECD was clean both directions. Swap to fresh mud while RIH 06:55 - 08:30 1.58 DRILL P PROD1 Drill from tag at 12738' 1.53/1.51/4450/608 w/ 225 psi induced whp to give 13.52 ECD=4576 psi dhp. Drilling w/ 100-200 psi dill, 0.5-1.5k wob w/ -3.8k surface wt at 93 deg while trying to get higher in the Al and prepping to cross the next fault which is also expected to be upthrown Drill to 12811' w/fresh mud all the way around. GR is trending down and we appear to be back in a good sand again 08:30 - 08:45 0.25 DRILL P PROD1 10k overpull (twice) due to diff sticking at 12811'. Do a BHA wiper. Have trouble getting back to TD due to classic signs of lockup 08:45 - 10:30 1.75 DRILL P PROD1 Drill from 12811' w/ 1.52/1.50/4430/858 w/ 250 psi induced whp to give 13.50 ECD. Get bit digging in good sand and were able to make decent penetration rate again. Continue to build at 95 deg while drill to 12900' 10:30 - 12:15 1.75 DRILL P PROD1 Wiper to window maintaining 13.5 ECD was clean 12:15 - 12:30 0.25 DRILL P PROD1 Log tie-in down to GR at 10103', corr+9' 12:30 - 14:15 1.75 DRILL P PROD1 Wiper to TD tagged at 12906' was clean 14:15 - 15:45 1.50 DRILL P PROD1 Drill from 12906' 1.44/1.41/4380/808 w/ 275 psi induced whp to give 13.53 ECD. Drop TF to maintain 93 deg climb. Drill w/ 50-200 psi diff, w/ 0.7k wob w/ -6.6k surface wt. Drill to 12961' and GR has increased to 100 api. Having trouble getting wt to bit 15:45 - 16:25 0.67 DRILL P PROD1 After several P/U, were not able to get bit back to TD. Do a 300' wiper and can't get back in hole from 12660'. Reduce rate and creep in hole 16:25 - 18:40 2.25 DRILL P PROD1 Get bit drilling again at 12961' while sending additional 1.5% Lo Torque mud down the CT. New total concentration will be 5.5% tubes. Drill ahead at 1.37/1.30/4000/1308 w/ 200-275 psi induced whp to give 13.52 ECD. Getting 0.4k wob w/ -4.6k Printed: an vzoua u:ao:ai Pnn i ~ BP AMERICA Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Start: 2/1/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Page 13 of 36 ~ Spud Date: 10/2/1988 End: 3/31 /2008 Date From - To Hours !~ Task Code NPT Phase i Description of Operations 3/9/2008 16:25 - 18:40 2.25 DRILL P PROD1 surface wt. Drilled to 13037'. P/U due to dill sticking and having trouble getting bit back to TD. 18:40 - 20:30 1.83 DRILL P PROD1 P/U and do a 300' wiper. RIH and could not get back to TD. Wiper trip to window. Hole clean. 20:30 - 20:45 0.25 DRILL P PROD1 Tie-in to GR character at 10103'. +3' correction. 20:45 - 22:45 2.00 DRILL P PROD1 Wiper to bottom, Tag at 13,037. 22:45 - 00:00 1.25 DRILL P PROD1 Drill lateral at 1.33/1.24 bpm, 4020 psi cp, 20 fph ROP, 0.6k WOB, 92 deg incl, 85R TF 13.6 ECD, 242 PVT. Holding 250 psi WHP, BHP at 4590 psi. Havin troulble slidin .Drilled to 13 061' 3/10/2008 00:00 - 02:45 2.75 DRILL P PROD1 Drill "A" lateral from 13,061' ~ 1.36/1.35 bpm, 4120 psi cp, 54 fph ROP, .5k WOB, -6.5k surface weight. 92 deg incl, 75R TF 13.6 ECD, 241 PVT. Holding 250 psi WHP, BHP at 4600 psi. Drilled to 13,180' and reached lock up. 02:45 - 04:45 2.00 DRILL P PROD1 Wiper to window 04:45 - 04:50 0.08 DRILL P PROD1 RIH tie into GR ~ 10130 + 5 ft corection. 04:50 - 06:20 1.50 DRILL P PROD1 Wiper to TD was clean to 12960' 06:20 - 08:00 1.67 DRILL P PROD1 Struggle to get in hole from 12960'. Reduce rate and creep in hole. Injector keeps tripping out due to neg wt. Start 2 ppb beads. Work to 13078' by the time beads were at the bit. String wt gradually came back to zero after 30 bbls were out of the bit while still RIH at 3'/min and 1.3/3900. RIH to TD at 10'/min to to t F NAL DEPTH of 13181' ' 08:00 - 09:30 1.50 DRILL P PROD1 Wlper thru open hole while swapping wellbore to fresh 9.8 ppg Flo Pro mud mixed w/ 2 ppb Alpine beads in 5% tubes at 1.28/3800 at 37'/min while holding 13.5 ECD 09:30 - 11:30 2.00 DRILL P PROD1 Pulled thru window and cement ramp area clean w/ 23.5k which was 4.5k less than the last trip due to the beads. . POOH for liner while circ beaded mud thru bit 1.3/3800 following pressure schedule for 13.1 ECD. Tag up w/ 1171 psi whp w/ pump SD. Close TRSSSV. Bleed down pressure thru choke 11:30 - 11:45 0.25 DRILL P PROD1 Flow check IA 32, OA 289 11:45 - 12:45 1.00 DRILL P PROD1 LD drilling BHA. Bit was 3-1-I w/ chipped/partially missing nose cutters 12:45 - 13:00 0.25 CASE P LNR1 Safety mtg re: MU liner 13:00 - 14:30 1.50 CASE P LNR1 MU Unique Indexin Guide Shoe one solid 't O-rin ea 2-3/8". 4.41 #. L-80. R2. STL w/ BTT. Deolovment sleeve 14:30 - 15:20 0.83 CASE P LNR1 MU MWD assy. PT CTC C~ 4000. MU to liner assy. Stab on w/ injector. Begin circ at 0.29/0.25/2160 w/ 1200 psi induced whp. Open TRSSSV PVT 28 15:20 - 17:00 1.67 CASE P LNR1 RIH w/ liner on CT (BHA #10=1091.61' OA) circ thru GS 0.30/2200 while follow pressure schedule for 13.1 ECD. Lost power to MWD tools at 8500' due to the wrong blind sub being installed at the UOC. 17:00 - 18:10 1.17 CASE P LNR1 9900' 22.2k, 8,5k w/ 1100 psi whp RIH thru window clean following estimated pressure schedule for 13.5 ppg ECD. RIH w/liner in open hole circ 0.3/2080 holding 500-600 psi whp 11500' +6.8k 12000' +6.2k 12500' +5.2k Printed: 4/11/2008 12:40:41 PM BP AMERICA Page 14 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ,Code NPT Phase Description of Operations 3/10/2008 117:00 - 18:10 I 1.171 CASE I P I I LNR1 113000 +3.6k 18:10 - 18:25 0.25 CASE P LNRi 18:25 - 21:10 2.75 CASE P LNR1 21:10 - 21:45 0.58 CASE P LNR1 21:45 - 23:00 1.25 CASE P LNRi 23:00 - 00:00 1.00 CASE P LNR1 3/11/2008 00:00 - 00:30 0.50 CASE P LNR1 00:30 - 01:45 1.25 CASE P LNR1 01:45 - 03:40 1.92 CASE P LNR1 03:40 - 04:30 0.83 CASE P LNR1 04:30 - 04:40 0.17 CASE P LNR1 04:40 - 07:00 2.33 CASE P LNR1 07:00 - 08:30 1.50 CASE P LNR1 08:30 - 08:45 I 0.251 CASE I N I DFAL I LNR1 08:45 - 09:30 ~ 0.75 ~ CASE ~ N ~ DFAL ~ LNR1 09:30 - 09:45 0.25 CASE N DFAL LNR1 09:45 - 10:15 0.50 CASE N DFAL LNR1 10:15 - 12:45 2.50 CASE N DFAL LNR1 12:45 - 13:00 0.25 CASE N DFAL LNR1 13:00 - 14:00 1.00 CASE N DFAL LNRi 14:00 - 15:40 I 1.671 CASE I N I DFAL I LNR1 13184' +3.3k Tag TD at 13184' CTD. SD pump and trap 1150 psi. Get up wt at 27k Put liner back at TD. Incr pump rate to 1.36/4200 w/ 300 psi whp and PUH at 21 k P/U weight indicate that liner is released. POOH following pressure schedule. top 200 rom surface Close SSSV and flow check. Hold PJSM for LD of BHA and running liner S/B injector, LD liner running BHA - MU 2nd liner assmbly. Unique Indexing Guide Shoe, one solid jt, O-ring sub, 29 ea 2-3/8" 4.41 # L-8D R2 5TL w%Aluminum billet Deployment sleeve w/ 3" GS profile. Continue M/U 2nd liner assmbly. MU MWD assy. MU to liner assy. Stab on w/ injector. Begin circ at 0.29/0.25/2160 w/ 1200 psi induced whp. Open TRSSSV RIH with second half of "A" lateral liner following pressure schedule. RIH to window. Up wt 19K, do 8K. RIH to 10510'. Tie-in to GR marker at 9550'. +3' correction. RIH w/liner. C~ 11000', up wt 19K, do wt 6K ~ 11500', up wt 20K, do wt 5.8K ~ 12132', up wt 22.5K, do wt 5.3k. Tag TD at 12132' CTD. Put liner back at TD. Incr pump rate to 1.38/4200 w/ 325 psi whp and PUH at 20k. Appears to have released from liner. POOH following pressure schedule. Tag up w/ 1150 psi induced whp Pressure undeploy the liner running assy w/ 1150 psi. Pull tested slickline before opening rams and broke the slickline. Had doubts about whether liner had been released too Safety mtg: change of plan. Will stab back on with the injector and conventional undeploy (without pressure-requires closing TRSSSV) Find wire parted just above the rope socket. Stab back on w/ injector. Use pressure deploy steps until equalized with wellbore pressure Close TRSSSV and flow check IA -1, OA 239 Set injector to side and determine with tugger that liner is still attached. RU blocks and pull BHA to floor. LD MWD assy and blow down on catwalk Remove aluminum billet on hyd GS assy. Release dogs. Inspect profile and dogs and see no obvious problem. Change out dogs on GS while wo knuckle BHI removed leaking double ball valves and replaced O-rings. Tested tool and found short in surface line to satellite office and replaced Cleaned rock catcher in reel house. Minor welding in the pits Safety mtg: MU BHA MU liner running BHA #12. BTT aluminum deployment sub w/ GS and knuckle jt. Add BHI MWD assy and test. Begin circ 0.31/2160 w/ 1170 psi induced whp. Open TRSSSV RIH w/ BHA #12 circ thru GS following pressure schedule. RIH Printed: 4/11/2008 12:40:41 PM • 1 J~" ~'b~6 BP AMERICA Page 15 of 36 0!perations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/11/2008 14:00 - 15:40 1.67 CASE N DFAL LNR1 to window. Up wt 21.5K, do 9.5K. 15:40 - 16:45 1.08 CASE N DFAL LNR1 RIH to 10510'. Tie-in to GR marker at 9550'. +1' SLB correction. RIH w/liner. C~ 11000', do wt 8K C~ 11500', do wt 7.8K C~3 12132', do wt 7k. PUH, incr rate to 1.58/4550, zero DHWOB, up wt 24K. Surface weight indicates we are dragging liner. RIH Tag TD at 12132' CTD. P/U at 21.5K, 2K DHWOB, surface weight is pulling smooth. Indicates liner has released. 16:45 - 19:30 2.75 CASE N DFAL LNR1 POOH following pressure schedule. Bring rate down to 0.5/2200. PUH to above window. Up wt 18K, do wt 7.5K. POOH following pressure schedule. PJSM while POH regarding pressure undeployment. 19:30 - 22:30 3.00 CASE N DFAL LNR1 Start pressure undeployment procedure. Appears checks are not holding, regroup & discuss. Continue to pressure undeploy BHA. 22:30 - 00:00 1.50 RIGU P PROD2 Liner is not attached to tool string. LD BHI tools on catwalk, blow down same w/ water & air. RU new BHI tool string. Simultaneously conduct slack management. C/O injector stripping rubber. BHI upper check valves appear ok, lower dart style are gummed up w/ bits of Alpine beads. 3/12/200$ 00:00 - 00:15 0.25 RIGU P PROD2 Continue to pump slack into coil. Turn on centrifuge 'B' & use gun line to remove Alpine beads from pits. 00:15 - 01:00 0.75 RIGU P PROD2 PJSM regarding cutting coil & reheading coil. Cut 142ft of coil. Test wire -good test. 01:00 - 01:40 0.67 RIGU P PROD2 Install new Kendall CTC. Pull test CTC to 35k -good. 01:40 - 03:15 1.58 RIGU P PROD2 Rehead BHI tools. Test BHI head -bad. C/O flow sub & re-test - good. 03:15 - 03:25 0.17 RIGU P PROD2 P.T. CTC &BHI UQC to 4000 psi -good. 03:25 - 04:20 0.92 RIGU P PROD2 Stab injector onto well & P.T. injector packoffs per AOGCC regs. Test BHI UOC check valves w 1500psi i press -good. PJSM while testing packoffs regarding pressure deploying BHA. 04:20 - 06:00 1.67 STWHIP P PROD2 Begin pressure deploying BHA. M/U Aluminum billet kick-off BHA #13. 1.5 deg motor and HCC 2.73" STR bit. 06:00 - 06:30 0.50 STWHIP P PROD2 Crew change. PJSM for finishing pressure deployment procedure. 06:30 - 07:50 1.33 STWHIP P PROD2 Continue pressure deploying kick-off BHA. 07:50 - 09:35 1.75 STWHIP P PROD2 RIH w/ WO BHA #13 following pressure schedule. 09:35 - 09:50 0.25 STWHIP P PROD2 Log tie-in to GR. +11' correction. 09:50 - 10:00 0.17 STWHIP P PROD2 RIH to 9950' 10:00 - 12:30 2.50 STWHIP N RREP PROD2 Having problems w/ mud pump #1. Troubleshoot pump. Replace valves and seats in MP#1. Clean out suction. i 13:40 - 14:15 0.58 STWHIP P PROD2 P/U. Orient 50 deg ROHS. Incr rate to 1.5/1.5 bpm at 3950 psi. RIH, tag top of billet. Time drill off billet 0.1' every 5 min for 0.3'. Lost communication w/ HI tools. ~"~ 14:15 - 16:30 2.25 STWHIP N DFAL PROD2 POH to troubleshoot BHI tools following pressure schedule. ~ ~ e 16:30 - 17:00 0.50 STWHIP N DFAL PROD2 PJSM for pressure undeploying BHA #13 17:00 - 17:50 0.83 STWHIP N DFAL PROD2 Pressure undeploy AI billet WO BHA #13. After P/U injector, close double ball valves and test BHI UOC and LQC. Appears ~,(,ry to be in the tool string. Continue to pressure undeploy. ~G rc.. ~ SJ~ -~ ~'. Printed: 4/11/2008 12:40:41 PM • BP AMERICA Page 16 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: i 0/2/1988 Start: 2/1 /2008 End: 3/31 /2008 Rig Release: 3/31 /2008 Rig Number: Date From - To Hours ' Task Code NPT Phase 3/12/2008 17:50 - 18:25 0.58 STWHIP N DFAL PROD2 18:25 - 19:30 1.08 STWHIP N DFAL PROD2 19:30 - 21:00 1.50 STWHIP N DFAL PROD2 21:00 - 21:20 0.33 STWHIP N DFAL PROD2 21:20 - 23:40 2.33 STWHIP N DFAL PROD2 23:40 - 00:00 0.33 STWHIP N DFAL PROD2 3/13/2008 00:00 - 01:30 1.50 STWHIP N DFAL PROD2 01:30 - 01:40 0.17 STWHIP N DFAL PROD2 01:40 - 02:30 0.83 STWHIP N DFAL PROD2 02:30 - 02:45 I 0.251 STWHIPI P I I PROD2 02:45 - 03:40 I 0.921 STWHIPI P I I PROD2 03:40 - 04:20 0.671 STWHIPI P PROD2 04:20 - 04:35 I 0.251 STWHIPI P I I PROD2 04:35 - 05:35 ( 1.001 STWHIPI P I I PROD2 05:35 - 09:00 3.421 STWHIPI N STUC PROD2 09:00 - 10:50 I 1.831 STWHIPI N 10:50 - 11:00 I 0.171 STWHIPI N 11:00 - 13:15 I 2.251 STWHIPIN STUC I PROD2 STUC I PROD2 STUC I PROD2 Description of Operations Stop for night shift. PJSM regarding pressure undeploying. Continue to pressure undeploy BHA. LD BHI tools on catwalk. Purge & blow down BHA on catwalk, Remove power & comms & test tools -still more tool problems. Continue to RU new tool string on catwalk, configure & test same. LD motor on RF & scribe same. PJSM regarding pressure deployment. Pressure deploy new BHI tool string into well. RIH w/ WO BHA #14 following pressure schedule. Continue to RIH w/ BHA # 14 following pressure schedule. Inspect previous BHI tool string & found that the EDC was the culprit for the failure. Log down for tie-in @ 9565' (+5ft corr. RIH. Annular pressure = 4400psi &WHP = 700psi, w/out pumps while going through cement ramp/window area. Dry tag aluminum billet @ 11169'. PU & get drilling parameters while slowly creeping in hole. Begin time drilling from 11168.4' (~ 0.1' every 5min for 1 ft w/ TF 50R HS. Op = 1.50 / 1.45 bpm Pt = 3800psi fs w/ 50 psi motor work. DHWOB = 0.4-1.4k# VP = 198 bbl ECD = 13.15 WHP = 260 Time drill from 11169.4' C~ 0.1' every 3min for 1 ft w/ TF 50R HS. Op = 1.50 / 1.45 bpm Pt = 3800psi fs w/ 100 psi motor work. DHWOB = 0.75-1.4k# VP = 197 bbl ECD = 13.23 WHP = 230 Stalled while at 11170.4'. Aluminum coming over shaker now. Time drill from 11169.2' C~3 0.1' every 3min for 1 ft w/ TF 50R HS. Qp=1.50/1.45 bpm Pt = 3800psi fs w/ 100 psi motor work. DHWOB = 0.75-2.Ok# VP = 196 bbl ECD = 13.23 WHP = 230 Stalled while at 11169.3'. Time drill from 11169.2' Q 0.1' every 3min for 1 ft w/ TF 50R HS. Op = 1.50 / 1.45 bpm Pt = 3800psi fs w/ 50 psi motor work. DHWOB = 0.75-2.Ok# VP=196bb1 ECD=13.12 WHP=230 Keeps stalling shallower & shallower on each attempt to pet to bottom. Last stall was at 11154'. PU & stop pumping, close choke. RIH & dry tag at 11156'. PU -clean. RIH & dry tag at 11171'. PU & pulling heavy, stop at 11126'. Try to move pipe up & down. Can circulate no problem & orientate w/ no problem. Work pipe. Seem to be mechanically stuck between DPS and HOT. Discuss w/ town on plan forward. Pump 40 bbl low vis sweep followed by 20 bbl high vis sweep. Work pipe, try different orientations and pump rates. When orienting, appears that BHA above the HOT output shaft is rotating, but cannot get TF to change. Discuss w/ town. Decide to use EDC to disconnect. Spot high vis pill. Send command to EDC and disconnect from BHA. POOH to surface following pressure schedule. PJSM for Printed: 4/11/2008 12:40:41 PM • BP AMERICA Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Start: 2/1/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Page 17 of 36 ~ Spud Date: 10/2/1988 End: 3/31 /2008 Date. From - To Hours Task li Code NPT Rhase Description of Operations 3/13/2008 11:00 - 13:15 2.25 STWHIP N STUC PROD2 pressure undeploy. 13:15 - 14:00 0.75 STWHIP N STUC PROD2 Pressure undeploy BHA using modified pressure undeploy 14:00 - 15:00 1.00 FISH N 15:00 - 22:00 7.00 BOPSU P 22:00 - 22:50 0.83 FISH N 22:50 - 00:00 1.17 FISH N 3/14/2008 00:00 - 01:00 1.00 FISH N 01:00 - 03:50 2.83 FISH N 03:50 - 04:20 I 0.501 FISH I N 04:20 - 04:50 0.50 FISH N 04:50 - 06:15 1.42 FISH N 06:15 - 08:30 2.25 FISH N 08:30 - 09:15 0.75 FISH N 09:15 - 09:40 0.42 FISH N 09:40 - 11:00 1.33 FISH N 11:00 - 12:15 1.25 FISH N 12:15 - 12:45 0.50 FISH N 12:45 - 15:15 2.50 FISH N 15:15 - 15:30 0.25 FISH N 15:30 - 16:45 1.25 FISH N 16:45 - 18:35 1.83 FISH N 18:35 - 18:45 0.17 FISH N 18:45 - 19:10 0.42 FISH N procedure. BHA is 15.9' long, short enough to tag up and close swab valve while using mud pump 2 to circulate through managed pressure loop. STUC PROD2 Prep for BOP test. P/U BTT fishing tools to rig floor thru beaver slide. PROD2 Test BOPE. 250 si low, 4500 psi high. Test witness waived by AOGCC inspector Chuck Scheve. STUC PROD2 Pop off well. Close TRSSSV w/ 1200psi below & flow check. PJSM regarding pumping slack out of reel. Simultaneously place injector over bung hole & pump slack out of reel, recovered 280ft. STUC PROD2 MU BOT CTC, pull test same to 35k -good. PJSM regarding handling BHA. Well stopped flowing ~ 23:50. MU fishing BHA. STUC PROD2 Continue to MU fishing BHA. MU fishing BHA to coil. Stab onto well. Set counters. STUC PROD2 RIH w/fishing BHA, circ 0.35bpm/2000psi. Pressure up & open TRSSSV, WHP = 1179psi. Stop pumping ~ 9960'. WT ck ~ 9960' = 24k. RIW = 8k. Clean through window. WT ck C~ 11000' = 24.5k. RIW = 6.3k. Clean hole to TD. STUC PROD2 Latch into fish ~ 11097'. Jar down 2 times & have movement. Jar up 6 times. Popped free, however we are dragging something up hole. STUC PROD2 POH. Pulls fine for 20'-30' then 7k to 20k overpulls. Stop PUH C~ 10365'. Discuss with town. STUC PROD2 Work fish down hole. 2 jar licks down & moved 5ft. 1 jar lick & moves down hole smooth. RIH to 10400' -clean. PUH to 10380' -pulled heavy. RIH to 10395' & set down. 1 jar lick down. RIH to 10425' -clean. PUH to 10350' -clean. RIH to 10478' & set down. Continue to work up & down the hole from 10325ft to 10500ft. Clean without overpulls or set downs for 3 attempts. Decide to PUH through window. PUH through the window w/ no overpulls. STUC PROD2 POH keeping pressure on well. POOH to 1500'. STUC PROD2 Close TRSSSV. Flow check. STUC PROD2 POOH to surface. PJSM for UD fishing BHA. STUC PROD2 UD fishing BHA #15. 1.5' of eline hanging out of end of CTC. Recovered 100% of fish. No clear indication of any damage or scarring on fish from debris. STUC PROD2 R/U to perform a-line slack management. Reverse circulate at 2.8 bpm at 3600 psi. Heard a-line moving in coil. STUC PROD2 Cut 308' of coil to expose a-line. DPRB PROD2 M/U SLB Kendall CTC and pull test to 35K. M/U BHI UOC and rehead a-line. Meg a-line, good test. PT CTC to 4000 psi. DPRB PROD2 PJSM for M/U cleanout BHA DPRB PROD2 C/O injector packoffs. M/U open hole cleanout BHA #16. Test coiITRAK tools. DPRB PROD2 Increase WHP to 1300 psi. Open TRSSSV. RIH following pressure schedule. DPRB PROD2 Log down for tie-in from 9560ft (+9ft corr. DPRB PROD2 RIH. Lightly tag up at 10065ft. PU clean. RIH. Lightly tag up at Printed: 4/11/2008 12:40:41 PM • BP AMERICA Page 18 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date .From - To Hours Task I Code NPT Phase I Description of Operations 3/14/2008 18:45 - 19:10 0.42 FISH N DPRB PROD2 10064ft. PU clean. 19:10 - 19:30 0.33 FISH N DPRB PROD2 PUH & re-log for depth confrimation. 19:30 - 19:50 0.33 FISH N DPRB PROD2 Log down for tie-in from 9545ft (+1 ft corr. 19:50 - 20:15 0.42 FISH N DPRB PROD2 RIH. Lightly tag up at 10064ft. While setting 1 k, try to orientate 20:15 - 23:15 I 3.001 FISH I N I DPRB I PROD2 23:15 - 00:00 0.75 FISH N DPRB PROD2 3/15/2008 00:00 - 01:45 1.75 FISH N DPRB PROD2 01:45 - 03:00 1.25 FISH N DPRB PROD2 03:00 - 05:20 2.33 FISH N DPRB PROD2 05:20 - 06:00 0.67 FISH N DPRB PROD2 06:00 - 06:45 0.75 FISH N DPRB PROD2 06:45 - 07:50 1.08 FISH N DPRB PROD2 07:50 - 09:30 1.67 FISH N DPRB PROD2 09:30 - 09:45 0.25 FISH N DPRB PROD2 09:45 - 10:20 0.58 FISH N DPRB PROD2 10:20 - 10:35 0.25 FISH N DPRB PROD2 10:35 - 11:00 0.42 FISH N DPRB PROD2 11:00 - 11:20 0.33 FISH N DPRB PROD2 11:20 - 12:20 1.00 FISH N DPRB PROD2 12:20 - 13:50 ~ 1.50 ~ FISH ~ N ~ DPRB ~ PROD2 past problem area, w/out pumping. Turns fine 45 deg L & R of HS with no increase in amps to tool. Orientate back to drilled TF & PU -clean. PUH while discuss w/ town. Slightly gassy returns. Stop POH C~3 9200ft. Slowly RIH & increase rate to 1.5bpm. CBU while POH. Inform town concerning current issue. PJSM regarding pressure undeploying of BHA. Tag up. Begin pressure undeploying BHA. Continue to pressure undeploy BHA. LD BHI tools on catwalk & C/O o-ring on LOC. Inspect mill, 2.74 go & 2.73 no-go (no wear/marks on mill/motor/tools). Dial up motor to 2.4 AKO & turn wear pad to inside of bend (for ease of pressure deployment). PU injector & stab onto well. Test injector packoffs per AOGCC reps 250/4500 -PASS. Pop off well & place in bung hole. Pressure deploy BHA. Having great difficulties getting larger bend motor through tree/hanger - 40 min to get BHI tools into position. Continue with deployment procedure. Inspect CTC. CTC MT connection is loose. Remove flow sub & UOC & anchor. Re-lock fife & torque up CTC MT connection. Install anchor, flow sub & UOC. Cannot get anchor back into UOC due to slack. Behead BHI UOC. Crew Change. SAFETY MEETING. Review hazards, mitigation, and procedures for pressure deployment. Finish reheading BHI UOC. Finish pressure deploy window dressing BHA #17. CoiITRAK tools, 2.4 deg motor, 2.74" D331 mill w/ cut right backreaming cutters. RIH w/ lateral cleanout BHA following pressure schedule. Tie-in to GR at 9565'. -3' correction. RIH to top of cement ramp w/ no pumps and holding 1200 psi WHP. Orient LS. RIH to 10050' and orient HS. RIH, tag at 10063.5', 3.5K WOB. P/U, RIH slow, tag at 10062.9', 1 K WOB. Kick on pumps, WOB dropped to 0.4K. S/D pumps. RIH to see if we can pass thru window. RIH thru window clean to 10073'. Discuss w/ town. PUH clean thru window to 9545'. Tie-in in GR at 9545'. +2' correction. RIH to window w/ no pumps. Tag at 10063.6', 1.2K WOB. P/U to 10050', RIH, tag at 10063.1', 0.6K WOB. P/U and try to get thru multiple times with kicking on pumps to 0.5 bpm. BHA is turning around bit. Finally able to work thru window. Discuss w/ town. cleanout openhole at 1.57 bpm, 3900 psi, 12-15 fpm. RIH 13:50 - 17:15 3.42 FISH N DPRB PROD2 POOH, swap well to new mud. Slight overpulls from 10500'-10480'. Ream and backream hole thru this section. Hole cleaned up. PUH clean thru window. POOH following Printed: 4/11/2008 12:40:41 F'M • BP AMERICA Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA ,Rig Name: NORDIC 2 Date i From - To Hours ~' Task Code 3/15/2008 3/16/2008 13:50 - 17:15 17:15 - 17:45 17:45 - 18:00 18:00 - 18:30 Start: 2/1 /2008 Rig Release: 3/31 /2008 Rig Number: Page 19 of 36 Spud Date: 10/2/1988 End: 3/31 /2008 NPT ~ Phase Description of Operations 3.42 FISH N DPRB PROD2 0.50 FISH N DPRB PROD2 0.25 FISH N DPRB PROD2 0.50 FISH N DPRB PROD2 18:30 - 19:40 I 1.171 FISH I N 19:40 - 20:00 20:00 - 23:15 0.33 CASE N 3.25 CASE N 23:15 - 00:00 00:00 - 01:00 01:00 - 02:05 0.75 CASE N 1.00 CASE N 1.08 CASE N 02:05 - 04:20 2.251 CASE N 04:20 - 06:00 1.67 CASE N 06:00 - 06:30 0.50 CASE N 06:30 - 07:00 0.50 CASE N 07:00 - 08:30 1.50 STWHIP N 08:30 - 08:40 0.17 STWHIP N 08:40 - 11:45 3.08 STWHIP N 11:45 - 13:30 1.75 STWHIP N 13:30 - 13:45 0.25 STWHIP N 13:45 - 15:00 1.25 STWHIP N 15:00 - 15:10 0.17 STWHIP P 15:10 - 16:15 1.08 STWHIP P 16:15 - 16:50 16:50 - 17:10 0.581 STWHIPI P 0.331 STWHIPIP DPRB PROD2 DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNR1 DPRB LNRi DPRB LNR1 DPRB LNR1 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 DPRB PROD2 PROD2 PROD2 PROD2 PROD2 pressure schedule. Stop at 1500' and close TRSSSV. Flow Check. POH to surface. C/O w/ day crew. PJSM regarding LD BHA. Flow check well while conducting PJSM. Pop off well & place injector over bung hole. Purge/blow down BHI tools. LD tools on catwalk & reconfigure same for running liner, C/O o-rings on LOC. No marks on mill/motor 2.73" no-go/2.74" go. MU safety jt for running liner. C/O elevators. PJSM regarding MU liner. Start MU liner consisting of unique guide shoe+26jts slotted liner+Al billet w/GS profile (non-splined), torqued w/little jerk tongs. PU BHI's coil track tools+knuckle jt+hyd GS & MU to liner. PU injector & MU to tools (had trouble MU UOC due to angle). Stab onto well. Power up & test tools. Set counters. Simultaneously C/O MPD hose & install a tee (used to blow down chokes). P.T. 250/4500 -pass. RIH w/liner following pressure schedule. Continue to RIH w/liner following pressure schedule. Wt ck ~ 10000ft 23.5k, RIW = 7.1k. Continue to RIH w/ liner. Smooth through ramp/window area. Log down for tie-in (-3.6ft). RIW = 5.4k ~ 11170ft. Tag up C~3 11170ft. Up Wt = 25k. RIH & tai up C~? 11170ft & set 6k down. Start pumping C~ 1.5bpm / 4100psi & release from liner, 21.7k up Wt (w/out pumps). TOL = 10330.6ft. POH following pressure schedule while pumping 0.4bpm/2100psi. PJSM while POH regarding pressure undeploying BHA. Pressure undeploy BHA. Crew Change. PJSM to finish pressure undeploying liner running BHA. Continue pressure undeploying liner running BHA. M/U BHI Toolstring on catwalk. Test tools. PJSM for pressure deploying WO BHA. Pressure deploy Aluminum Billet K/O BHA #19. Rehead slickline rope socket. Cut 4' of slickline. slickline was slightly kinked right above rope socket. RIH following pressure schedule Tie-in to GR at 9565'. +4' correction. RIH to window. Tag window 3x at 10063.8' going 3 fpm. P/U and run thru window at 8 fpm, 2.5K WOB. RIH to bottom. Orient 30 ROHS. Dry tag aluminum billet @ 10329'. PU & get drilling parameters while slowly creeping in hole. Up wt 25K. Tag billet at 10328.5'. 3850 psi FS. Time drill off billet, 30 ROHS, 1.5 bpm, 4000 psi, 1.5K WOB. Time drill at 1 fph. Getting aluminum in returns. Drilled to 10329.5' Time drill off billet, 0.1' every 3 min. 1.5 bpm, 4000 psi, 1.2K WOB. Drilled to 10330.5' Time drill off billet, 0.1' every 2 min. 1.5 bpm, 3950 psi, 0.4K WOB. Drilled to 10331.5' Printed: 4/11/2008 12:40:41 F'M • ~~ 'V v~ - BP AMERICA Page 20 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ', Hours Task Code NPT Phase Description of Operations 3/16/2008 17:10 - 18:00 0.83 STWHIP P PROD2 Time drill off billet, 10-15 fph. 1.5 bpm, 3925 psi, 0.8K WOB. Stacking wt, P/U several times and RIH to bottom. Drilled to 10336.0' 18:00 - 19:30 1.50 STWHIP P PROD2 Continue drilling at 10336.0'. Time drill from 10336.0' @ 5'/hr w/ TF 30R HS. Op = 1.55 / 1.55 bpm Pt = 4000psi fs w/ 100 psi motor work. DHWOB = 0.75-1.5k# VP = 55 bbl ECD = 13.1 WHP = 300 DHT= 136 ST = 81 Had to PU start over due to stacking & had numerous 2k overpulls at 10336ft. Drill to 10350'. NBI shows that we are KO'd but shows a larger than expected jump in inclination. 19:30 - 20:45 1.25 STWHIP P PROD2 Ream 45 deg L&R of drilled TF to open up sidetrack until section is clean. Op = 1.55 / 1.55 bpm Pt = 4000psi fs w/ 25 psi motor work. DHWOB = 0.25-0.5k# VP=53bb1 ECD=13.1 WHP=300 Repeat 6 times. Smooth RIH & OH. 20:45 - 23:20 2.58 STWHIP P PROD2 PU through window to 10040'. RIH ~ 15ft/min to 10070'. No set downs in the window. POH following pressure schedule. Tag & trap 1200psi on well. Blow down chokes. 23:20 - 00:00 0.67 STWHIP P PROD2 Begin pressure undeploying BHA. C/O high pressure filter on the hardline in the reel house -filter was eroded & cracked, replace same. Circulate coil volume to purge reel w/clean mud. Turn on gun lines & return mud across shaker to remove aluminum/debris from pits -fair quantity of aluminum/debris removed from active pits. 3/17/2008 00:00 - 01:10 1.17 STWHIP P PROD2 Continue to pressure undeploy BHA. 01:10 - 02:00 0.83 DRILL P PROD2 LD BHI coiITRAK tools on catwalk & purge/blow down same & reconfigure for resistivity. Bit was 2.73"go, partially plugged w/ aluminum from pumping it around from the pits. MU new 2-3/8" Xtreme mud motor w/ 0.9 AKO setting w/ new Hughes BC bit. C/O o-rings on LOC & clean out aluminum debris from LOC. Simultaneously, turn on guns lines from active pits returning across shaker again to remove solids from pits, recovered more aluminum/debris. 02:00 - 02:15 0.25 DRILL P PROD2 PJSM regarding pressure deploying BHA. 02:15 - 04:30 2.25 DRILL P PROD2 Begin pressure deploying lateral BHA. 04:30 - 06:30 2.00 DRILL P PROD2 RIH w/ lateral BHA following pressure schedule. 06:30 - 06:45 0.25 DRILL P PROD2 Tie-in to GR, +16' correction. 06:45 - 07:20 0.58 DRILL P PROD2 RIH, slight weight bobble when passing thru window, but went thru w/ no roblems. RIH to bottom. 07:20 - 09:15 1.92 DRILL P PROD2 Tag bottom at 10349.5'. Drill ALi lateral at 1.55/1.55 bpm, 4100 psi, 60 fph ROP, 1.3k WOB, 98 deg incl, 15L TF, 13.5 ECD. Holding 300 psi WHP, BHP at 4590 psi. Drilled to 10427' 1~ ^ 09:15 - 10:30 1.25 DRILL P PROD2 Drill AL1 lateral at 1.6/1.6 bpm, 4300 psi, 45-80 fph ROP, 0.6k ~ f'~ WOB, 95 deg incl, 90L TF, 13.6 ECD, 300 psi WHP, BHP at 4630 psi. C l 10:30 - 10:50 0.33 DRILL P PROD2 Wiper to window. 1 10:50 - 11:30 0.67 DRILL N DPRB PROD2 RIH, tag 3x at 10140'. Stall everytime we tag. S/D pumps, RIH dry and tag at 10140', stack wt and cant get thru. P/U, incr Printed: 4/11/2008 12:40:41 F'M ~ i BP AMER91CA Page 21 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To 'Hours Task Code NPT Start: 2/1 /2008 Rig Release: 3/31 /2008 Rig Number: i Spud Date: 10/2/1988 End: 3/31 /2008 Phase Description of Operations 3/17/2008 10:50 - 11:30 0.67 DRILL N DPRB PROD2 11:30 - 13:00 1.50 DRILL N WAIT PROD2 13:00 - 14:30 1.50 DRILL N DPRB PROD2 14:30 - 16:10 1.67 DRILL N DPRB PROD2 16:10 - 18:00 1.83 DRILL N DPRB PROD2 18:00 - 18:30 0.50 DRILL N DPRB PROD2 18:30 - 20:15 1.75 DRILL N DPRB PROD2 20:15 - 21:20 1.08 ~ DRILL ~ N ~ DPRB ~ PROD2 21:20 - 23:00 ~ 1.67 ~ DRILL ~ N ~ DPRB i PROD2 23:00 - 23:55 0.92 DRILL N 0.08 DRILL N 0.17 DRILL N DPRB I PROD2 23:55 - 00:00 3/18/2008 00:00 - 00:10 00:10 - 00:45 00:45 - 01:10 DPRB PROD2 DPRB PROD2 0.58 DRILL N DPRB PROD2 0.42 DRILL N DPRB PROD2 01:10 - 02:30 1.33 DRILL N DPRB PROD2 02:30 - 03:00 0.50 DRILL N DPRB PROD2 03:00 - 03:20 0.33 DRILL N DPRB PROD2 03:20 - 04:30 1.17 DRILL N DPRB PROD2 04:30 - 05:30 ~ 1.00 ~ STKOH N DPRB PROD2 pumps to 1,5 bpm, RIH, stall. P/U and slowly ream hole section. Ream w/ 100 psi motor work, 45L TF for 3' at 10-20 fph. WOB fell off but still had 50 psi motor work. Incr ROP to 50-100 fph, seems to be drilling w/ 150-200 psi motor work, 1.5K WOB, 45L TF, 100 fph. Drilled to 10159'. NBI indicated we were very close to as drilled wellbore, but did not drill enough to get a good survey. Appears we may be inadvertently sidetracked at 10140'. PUH into tubing tail. Open EDC and circ. Discuss w/ town. Decide to POOH for 2.4 deg motor and BC bit. POOH following pressure schedule. PJSM for pressure undeploying lateral drilling BHA. Pressure undeploy BHA. Bit graded 1/1/i with 3 plugged nozzles. UD BHI tools on catwalk. M/U new BHI toolstring w/ 2.4 deg motor and HYC BC bit. C/O w/day crew. PJSM regarding pressure undeploying BHA. Begin pressure undeploying BHA. Can't get motor/bend through BOP stack. Can't come up or down w/ tool string - we need a set of short spangs & WT bar for doing this kind of work! Close TRSSSV & flow check well. PJSM regarding handling the stuck BHA. Pop off well & turn BHA w/ wrenches. RD lubricator. MU tools to coil. Stab onto well. Power up & check tools. Set counters. Pressure up well & open TRSSV. RIH following pressure schedule. Slightly tagged TRSSSV -possible trash building up behind flapper valve, will deal with it on the way OOH. Log down from 9569ft for tie-in, missed the GR tie-in point. PU to 9549ft & re-log down (+28ft corr. Continue to RIH. Continue to RIH. RIH through ramp/window was clean. RIH through OH section w/ out pumps ~ 30ft/min & set down at 10159ft w/drilled TF. PU was clean. Start pumping at 1.44bpm & RIH ~ HS past 10160ft then drilled TF to 10330ft. PU was clean to 10114ft. RIH w/out pumps w/ HS TF C~ 15fUmin & set down @ 10159ft. PU was clean. RIH pumping w/ HS TF to 10192. PU to 10118ft & try to back ream (drilled TF) a little but was clean. RIH w/out pumps w/ HS TF & tag ~ 10159ft. Slowly PUH from 10159ft to 8500ft following pressure schedule & discuss w/ town eng & formulate a plan forward. RIH following pressure schedule. Log down for tie-in from 9565ft (+8ft). RIH. Start pumping C~ 1.5bpm/4000psi w/ HS TF. Tag up at 10159ft, we are fighting the stops on the coil. Try 3 times. Coil has too much torque/twist & can't seem to compensate for TF changes by the time we get to 10150ft. PU to 10100ft. Try different speeds & yo-yo pipe/pump for 3 more times with & w/out pumps. Try different TF's L & R of HS. Set down 10158ft & get 0.5k WOB & start pumps & drill to 10161 ft. WOB fell off. RIH & can't. PU & start over. Go to 10164ft. Stop & PU & discuss w/ town. Printed: 4/11/2008 12:40:41 PM • • BP AMERtCq Page 22 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To , .Hours '~ Task Code NPT Phase Description of Operations STKOH N DPRB PROD2 Begin OH side track from 10164ft C~3 60ft/hr w/ TF 45R HS. 3/18/2008 05:30 - 06:40 1.17 - _ - -_ 06:40 - 07:45 1.08 STKOH N WAIT ~ PROD2 07:45 - 10:35 2.831 DRILL N DFAL PROD2 10:35 - 11:20 0.75 DRILL N DFAL PROD2 11:20 - 13:45 2.42 DRILL N DFAL PROD2 13:45 - 14:00 0.25 DRILL N DFAL PROD2 14:00 - 15:25 1.42 DRILL N DFAL PROD2 15:25 - 17:40 2.25 DRILL N DFAL PROD2 17:40 - 17:50 0.17 DRILL N DFAL PROD2 17:50 - 18:20 0.50 DRILL N DFAL PROD2 18:20 - 19:50 1.50 DRILL P PROD2 19:50 - 20:15 0.42 DRILL P PROD2 20:15 - 23:25 3.17 DRILL P PROD2 23:25 - 23:50 0.42 DRILL P PROD2 23:50 - 00:00 0.17 DRILL P PROD2 13/19/2008 ~ 00:00 - 03:11 ~ 3.18 ~ DRILL P PROD2 Op = 1.43 / 1.41 bpm Pt = 4000psi fs w/ 100 psi motor work. DHWOB = 0.75-2.5k# VP = 441 bbl ECD = 13.28 WHP = 300 DHT= 136 ST = 76 Build NBI to 88 deg. Drilled to 10194'., P/U and wait on orders from town. Discussing directional plan. PUH into tubing tail. Attempt to open EDC, but having trouble opening. EDC at an unknown position. Have to POH for EDC failure. POOH following pressure schedule. Circulating thru kill line due to EDC problem. Saw 3K Ib overpulls going thru SSSV. PJSM for UD BHA. Unsure of EDC position. Close TRSSSV. Flow check. S/B injector, UD BHA. M/U new BHI toolstring on catwalk. C/O depth counter wheel on injector. PJSM for P/U lateral drilling BHA. P/U lateral drilling BHA w/ res tool, 1.1 deg motor, HYC BC bit. Stab injector. Set counters. Pressure well & open TRSSV. RIH following pressure schedule. RIH past TRSSV -clean. PU through TRSSV - clean. Log down for tie-in from 9580ft (+4ft). RIH. Tied in at 9608 ft and correcte plus 4 ft. RIH and tagged at 10,195ft Drilling lateral with 1.1 AKO Motor. Op = 1.48 / 1.49 bpm CTP (Off6) = 4000 psi BHP = 4566 psi w/ ECD at 13.5 ppg WHP = 227 psi Density = 9.86 / 9.88 ppg Vp = 425 bbl Wiper and then orient TF to build up through shale section Ran MAD pass from 10,166 ft to10,195 ft Drilling lateral with 1.1 AKO Motor. Turned TF at HS to drill through shale Op = 1.48 / 1.49 bpm CTP (Off6) = 4000 psi BHP = 4566 psi w/ ECD at 13.6 ppg WHP = 223-322 psi Density = 9.86 / 9.88 ppg Vp = 426 bbl ROP = 20-60 fph with 1.00 to 1.50 klbf WOB Wiper trip Drilling lateral with 1.1 AKO Motor. Op = 1.48 / 1.49 bpm CTP (Off6) = 4087 psi BHP = 4675 psi w/ ECD at 13.8 ppg WHP = 223-322 psi Density = 9.86 / 9.9 ppg Vp = 416 bbl ROP = 50 fph with 1.00 to 1.50 klbf Drilling lateral with 1.1 AKO Motor. Walking TF around to the left to try and stay in the polygon. Op = 1.48 / 1.49 bpm CTP (Off6) = 4087 psi On bottom P = 4160 psi Printed: 4/11/2008 12:40:41 PM BP AMERICA Page 23 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours I! Task Code NPT Phase I' Description of Operations 3/19/2008 100:00 - 03:11 3.18 DRILL P PROD2 BHP = 4675 psi w/ ECD at 13.8 ppg WHP = 223-322 psi Density = 9.86 / 9.9 ppg Vp = 410 bbl ROP = 40-50 fph 03:11 - 03:35 0.40 DRILL P PROD2 Wiper trip and tie in at 10,125 ft 03:35 - 03:45 0.17 DRILL P PROD2 RIH at correct TF logging tie in at 150 fpm and a Op = 0.33 bpm. WHP = 600 psi ,BHP = 4484 psi, 13.38 ppg ECD No correction, Geologist wanted to correct 0.15 ft and WSL nix the idea 03:45 - 04:00 0.25 DRILL P PROD2 RIH and increased Op at 10,200 ft to 1.45 bpm 04:00 - 06:15 2.25 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor. Op = 1.50 / 1.50 bpm CTP (Off6) = 4087 psi On bottom P = 4260 psi BHP = 4638 psi w/ ECD at 13.6 ppg WHP = 253 psi Density = 9.86 / 9.9 ppg Vp = 395 bbl ROP = 40-60 fph 06:15 - 06:45 0.50 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor from 10670ft w/ TF 90L HS. Op = 1.50 / 1.50 bpm CTP (OffB) = 4087 psi On bottom P = 4050 psi BHP = 4520 psi w! ECD at 13.4 ppg WHP = 200 psi Density = 9.89 / 9.97 ppg Vp = 395 bbl ROP = 40-60 fph Turn on centrifuge 'A' & 'B' Turn on gun lines from active system & return across shaker to remove solids. 06:45 - 07:15 0.50 DRILL P PROD2 Wiper from 10700ft to 10145ft, 20ft/min ~ 1.5bpm/4000psi - clean. 07:15 - 07:45 0.50 DRILL P PROD2 Reduce rate to 0.45bpm/2000psi while wiper from 10145ft to 10200ft holding 600psi WHP. Increase to 1.5bpm/4000 from 10200ft to TD reduceing WHP to 250psi. Wiper was clean. 07:45 - 09:50 2.08 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor from 10700ft w/ TF 90L HS. Op = 1.56 / 1.53 bpm CTP (OffB) = 3800 psi On bottom P = 4275 psi BHP = 4636 psi w/ ECD at 13.74 ppg WHP = 200 psi Density = 9.89 / 9.97 ppg Vp = 402 bbl ROP = 30-80 fph 09:50 - 10:30 0.67 DRILL P PROD2 Wiper from 10850ft to 10150ft, 20ft/min C~ 1.5bpml4000psi - clean, PU wt = 21 k. 10:30 - 11:00 0.50 DRILL P PROD2 Reduce rate to 0.45bpm/2000psi while wiper from 10145ft to 10200ft holding 600psi WHP. Increase to 1.5bpm/4000 from 10200ft to TD & reduce WHP to 250psi. Wiper was clean. RIW 6k. 11:00 - 13:15 2.25 DRILL P PROD2 Drilling lateral with 1:1 AKO Motor from 10850ft w/ TF 95L HS. Printetl: 4/11/2008 12:40:41 PM BP AMERICA Page 24 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~~, Hours Task Code NPT Phase Description of Operations 3/19/2008 11:00 - 13:15 ~ 2.25 ~ DRILL P PROD2 Op = 1.55 / 1.58 bpm CTP (OffB) = 4065 psi On bottom P = 13:15 - 14:00 I 0.751 DRILL I P 14:00 - 14:05 I 0.081 DRILL I P 14:05 - 14:20 0.25 DRILL P 14:20 - 14:50 0.50 DRILL P 14:50-17:00 ~ 2.17~DRILL ~P 17:00 - 17:35 I 0.581 DRILL I P 17:35 - 18:22 I 0.781 DRILL I P 18:22 - 21:21 2.981 DRILL ~ P 21:21 - 22:56 1.58 DRILL P 22:56 - 00:00 1.07 DRILL P 13/20/2008 100:00 - 03:15 I 3.25 I DRILL I P 4200 psi BHP = 4636 psi w/ ECD at 13.73 ppg WHP = 275 psi Density = 9.84 / 9.84 ppg Vp = 405 bbl ROP = 30-80 fph Drill to 11000ft PROD2 Wiper from 11000ft to 10150ft, 20ft/min @ 1.5bpm(3900psi - clean, PU wt = 22k. PROD2 Reduce rate to 0.45bpm/2000psi while wiper from 10145ft to 10200ft holding 600psi WHP. Increase to 1.5bpm/4000 from 10200ft to TD & reduce WHP to 250psi -clean PROD2 Log down for tie-in from 10350ft (+2ft). PROD2 Increase rate to 1.5bpm/3890psi & wiper from 10386ft to 11000ft holding 300psi WHP -clean. PROD2 Drilling lateral with 1.1 AKO Motor from 11000ft w/ TF 90L HS. Op = 1.50 / 1.50 bpm CTP (OffB) = 3900 psi On bottom P = 4000 psi BHP = 4630 psi w/ ECD at 13.70 ppg WHP = 300 psi Density = 9.83 / 9.82 ppg Vp = 405 bbl ROP = 30-80 fph PROD2 Wiper from 11150ft to 10150ft, 20ft/min C~3 1.5bpm/3900psi - clean, PU wt = 23k. PROD2 Reduce rate to 0.45bpm/2000psi while wiper from 10150ft to 10200ft holding 600psi WHP. Increase to 1.5bpm/4000 from 10200ft to TD & reduce WHP to 300psi PROD2 Tagged bottom at 11,150 ft. Wiper trip good. Drilling Lateral in Kuparuk A2 Sand at per Geologist. Objective is 6487 ft TVD and then level out to 90 de . Tur ed TF to 90R at 11,230 ft and 150R at 11,290 ft. Op = 1.55 / bpm at CTP of 4000 psi off bottom Density = 9.82 / 9.69 ppg BHP /WHP = 4721 psi (13.99 ppg) / 311 psi. Dropped WHP to 240 psi BHP at 4650 psi Vp = 391 bbl's PROD2 Wiper trip after drilling 150 ft lateral PROD2 Tagged bottom at 11,300 ft. Wiper trip good. Now they want to climb up to 6,482' (5 ft TVD extra) and then cross cut back down again to 11,450 ft Drilling Lateral in Kuparuk A2 Sand at per Geologist. TF at 120R to 90R Op = 1.51 /bpm at CTP of 3970 psi off bottom Density = 9.82 / 9.69 ppg BHP /WHP = 4680 psi (13.89 ppg) / 300 psi. PROD2 Drilling Lateral in Kuparuk A2 Sand as per Geologist. TF at 90 R Op = 1.51 /bpm at CTP of 3970 psi off bottom Density = 9.84 / 9.75 ppg BHP /WHP = 4715 psi (14.00 ppg) / 308 psi. Printed: 4/11/2008 12:40:41 YM ! • BP AMERICA Page 25 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 3/20/2008 ~ 00:00 - 03:15 3.25 DRILL P PROD2 Nagged the Fault ? at 11,394 ft, ROP slowed down to nothing 03:15 - 04:20 1.08 DRILL P PROD2 04:20 - 06:10 1.83 DRILL P PROD2 06:10 - 09:25 3.25 DRILL P PROD2 09:25 - 10:40 1.25 DRILL P PROD2 10:40 - 11:35 0.92 DRILL P PROD2 11:35 - 11:50 0.25 DRILL P PROD2 11:50 - 13:05 1.25 DRILL P PROD2 13:05 - 15:25 2.33 DRILL P PROD2 15:25 - 16:40 1.25 DRILL P PROD2 16:40 - 17:50 1.17 DRILL P PROD2 17:50 - 19:10 1.33 DRILL P PROD2 19:10 - 21:50 2.67 DRILL P PROD2 Starting the mud swap at 11,393 ft (01:30 hrs) Took 1.5 hrs to get through. Sample art 11,400 showed increas in pyrite Drilling Lateral in Kuparuk Mid A2 Sand Op = 1.51 /bpm at CTP of 3970 psi off bottom Density = 9.82 / 9.90 ppg BHP /WHP = 4615 psi (13.86 ppg) / 297 psi. Finished Mud swap at 03:45 hrs Wiper trip -clean. Drilling lateral with 1.1 AKO Motor from 11450t w/ TF 90R HS in A2 sand. Op = 1.55 / 1.58 bpm CTP (OffB) = 4000 psi On bottom P = 4200 psi BHP = 4675 psi w/ ECD at 13.85 ppg WHP = 300 psi 0.8-1.5K WOB 5k Surface WT Density = 9.84 / 9.84 ppg Vp = 405 bbl ROP = 30-60 fph Drill to 11600ft. Wiper trip, 20Wmin 1.5bpm/3900psi. Motor work at 11520ft to 11515ft. Otherwise clean. Pull through window/ramp area -clean. Open EDC C~? 9900ft & circulate max rate 1.9bpm/4100psi while PUH ~ 21ft/min following pressure schedu{e. Log down for tie-in from 9585ft (+5ft corr. C/O shaker screen. RIH through ramp/window area -clean. Pump min rate past window to 10200ft. Increase rate to 1.4bpm/3700psi & wiper to TD. Slight motor work ~ 11520ft - 11525ft. Drilling lateral with 1.1 AKO Motor from 11604ft w/ TF 45R HS in A2 sand. Op = 1.5 / 1.5 bpm CTP (OffB) = 3850 psi On bottom P = 4200 psi BHP = 4675 psi w/ ECD at 13.89 ppg WHP = 300 psi 0.8-1.5K WOB 5k Surface WT Density = 9.83 / 9.86 ppg Vp = 359 bbl ROP = 30-60 fph Drilled to 11750ft. Wiper trip, slight motor work at 11520ft-11525ft, otherwise clean. Wiper to TD, clean, no motor work at 11525ft (suspect it's TF change related). Drilling lateral with 1.1 AKO Motor from 11750ft w/ TF 125R HS in A3 sand. Op = 1.5 / 1.5 bpm CTP (OffB) = 3850 psi On bottom P = 4200 psi BHP = 4675 psi w1 ECD at 13.82 ppg WHP = 300 psi 0.8-1.OK WOB 5k Surface WT Density = 9.83 / 9.80 ppg Vp = 363 bbl ROP = 30-80 fph The ankerite bed we drilled up through last night we found again going down tonight at 11820 ft. Pflnt2tl: 4/11/20Ut3 1G:4():41 YM BP AMERICA Page 26 of 36 Operations Summary Report Legal Well Name: 3 0-02 Common W ell Name: 3 0-02 Spud Date: 10/2/1988 Event Nam e: REENTE R+COM PLET E Start : 2/1/2008 End: 3/31/2008 Contractor Name: N ORDIC CALIST A Rig Release: 3/31 /2008 Rig Name: N ORDIC 2 Rig N umber: Date From - To II Hours Task Code NPT i Phase I Description of Operations 3/20/2008 19:10 - 21:50 2.67 DRILL P PROD2 Objective; drill down to 12050 ft (-6500 TVDss) and 90 deg Op = 1.5 / 1.5 bpm CTP (Off6) = 3870psi On bottom P = 4200 psi BHP = 4664 psi w/ ECD at 13.85 ppg WHP = 300 psi 0.8-1.OK WOB 5k Surface WT Density = 9.81 / 9.66 ppg Vp = 363 bbl ROP = 30-80 fph 21:50 - 00:00 2.17 DRILL P PROD2 Working through ankrite bed TF 50L Op = 1.52 / 1.52 bpm CTP (OffB) = 3870psi On bottom P = 4043 psi BHP = 4647 psi w/ ECD at 13.80 ppg WHP = 340 psi Density = 9.81 / 9.66 ppg Vp = 354 bbl, ROP = 3-40 fph 3/21/2008 00:00 - 01:30 1.50 DRILL P PROD2 Drilled to 11 900 ft 01:30 - 03:35 2.08 DRILL P PROD2 Wiper trip. 03:35 - 06:50 3.25 DRILL P PROD2 Drilling lateral Hit another hard spot (ankerite) at 11,915 ft. The ankerite bed at 11,920 ft Op = 1.52 / 1.52 bpm CTP (OffB) = 3870psi On bottom P = 4175 psi BHP = 4708 psi w/ ECD at 13.98 ppg WHP = 340 psi Density = 9.81 / 9.66 ppg Vp = 341 bbl, ROP = 20-70 fph 06:50 - 08:35 1.75 DRILL P PROD2 Wiper trip -clean. 08:35 - 08:45 0.17 DRILL P PROD2 Log down for tie-in C~ 10350ft (+3.5ft). 08:45 - 10:10 1.42 DRILL P PROD2 Wiper to TD -clean. 10:10 - 13:20 3.17 DRILL P PROD2 Drilling lateral in A3 sands from 12,050 ft. Op = 1.52 J 1.52 bpm CTP (Off6) = 3910psi On bottom P = 4055 psi BHP = 4696 psi w/ ECD at 13.91 ppg 0.8-1.65K WOB -2k Surface WT WHP = 245 psi Density = 9.86 / 9.96 ppg Vp = 341 bbl, ROP = 20-50 fph Drill t 1 13:20 - 14:20 1.00 DRILL P PROD2 Wiper trip. Motor work through the ankerite sections. 14:20 - 16:05 1.75 DRILL P PROD2 Wiper to trip to bottom was clean. 16:05 - 18:00 1.92 DRILL P PROD2 Drilling lateral in A2 sands from 12,200 ft. Op = 1.49 / 1.48 bpm CTP (OffB) = 3810psi On bottom P = 3950 psi BHP = 4722 psi w/ ECD at 14.00 ppg 0.8-1.65K WOB -2k Surface WT WHP = 245 psi Density = 9.86 / 9.96 ppg Vp = 321 bbl, ROP = 30-60 fph 18:00 - 19:30 1.50 DRILL P PROD2 Drilling Lateral Started Mud swap Op = 1.58 / 1.54 bpm CTP (Off6) = 3810psi On bottom P = 4000 psi BHP = 4722 psi w/ ECD at 14.00 ppg 0.8-1.65K WOB -2k Surface WT WHP = 245 psi Density = 9.86 / 9.96 ppg Vp = 321 bbl, ROP = 30-60 fph 19:30 - 22:15 2.75 DRILL P PROD2 Wiper trip 22:15 - 00:00 1.75 DRILL P PROD2 Drilling Lateral in Kup A2 1 Will drill to 12,400 ft at 6,490 ft Printed: 4/11/2008 12:40:41 PM BP AMERICA Page 27 of 36 Operations. Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To I' Hours Task ~ Code NPT Phase Qescription of Operations 3/21/2008 22:15 - 00:00 1.75 DRILL P PROD2 TVD ss then to 12,500 ft 6,485 ft at 91 deg TF at 90LHS Op = 1.55 / 1.56 bpm CTP (OffB) = 3856psi On bottom P = 4000 psi BHP = 4637 psi w/ ECD at 13.73 ppg WHP = 275 psi Density = 9.77 / 9.70 ppg Vp = 266 bbl, Finishing mud swap ROP = 30-70 fph Some gas cut mud to surface, increased WHP to 350 psi, isolated 1 pit. circulated out and density increased back to 9.8 PP9 3/22/2008 00:00 - 01:10 1.17 DRILL P PROD2 Drilling lateral as per Geologist CT WOB -6700 Ib at surface and DHWOB = 1.1k1b 01:10 - 03:10 2.00 DRILL P PROD2 Wiper trip to 10,360 ft Log tie in with 450 psi WHP BHP = 4512 psi (13.34ppg ECD) Correct 5.5 ft 03:10 - 04:35 1.42 DRILL P PROD2 RIH and tagged at 12504 ft following tie-in correction 04:35 - 05:30 0.92 DRILL P PROD2 Drilling Lateral in Kup A2 TF at 90-70 L and try and hold 91 deg. Op = 1.51 / 1.50 bpm CTP (OffB) = 3812psi On bottom P = psi BHP = 4707 psi w/ ECD at 13.79 ppg WHP = 300 psi Density = 9.80 / 9.80 ppg Vp = 359 bbl, CROP = 90 fph DHWOB at 0.9k and CTW at -60001b. Getting close 05:30 - 07:00 1.50 DRILL P PROD2 Having trouble getting WOB due to wellbore configuration. Drilled to 12 548 ft and CTW at -7k. Unable to get back to 12, 548 ft presently. Make 1000 ft wiper trip to see if we can get down 07:00 - 10:00 3.00 DRILL P PROD2 Drilling Lateral in Kup A2 TF at 90-70 L from 12548ft. Op = 1.51 / 1.50 bpm CTP (Off6) = 3812psi On bottom P = 3920 psi BHP = 4700 psi w/ ECD at 13.89 ppg WHP = 320 psi Density = 9.77 / 9.72 ppg Vp = 359 bbl, DHWOB at 0.9k and CTW at -40001b. Drilled to 12644ft & stackin wt. 10:00 - 12:00 2.00 DRILL P PROD2 Wiper to window -clean. Stop pumping & PU through window/ramp -clean. Open EDC C~3 9900ft & jet ~ max rate while PU to 9500ft. 12:00 - 12:30 0.50 DRILL P PROD2 Log down for tie-in from 9565ft (+6ft corr. 12:30 - 14:15 1.75 DRILL P PROD2 Close EDC &RIH through window/ramp, weight bobble at 10065ft. Pump 0.45bpm/1900psi while RIH past 10200ft. 14:15 - 15:50 1.58 DRILL P PROD2 Drilling Lateral in Kup A2 TF at 105-90 L from 12644ft. Op = 1.59 / 1.59 bpm CTP (Off6) = 4000psi On bottom P = 4050psi BHP = 4660 psi w/ ECD at 13.86 ppg WHP = 300 psi Density = 9.79 / 9.82 ppg Vp = 344 bbl, DHWOB at 0.9k-1.1 k and CTW at -60001b. Drilled to 12699ft. Hit somethin hard at 12699ft. Found n a itator! 15:50 - 19:40 3.83 DRILL P PROD2 POH for agitator. Pull through window/ramp -clean. Open EDC & jet max rate while POH.Jetted SSSV area with open EDC POOH and increased WHP to 950 psi, closed SSSV and it holds. 19:40 - 21:15 1.58 DRILL P PROD2 POOH, tagged up, checked flow, OK LD BHA and motor and bit (2-1) Printetl: 4/11/LUUkf 1"L:4U:41 PM BP AMERICA Page 28 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31 /2008 Rig Name: NORDIC 2 Rig Number: Date From - To i Hours '~ Task Code NPT Phase i Description of Operations 3/22/2008 19:40 - 21:15 1.58 DRILL P PROD2 Lined out flow loop through Swaco choke and applied 950 psi to well head. Maintain a constant WHP while circulating at 0.25 bpm. Replaced pack-offs, counter assembly and o-ring seals on the 2" hydraulic RIH side of injector. Wipe down 480 injector. BHI checking coiltrac 21:15 - 22:45 1.50 DRILL P PROD2 PJSM on CDL. Slip and cut drilling 22:45 - 23:00 0.25 BOPSU P PROD2 PJSM on Function testing BOP's. Function test same 23:00 - 23:15 0.25 DRILL P PROD2 PJSM on PU BHA 23:15 - 00:00 0.75 DRILL P PROD2 SD and trapped 950 psi on wellhead. bleed pressure off the top and confirmed the integrity of the SSSV. OK PU BHA and scribed offset on MWD tool 3/23/2008 00:00 - 00:30 0.50 DRILL P PROD2 Finish MU BHA 00:30 - 02:23 1.88 DRILL P PROD2 RIH with BHA with MPD technique. Stopped at 1750 ft and open SSSV with equal pressure. RIH 02:23 - 02:40 0.28 DRILL P PROD2 Logged GR marker (Plus 11 ft) 02:40 - 05:00 2.33 DRILL P PROD2 RIH, (no problem in the ramp or window area). RIH with correct TF and following pressure schedule 05:00 - 05:30 0.50 DRILL P PROD2 Tagged bottom at 12,699 ft . Pp high,4300 psi) with agitator Qp = 1.45 / 1.47 bpm CTP = 4142 psi On bottom 4350 psi Density = 9.77 / 9.73 ppg BHP /WHP = 4628 / 300 psi ECD = 13.73 ppg Vp = 326 bbl 05:30 - 05:50 0.33 DRILL P PROD2 -Gas cut mud at surface, divert to tiger tank. Increased WHP to 400 psi, PU off bottom and work Notified 30 Pad Operator of the gas venting. Took 25 bbl of gas cut mud to tiger tank 05:50 - 08:00 2.17 DRILL P PROD2 Tagged bottom at 12,726 ft . Op = 1.45 / 1.47 bpm CTP = 4195 psi On bottom 4350 psi Density = 9.77 / 9.00 ppg Still cleaning up BHP/WHP=4713/300 psi ECD=I4.OOppg Vp = 310 bbl Drilled to 12,850ft. 08:00 - 09:55 1.92 DRILL P PROD2 Wiper trip to 10,150ft w/ 1.45bpm/4250psi -clean. 09:55 - 11:35 1.67 DRILL P PROD2 Reduce to min mate while RIH from 10145ft to 10200ft. Increase to 1.4bpm/4100psi while RIH. Very ratty below 12800ft. 11:35 - 14:55 3.33 DRILL P PROD2 Drilling Lateral in Kup A2 from 12850ft TF at 90-70 R Qp = 1.43 / 1.43 bpm CTP = 4241 psi On bottom 4440 psi Density = 9.77 / 9.83 ppg BHP /WHP = 4725 / 350 psi ECD = 14.03 ppg Vp = 291 bbl DHWOB at 0.9k-1.5k and CTW at -65001b. ROP 40-70 fph 14:55 - 16:55 2.00 DRILL P PROD2 Wiper trip to 10,150ft w/ 1.45bpm/4250psi -clean. 16:55 - 19:00 2.08 DRILL P PROD2 Reduce to min mate while RIH from 10145ft to 10200ft. Increase to 1.4bpm/4100psi while RIH. Little drag at 12, 800 to 12, 850 ft, worked through. Tagged bottom at 13,025 ft 19:00 - 00:00 5.00 DRILL P PROD2 Tagged bottom at 13,024 ft. Drilled lateral from 13,024 ft at Rside TF Op = 1.39 / 1.35 bpm Had to drop the Op to 1.37 bpm due to high CTP CTP = 4250 / 4570 psi WOB / DHWOB = 0.56k / 1500 Ibf Vp = 273 bbl ROP is 20 to 40 fph rnmea: anuzuua icau:ai rm BP AMERICA Page 29 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours Task Code NPT Phase ', Description of Operations 3/24/2008 00:00 - 00:25 0.42 DRILL P PROD2 Drilling lateral to a TD of 13,187~ft MD and 6500 ft TVDss 00:25 - 02:45 2.33 DRILL P PROD2 Wiper trip to tie-in to 10166 ft 02:45 - 03:15 0.50 DRILL P PROD2 RIH to 10365 ft. Logged 10,365 ft 10394 ft and corrected +8 ft 03:15 - 05:15 2.00 DRILL P PROD2 RIH to confirm TD. Had trouble with the shales at 12,800 to 12,900 ft. Used lower flowrates and various speeds to get from 12,800 ft to 13, 180 ft. Tagged at 13,185 ft 05:15 - 10:30 5.25 DRILL P PROD2 POOH laying in 1 ppb beads, spotted only in open hole. Reduce pulling speed at 10,900ft & increase pump rate & CBU, divert to tiger tank as needed due gas in returns. Continue to POH following pressure schedule. SD pumps & pull through window/ramp area -clean. Start pumping ~ 9900ft while POH following pressure schedule -swap to hand choke due to bead issues packing off MI choke. Close TRSSV & flow check. Continue POH pumping. Tag up, stop pumping. 10:30 - 10:45 0.25 DRILL P PROD2 Flow check well. 10:45 - 11:00 0.25 DRILL P PROD2 PJSM regarding LD BHA. 11:00 - 12:00 1.00 DRILL P PROD2 Pop off well. Break off coil from BHI tools. Place injector over bung hole & circulate. Blow down/purge BHI's tools w/ water/air & LD on catwalk. Oil agitator prior to storage & test same - good vibrations. Smith bit was same condition prior to running. Prep BHI tools for running liner. C/O elevators. 12:00 - 12:15 0.25 DRILL P PROD2 PJSM regarding running liner. 12:15 - 15:00 2.75 CASE P LNR2 MU liner per pro ram. PU BHI tools w/ knuckle jt & 3" Hyd GS. U coil to tools. Stab injector onto well. 15:00 - 17:55 2.92 CASE P LNR2 Pump down backside & pressure up well to 1200psi. Open TRSSSV. RIH following pressure schedule while pumping down backside to assist WHP stabilization. WT ck @ 9900ft, 6k RIW, 23k up wt. RIH through ramp/window -clean. Log down @ 10990ft for tie-in (+17ft corr. Continue to RIH. RIW = -5.5k # 13,000ft. Tag bottom at 13,186ft. PU to 13,175ft = 28k. Tag bottom at 13,186ft. Line up down coil & pump at 1.5bpm C~ 4500psi holding 400psi WHP. PU & release from liner, 20k up. SD pumps & trap 900 psi while slowly PUH, 22k up. 17:55 - 21:04 3.15 CASE P LNR2 POH pumping 0.87bpm/3150psi following pressure schedule. OOH and closed SSV with 1150 psi on well 21:04 - 21:30 0.43 CASE P LNR2 LD liner setting BHA 21:30 - 22:10 0.67 CASE P LNR2 PJSM on handling tubulars /liner 22:10 - 00:00 1.83 CASE P LNR2 PU and RIH with liner 3/25/2008 00:00 - 01:10 1.17 CASE P LNR2 Finish PU liner as per Summa Held PJSM on PU BHI's Coiltrac and BOT AI Billet. PU Same and stabbed on injector head Set counter at 1538.62 ft Set Swaco pressure set point to 1350 psi 01:10 - 03:25 2.25 CASE P LNR2 RIH with 1340 psi on well head down the backside. Wt check at 9890 ft = 22,000 Ib Run in wt 4klb. (WHP = 12000 psi). RIH Wt check at 11700 ft "34.~- ~~ ~ = 2.4 at 20 fpm. RIH and taaaed at 11.239 ft. DH WO shoe at 2.7k Released from~iner and PU, lost 4000 Ib of liner wt. Top 03:25 - 06:35 3.17 CASE P LNR2 POOH maintaining WHP 06:35 - 07:15 0.67 CASE P LNR2 Tagged up, closed SSSV and released topside WHP. Confirmed SSSV integrity. Continue OOH filling tubing. Flow check -good. PJSM regarding LD BHA. Pop off well. Blow down/purge BHI's tools with water/air. LD same BHA on Printed: 4/11/2008 12:40:41 PM i b ~~~ ` ~~_ BP AMERICA Page 30 of 36 Qperations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From -To ', Hours Task Code NPT Phase ', Description of Operations 3/25/2008 06:35 - 07:15 0.67 CASE P LNR2 catwalk. Close both swab valves. 07:15 - 07:30 0.25 STWHIP P PRODS MU weight bar & swizzle stick, stab onto well & jet BOP stack. 07:30 - 09:10 1.67 STWHIP P PRODS Pop off well & LD weight bar & swizzle stick. Cut off CTC & dress wire. Stab onto well & reverse circulate. Pop off well & RU cutter. Cut 100ft of coil. MU new Kendall CTC. Pressure up well via MPD loop holding 1100psi WHP & open TRSSSV. 09:10 - 10:45 1.58 STWHIP P PRODS Head up BHI's UOC. 10:45 - 11:20 0.58 STWHIP P PRODS Pull test CTC to 30k -good. Pressure test to 4000psi -good. 11:20 - 17:30 6.17 BOPSU P PRODS Perform weekly BOPE test per AOGCC regs. State witnessed by John Crisp. Pressure tested to 250psi/4500psi -PASS. 17:30 - 18:30 1.00 BOPSU P PRODS Crew change and take on 200 bbl of new flo-pro 18:30 - 18:53 0.38 BOPSU P PRODS PJSM with crew on PT the inner valve. Discuss hazards and miigated hazards 18:53 - 20:00 1.12 BOPSU P PRODS PU inject and stab on welll to test inner reel valve and stripper 20:00 - 20:30 0.50 BOPSU P PRODS Completed pressure test of all Surface equipment. Close SSSV check for flow ~ surface. 20:30 - 21:00 0.50 BOPSU P PRODS Safety meeting/procedure review prior to P/U BHA. 21:00 - 21:20 0.33 STWHIP P PRODS Deploy BHA #26, 2-3/8" Xtreme with 2.730" STR324 PDC Bit. Total BHA lenght 61.97ft. 21:20 - 21:30 0.17 STWHIP P PRODS Make up Injector, RIH to 175' CTMD, pressure up WHP to 1150 psi & open SSSV. Continue to RIH 21:30 - 23:00 1.50 STWHIP P PRODS Slow speed, tie in depth 9564ft CTMD. 23:00 - 23:30 0.50 STWHIP P PRODS Adjusted depth + 10.5 ft (9605ft to 9615.5ft), continue RIH. 23:30 - 00:00 0.50 STWHIP P PRODS Slow speed from 10,000 ft, stop pumping ~ 10,050ft through window. Ta ed Billet Plu ~ 10 256 um sat min. rate. 3/26/2008 00:00 - 00:10 0.17 STWHIP P PRODS Tagged billet C~ 10,256 ft P/U and increase pump rates to 1.4 bpm, start sidetrack ~ 10,255 ft CTMD. Establish good 1:1 returns holding 400 psi WHP using 9.8# MW. 00:10 - 01:20 1.17 STWHIP P PRODS 10,256ft Getting Alum. cutting to surface, holding 1:1 returns n ~ ~~ with 400 psi WHP. MW 9.8# in/out. Sitting down 150# to 240# , on bottom while time drilling. 01:20 - 03:34 2.23 STWHIP P PRODS Timed mill off of billet to 10,259 ft 03:34 - 06:11 2.62 STW HIP P PRODS Drillina to 10, 270 ft and back reamed above 10,250 ft ~~ TF at 15R HS Backed reamed at 30L, 15R and 60R TF 06:11 - 06:30 0.32 STWHIP P PRODS RIH to drill turn section Drilling turn section Op = 1.46 / 1.46 bom at 4017 psi off bottom Density = 9.81 / 9.81 ppg DHWOB /ROP = 1.8k at 43 fph BHP /WHP = 4665 / 4100 psi ECD of 13.8 ppg Vp = 438 bbl Window 10,255 ft to 10,259 ft 06:30 - 07:30 1.00 STWHIP N DFAL PRODS Plugged motor, orient TF to HS and pulled above window. Tried to circulate the CT and its still plugge. Open EDC and circulated at 1.4 bpm while hold in 400 to 600 psi on wellhead. SD and close EDC and try circulating. Motor still plugged. 07:30 - 09:10 1.67 STWHIP N DFAL PRODS POOH for motor change. Held PJSM and covered hazards associated with handling the BHA and the closed SSSV. POOH, at 1600 ft and 1190 psi, closed SSSV and checked integrity. OK POOH 09:10 - 09:55 0.75 DRILL N DFAL PRODS Changed out Motor (1.5 deg AKO) and PU RR STC BC bit ST bit is plugged with Alumium and stator rubber 09:55 - 11:35 1.67 DRILL N DFAL PRODS Set counters and RIH, Pressured up on the WH to 1200 psi Printetl: 4/11/2008 12:40:47 F'M BP AMERICA Page 31 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/26/2008 11:35 - 11:50 0.25 DRILL N DFAL PRODS Log tiein at 9580 ft down Corrected +4 ft 11:50 - 12:10 0.33 DRILL N DFAL PRODS RIH 12:10 - 14:14 2.07 DRILL P PRODS Ta ed bottom at 10,285 ft Op = 1.46 / 1.46 and 4,160 psi Density = 9.81 / 9.81 ppg DHWOB /ROP = 1.8k at 43 fph BHP / WHP = 4,688 / 410 psi ECD of 13.8 ppg Vp = 236 bbl Window 10,255 ft to 10,259 ft 14:14 - 16:35 2.35 DRILL P PRODS POOH, tagged up and closed SSSV with 1250 psi below. Checked flow OK Held PJSM on handling BHA 16:35 - 18:30 1.92 DRILL P PRODS LD BHA Circulating and maintaing constant BHP using MPD technique Crew change out 18:30 - 18:45 0.25 DRILL P PRODS Safety Meeting/ Procedure review prior to P/U BHA. 18:45 - 19:30 0.75 DRILL P PRODS Close SSSV, monitor well, remove night cap & P/U BHA # 28 - 2-3/8" Coiltrack, 2.7 X 3" Bi-center, AKO 1.1, total lenght 71.69ft. make up CT Injector and begin to RIH slowly. 19:30 - 19:45 0.25 DRILL P PRODS Pressure up to 1200 psi, Stop CT ~ 175' open SSSSV, RIH. 19:45 - 21:15 1.50 DRILL P PRODS Log tie in from 9580 ft. 21:15 - 21:50 0.58 DRILL P PRODS Correction depth +8.5ft. Continue to RIH slowly 21:50 - 22:20 0.50 DRILL P PRODS Mad Pass from 10255 - 10370 ft. Res tool not functioning properly. 22:20 - 00:00 1.67 DRILL P PRODS On bottom drilling 10,370ft : Op 1.5 bpm/4400 psi Density 9.81/ 9.80 DHWOB 2.9 / 21fph BHP/WHP 4560 / 402 ECD 13.52 Current de th at midni ht 10,439 ft. ROP - 60 fUhr 3/27/2008 00:00 - 00:55 0.92 DRILL P PRODS Short trip from 10500ft to 10265'. Vac truck removed 290 bbls of dirty DM. Transferred 280 bbl of clean 9.8 DM. Total pit volume of clean DM 387 bbls. 00:55 - 01:55 1.00 DRILL P PRODS Mad Pass from 10265' to 10500'. 01:55 - 04:00 2.08 DRILL P PRODS BOBD -crews reviewed Spill response and Fire Drills procedures. GeoSteer in Kup Al sand as per Geologist 1.50 BPM/ 4300 psi Density = 9.78 / 9.82 ppg 1:1 DHWOB / ROP 1.90 / 78 fph BHP/WHP = 4600/410 psi ECD=13.58ppg Vp= 387 bbls Current depth 10600 ft 04:00 - 04:40 0.67 DRILL P PRODS Wiper trip from 10650' to 10275' 04:40 - 07:10 2.50 DRILL P PRODS GeoSteering in KupA1 sand as per Geologist from 10,650 ft to 10,800 ft Op = 1.5 BPM/ 4100 psi 9.78/ 9.85 density 1:1 DHWOB/ROP = 1.4/ 67fph BHP/WHP = 4590/400 ECD 13.5 Vp = 383 bbl 07:10 - 08:28 1.30 DRILL P PRODS Wiper Trip at 10,800 ft 08:28 - 12:05 3.62 DRILL P PRODS GeoSteering in KupA1 sand as per Geologist from 10,800 ft to 10,823 ft Orient TF to 135 R and drop TVD. Op = 1.5 / 1.5 BPM ~ 4100 psi off bottom Printed: 4/11/2008 12:40:41 PM BP AMERICA Page 32 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code ~i, NPT ~ Phase ~ Description of Operations 3/27/2008 108:28 - 12:05 3.621 DRILL P PRODS 9.78/ 9.85 ppg density 1:1 12:05 - 13:00 0.92 DRILL P 13:00 - 14:00 1.00 DRILL P 14:00 - 16:00 ~ 2.00 DRILL ~ P 16:00 - 17:50 1.83 DRILL P 17:50 - 20:00 2.17 DRILL P 20:00 - 21:15 1.25 DRILL P 21:15 - 00:00 2.75 DRILL P 3/28/2008 00:00 - 00:30 0.50 DRILL P 00:30 - 01:40 1.17 DRILL P 01:40 - 03:30 1.83 DRILL P 03:30 - 04:40 1.171 DRILL P 04:40 - 05:06 0.43 DRILL P 05:06 - 06:35 1.48 DRILL P 06:35 - 06:55 0.33 DRILL P 06:55 - 10:00 3.08 DRILL P DHWOB / ROP = 1.4/ 67fph BHP/WHP = 4590 psi /400 fpm w/ ECD 13.5 ppg Vp = 371 bbl PRODS Wiper trip at 10,950 ft Clean PRODS GeoSteering in KupA1 sand as per Geologist Goal To drill to 11 200 MD and land at 6525 ft TVD Op = 1.5 / 1.5 BPM ~ 4140 psi off bottom 9.78! 9.85 ppg density 1:1 DHWOB / ROP = 1.4/ 67fph BHP/WHP = 4590 psi /400 fpm w/ ECD 13.5 ppg Vp = 366 bbl PRODS Drillled into ankerite and the ROP came to a halt then broke through Op = 1.5 / 1.5 BPM C~3 4140 psi off bottom 9.78/ 9.85 ppg density 1:1 DHWOB / ROP = 1.4/ 67fph BHP/WHP = 4616 psi /377 fpm w/ ECD 13.64 ppg Vp = 362 bbl PRODS Wiper trip PRODS Drilllin to 11250ft riorto Wi er Op = 1.5/ 4100 9.78/ 9.90 density 1:1 DHWOB/ROP 1.5 / 60 fph BHP/WHP 4630psi/ 390 psi ECD 13.7 Vp 350 PRODS Wiper trip to 10275ft. PRODS BOBD from 11250 ft, current depth ~ midnight 11,385 ft Op = 1.5 bpm/ 4160 psi 9.9/9.80 density 1:1 DHWOB/ROP 2.3/ 60fph BHP/WHP 4660/400 ECD 13.72 VP 342 bbls PRODS Continue drilling to 11,400' PRODS Wiper trip to 11,275' PRODS BOBD target depth 11,550 ft. Op = 1.48 bpm at CTP of 4,300 psi Density + 9.89/ 9.9 ppg DHWOB / ROP = 1.9 / 72 fph BHP /WHP 4690 psi / 400 psi ECD 13.73 ppg Vp = 337 bbls TD Lateral 11,545ft PRODS Wiper up to Tie in depth 9,585 ft. Slow to min. pump rate/pinch in choke from 10,260 ft up to window. Stop pumping/close choke, no problems ~ window. Increase pump rate and open choke slowly. ECD 13.63 ppg PRODS Tie in starting depth 9,585 ft. Correction+l7 ft PRODS RIH to confirm TD Tagged TD at 11,555 ft, PU and confirmed PRODS Circulate liner pill down CT and lay in (no beads as per engineer) PRODS POOH laying in liner pill and following the MPD Pressure schedule plus 100 psi Printed: 4/11/2008 12:40:41 PM ~ ~ BP AMERICA Page 33 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date I' From - To Hours. .Task Code NPT Phase Description of Operations 3/28/2008 06:55 - 10:00 3.08 DRILL P PROD3 At surface, closed SSSV and bleed off topside and SSSV is holding 10:00 - 10:15 0.25 DRILL P PROD3 Held PJSM and discussed Hazard associated with LD USR directional BHA 10:15 - 11:05 0.83 DRILL P PROD3 LD BHA 11:05 - 11:25 0.33 CASE P LNR3 Held PJSM and disussed Discussed with town the plan forward on the L2 lateral 11:25 - 13:00 1.58 CASE P LNR3 PU slotted liner as er Summa PU CoilTrac with GS running tools Line up Swaco choke to hold 1250 psi on the wellhead / annulus 13:00 - 14:45 1.75 CASE P LNR3 RIH and at 10,000 ft PUW = 23,000 Ib up, RIH, stopped at 10,360 ft and logged down to tie-in 14:45 - 15:08 0.38 CASE P LNR3 Log tie-in down from 10,360 ft / 9545 ft MD BHP = 4377 psi at 13.7 ppg. ECD WHP = 963 psi + 8 ft correction 15:08 - 15:40 0.53 CASE P LNR3 RIH, wt check at 11,525 ft = 26k RIH and tagged TD at 11,557 : ft Lined out to pump down the CT. Op = 1.35 bpm at 4050 psi Lost 2k without pump 15:40 - 18:00 2.33 CASE P LNR3 POOH with liner running tools and Coiltrak following MPD pressure schedule 18:00 - 18:30 0.50 CASE P LNR3 CT ~ surface, weight is 2000# heavier than last trip. Discuss possibilty of Liner still attached to CT BHA during safety meeting. 18:30 - 19:15 0.75 CASE P LNR3 Close SSSV, 1250 psi WHP, bleed down and monitor pressure. Remove injenctor head, P/U BHA and the liner string did come back with the BHA. Remove upper part of BHA, install Safety joint across BOP's until GS is inspected/rebuilt. 19:15 - 20:00 0.75 CASE N DFAL LNR3 Upon tesUinspection of the BHA the knuckle joint seals were leaking. Decision made to remove the knuckle joint and re-run the BHA. 20:00 - 20:30 0.50 CASE N DFAL LNR3 P/U BHA, make up injector. Pressure up above SSSV to 1200 psi, open &RIH. 20:30 - 22:30 2.00 CASE N DFAL LNR3 RIH to Tie in depth of 10,360 ft 22:30 - 22:46 0.27 CASE N DFAL LNR3 Tie in correction of + 1ft, continue to RIH. 22:46 - 23:12 0.43 CASE N DFAL LNR3 RIH weight check C~3 11520 ft 26,000#. Down weight 4200# C~ surface. 23:12 - 23:40 0.47 CASE N DFAL LNR3 Tag bottom Cad 11556ft P/U weight 25,000# POOH up to 11540 t Start pumping C~3 1.6 bpm, reduce WHP to 300 psi, Circ. press. 4600psi RIH weight 2300# on CT, tag bottom sit down to -4200# on CT weight 3.0 WOB, P/U weight 20,400# still pumping same rate and pressures. Close choke & shut down pumps to verify initial weight check ~ 11400 ft. Currently 3000# lighter on CT weight ,POOH pumping as per MPD schedule. Liner top left at 10750' 23:40 - 00:00 0.33 CASE N DFAL LNR3 POOH pumping as per MPD schedule from 11400 ft. 3/29/2008 00:00 - 02:00 2.00 CASE N DFAL LNR3 POOH, following the MPD schedule. Close SSSV as a precaution if the liner is still attached. WHP 1200 psi, bleed Printed: 4/11/2008 72:40:41 F'M 3® ~~ BP AMERICA Page 34 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT -Phase Description of Operations 3/29/2008 00:00 - 02:00 2.00 CASE N DFAL LNR3 down at surface. 02:00 - 02:30 0.50 CASE P LNR3 Remove CT injector off well, lay down BHA -Liner was set in place. Set up valves on surface for MPD procedure at surface. ~ ~ ii ~ Close master & swab valves, pressure up to 1200 psi, open 2 - , L SSSV. 02:30 - 03:15 0.75 STWHIP P PROD4 Baker surface testing BHA prior to Deployment. 03:15 - 03:35 0.33 STWHIP P PROD4 Discuss pressure deployment procedures and personnel tasks. 03:35 - 06:54 3.32 STWHIP P PROD4 Pressure deploy BHA 06:54 - 08:40 1.77 STWHIP P PROD4 RIH with STR 324 ST BHA (1.5deg AKO) 08:40 - 08:44 0.07 STWHIP P PROD4 Tie in at 9545 ft at 150 fph Corrected + 2ft 08:44 - 09:38 0.90 STWHIP P PROD4 RIH with the drilled TF and MPD Pressure schedule 09:38 - 09:44 0.10 STWHIP P PROD4 RIH and tagged the aluminum billet at 10750.8 ft dry tagged. PUH 09:44 - 13:20 3.60 STWHIP P PROD4 Time Mil ing o i e Started at 10,749.54 ft Qp = 1..52 / 1.53 bpm at 3960 psi off bottom Milled for 1 ft and then took brake off and try to drill Some '~~.~ ~° packing off around the tool 13:20 - 15:10 1.83 STWHIP P PROD4 Drilling ahead from 10,753' CP=3900 psi _ 1 ~ ~ Op= In/Out = 1.52 / .51 bpm ECD 13.4 ppg WOB 3700 Ibs DH WOB 2100 Ibs with ROP 6 ft/hr Pit Volume = 276 bbls 15:10 - 15:55 0.75 STWHIP P PROD4 Hanging up at 10,758' with no motor work Short Trip to 10,265' 15:55 - 19:00 3.08 STWHIP P PROD4 10,756' first WOB indication drilling ahead Op= in 1.54 bpm out 1.53 bpm CP=3975 psi TF~17deg RT Den=9.86/9.94 ppg DH Press.=4532 psi; DH WOB=3200 Ib Pit Vol=276 bbls Changed TF to 121 RT C~ 10,770' Hard drilling 19:00 - 19:30 0.50 STWHIP P PROD4 10,785' begin POOH/ backreaming through billet section no problems. Stop POOH ~ 9550' ft. Open Circ. sub in BHA. 19:30 - 21:00 1.50 STWHIP P PROD4 POOH from 9550' while following the MPD schedule. 21:00 - 21:15 0.25 STWHIP P PROD4 Discuss Un-deplying procedure. Shut in choke and maintain 1200 psi on WHP. 21:15 - 23:00 1.75 STWHIP P PROD4 Undeploying BHA. Milling bit was in good shape with no AI fragments in bit nozzles. 23:00 - 00:00 1.00 DRILL P PROD4 Make up & test BHA at surface. Pre-deployment safety meeting. 3/30/2008 00:00 - 02:15 2.25 DRILL P PROD4 Deploy BHA #32, Coiltrak Extreme AKO 1.1"with 2.70" X 3.0" Smith Bicenter bit. 02:15 - 04:00 1.75 DRILL P PROD4 RIH following MP schedule. 04:00 - 04:30 0.50 DRILL P PROD4 Tie depth 9580' -1 correction 04:30 - 05:12 0.70 DRILL P PROD4 RIH try MAD pass from 10730' ,resistivity tool not functioning properly. Continue in hole, no problems past billet section. 05:12 - 08:15 3.05 DRILL P PROD4 Tagged at 10,785 ft Op = 1.46 / 1.44 bpm at 4000 psi off bottom pressure DHBHP / WH = 4577 / 293 psi ECD at 6508 ft TVD = 13.56 PP9 TF average 10R to 135R deg Printed: 4/11/2008 12:40:41 PM BP AMERICA Page 35 of 36 Operations Summary Report Legal Well Name: 3 0-02 Common W ell Name: 3 0-02 Spud Date: 10/2/1988 Event Nam e: REENTE R+COM PLET E Start : 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALIST A Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: ~ Date ' From - To Hours Task I Code NPT Phase Description of Operations 3/30/2008 08:15 - 09:00 0.75 DRILL P PROD4 Wiper trip to 10,400 ft Little motor work at 10,765 ft Mud swap 09:00 - 11:50 2.83 DRILL P PROD4 Tagged at 10,950 ft drilled to 11,100 ft MD Op = 1.46 / 1.44 bpm at 4000 psi off bottom pressure DHBHP /WHP = 4577 / 293 psi ECD at 6508 ft TVD = 13.56 PP9 TF 135R deg The geologist target is a moving icon at approximately 11,200 ft MD with a corresponding TVD of 6,498 ft 11:50 - 13:27 1.62 DRILL P PROD4 Wiper trip and MAD Pass (10,777 ft to 10,830 ft) Logged MAD Pass as per Geologist 13:27 - 16:05 2.63 DRILL P PROD4 Tagged at 11,100 ft MD and drilled to 11,250 ft Op = 1.54 / 1.1.55 bpm at 4100 psi off bottom pressure DHBHP /WHP = 4573 / 325 psi ECD at 6496 ftTVD = 13.56 PP9 TF 64R deg 11255 ft MD TVDss 6495 ft the build 2 ft to TD 16:05 - 17:35 1.50 DRILL P PROD4 Wiper trip to 10, 265 ft, Clean up and down 17:35 - 21:00 3.42 DRILL P PROD4 Tagged at 11,250 ft MD. Drilled to 11468 ft (approximately) Op = 1.50 / 1.1.51 bpm at 4135 psi off bottom pressure DHBHP/WHP=4550/325 psi ECD at6496ftTVD=13.61 PP9 TF 145E deg Projected TD at 11468 ft MD ~ 6487 ft TVDss 21:00 - 22:00 1.00 DRILL P PROD4 Wiper trip from TD 11,468 up to 9575' Bit depth. Tie in Correction depth +6 ft. 22:00 - 00:00 2.00 DRILL P PROD4 RIH tag TD ~ 11471 ft. POOH to 10,500ft. RIH to TD spot Hi Visc pill. 3/31/2008 00:00 - 03:00 3.00 DRILL P PROD4 Complete spotting 50 bbl Pill, est. from TD to 9,000 ft. Open Circ sub once above window. Continue pumping using MP guidelines while POOH, 03:00 - 03:30 0.50 DRILL P PROD4 Close SSSV with 1250 psi on WH, bleed down ~ surface. Hold Safety meeting to discuss laying down BHA & P/U liner as per tally. 03:30 - 04:00 0.50 DRILL P PROD4 Lay down BHA. 04:00 - 04:15 0.25 CASE P LNR4 Safety meeting for P/U liner & tally review. 04:15 - 06:00 1.75 CASE P LNR4 Start P/U liner. 06:00 - 06:30 0.50 CASE P LNR4 Crew change and PJSM with daylite 06:30 - 07:55 1.42 CASE P LNR4 Finish PU liner as per Llner Summa Stab in injector. 07:55 - 08:00 0.08 CASE P LNR4 RIH with Liner. 08:00 - 08:30 0.50 CASE P LNR4 While Pressureing up on the wellhead, the CT pressure increased invertly and the pump was then shut down. CTP was bleed off Unstab injector to verify liner is still attached. Liner was still attached, Stab in injector. 08:30 - 10:10 1.67 CASE P LNR4 RIH with liner. Wt check at 9,900 ft = 21 k 10:10 - 10:45 0.58 CASE P LNR4 RIH (open hole) with liner Tagged at 11471 ft MD Lined up through CT with fluid and release from liner with 4k WOS With Op at 1.5 bpm and CTP at 4500 psi PU on and lost 2000 Printed: 4/11/2008 12:40:41 PM 1 M BP AMERICA Page 36 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours ~, Task Code NPT Phase Description of Operations - --- 3/31/2008 10:45 - 12:45 2.00 CASE P LNR4 POOH following MPD schedule. 12:45 - 13:20 0.58 CASE P LNR4 Closed SSSV and bleed top side WHP down to 0 psi. Unstab injector and PU CoilTrak BHA. Liner gone 13:20 - 15:20 2.00 CASE P LNR4 RIH with stinger BHA 15:20 - 15:55 0.58 CLEAN P CLEAN Displace well with seawater. Op= 1.86/1.74 bpm in/out CP=4000 psi. WHP=500 psi. in /out density at start 8.73/9.84 ppg. 15:55 - 17:30 1.58 CLEAN P CLEAN POOH displacing flo pro with SW and holding 1500 to 2000 psi on well Stopped at 2,500 ft and pumped 30 bbl of Diesel. 17:30 - 18:00 0.50 CLEAN P CLEAN Ct C~3 surface. Close SSSV, 1600 psi on WH, bleed down ~ surface. 18:00 - 18:30 0.50 CLEAN P CLEAN Crew change & Safety meeting reviewing Rig down procedure prior to removing injector. 18:30 - 19:00 0.50 WHSUR P CLEAN Remove BHA, displace and purge CT for rig move. 19:00 - 19:30 0.50 WHSUR P CLEAN Confirm SSSV is holding ,set BPV. "0" pressure ~ surface. 19:30 - 21:00 1.50 WHSUR P CLEAN Install CT grapple, Unstab CT from Injector. Remove injector legs and stripper. Set down injector on rig floor for maintenance. 21:00 - 21:15 0.25 BOPSU P POST Pre-job safety meeting for ND BOP stack and valves. 21:15 - 00:00 2.75 BOPSU P POST ND BOP's, valves and hard line to TT. Install tree cap and Pressure test to 4000psi. Rig released (~ midnight. Printed: 4711/2008 12:40:41 PM ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 30 Pad 30-02 30-OZA TD Design: 30-02A TD Baker Hughes INTEQ Survey Report 03 April, 2008 r~~r BAKER FI~I~FIES INTE(~ ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Welibwe: 30.02A TD Design: 30-02A TD ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: Well 30-02 TVD Reference: Mean Sea Level MD Reference: 30-02 Q 59.OOft (30-02) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod r rl-.r B~t~s LNTEQ Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site _Kuparuk 30 Pad _ Site Position: Northing: 6,022,094.67 ft Latitude: From: Map Easting: 525,478.25 ft Longitude: Position Uncertainty: 0.00 ft Slot Radius: 0 " Grid Convergence: Well 30-02 Well Position +N/-S 0.00 ft Northing: 6,022,073.89ft Latitude: +E/-W 0.00 ft Easting: 525,490.94 ft Longitude: Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: Wellbwe 30.02A TD Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2007 10/24/2007 17.95 79.82 57,269 Design 30-02A TD Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +N/-S (ft) (ft) 0.00 0.00 _. _ _ __ Tie On Depth: +E/-W (ft) 0.00 10,000.00 Direction (°) 225.00 70° 28' 17.333 N 149° 47' 30.897 W 0.20 ° 70° 28' 17.128 N 149° 47' 30.526 W 0.00 ft S s 4/3/2008 2:21:25PM Page 2 COMPASS 2003.16 Build 42F ~-" ConocoPhillips ConocoPhiillps Baker Hughes INTEQ Survey Report Alaska Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 30 Pad MD Reference: Well: 30-02 North Reference: Welibore: 30-02A TD Survey Calculation Method: Design: 30-02A TD Database: Survey Program Date From To (ft) (ft) Survey (Welibore) Tool Name Description 100.00 10,000.00 30-02 (30-02) BOSS-GYRO Sperry-Sun BOSS gyro multishot 10,056.00 13,137.50 30-02A MWD TD (30-02A TD) MWD MWD -Standard Survey Well 30-02 Mean Sea Level 30-02 Q 59.OOft (30-02) True Minimum Curvature EDMv16 Prod r~.r i$ Wolf YR4 MD Inc Azl TVDSS NIS EIW Northing Easting DLS Vertical Section TFO (ft) (°) (°) (ft- (ft) (ft) (ft) (ft) (°llooft) (ft) (°- 10,000.00 47.50 293.70 6,434.02 3,989.47 -6,003.86 6,026,042.38 519,474.05 2.07 1,424.39 140.04 ', 10,056.00 46.59 294.48 6,472.18 4,006.20 -6,041.27 6,026,058.98 519,436.58 1.92 1,439.02 148.16 ' 10,078.32 59.79 294.48 6,485.53 4,013.58 -6,057.50 6,026,066.31 519,420.33 59.14 1,445.27 0.00 10,105.44 70.05 302.16 6,497.02 4,025.27 -6,079.04 6,026,077.92 519,398.76 45.67 1,452.23 35.85 10,133.94 73.15 304.09 6,506.02 4,040.05 -6,101.68 6,026,092.62 519,376.07 12.63 1,457.79 30.88 ', 10,161.25 79.38 295.65 6,512.51 4,053.22 -6,124.66 6,026,105.71 519,353.04 37.69 1,464.73 -53.84 ', 10,195.08 90.55 287.26 6,515.48 4,065.50 -6,155.96 6,026,117.88 519,321.71 41.21 1,478.18 -37.27 ', 10,225.53 90.71 291.12 6,515.15 4,075.50 -6,184.71 6,026,127.78 519,292.92 12.69 1,491.44 87.61 10,255.16 92.27 295.25 6,514.37 4,087.16 -6,211.93 6,026,139.35 519,265.67 14.89 1,502.44 69.26 10,288.42 90.89 298.33 6,513.46 4,102.14 -6,241.61 6,026,154.23 519,235.94 10.14 1,512.83 114.09 ', 10,325.10 91.17 303.20 6,512.80 4,120.90 -6,273.11 6,026,172.87 519,204.38 13.30 1,521.84 86.67 ~I 10,352.70 90.64 305.83 6,512.36 4,136.53 -6,295.85 6,026,188.43 519,181.59 9.72 1,526.86 101.37 ', 10,383.34 89.75 309.50 6,512.26 4,155.25 -6,320.10 6,026,207.06 519,157.28 12.32 1,530.78 103.62 ', 10,414.20 88.74 309.45 6,512.66 4,174.87 -6,343.91 6,026,226.60 519,133.40 3.28 1,533.75 -177.17 i 10,447.56 86.04 306.86 6,514.18 4,195.45 -6,370.11 6,026,247.09 519,107.13 11.21 1,537.72 -136.27 10,480.35 85.76 303.75 6,516.53 4,214.35 -6,396.80 6,026,265.90 519,080.38 9.50 1,543.22 -95.27 10,506.25 83.98 300.31 6,518.84 4,228.03 -6,418.67 6,026,279.50 519,058.47 14.91 1,549.01 -117.60 ', 10,535.02 85.08 297.61 6,521.59 4,241.90 -6,443.72 6,026,293.28 519,033.37 10.09 1,556.92 -67.87 10,569.04 86.44 295.24 6,524.10 4,256.99 -6,474.10 6,026,308.27 519,002.94 8.02 1,567.73 X0.17 ' 10,612.19 87.32 292.29 6,526.45 4,274.35 -6,513.53 6,026,325.49 518,963.46 7.12 1,583.34 -73.45 10,646.52 87.17 289.44 6,528.10 4,286.57 -6,545.57 6,026,337.59 518,931.38 8.30 1,597.35 -93.08 4/3/2008 2:21:25PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Wellbore: 30-02A TD Design: 30-02A TD Survsy MD tft) 10,677.52 ~', 10,705.24 10,735.82 ', 10,761.73 ', 10,792.80 10,822.63 ', 10,858.04 10,891.45 10,923.55 10,957.13 ', 10,988.20 ', 11,021.93 ', 11,052.92 11,082.37 11,113.28 ', 11,147.03 ', 11,177.45 !, 11,209.57 ', 11,245.56 I 11,277.37 11,307.61 11,335.82 ~ 11,364.86 ', 11,396.50 '~ 11,429.56 11,460.11 11,490.88 Inc 87.76 87.61 88.34 88.99 89.66 90.95 90.12 90.55 91.78 91.01 90.28 88.47 89.48 88.43 89.51 89.48 89.11 85.85 85.23 84.22 82.96 83.48 83.45 83.98 88.10 90.92 92.42 Azf ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: Well 30-02 TVD Reference: Mean Sea Level MD Reference: 30-02 @ 59.OOft (30-02) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod 287.13 284.46 281.79 280.61 276.91 271.42 265.26 258.79 252.96 246.56 239.34 231.93 227.05 221.78 220.42 227.28 235.38 239.36 246.11 251.94 256.14 261.14 266.21 263.78 259.52 253.94 248.42 TVDSS N/S (ft) (ft) 6,529.47 4,296.28 6,530.59 4,303.82 6,531.67 4,310.76 6,532.28 4,315.79 6,532.64 4,320.52 6,532.49 4,322.69 6,532.15 4,321.66 6,531.96 4,317.03 6,531.31 4,309.20 6,530.49 4,297.59 6,530.14 4,283.47 6,530.51 4,264.45 6,531.06 4,244.33 6,531.60 4,223.30 6,532.15 4,200.02 6,532.45 4,175.69 6,532.83 4,156.70 6,534.24 4,139.40 6,537.04 4,122.98 6,539.97 4,111.64 6,543.35 4,103.38 6,546.68 4,097.86 6,549.98 4,094.69 6,553.45 4,091.94 6,555.73 4,087.15 6,555.99 4,080.14 6,555.10 4,070.23 E/W Northing (ft) (ft) -6,574.97 6,026,347.21 -6,601.62 6,026,354.65 -6,631.38 6,026,361.49 -6,656.79 6,026,366.43 -6,687.49 6,026,371.06 -6,717.23 6,026,373.12 -6,752.60 6,026,371.97 -6,785.67 6,026,367.23 -6,816.78 6,026,359.29 -6,848.26 6,026,347.58 -6,875.91 6,026,333.37 -6,903.73 6,026,314.25 -6,927.28 6,026,294.05 -6,947.88 6,026,272.96 -6,968.20 6,026,249.60 -6,991.57 6,026,225.20 -7,015.29 6,026,206.13 -7,042.31 6,026,188.74 -7,074.18 6,026,172.21 -7,103.75 6,026,160.77 -7,132.63 6,026,152.41 -7,160.09 6,026,146.80 -7,188.75 6,026,143.53 -7,220.08 6,026,140.68 -7,252.70 6,026,135.78 -7,282.42 6,026,128.67 -7,311.52 6,026,118.65 Fasting (ft) 518,901.95 518,875.28 518,845.50 518,820.07 518,789.36 518,759.62 518,724.25 518,691.20 518,660.12 518,628.68 518,601.08 518,573.33 518,549.85 518,529.32 518,509.09 518,485.81 518,462.15 518,435.20 518,403.38 518,373.86 518,345.01 518,317.57 518,288.92 518,257.61 518,225.01 518,195.32 518,166.26 DLS (°/100ft) 7.68 9.64 9.05 5.20 12.10 18.90 17.55 19.41 18.56 19.19 23.35 22.61 16.08 18.24 5.62 20.33 26.65 16.01 18.78 18.52 14.42 17.70 17.35 7.82 17.90 20.46 18.58 ~c.r s~~$ IN'CEQ Vertical Section (ft) 1,611.28 1,624.79 1,640.93 1,655.34 1,673.70 1,693.20 1,718.94 1,745.59 1,773.13 1,803.60 1,833.13 1,866.26 1,897.14 1,926.57 1,957.40 1,991.12 2,021.33 2,052.66 2,086.82 2,115.74 2,142.01 2,165.32 2,187.84 2,211.93 2,238.38 2,264.35 2,291.94 TFO -75.71 -93.27 -74.75 -61.16 -79.76 -76.77 -97.64 -86.18 -78.04 -96.78 -95.73 -103.75 -78.36 -101.31 -51.56 90.28 92.66 129.42 95.52 100.13 107.03 84.32 90.63 -77.76 -46.06 -63.23 -74.72 4/3/2008 2:21:25PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Weil: 30-02 Welibore: 30-02A TD Design: 30-02A TD Survey MD (n) 11,521.87 ', 11,556.31 ', 11,588.23 ', 11,634.87 ', 11,662.89 ', 11,691.99 ', 11,716.27 ', 11,746.04 ', 11,777.40 ', 11,808.54 ', 11,840.44 11,869.93 ', 11,912.36 ', 11,944.62 '~, 11,992.62 ', 12,028.58 12,059.92 12,096.13 12,128.33 12,160.39 12,190.53 ', 12,220.29 12,253.12 12,278.66 12,319.61 12,352.44 'I 12,385.51 ConocoPhillips Baker Hughes INTEQ Survey Report s~R ^ ~~ES LNTEQ Local Co-ordinate Reference: Well 30-02 TYD Reference: Mean Sea Level MD Reference: 30-02 @ 59.00ft{30-02) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Inc Azi TVDSS NIS E/W Northing Easting DLS Vertical Section TFO (°) (°) (ft) (ft) ln) (ft) lft) (°/100ft) (ft) (°) 95.53 244.31 6,552.95 4,057.84 -7,339.83 6,026,106.17 518,137.99 16.60 2,320.72 -52.69 93.78 239.34 6,550.15 4,041.63 -7,370.08 6,026,089.86 518,107.80 15.25 2,353.56 -109.24 93.35 235.46 6,548.17 4,024.47 -7,396.91 6,026,072.61 518,081.03 12.21 2,384.67 -96.21 93.63 227.42 6,545.32 3,995.48 -7,433.28 6,026,043.49 518,044.76 17.22 2,430.89 -87.76 95.33 223.42 6,543.13 3,975.88 -7,453.18 6,026,023.83 518,024.93 15.47 2,458.82 -66.76 95.38 221.31 6,540.42 3,954.47 -7,472.70 6,026,002.36 518,005.49 7.22 2,487.76 -88.54 93.90 217.11 6,538.45 3,935.72 -7,487.99 6,025,983.56 517,990.26 18.29 2,511.83 -109.29 92.06 221.13 6,536.90 3,912.66 -7,506.75 6,025,960.44 517,971.58 14.83 2,541.40 114.51 90.98 225.77 6,536.07 3,889.91 -7,528.30 6,025,937.61 517,950.11 15.19 2,572.73 103.04 92.03 231.76 6,535.25 3,869.40 -7,551.70 6,025,917.03 517,926.79 19.52 2,603.78 79.98 92.55 237.63 6,533.98 3,850.99 -7,577.70 6,025,898.53 517,900.85 18.46 2,635.18 84.82 94.83 241.75 6,532.08 3,836.14 -7,603.10 6,025,883.59 517,875.51 15.94 2,663.64 60.87 94.64 248.16 6,528.57 3,818.25 -7,641.39 6,025,865.57 517,837.28 15.06 2,703.37 91.44 94.77 253.18 6,525.92 3,807.61 -7,671.72 6,025,854.83 517,806.99 15.51 2,732.33 88.31 95.22 262.43 6,521.74 3,797.52 -7,718.40 6,025,844.58 517,760.35 19.22 2,772.48 86.81 94.73 263.70 6,518.62 3,793.19 -7,753.96 6,025,840.13 517,724.80 3.77 2,800.69 111.11 92.64 258.75 6,516.60 3,788.42 -7,784.86 6,025,835.26 517,693.92 17.11 2,825.91 -112.76 89.85 252.22 6,515.81 3,779.36 -7,819.88 6,025,826.07 517,658.94 19.61 2,857.09 -113.04 89.32 247.19 6,516.05 3,768.19 -7,850.07 6,025,814.80 517,628.79 15.71 2,886.33 -96.03 90.86 244.24 6,516.00 3,755.01 -7,879.29 6,025,801.52 517,599.62 10.38 2,916.31 -62.44 92.15 239.48 6,515.20 3,740.80 -7,905.85 6,025,787.23 517,573.11 16.36 2,945.14 -74.78 91.51 235.72 6,514.25 3,724.87 -7,930.96 6,025,771.21 517,548.06 12.81 2,974.16 -99.60 92.46 233.29 6,513.12 3,705.82 -7,957.67 6,025,752.07 517,521.41 7.94 3,006.52 -68.60 89.79 226.94 6,512.61 3,689.45 -7,977.26 6,025,735.64 517,501.89 26.96 3,031.93 -112.72 92.18 222.86 6,511.91 3,660.46 -8,006.15 6,025,706.55 517,473.10 11.55 3,072.87 -59.61 92.98 219.04 6,510.43 3,635.69 -8,027.64 6,025,681.71 517,451.69 11.88 3,105.58 -78.08 93.54 216.57 6,508.55 3,609.61 -8,047.88 6,025,655.56 517,431.55 7.65 3,138.33 -77.14 4/3/2008 2:21:25PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Wellbore: 30-02A TD Design: 30-02A TD Survey MD (ft) 12,422.08 ', 12,457.44 12,490.07 ', 12,520.67 12,550.11 12,580.06 12,610.29 12,640.24 12,670.54 12,699.99 12,738.16 ', 12,768.32 12,807.69 ', 12,843.41 12,874.22 12,904.51 12,933.68 12,964.33 ', 12,994.38 13,025.47 ', 13,055.42 13,085.31 ~i 13,115.42 ', 13,137.50 13,181.00 ConocoPhillips Baker Hughes INTEQ Survey Report sni~etr Ew~i~1Es 1N'L'EQ Local Co-ordinate Reference: Well 30-02 TVD Reference: Mean Sea Level MD Reference: 30-02 Q 59.OOft (30-02) North Reference: True Survey Calculation Method: Minimum Curvature. Database: EDMv16 Prod Inc Azi TVDSS NIS E/W Northing Easting DLS Vertical Section TFO (°) (°) (ft) (ft) (ft) (ft) lit) (°1100ft) (ft) (°) 91.53 209.52 6,506.93 3,579.00 -8,067.78 6,025,624.89 517,411.75 20.03 3,174.05 -105.75 89.32 203.57 6,506.67 3,547.39 -8,083.58 6,025,593.23 517,396.06 17.95 3,207.57 -110.34 88.77 200.05 6,507.21 3,517.10 -8,095.70 6,025,562.90 517,384.05 10.92 3,237.55 -98.91 90.55 198.05 6,507.40 3,488.18 -8,105.68 6,025,533.95 517,374.16 8.75 3,265.07 -48.34 87.08 195.13 6,508.00 3,459.98 -8,114.09 6,025,505.72 517,365.86 15.40 3,290.95 -139.95 85.64 194.79 6,509.91 3,431.11 -8,121.80 6,025,476.82 517,358.24 4.94 3,316.82 -166.75 85.26 196.49 6,512.30 3,402.09 -8,129.93 6,025,447.78 517,350.22 5.75 3,343.09 102.71 87.73 199.91 6,514.14 3,373.70 -8,139.26 6,025,419.36 517,340.98 14.07 3,369.76 54.23 90.37 203.15 6,514.64 3,345.52 -8,150.38 6,025,391.15 517,329.96 13.79 3,397.55 50.86 91.38 207.90 6,514.19 3,318.96 -8,163.06 6,025,364.54 517,317.37 16.49 3,425.30 77.97 93.07 213.98 6,512.70 3,286.26 -8,182.66 6,025,331.78 517,297.89 16.52 3,462.28 74.35 95.60 217.76 6,510.42 3,261.89 -8,200.28 6,025,307.36 517,280.36 15.05 3,491.96 56.00 93.96 220.20 6,507.14 3,231.40 -8,224.95 6,025,276.78 517,255.79 7.45 3,530.98 123.89 94.79 224.69 6,504.42 3,205.12 -8,248.98 6,025,250.43 517,231.85 12.75 3,566.55 79.33 94.57 227.63 6,501.90 3,183.86 -8,271.13 6,025,229.09 517,209.78 9.54 3,597.24 94.17 93.80 230.24 6,499.69 3,164.01 -8,293.90 6,025,209.17 517,187.07 8.96 3,627.38 106.38 95.77 235.11 6,497.26 3,146.39 -8,317.01 6,025,191.47 517,164.03 17.95 3,656.18 67.72 93.84 237.76 6,494.69 3,129.51 -8,342.46 6,025,174.50 517,138.64 10.67 3,686.11 126.04 91.14 238.82 6,493.38 3,113.73 -8,367.99 6,025,158.64 517,113.16 9.65 3,715.32 158.56 91.96 244.08 6,492.54 3,098.88 -8,395.28 6,025,143.70 517,085.93 17.12 3,745.12 81.07 92.76 248.12 6,491.31 3,086.76 -8,422.64 6,025,131.49 517,058.62 13.74 3,773.03 78.71 92.82 252.61 6,489.85 3,076.73 -8,450.75 6,025,121.36 517,030.54 15.01 3,800.00 89.12 92.09 256.07 6,488.56 3,068.62 -8,479.71 6,025,113.15 517,001.61 11.73 3,826.22 101.85 91.90 257.62 6,487.79 3,063.59 -8,501.20 6,025,108.05 516,980.15 7.07 3,844.97 96.97 91.90 257.62 6,486.35 3,054.27 -8,543.66 6,025,098.59 516,937.72 0.00 3,881.58 0.00 • 4/3/2008 2:21:25PM Page 6 COMPASS 2003.16 Build 42F ConocoPhillips Alaska ConocoPhillips Baker Hughes INTEQ Survey Report Company: ConocoPhillips(Alaska) Inc. Protect: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Wellbore: 3O-02A TD Design: 3O-02A TD Targets Target Name - hlUmiss target Dip Angle Dlp Dir. TVD +NI-S +EI-W -Shape (°) (°I (ft) (n) (ft) 30-02A Target 7 0.00 0.00 6,529.00 3,565.02 -8,005.16 - actual wellpath misses by 64.23ft at 12398.69ft MD (6507.82 TVD, 3598.87 N, -8055.48 E) - Point 30-02A Polygon 0.00 0.00 0.00 4,078.23 -6,314.16 - actual wellpath misses by 6442.11ft at 10000.OOft MD (6434.02 TVD, 3989.47 N, -6003.86 E) - Polygon Point 1 0.00 4,078.23 -6,314.16 Point2 0.00 4,148.87 -6,501.94 Point 3 0.00 4,141.13 -6,875.01 Point 4 0.00 4,041.14 -7,178.38 Point 5 0.00 3,959.85 -7,392.67 Point 6 0.00 3,846.29 -7,525.07 Point 7 0.00 3,573.30 -7,833.02 Point 8 0.00 3,317.04 -8,059.91 Point 9 0.00 2,768.27 -8,442.80 Point 10 0.00 2,871.97 -8,647.47 Point 11 0.00 3,057.99 -8,646.85 Point 12 0.00 3,484.07 -8,360.38 Point 13 0.00 3,915.05 -7,749.86 Point 14 0.00 4,057.02 -7,438.35 Point 15 0.00 4,213.18 -7,184.80 Point 16 0.00 4,322.31 -6,924.40 Point 17 0.00 4,381.47 -6,672.17 Point 18 0.00 4,327.70 -6,445.33 Point 19 0.00 4,256.04 -6,252.55 Point 20 0.00 4,123.57 -6,115.99 Point 21 0.00 3,991.81 -0,192.44 3O-02A Target 1 0.00 0.00 6,474.00 4,007.23 -6,043.85 - actual wellpath hits target - Point 30-02A Target 4 0.00 0.00 6,540.00 4,155.02 -7,121.01 - actual welipath misses by 46.60ft at 11282.01ft MD (6540.44 TVD, 4110.2 3 N, -7108.15 E) - Point B~R~ Nudes INTEQ Local Co-ordinate Reference: Well 30-02 TVD Reference: Mean Sea Level MD Reference: 30-02 Q 59.OOft (30-02) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Northing Easting Ift) (ft) Latitude Longitude 6,025,611.12 517,474.41 70° 28' 52.147 N 149° 51' 25.979 W 6,026,130.07 519,163.48 70° 28' 57.210 N 149° 50' 36.255 W 6,026,130.07 6,026,200.06 6,026,191.04 6,026,090.02 6,026,008.01 6,025,894.01 6,025,619.99 6,025,362.98 6,024,812.96 6,024,915.95 6,025,101.95 6,025,528.96 6,025,961.99 6,026,105.01 6,026,262.02 6,026,372.03 6,026,432.05 6,026,379.06 6,026,308.07 6,026,176.08 6,026,044.07 6,026,060.00 6,026,204.09 519,163.48 518,975.48 518,602.47 518,299.48 518,085.49 517,953.49 517,646.51 517,420.52 517,039.55 516,834.55 516,834.53 517,119.51 517,728.49 518,039.48 518,292.47 518,552.47 518,804.47 519,031.47 519,224.47 519,361.47 519,285.48 519,434.00 70° 28' 56.514 N 149° 50' 28.303 W 518,356.45 70° 28' 57.958 N 149° 50' 59.991 W 4/3/2008 2:21:25PM Page 7 COMPASS 2003.16 Build 42F •--' ConocoPhillips ConocoPhilfips Baker Hughes INTEQ Survey Report Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Wellbore: 30-02A TD Design: 30-02A TD 30-02A Target 2 0.00 0.00 6,530.00 4,260.45 -6,663.58 -actual welipath misses by 55.68ft at 10757.59ft MD (6532.20 ND, 4315.02 N, -6652.73 E) - Point 30-02A Target 3 0.00 0.00 6,525.00 4,247.19 -6,877.66 -actual welipath misses by 29.93ft at 11010.08ft MD (6530.25 ND, 4271.54 N, -6894.24 E) - Point 3O-02A Target 5 0.00 0.00 6,557.00 4,021.01 -7,410.51 -actual welipath misses by 10.87ft at 11600.47ft MD (6547.44 ND, 4017.36 N, -7406.85 E) - Point 3O-02A Target 9 0.00 0.00 6,520.00 3,095.39 -8,414.84 - actual welipath misses by 28.62ft at 13043.62ft MD (6491.84 ND, 3091.31 N, -8411.76 E) - Point 30-02A Target 6 0.00 0.00 6,544.00 3,782.08 -7,726.38 -actual welipath misses by 27.13ft at 12000.43ft MD (6521.03 ND, 3796.51 N, -7726.12 E) - Point 3O-02A Target 10 0.00 0.00 6,519.00 2,877.78 -8,532.60 - actual welipath misses by 179.83ft at 13181.OOft MD (6486.35 ND, 3054.27 N, -8543.66 E) - Point 30-02A Target 8 0.00 0.00 6,524.00 3,330.82 -8,242.00 - actual welipath misses by 74.94ft at 12730.01ft MD (6513.12 ND, 3293.06 N, -8178.19 E) - Point • < r~.r sa~~Es INTEQ Local Coordinate Reference: Well 30-02 ND Reference: Mean Sea Level MD Reference: 30-07 @ 59.OOft (30-02)' North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod 6,026,311.08 518,813.47 70° 28' 58.999 N 149° 50' 46.538 W 6,026,297.08 518,599.46 70° 28' 58.867 N 149° 50' 52.835 W 6,026,069.10 518,067.44 70° 28' 56.637 N 149° 51' 8.502 W 6,025,140.14 517,066,39 70° 28' 47.523 N 149° 51' 38.013 W 6,025,829.11 517,752.42 70° 28' 54.284 N 149° 51' 17.786 W 6,024,922.15 516,949.38 70° 28' 45.382 N 149° 51' 41.469 W 6,025,376.13 517,238.40 70° 28' 49.841 N 149° 51' 32.938 W Casing Points Measured Vertical Depth Depth (ft) (ft) Name Casing Hole Diameter Diameter (") (") i 5,895.00 3,922.38 9 5/8 9-5/8 12-1/4 Checked By: Approved By: Date: 4/3/2008 2:21:25PM Page 8 COMPASS 2003.16 Build 42F KRU 30-02 Producer 3'rz' TRDP SSSV at 1787' A-sand CTD Completion Updated 3/31/2008 3'/:", 9.3#, EUE 8rd Mod tubing w/ 3'/i' gas lift mandrels (six) Actual Drilled Footage = 8358 9i:' surface casing shoe at 5930' • 3'/i' x 7" Baker RHS packer with PBR at 9891" • 2.75" D-nipple at 9928' • 3'/:" tubing tail at 9963' 2'/" liner top 9940' AL2-01 lateral (northern, upper) A2/3 Sand, TD ~ 11,471' Cement ramp exit, top of 2'/." slotted & solid liner 9940' - 11,471' cement -9970' MD . ,_ . _ _, _. . AL1 Lateral (westem, upper) ~~ ~ A2/3 Sand, TD ~ 13,186' Aluminum billet ~~ 2%." slotted liner 10,255' -13,186' @ 10,255' ~~ ~ Aluminum billet _ _ _ _ _ _ _ ii @ 10,749' v ~ / Wiidav in T'rasing \ \ \ 10.330'A10,500' I~ Co310,060'MD ~\ AL2 lateral (northern, lower) \ i ~~ Al Sand, TD @ 11,555' ~~ ~~~ ~ ~~ 2'/8" slotted liner 10,749'-11,555' ~~ _ ~~• .~ A sand perfs: - ~= - - - 10,052' - 10,148' 'A' sidetrack (westem, lower) 'A' barefoot segment _ (cemented) Al Sand, TD ~ 13,180' 10,140' - 10,329' 2'/" slotted liner 10,329' - 13,180' .................. I 1 ICJ i 7', 26 ppf, J-55 casing shoe at 10,392' Delay BOP Funcrion Test un ~ rl -- ` "bv ` "` - Maunder, Thomas E (D4Aj From: Eller, J Gary [J.Gary.Elier@conocophillips.com] Sent: Friday, March 21, 2008 4:20 PM To: Maunder, Thomas E (DOAj Cc: Pat Archey; Harry Engel; Eggemeyer, Jerome C.; AOGCC North Scope Office; Nordic 2 Company Man ~/ Subject: RE: Delay BOP Function Test Until OOH-30-02AL1 ~ Z -" t ~ ~ ~' ~~~1- ~ ~ O s~~ -The only 13~P on l~ordic 2 rc~mponents that have not been furction tested v~~ithin the last 7 days are tl~se ,°~!shears, upper ~" cobi pipe rams, lover ~" corr-sbi pipe rams, and the I~~P on the choke lis°;e. The arsnular -',;,ill line l~~P, and the 2-~/8" co~~nbi rams S;~ere f~nc#icned the last time c press€are deplcyed an assembly, ''~,°s on ~l`171t7. _ ~ ~~viously cannot function test tl~sv blind,shears j~hile e. ubing is in the bole. ;# is ~ ..~ test the ~" pipe rams (upper loweri ~vnile v~~e're in Vie, but it is nc~t +isale ~, ~:. - - a_~atios~. ~~Ithc~ugh it is highl}~ urslikely #o happen, junk or ` -."r ., srs the ~vellbore c, ~ tai image se '1 . g if ~rbfe were to function the rams nova: which would result is7 a F4 ~:: '.'eel of coil and 1-~ s of clo~vr.:. l .~~~ that's n~.~t;reri~ ls~es, to happen, s~u~ it's not unhearo o~. ire ~; prefer ~o east un#~! we'~ _'I ~f the hol risen ~,ve can function #l~e rasps on a test ois-i~. l'll ba available ors spy cell phone f~~9-'Ig7g} if yos~'d nice to discuss it some s-rsr;re. Tt,._ ~. -~~r~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 21, 2008 1:46 PM To: Nordic 2 Company Man Cc: Etter, J Gary; Pat Archey; Harry Engel; Eggemeyer, Jerome C.; AOGCC North Slope Office Subject: RE: Delay BOP Function Test Until OOH--30-02AL1 i All, f# is acceptable to delay the function test until you are on the bank. While you plan to be on bottom for 24 - 48 hours, we all know that can change. The test should be conducted when d©H. i am surprised that it is necessary #o be aut of the hole to conduct the function test. It is a given that dt necessary to func#ion the blind rams, however ! do not understand why the pipe rams and annular cannot be~functioned. [ would appreciate a return message explaining the reasoning here, why closi g properly sized tarns on the coil is being avoided. ! look forward to your reply. Please make sure any reply includes the aogcc rudhoe bay address. Tom Maunder, PE j AC3GGC From: NSU, ADW Drlg Nordic 2 Supervisor {maim Sent: Friday, March 21, 2008 11:22 AM To: Maunder, Thomas E (DOA) Cc: Eller, Gary (ConocoPhillips) Subject: RE: Delay BOP Function Test Until OOH -_ ans~e; your c~~aefition, i# is all dependent o s rate cf parse#rat+an. s ~e arw cssrrently or =aottors~s drilling, vve 4/30/2008 Delay BOP Function 1"est untuvvn -~., - --a- - -- - • r.- "_A ~°p~rs antil ~.~e erect to be of the hale. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, Mare 21, 2008 10:33 AM To: Eller, Gary (ConocoPhiAips) Cc: NSU, ADW Drlg Nordic 2 Su~rvisor Subject: t2E: Delay BOP Function Test Until OOH Gary, When do you all expect to be cut of the hale? Tam From: Etter, l Gary [mailto:J.Gary.Eller@conocophillips.mm] Sent: Friday, March 21, 2008 9:38 AM To: Maunder, Thomas E (DOA) Cc: Nordic 2 Company Man Subject: Delay BOP Function Test Until OOH Tom - As per our phone conversation today, on Nordic #2 we would like to delay our weekly function BOP test un#il the next time we trip out of the hole. We are currently drilling ahead in the 30-02AL1 lateral. Our next BOP function-pressure test is due by Thursday {3127), and Lou Grimaldi has asked for sufficient notice so that he can witness it. Please confirm that it is acceptable for us to delay that function #est. -Gary Eller CPAI Wells Engineer 4/30/2008 1 day BOPE function test exempt : --,. 1 "s" ` "` i Regg, James B {DOA) From: Grimaldi, Louis R (DOA) Sent: Thursday, March 20, 2008 5:11 PM To: NSU, ADW Dr1g Nordic 2 Supervisor ?~2~1~D~ Cc: Regg, James B (DOA) ~~~~~ Subject: RE: 1 day BOPE function test exemption Matt, Yes, postponement is OK. We need to witness a BOP test on your rig, please provide us with adequate notice for your next BOP test. Thanx, Lou From: NSU, ADW Drlg Nordic 2 Supervisor [mailto:nsuadwdrlgnordic2supv@sel.bp.com] Sent: Thursday, March 20, 2008 2:37 PM To: Grimaldi, Louis R (DOA) Subject: 1 day BOPE function test exemption ~0~~ R a~ ~ d ~ ~ Lou; 3Q-oz.A ti.~... ~-d\t °- ~S~ Nordic 2, CTD rig is currently on bottom drilling in Kuparuk on well 3Q~6'~. t would like to request one day's exemption & postpone our BOPS function test that is due tonight at midnight on the 20th of March, 2008. The last time we were out of hole was 2pm on March 18th, 2008. Thanks. Matthew Ross 3/21 /2008 ~`" /' Page 1 of 1 • • Maunder, Thomas E (D4A) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 18, 2008 1:47 PM To: 'Eller, J Gary' Cc: Perfetta, Patrick J; Nordic 2 Company Man; Staudinger, Garret; Michaelson, Bifl(Baker Hughes Inteq); Venhaus, Dan E; Hubble, Terrie L; jon.mapes1@inteq.com Subject: RE: Lateral Naming in Well 30-02 Gary, I confirm our discussion and you have captured it correctly. Good luck with the remaining operations. I will place a copy of this message in the -02A (207-158), -02AL1 (207-159) and -02AL3 (208-036) files. You are correct that the -02AL3 permit should be cancelled since it will not be drilled. Call or message with any questions. Tom Maunder, PE AOGCC From: Eller,) Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Tuesday, March 18, 2008 1:21 PM To: Maunder, Thomas E (DOA) Cc: Perfetta, Patrick J; Nordic 2 Company Man; Staudinger, Garret; Michaelson, Bill(Baker Hughes Inter); Venhaus, Dan E; Hubble, Terrie L; jon.mapesi@inteq.com Subject: Lateral Naming in Well 30-02 Torn -- As per our phone conversation yesterday afternoon, we unintentionally sidetracked from well 30-OZA while drilling the AL1 lateral. That lateral had been drilled to 10,500' MD, but we accidentally sidetracked at 10,140' MD during a wiper trip. We were unable to re-enter the original borehole last night in order to run slotted liner. We have instead continued drilling ahead from the sidetrack point that we were given at 10,140' MD. I propose that the unlined lateral from 10,330' MD to 10,500' MD off of the `A' sidetrack be named the AL1 PB1 lateral. It crosses the A2 shale shortly after kickoff and is not likely to remain productive without a slotted liner in place. The lateral that we are currently drilling will be the AL1 lateral (PTD #207-159) with a kickoff point of 10,140' from the `A' sidetrack. The 'A' sidetrack (PTD #207-158) that was drilled from 10,060' MD to 13,120' MD is lined with slotted liner from TD up to 10,330' MD. It is unlined (i.e. barefoot) from 10,330' to 10,140' MD, but since this is in clean sandstone it is our hope that this sidetrack will remain viable for production. We will be unable to drill the AL3 lateral (PTD # 208-036) that was intended to kickoff at 11,170' MD, and we will cancel that PTD in the near future. Please let me know if you need any other info at this time. Of course, our completion notice will contain a wellbore diagram to help keep track of these many laterals in 30-02, but in the meantime I will be glad to answer any questions that you might have. 7. Gary Eller Wells Engineer ConocoPhillips -Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 3/18/2008 Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Drlg Nordic 2 Toolpusher [nsuadwdrlgnordic2toolpu@bp.com] ~ ~,, ~'0~ ~ ~. Sent: Tuesday, March 04, 2008 5:28 PM To: Regg, James B (DOA) Subject: RE: Nordic #2 BOPE test on 30-02A on 2/28/08 ~? Jim; ~. I reviewed the test charts and it seems as the low pressure tests where all in the 350-450 psi range. Yes we typically preform the low test in the 200-300 range. The driller that preformed this test is on days off right now but ail of our drillers will be brought back up to speed "~ concerning the low pressure testing requirerments set forth in API RP 53. I will also inform the Nordic Anc office of this higher than allowed low test pressure. I can assure you that this will not happen again. Ron Holmes Nordic #2 Toolpusher Phone :907-659-4398 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, March 04, 2008 4:53 PM To: NSU, ADW Drlg Nordic 2 Toolpusher Cc: DOA AOGCC Prudhoe Bay Subject: RE: Nordic #2 BOPE test on 30-02A on 2/28/08 I am curious about the low pressure test -attached report shows you tested to 450 psi. AOGCC regs are silent except to incorporate by reference API RP 53 says low pressure test should be 200-300 psi; typically rigs (including Nordic 2) test to 250 psi. I'd appreciate an explanation. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Drlg Nordic 2 Toolpusher [mailto:nsuadwdrlgnordic2toolpu@bp.com] Sent: Friday, February 29, 2008 9:28 AM To: aogcc_prudhoe_bay@admin.state.ak.us; Ben Wedin; Fleckenstein, Robert J (DOA); Scheve, Charles M (DOA); Regg, James B (DOA); noeltherrien@nordic-calista.com; NSU, ADW Drlg Nordic 2 Supervisor; NSUadwdrlgnordic2tou@BP.com; Maunder, Thomas E (DOA); Udo Cassee Cc: slaporte@nordic-catista.com Subject: Nordic #2 BOPE test on 30-02A on 2/28/08 3/5/2008 ~o~ -lS-~ STATE OF ALASKA 11!13/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit ta: Contractor: Nordic Rig No.: 2 DATE: 2/28/08 Rig Rep.: Holmes/Sloan Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Hildreth E-Mail Well Name: Kuparuk 30-0ZA PTD # ZOT-158 Operation: Drlg: X Test: Initial: X Test Pressure: Rams: 450/4500 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P Workover. Explor.: Weekly: Bi-Weekly Annular.450/45f~ Valves: 450/4500 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result p Upper Kelly NA r P BOP STACK: Quantity Size/Type Test Result Stripper 1 2" P Annular Preventer 1 7 1/16" P #1 Rams 1 Blind/Shear P #2 Rams 1 2" Combi P #3 Rams 1 2 3/8" Combi P #4 Rams 1 2" Combi P #5 Rams NA Choke Ln. Valves 1 3 1/8" P HCR Valves 2 3 1/8" P Kill Line Valves 1 31/8" P Check Valve 2 21!16" P CHOKE MANIFOLD: Quantity Test Result No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P Lower Kelly NA Ball Type 1 P Inside BOP NA MUD SYSTEM: Visua! Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Quantity Test Result Ins~e Reel valves 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 2100 P 200 psi Attained 25 sec P Full Pressure Attained 95 sec. P Blind Switch Covers: All stations Yes Nitgn. Bottles {avg}: 4 ~ 2100 Test Results Number of Failures: 0 Test Time: 6_5 Hours Components tested 30 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Test start to finish time is different than the test time due to Gray-loc replacement & tree testing that was done in the middle of the test. 24 HOUR NOTICE GIVEN YES XX NO - Date 2/27/08 Time 0900 start 05:00 Finish BOP Coil for Rigs BFL 11/13/07 By Lou Grimaldi Witness Hildreth/Holmes Nordic 2 BOP 2-28-08.x1s r • Q..~ a.x R..1 4..( ~_3 :~1 L.J ~..( EJ i,~~:l t..,~ °.._..~ .2 J L~ COrIT5E8VATI0 COhIIIIS5I01S1T Gary Eller CT Drilling Engineer Conoco Phillips Alaska Inc. C/o PO Box 196612 Anchorage, Alaska 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 30-02A Conoco Phillips Alaska Inc. Permit No: 207-158 Surface Location: 745' FNL, 1855' FWL, SEC. 22, T13N, R09E, UM Bottomhole Location: 2117' FSL, 1401' FEL, SEC. 17, T13N, R09E, UM Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9059-3607 (pager). DATED this ~ day of November, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMIS~N ~ ~( ~~ NQ~ ~ ~ ~QQ7 PERMIT TO DRILL Al~skl~ p;~ ~, Gas Cons. Commission 20 AAC 25.005 Annhnr~na 1 a. Type of work ~ ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for. ~ ~° ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 30-02A 3. Address: Go P.O. Box 196612, Anchorage, AK 99519-6612 6. Proposed Depth: . MD 13200 ' TVD 6518ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 745' FNL 1855' FWL SEC 22 T13N R09E UM 7. Property Designation: ~~+t,2St/ ADL 025512 ~GD~i.• ~ River Pool , , , , . , Top of Productive Horizon: 3274' FSL, 4156' FEL, SEC. 16, T13N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 2008 Total Depth: 2117 FSL, 1401' FEL, SEC. 17, T13N, R09E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 10,600' 4b. Location of Well (State Base Plane Coordinates): Surface: x-525491 y-6022072 Zone-ASP4 ~ 10. KB Elevation (Height above GL): 59' feet 15. Distance to Nearest Well Within Pool: 1,400' 16. Deviated Wells: Kickoff Depth: 10060 feet - Maximum Hole An le: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4995 Surface: 4335 18. asin "' ram: S f To - Se in - Bo om anti of m nt .f. or ack Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" . 4.6# L-80 STL 2900' 10300' 6513' 13200' 6518' Uncemented Slotted Liner 19. PRESE NT WELCCONDITION SUMMARY (To be completed for Redrill.and Re-entry Operations) Total Depth MD (ft): 10420 Total Depth TVD (ft): 6794 Plugs (measured): None Effective Depth MD (ft): 10308 Effective Depth TVD (ft): 6712 Junk (measured): 10185 Casing Length Size - Cement Volume MD '- D Conductor /Structural 115' 16" 1 9 sx Arcticset II 11 115' Surface 5930' 9-5/8" 1400 sx AS III, 400 sx'G', To Job: 10o sx AS I 5930' 4002' Intermediate Pr c ion 10392' 7" 15 sx CI s' 175 sx CSI 10392' 6773' Liner Perforation Depth MD (ft): 10052' - 10148' Perforation Depth TVD (ft): 6529' - 6596' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby ce ~ that the forec~ ing is true and correct. Contact Gary Eller, 529-1979 (Cell) Printed Na ~ . ary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 263-4172 Date ~~ b d`j Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~- ~~S PI Number: ~ 50-029-21837-01-00 Permit Approval See cover letter for Date: other re uirements Conditions of Approval: !f box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes Mud Log Req'd: ^ Yes [~NO HZS Measures: s it Tonal Survey Req'd: Q'Yes ^ No Other: ~S~O ~ S ~ 1~d Q }~ S~ APPROVED BY THE COMMISSION Date ~ ~r~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ (/ ~~ ~ Submit In Duplicate KRU 30-02 Quad Sidetrack/Laterals - Coil Tubin Drilling 9 Summary of Operations: A coiled tubing drilling rig will drill four sidetracks & laterals in well KRU 30-02 using the managed pressure drilling technique. These horizontal laterals will target Kuparuk A2/3 and Al sand reserves to access upswept and trapped oil. The perforations in the motherbore will be plugged with cement. 3Q'1- 3~i ~ 1. The A sidetrack will exit the motherbore at 10,060' MD and be a 3140' horizontal targeting the Al -"~ sand to the southwest. It will be completed with 23/a" slotted liner to a TD of 13,200' MD. •- 2. The AL1 lateral will kick off from the A sidetrack at 10,300' MD targeting A2/3 Sands to the southwest. The AL1 lateral will be 2900' in length and will be completed with 23/8" slotted liner to a TD of 13,200' MD. 3. The AL2 lateral will kick off from the A sidetrack at 10,225' MD and will target Al Sand to the north. The AL2 lateral will be 1405' in length and will be completed with 23/8" slotted liner to a TD of 11,630' MD. 4. The final lateral, AL3, will kick off from the AL2 lateral at 10,960' MD and will target the A2/3 Sands to the north. The AL3 lateral will be 665' in length and will be completed with 23/8" slotted liner to a TD of 11,625' MD. Only the final drilled lateral will remain accessible through-tubing. - CTD Drill and Complete 30-02 program: January 2008 Pre-Rig Work 1. Obtain updated static BHP on A sand. ~ 2. Test Packoffs - T & IC. ~h~ -~j~"~.~ 3. Positive pressure and drawdown tests on MV and SV. V 4. Drawdown test on SCSSV. 5. Slickline tag fill and drift 3%i" tubing. 6. Install dummy valves in GLMs 7. MIT-IA, MIT-OA. 8. Coil tubing plug existing A sand perfs with 17 ppg cement up to tubing tail at 9963' MD. 9. Slickline tag top of cement. Rig Work 1. MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Drill low-side pilot hole and cement ramp for exit at 10,060' MD. Mi112.74" window and 10' of open hole from 10,060' MD. 3. _ 30-02A Sidetrack (Western Lower) ,{'\ _;~j ~ ` `t` '~ a. Drill pilot and cement ramp for high-side exit at 10,060' MD. 060' MD in the A Mi112 74" i ti Th l ned KOP i t 10 b ith hi h id i t d ~` . w on. e p an s a , . n ow w g -s e or en a (~` sand. Q c. Dril13" bi-center horizontal `A' sidetrack southwest in the Al sand from the window to TD at 13,200' MD. -` d. Kil~ayell. Run 23/8" slotted liner with aluminum billet from TD up to (10,300' MD. - 4. 30-02AL1 Lateral (Western Upper) a. Dr'i113" bi-center horizontal AL1 lateral southwest in the A2/3 sand from 10,300' to TD at 13,200' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to f 10,225' MD. 5. 30-02AL2 Lateral (Northern Lower) a. Dri113" bi-center horizontal AL2 lateral north in the Al sand from 10,225' to TD at 11,630' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to (10,960' MD. 6. 30-02AL3 Lateral (Northern Upper) a. Dri113" bi-center horizontal AL3 lateral north in the A2/3 sands from 10,960' to TD at 11,625' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up into the 3%" tubing tail at 9963' MD. 7. Freeze protect. ND BOPS. RDMO Nordic 2. Page 1 of 3 November 2, 2007, FINAL KRU 30-02 Quad Sidetrack/Laterals -Coiled Tubing Drilling Post-Rig Work 1. Run GLVs 2. Obtain static BHP 3. Produce well to sales. Mud Program: • Will use chloride-based Biozan brine (10.0 ppg) for milling operations, and chloride-based Flo-Pro mud 010.0 ppg) for drilling operations. Since there is an SCSSV installed in 30-02, we should not have to kill the well to deploy 23/8" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well `~ • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 30-02A: 23/8", 4.6#, L-80, STL slotted liner from 10,300' MD to 13,200' MD • 30-02AL1: 23/s", 4.6#, L-80, STL slotted liner from 10,225' MD to 13,200' MD • 30-02AL2: 23/8", 4.6#, L-80, STL slotted liner from 10,960' MD to 11,630' MD • 30-02AL3: 23/8", 4.6#, L-80, STL slotted liner from 9960' MD to 11,625' MD Existing Casing/Liner Information Surface: 95/8", J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi. Production: 7", J-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Well Control: • Two well bore volumes 0180 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4500 psi. Maximum potential surface pressure is 4335 psi assuming a gas gradient to surface and maximum potential formation pressure based on the highest pressure measured in offset injectors (i.e. 4995 psi in 3Q-15 in July 2006). • The annular preventer will be tested to 250 psi and 2500 psi. Directional• • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 30-02A: 10,600' to property line, 1400' to 3Q-16 at the toe • 30-02AL1: 10,600' to property line, 1400' to 3Q-16 at the toe • 30-02AL2: 9000' to property line, 1000' to 3R-19 at the toe • 30-02AL3: 9000' to property line, 1000' to 3R-19 at the toe Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. fY Page 2 of 3 November 2, 2007, FINAL • • KRU 30-02 Quad Sidetrack/Laterals -Coiled Tubing Drilling Hazards Expect to encounter increased pressure in the western laterals, particularly beyond a fault that will be ~'~'~ encountered at 11,500' MD. The static reservoir pressure in the 3Q-16 injection well which the western ~ f laterals are drilling towards is approximately 14.5 ppg EMW. v''~~ ~'" r~' Lost circulation is a risk due to the likelihood of encountering increased formation pressure at major fault ~~ crossings, particularly in the western laterals. We1130-02 has 145 ppm HZS as measured on 1/22/07. Wells 30-01 and 30-03 are adjacent to 30-02. a'`` 30-01 has 265 ppm HZS as measured on 1/22/07, and 30-03 has 140 ppm HZS as measured on 1/25/07. The maximum HZS level on the 30 pad is 265 ppm from well 30-01. All HZS monitoring equipment will be operational. Reservoir Pressure ~ • The most recent static pressure measured in 30-02 is 3703 psi on 10/02/07 (i.e. 10.9 ppg EMW at 6567' TVD). Prior to that, the survey taken in January 2005 showed that reservoir pressure was 3006 psi (i.e. 8.8 ppg EMW). "-" Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the 23/8" pipe/slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. There is a functional SCSSV in we1130-02, so the well should not have to be killed prior to running 23/8" slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3703 psi at 10,101' MD (6562' TVD), or 10.9 ppg EMW. ~ • Expected annular friction losses while circulating: 905 psi (assuming friction of 90 psi/1000 ft). • Planned mud density: 10.0 ppg equates to 3412 psi hydrostatic bottom hole pressure at 6562' TVD °' • While circulating 10.0 ppg fluid, bottom hole circulating pressure is estimated to be 4317 psi or 12.7 ppg EMW without holding any additional surface pressure. • When circulation is stopped, it is anticipated that 300 psi of additional surface pressure shall have to be applied to balance reservoir pressure. 905 psi of additional surface pressure must be held to maintain the same bottom hole pressure as during drilling operations. Page 3 of 3 November 2, 2007, FINAL ConocoPhillips Alaska, Inc. (n. 0 Mand (35 Mand (62 Mand (7a andrel (86 G andrel (92 C andrel (98 C (sa c (98 C (99 C C I ;1005 '1007 '1010 '1011 '1013 23' ;1018 C KRU 30-02 30-02 API: 500292183700 Well T : PROD An le TS: 47 d 10035 SSSV Type: TRDP Orig 10/2/1988 Angle @ TD: 43 deg @ 10420 sssv Com letion: 7.17aa, Annular Fluid: Last W/O: Rev Reason: NEW GLD r.3.soo> Reference Lo : Ref L Date: Last U date: 6/2/2006 Last Ta : 10101 TD: 10420 ftK6 Last Ta Date: 1 /23/2005 Max Hole An le: 60 d 3000 Gas Lin Casin Strin -ALL STRINGS elNalve Descri lion Size To Bottom TVD Wt Grade Thread 1 CONDUCTOR 16.000 0 115 115 62.50 H-40 s-3sos, SUR. CASING 9.625 0 5930 4001 36.00 J-55 PROD. CASING 7.000 0 10392 6772 26.00 J-55 Tubin Strin -TUBING Gas Lin NNalve Size To Bottom TVD Wt Grade Thread z 3.500 0 9963 6468 9.30 J-55 EUE 8RD AB MOD s-x257, Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 10052 - 10068 6528 - 6539 A-3 16 12 3/30/1989 APERF 60 deg. phasing; 2 1/8" Gas un EnerJet ewalve 3 10072 - 10098 6542 - 6559 A-2 26 12 3/30/1989 APERF 60 d hasin 2 1/8" e9~ P 9; s-7aa7, EnerJet 10102 - 10110 6562 - 6568 A-1 8 6 3/28/1989 APERF 60 deg. phasing; 2 1/8" EnerJet Gas un 10110 - 10130 6568 - 6582 A-1 20 8 10/2/1988 IPERF 45 deg. phasing; 4" Ultrapak Dummy CS GUn valve a 8-8659 10130 - 10148 6582 - 6595 A-1 18 6 3/28/1989 APERF 60 d hasin 2 118" e9~ P g. , ):a.75o) EnerJet Gas Lift MandrelsNalves l in G St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv _ as Dummy Mfr Run Cmnt Valves 1 3508 2542 MMH FHMO GLV 1.0 BK 0.125 1280 5/31/2006 e•s2as, ):4.750) 2 6256 4191 MMH FHMO GLV 1.0 BK 0.188 1351 5/31/2006 3 7846 5134 MMH FHMO OV 1.0 BK 0.188 0 5/31/2006 4 8658 5630 MMH FHMO DMY 1.0 BK 0.000 0 4/21/2000 _ Gas Lin Dummy 5 9248 6005 MMH FHMO DMY 1.0 BK 0.000 0 2/15/1998 valve 6 6 9836 6384 Otis LBX DMY 1.5 T-2 0.000 0 9/7/1996 s-x637, Other lu s, a ui ., etc. -JEWELRY ):5.500) De th TVD T e Descri tion ID 1787 1585 SSSV Camco'TRDP' 2.812 PBR 9878 6411 PBR AVA 3.000 8-9879, ):3.500) J$g1 6420 PKR AVA'RHS' 3.000 9928 6444 NIP Camco'D' Ni le NO GO 2.750 9962 6467 SOS Baker 2.992 9963 6468 TTL 2.992 PKR Fish -FISH .1-sasz, De th Descri lion Comment ):s.151> 10185 23' Stri Gun Lost in Hole General Notes Date Note NIP 4/4/1996 WAIVERED WELL: IA x OA COMMUNICATION 8-9929, ):3.500) rUBING - 0-9963, ):3.500, ):2.992) Perf -10068) Perf -10098) Perf - -10110) Perf ~-10130) Perf i-10148) Vip Gun i-10208, ):2.000) KRU 30-02 Producer 3'rz" TRDP SSSV at 1787' Proposed A-sand CTD Completion Footage Drilled = 81 10' 3'/i', 9.3#, EUE 8rd Mod tubing w/ 3'/z' gas Updated 11 /2/2007 lift mandrels (six) 9%' surface casing shoe at 5930' 3'/z' x 7" Baker RHS packer with PBR at 9891" • 2.75" D-nipple at 9928' • 3'/z' tubing tail at 9963' 2'/a" slotted liner top -9950' ~ -~ I~ Window in T' 261E J55 casing Cement ramp exit, top of I I ' @ 10,060' MD cement -9970' MD ~ f ~ ~\ Aluminum billet ~' \\ @ 10,225' ~~~ ,~~ ~' AL3 lateral (northern, upper) ' ~~ ° ° ~ ~ ~ . rac western upper) A2/3 Sand, TD @ 11,625 ~~ ~~ ~ ~~~ ° o ~~ , ~ ~2/3'Sand, TD @ 13,200' _ _ _ ~\ A sand perfs: _ _-= _ _~~ ~ ~ ~ 052' - 10,148' 10 ~ ~ ~ \\ \ \ ~- ~ //. iG, o ~ , \~ (Plu99ed) ~ \ II ~ ~ I \ Aluminum billet ' ~ @ 10,300 ~ ~/ ~ ~ -- Q S ~ . AL2 lateral (northern, lower) Aluminum billet AL1 lateral (western, lower) Al Sand, TD @ 11,630' @ 10,960' ,FY(Sand, TD @ 13,200' a~ ~~ //. /~ . o ) 7", 26 ppf, J-55 casing shoe at 10,392' by BP Alaska r Baker Hughes INTEQ Planning Report 1NTE Q Comp>toy: BP AMOCO Date: 10/23/2007 Time: 15:48:08 Page: 1 Wield: KupaRtk Co-ordinate(NE) Reference: We11:30-02, True North Ske: KRU 3t? Pad Vertical (TVD) Rett:reuce: 30-02 Orig Rig 59.0 FVe1L 30-02 Section (VS)'Refereace: WeN (O.OON,O.OOE,225.OOAzi) Wetlpath: Plan 5,:30-02A Survey Calculation Method: Minimum Curvature Db: OraGe Field: Kuparuk Map Systero:US State Plane Coordinate System 1927 Map 2,oue: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: KRU 30 Pad UNITED STATES :North Slope Site Position: Northing: 6022812 ,21 ft L.atitade: 70 28 24.450 N From: Map Easting: 523632 .43 ft Longitude: 149 48 25.100 W POSition Uneerteinty: O.OO ft North Retereuce: True Ground Level: 0.00 ft Grid Convergence: 0.18 deg Well: 30-02 Sbt Name: Well Position: +N/-S -744.80 ft Northing: 6022073 .38 ft ~ Latitude: 70 28 17.123 N +E/-W 1856.56 ft Eastiog : 525491 .16 ft ~ Longitude: 149 47 30.520 W Positron Uncertainty: 0.00 ft Wellpath: Plan 5, 30-02A Drilled From: 30-02 500292183701 Tie-on Depth: 10000.00 ft Cnrreut Datam: 30-02 Orig Rig Height 59.00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/22/2007 Deciiuatiou: 23.06 deg Field Strength: 57625 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 59.00 0.00 0.00 225.00 Plan: Plan #5 Date Composed: 10/22/2007 Versioe: 7 Principal: Yes Tied-to: From: Definitive Path Targets Map Map ~--- Latitude --> <-- Lou~itnde -- Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Mia Sec Dip. Dir. ft ft ft ft ft 30-02A Western Poygon 59.00 4078.68 -6314.85 6026130.01 519163.00 70 28 57.209 N 149 50 36.269 W -Polygon 1 59.00 4078.68 -6314.85 6026130.01 519163.00 70 28 57.209 N 149 50 36.269 W -Poygon 2 59.00 4149.33 -6501.63 6026200.01 518976.00 70 28 57.902 N 149 50 41.765 W -Polygon 3 59.00 4141.60 -6874.70 6026191.01 518603.00 70 28 57.823 N 149 50 52.739 W -Polygon 4 59.00 4042.64 -7179.07 6026091.01 518299.00 70 28 56.847 N 149 51 1.689 W -Polygon 5 59.00 3961.36 -7393.37 6026009.01 518085.00 70 28 56.046 N 149 51 7.990 W -Poygon 6 59.00 3847.80 -7525.77 6025895.01 517953.00 70 28 54.928 N 149 51 11.881 W -Poygon 7 59.00 3573.83 -7832.74 6025620.01 517647.00 70 28 52.230 N 149 51 20.902 W -Poygon 8 59.00 3317.58 -8060.64 6025363.01 517420.00 70 28 49.707 N 149 51 27.597 W -Polygon 9 59.00 2768.83 -8442.56 6024813.01 517040.00 70 28 44.306 N 149 51 38.811 W -Polygon 10 59.00 2872.54 -8648.23 6024916.01 516834.00 70 28 45.324 N 149 51 44.863 W -Polygon 11 59.00 3058.56 -8647.59 6025102.01 516834.00 70 28 47.154 N 149 51 44.851 W -Polygon 12 59.00 3484.62 -8360.10 6025529.01 517120.00 70 28 51.347 N 149 51 36.410 W -Poygon 13 59.00 3915.58 -7749.56 6025962.01 517729.00 70 28 55.592 N 149 51 18.466 W -Polygon 14 59.00 4057.53 -7439.04 6026105.01 518039.00 70 28 56.991 N 149 51 9.336 W -Polygon 15 59.00 4213.68 -7185.48 6026262.01 518292.00 70 28 58.529 N 149 51 1.882 W -Polygon 16 59.00 4322.80 -6925.08 6026372.01 518552.00 70 28 59.605 N 149 50 54.226 W -Polygon 17 59.00 4381.94 -6672.85 6026432.01 518804.00 70 29 0.189 N 149 50 46.808 W -Poygon 18 59.00 4328.16 -6446.01 6026379.01 519031.00 70 28 59.662 N 749 50 40.134 W -Polygon 19 59.00 4256.49 -6253.24 6026308.01 519224.00 70 28 58.958 N 149 50 34.461 W -Polygon 20 59.00 4124.01 -6116.68 6026176.01 519361.00 70 28 57.657 N 149 50 30.441 W -Polygon 21 59.00 3992.26 -6193.14 6026044.01 519285.00 70 28 56.360 N 149 50 32.687 W 30-02A Fautt 2 59.00 4649.04 -6694.94 6026699.01 518781.01 70 29 2.815 N 149 50 47.464 W -Polygon 1 59.00 4649.04 -6694.94 6026699.01 518781.01 70 29 2.815 N 149 50 47.464 W -Polygon 2 59.00 4249.69 -6896.33 6026299.01 518581.01 70 28 58.886 N 149 50 53.378 W -Poygon 3 59.00 3850.34 -7097.72 6025899.01 518381.01 70 28 54.957 N 149 50 59.290 W by BP Alaska ~~~ Baker Hughes INTEQ Planning Report INTE Q Comp>ey: BP Amoco Datc: 10/23/2007 Time: 15:48:08 Page: 2 >~ekl: KupBrtrk Co-erdinate(NE) Reference: Well: 30-02, True North Site: KRU 30 Pad Verlicai (1'VB) Reference: 30-02 Orig Rig 59.0 WeU: 30-02 Section (VS) Referencee 'Welt (O.OON,O.OOE,225.OOAzi) Wellpatb: Plan 5, 30-02A Sarvey Caicalatiou Method: Minirrwm Curvature Db: OraGe Targets ....Map Map ' <-- Latitude --> <~ Loegitude --> Name Description TVD +N/-S +FJ-W Nortbieg ; Fasting:: Deg 1Nia .Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 30-02A Fault 3 59.00 4459.58 -7149.64 6026508.01 518327.00 70 29 0.948 N 149 51 0.835 W -Polygon 1 59.00 4459.58 -7149.64 6026508.01 518327.00 70 29 0.948 N 149 51 0.835 W -Polygon 2 59.00 4060.23 -7351.02 6026108.01 518127.00 70 28 57.018 N 149 51 6.747 W -Polygon 3 59.00 3660.88 -7552.41 6025708.01 517927.00 70 28 53.089 N 149 51 12.659 W 30-02A Fault 4 59.00 3680.90 -7557.35 6025728.01 517922.00 70 28 53.286 N 149 51 12.805 W -Polygon 1 59.00 3680.90 -7557.35 6025728.01 517922.00 70 28 53.286 N 149 51 12.805 W -Polygon 2 59.00 3681.92 -7857.37 6025728.01 517622.00 70 28 53.293 N 149 51 21.630 W -Polygon 3 59.00 3682.95 -8157.40 6025728.01 517322.00 70 28 53.300 N 149 51 30.454 W 30-02A Fault 1 59.00 4621.97 -6383.00 6026673.01 519093.01 70 29 2.552 N 149 50 38.287 W -Polygon 1 59.00 4621.97 -6383.00 6026673.01 519093.01 70 29 2.552 N 149 50 38.287 W -Polygon 2 59.00 4221.93 -6384.37 6026273.01 519093.01 70 28 58.618 N 149 50 38.318 W -Polygon 3 59.00 3821.90 -6385.74 6025873.01 519093.01 70 28 54.683 N 149 50 38.348 W 30-02A Fauft 5 59.00 3227.59 -8066.95 6025273.01 517414.00 70 28 48.822 N 149 51 27.780 W -Polygon 1 59.00 3227.59 -8066.95 6025273.01 517414.00 70 28 48.822 N 149 51 27.780 W -Polygon 2 59.00 3228.62 -8366.98 6025273.01 517114.00 70 28 48.829 N 149 51 36.604 W -Polygon 3 59.00 3229.65 -8667.01 6025273.01 516814.00 70 28 48.836 N 149 51 45.428 W 30-02A Target 9 6578.00 2878.15 -8533.20 6024922.01 516949.00 70 28 45.381 N 149 51 41.481 W 30-02A Target 8 6579.00 3095.77 -8415.44 6025140.01 517066.00 70 28 47.522 N 149 51 38.025 W 30-02A Target 7 6583.00 3331.21 -8242.62 6025376.01 517238.00 70 28 49.839 N 149 51 32.949 W 30-02A Target 2 6584.00 4247.63 -6878.33 6026297.01 518599.00 70 28 58.866 N 149 50 52.848 W 30-02A Target 6 6588.00 3565.42 -8005.79 6025611.01 517474.00 70 28 52.145 N 149 51 25.991 W 30-02A Target 1 6589.00 4260.90 -6664.27 6026311.01 518813.00 70 28 58.998 N 149 50 46.552 W 30-02A Target 3 6599.00 4155.45 -7121.67 6026204.01 518356.00 70 28 57.957 N 149 51 0.004 W 30-02A Target 5 6603.00 3782.49 -7727.02 6025829.01 517752.00 70 28 54.283 N 149 51 17.799 W 30-02ATarget 4 6616.00 4021.43 -7411.16 6026069.01 518067.00 70 28 56.636 N 149 51 8.515 W Anaotatioo MD TVD ft ft 10000.00 6492.24 TIP 10060.00 6533.15 KOP 10074.00 6542.27 3 10168.70 6572.45 End of 40 Deg/100' DLS 10318.70 6572.45 5 10418.70 6574.80 6 10618.70 6585.32 7 10743.70 6588.84 8 10843.70 6586.75 9 10968.70 6584.28 10 11218.70 6598.96 11 11468.70 6615.03 12 11568.70 6615.68 13 11818.70 6609.21 14 11943.70 6602.85 15 12068.70 6597.28 16 12318.70 6587.97 17 12468.70 6584.61 18 12643.70 6582.80 19 12718.70 6581.96 20 by BP Alaska s Baker Hughes INTEQ Planning Report >:NTEQ Company:: BP Amtri:O Date: 10123!2007 Time: 15:48:08 Page: 3 Field: Kuparuk Go-ordinate(NE) Reference: Welt: 30-02, True North :Site: '< KRU 30 Pad Vertical (1'VD) Refcreeca - 30-02 Orig Rig 59.0 Fell: 30-02 ` SecNoe (VS) Rekreace: WeII (O.OON,O.OOE,225.OOAzi) Wellpat~ Plan 5, 30-02A 8nrvey Caku~tio® Method: Minimum Cwvature Db: Orade Annotation MD TVD ft ft 12918.70 6579.54 21 13200.00 0.00 TD Plan Section Information Ma Iacl Azim TVD +N/-S +E/-W DLS Bnikl Torn TFd Target ft deg deg ft ft ft deg/100ft tieg1100ft de9/100ft deg 10000.00 47.50 293.70 6492.24 3989.86 -6004.41 0.00 0.00 0.00 0.00 10060.00 46.52 294.54 6533.15 4007.79 -6044.47 1.93 -1.63 1.40 148.20 10074.00 52.12 294.54 6542.27 4012.20 -6054.12 40.00 40.00 0.00 0.00 10168.70 90.00 294.54 6572.45 4048.73 -6134.13 40.00 40.00 0.00 0.00 10318.70 90.00 312.54 6572.45 4131.27 -6258.64 12.00 0.00 12.00 90.00 10418.70 87.32 300.84 6574.80 4190.89 -6338.66 12.00 -2.68 -11.70 257.00 10618.70 86.74 276.81 6585.32 4254.88 -6526.31 12.00 -0.29 -12.01 268.00 10743.70 90.Q6 262.18 6588.84 4253.77 -6650.90 12.00 2.65 -11.71 282.50 10843.70 92.33 273.96 6586.75 4250.41 -6750.64 12.00 2.27 11.79 79.00 10968.70 89.93 259.15 6584.28 4242.92 -6875.03 12.00 -1.92 -11.85 261.00 11218.70 83.48 229.79 6598.96 4136.77 -7097.75 12.00 -2.58 -11.75 257.00 11468.70 89.31 259.29 6615.03 4030.93 -7320.51 12.00 2.33 11.80 80.00 11568.70 89.95 247.31 6615.68 4002.25 -7416.12 12.00 0.64 -11.98 273.00 11818.70 92.95 217.44 6609.21 3851.44 -7611.83 12.00 1.20 -11.95 276.00 11943.70 92.85 232.46 6602.85 3763.35 -7699.78 12.00 -0.08 12.02 90.00 12068.70 92.23 247.46 6597.28 3701.03 -7807.58 12.00 -0.49 12.00 92.00 12318.70 91.94 217.45 6587.97 3550.52 -8003.39 12.00 -0.12 -12.01 270.00 12468.70 90.61 235.40 6584.61 3447.57 -8111.59 12.00 -0.89 11.97 94.00 12643.70 90.57 214.40 6582.80 3324.31 -8234.42 12.00 -0.02 -12.00 270.00 12718.70 90.72 205.40 6581.96 3259.37 -8271.77 12.00 0.20 -12.00 271.00 12918.70 90.65 229.40 6579.54 3101.66 -8392.36 12.00 -0.03 12.00 90.00 13200.00 90.54 195.64 6576.51 2867.90 -8541.41 12.00 -0.04 -12.00 270.00 Survey MD Inc! Azim SS TVD N/S F./W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft tt ft degi100ft ft deg 10000.00 47.50 293.70 6433.24 3989.86 -6004.41 6026042.26 519473.72 0.00 1424.50 0.00 MWD ~ 10060.00 46.52 294.54 6474.15 4007.79 -6044.47 6026060.05 519433.60 1.93 1440.15 148.20 MWD 10074.00 52.12 294.54 6483.27 4012.20 -6054.12 6026064.43 519423.93 40.00 1443.86 0.00 MWD 10100.00 62.52 294.54 6497.29 4021.28 -6074.00 6026073.44 519404.03 40.00 1451.50 0.00 MWD 10168.70 90.00 294.54 6513.45 4048.73 -6134.13 6026100.68 519343.81 40.00 1474.60 0.00 MWD 10200.00 90.00 298.30 6513.45 4062.65 -6162.16 6026114.51 519315.74 12.00 1484.57 90.00 MWD 10300.00 90.00 310.30 6513.45 4118.90 -6244.62 6026170.46 519233.09 12.00 1503.11 90.00 MWD 10318.70 90.00 312.54 6513.45 4131.27 -6258.64 6026182.78 519219.03 12.00 1504.28 90.00 MWD 10400.00 87.82 303.03 6515.01 4181.01 -6322.80 6026232.30 519154.70 12.00 1514.47 257.00 MWD 10418.70 87.32 300.84 6515.80 4190.89 -6338.66 6026242.13 519138.82 12.00 1518.70 257.18 MWD 10500.00 87.02 291.08 6519.83 4226.39 -6411.58 6026277.37 519065.78 12.00 1545.16 268.00 MWD 10600.00 86.77 279.06 6525.26 4252.30 -6507.82 6026302.95 518969.46 12.00 1594.89 268..48 MWD 10618.70 86.74 276.81 6526.32 4254.88 -6526.31 6026305.47 518950.97 12.00 1606.14 269.14 MWD 10700.00 88.88 267.29 6529.44 4257.78 -6607:40 6026308.09 518869.87 12.00 1661.43 282.50 MWD 10743.70 90.06 262.18 6529.84 4253.77 X650.90 6026303.93 518826.39 12.00 1695.02 282.86 MWD 10800.00 91.34 268.81 6529.15 4249.35 -6706.99 6026299.32 518770.33 12.00 1737.81 79.00 MWD 10843.70 92.33 273.96 6527.75 4250.41 -6750.64 6026300.22 518726.68 12.00 1767.93 79.08 MWD 10900.00 91.26 267.29 6525.99 4251.02 -6806.87 6026300.64 518670.45 12.00 1807.26 261.00 MWD 10968.70 89.93 259.15 6525.28 4242.92 -6875.03 6026292.31 518602.32 12.00 1861.19 260.79 MWD 11000.00 89.09 255.49 6525.55 4236.05 -6905.56 6026285.34 518571.82 12.00 1887.63 257.00 MWD 11100.00 86.43 243.78 6529.47 4201.35 -6999.07 6026250.32 518478.44 12.00 1978.29 257.03 MWD 11200.00 83.92 232.00 6537.91 4148.50 -7083.33 6026197.19 518394.37 12.00 2075.24 257.49 MWD 11218.70 83.48 229.79 6539.96 4136.77 -7097.75 6026185.41 518379.99 12.00 2093.73 258.49 MWD 11300.00 85.26 239.43 6547.96 4089.98 -7163.63 6026138.40 518314.28 12.00 2173.40 80.00 MWO 11400:00 87.62 251.22 6554.19 4048.40 -7254.16 6026096.51 518223.90 12.00 2266.81 79.05 MWO • • by BP Alaska $ Baker Hughes INTEQ Planning Report INTE Q Coropaioy BP Amoco Date: 10/23/2007 Time: 15:48:08 Page: 4 Field: Kuparuk l;e-erdidate(NE) Retereuce: Well: 30-02, True North Site: KRU 30 Pad Vertical (1'VI)) Retereuce: 30-02 ' Orig Rig 59.0 Well: 30-02 Seetio®(VS) RefereACec Well (0.00N,0.00E,225.00Azi) Wellpat6: Plan 5, 30-02A Sarvey Cakelatio® Method: `Minimum Curvature Db: Orade Survey MD Incl Azim SS TVD N/S E/W IiZapN IilapE i)LS VS TFO To®I ft deg deg _ ft ' ft ' ft ft ~ degN 00ft _ft deg, 11468. 70 89.31 259.29 6556.03 4030.93 -7320.51 6026078.82 518157.61 12.00 2326.08 78.32 MWD 11500. 00 89.51 255.54 6556.35 4024.11 -7351.06 6026071.90 518127.10 12.00 2352.50 273.00 MWD 11568. 70 89.95 247.31 6556.68 4002.25 -7416.12 6026049.81 518062.12 12.00 2413.97 273.04 MWD 11600. 00 90.34 243.57 6556.60 3989.24 -7444.58 6026036.71 518033.70 12.00 2443.30 276.00 MWD 11700. 00 91.58 231.63 6554.93 3935.76 -7528.85 6025982.95 517949.62 12.00 2540.70 275.99 MWD 11800. 00 92.74 219.68 6551.14 3866.05 -7600.19 6025913.00 517878.53 12.00 2640.43 275.79 MWD 11818. 70 92.95 217.44 6550.21 3851.44 -7611.83 6025898.35 517866.94 12.00 2658.99 275.34 MWD 11900. 00 92.91 227.21 6546.05 3791.49 -7666.43 6025838.22 517812.55 12.00 2740.00 90.00 MWD 11943. 70 92.85 232.46 6543.85 3763.35 -7699.78 6025809.97 517779.31 12.00 2783.47 90.50 MWD 12000. 00 92.59 239.22 6541.18 3731.79 -7746.28. 6025778.26 517732.91 12.00 2838.67 92.00 MWD 12068. 70 92.23 247.46 6538.28 3701.03 -7807.58 6025747.28 517671.73 12.00 2903.77 92.32 MWD 12100. 00 92.23 243.71 6537.06 3688.10 -7836.05 6025734.26 517643.31 12.00 2933.04 270.00 MWD 12200. 00 92.15 231.70 6533.22 3634.80 -7920.36 6025680.68 517559.19 12.00 3030.35 269.85 MWD 12300. 00 91.98 219.69 6529.61 3565.13 -7991.74 6025610.77 517488.05 12.00 3130.09 269.39 MWD 12318. 70 91.94 217.45 6528.97 3550.52 -8003.39 6025596.12 517476.45 12.00 3148.66 268.96 MWD 12400. 00 91.23 227.18 6526.72 3490.49 -8058.04 6025535.91 517422.02 12.00 3229.74 94.00 MWD 12468. 70 90.61 235.40 6525.61 3447.57 -8111.59 6025492.81 517368.61 12.00 3297.96 94.27 MWD 12500. 00 90.60 231.65 6525.28 3428.97 -8136.76 6025474.13 517343.52 12.00 3328.91 270.00 MWD 12600. 00 90.58 219.64 6524.24 3359.19 -8208.12 6025404.11 517272.40 12.00 3428.71 269.96 MWD 12643. 70 90.57 214.40 6523.80 3324.31 -8234.42 6025369.15 517246.22 12.00 3471.97 269.84 MWD 12700. 00 90.68 207.64 6523.19 3276.10 -8263.42 6025320.84 517217.39 12.00 3526.57 271.00 MWD 12718 .70 90.72 205.40 6522.96 3259.37 -8271.77 6025304.08 517209.10 12.00 3544.30 270.93 MWD 12800 .00 90.70 215.16 6521.95 3189.25 -8312.71 6025233.83 517168.40 12.00 3622.83 90.00 MWD 12900 .00 90.66 227.16 6520.76 3114.10 -8378.40 6025158.46 517102.98 12.00 3722.42 90.12 MWD 12918 .70 90.65 229.40 6520.54 3101.66 -8392.36 6025145.98 517089.07 12.00 3741.09 90.27 MWD 13000. 00 90.64 219.65 6519.&2 3043.77 -8449.29 6025087.90 517032.33 12.00 3822.28 270.00 MWD 13100 .00 90.61 207.65 6518.52 2960.68 -8504.59 6025004.63 516977.32 12.00 3920.14 269.89 MWD 13200 .00 90.54 195.64 6517.51 ~ 2867.90 -8541.41 6024911.73 516940.83 12.00 4011.77 269.76 2 3/8" • M ` ~ • Kuparuk Managed Pressure Drilling BOP Configuration for 2" Coil Tubing Wel I I 30-02 Floor C ~~ C 3" 5000 psi l ,~ HCR Choke Line C C Tree Size 3-1 /8", 5M Lubricator ID = 6.375" with 6" Otis Unions 7 1/16" 5000 psi BOP's. ID = 7.06" 7 1/16" 5000 psi, RX-46 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee ~ SSV Master Valve Base Flan e Page 1 ~. TRANSMITTAL LETTER CHECKLIST WELL NAME ~2 ~~~ ~Z~ PTD# ~~ i l~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing welt ' (If last two digits in permit No. , API No. 50- - API number are production should continue to be reported as a function of the between 60-69) original API number stated above. PII.OT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- _) from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (a~me_of well) until after (Comp~nv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Comaany Name) must contact the Commission to obtain advance approval of such water well testing ro m. Rev: 7/1312007 U C] Cl L L ~3 rn o 4 a~ ~ ~, cy3 ~ o ~: ~ ~ Q ~ 7 C N p' i O' C: .. 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