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206-139
Image Project Well History File Cover Page 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. ~~' ~ - ~ ~ ~ Well History File Identifier Organizing (aone> ^ Two-sided I miuiiiuiu ~ Re=~a~~e~~ iuiuiii~iiiiiiu RES AN DIGITAL DATA Color Items: Diskettes, No. ^ Greyscale Items: ^ Other, NolType: ^ Poor Quality Originals: ^ Other: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Ma ' Date: ~ ~~ ~ ~ rn ^ Other:: lsl Project Proofing II I II II II ((III I I III BY: Maria Date: ~ ~~ ~ ~ /s/ Scanning Preparation ~ x 30 = + _°~ =TOTAL PAGES BY: Maria Date: / I~~ / Q ~~ (Count does not i ~ dude cover sheet) t /~ /~ Y k/ f Production Scanning Stage 1 Page Count from Scanned File: ~/ (Count does include co r sheet) Page Count Matches Number in Scanni g Preparation: YES NO BY: Maria Date: ~ ~~ /s/ ~,'~~ /~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II~III I II II (I III ReScanned II I II II II I I III V III BY: Maria Date: Comments about this file: o~a~,«e~~ed iuuiiiiiuiiiiu 10/6!2005 WeII History File Cover Page.doc ' • • OF Thr %%sr THE STATE Alaska Oil and as ®fl 1 �'� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue e).'ALASY'P Anchorage,Main: 90 9279.13433 Fax: 907.276.7542 I John McMullen SCANNED 1'J 1' 9 t n1�, Engineering Team Leader / 3 BP Exploration (Alaska), Inc. �® P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-32C Sundry Number: 313-440 Dear Mr. McMullen: 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, Cathy P. Foerster Chair DATED this 20 day of August, 2013. Encl. • • STATE OF ALASKA �a rr 1" ' ALASKA OIL AND GAS CONSERVATION COMMISSION OA AUG 1 2 201 APPLICATION FOR SUNDRY APPROVAL OTS 8'l I/23 20 AAC 25.280 AOGCC, 1. Type of Request: ❑Abandon ®Plug for Redrill ❑Perforate New Pool ❑Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate ❑Pull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ❑Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 206-139 • 3. Address: 6. API Numbe ®Development ❑Service P.O. Box 196612,Anchorage,Alaska 99519-6612 • 50.029-21559-03-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU C-32C Will planned perforations require a Spacing Exception? ❑Yes No 9. Property Designatior 10.Field/Pool(s): ADL 028305 • Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft)• Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11742' • 9032' • 11707' 9031' 10310', 10650' None Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2904' 13-3/8" 2904' 2713' 4930 2670 Intermediate 9246' _ 9-5/8" 9246' 8015' 6870 4760 Production Liner 593' 7" 9085'-9678' 7870'-8421' 7240 5410 Liner 604' 4-1/2" 9505'-10109' 8255'-8818' 8430 7500 Liner 1831' 3-1/2"x 3-3/16"x 2-7/8" 9911'-11742' 8647'-9032' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10241'- 11700' 8932'-9030' 4-1/2", 12.6# L-80 9516' Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV 9459'/8211' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ®Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: August 12,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG _4 Suspended • 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Johnston,564-5985 Printed Name: Joh f •f ,IJ' Ay Title: Engineering Team Leader Em 'I: David.Johnson2©bp.com Signature i , Phone: 564-4711 Date: g( 3 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �1 ��� Sundry Number: ❑Plug Integrity r BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: BGp fey f to s0 ip SC A /terhal-6 Flv y pM cki--,rhf a-/ p)-- veal per- .2044-C -2 S. 11Z CL i Spacing Exception Required? ❑Yes ❑No Subsequent Form Required: /U _ 40 77 RBF, S OCT 1 0 Cli / ^ APPROVED BY 8-23-13 Approved By: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 1 /2012 Approve Approve0pRitsr NfAi,Imonths from the date of approval Submit In Duplicate 10 a.‘/I • • To: Alaska Oil & Gas Conservation Commission From: David E. Johnston bp CTD Engineer Date: August 8, 2013 Re: C-32C Sundry Approval Sundry approval is requested to plug the C-32C perforations via the C-32D liner cement job and a liner top packer set after drilling and completing if the liner lap test fails. History and current status: C-32 was coil sidetracked to C-32A in 1998. The well was then rig sidetracked in 2003 to C-32B. This was followed by a coil sidetrack in 2007 to C-32C. C- 32C was perforated in Z1 B with 800'. Initial rates were Strong but with high GOR. The GOR ✓' quickly increased. In 7/11, a CIBP was set over the existing 800' of perforations and 40' Z1A perforations were added. The well wouldn't flow. 20' of Z1 B perforations were added in 11/11 and the well still wouldn't flow. Then in 12/11 15' Z1B perforations were added which kicked off the well but was high GOR. An end of life CIBP and Z2A perforations were shot in 4/12 ✓ but the GOR was too high making the well uncompetitive. Proposed plan C-32D will be a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on or around October 1, 2013. The existing perforations will be isolated by a 4-1/2 KB Packer whipstock set pre-rig to mitigate lost circulation to existing perforations while drilling. The sidetrack, C-32D, will exit the existing 4-1/2" liner and kick off in zone 4 and land in zone 1. This Sundry covers plugging the existing C-32C perforations via the C-32D liner cement lob or a liner top packer set post rig with Slickline if needed (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Cal(ter. (r,^1,/-1-0 The lvy Q/ le refiv,,'he5 prS' ,,�Sto/ s ,0�� �' Q 6 t?f .0%,(4,4"tee 64) /14.� i die well wO5 �� 4 600 41.240 t/uo"fed 7G w e/' 0"c 140 C -1 7 ,y sr, 41 aAl rdir // 7 the well alio:, -for c>iCr , r re 60 LILY)/. �� p� D01 -Fi0-(10/1 T , foi 7,yr ■ e . S • Required Permit?' Pre-Rig Work (scheduled to begin August 12, 2013) 10-403 PTD 1. F MIT-IA to 3,000 psi. No No 2. F MIT-OA to 2,000 psi. No No 3. S Dummy WS drift to 9,961' MD. No No 4. F Load and kill well with 1%KCL, and 2,500' of freeze protect No No 5. E Set 4-1/2" KB Whipstock-Top of whipstock at 9,852' MD No No 6. F MIT-T to 2,500 psi against KB packer whipstock No No 7. V PT MV, SV, WV. No No 8. V Bleed wellhead pressures down to zero. No No Bleed production, flow and GL lines down to zero and blind 9. V flange. No No 10. 0 Remove wellhouse and level pad. No No Required Permit? Rig Work (scheduled to begin October 1, 2013) 10-403 PTD 1. MIRU and test BOPE 250 psi low and 3,500 psi high. No Yes 2. Mill 3.80"window at 9,852' and 10' of rathole. No Yes 3. Drill 4.5" build section: 620' (18 deg DLS planned). No Yes 4. Drill 4.5" lateral section: 2508' (12 deg DLS planned). No Yes 5. Run 3-1/2"X 3-1/4" liner leaving TOL at — 9,790' MD. No Yes 6. Pump primary cement job: 11.1 bbls, 15.8 ppg, TOC at TOL. Yes* Yes 7. Perform liner cleanout and GR/CCL/MCNL log. No Yes 8. Perform liner lap pressure test to 2,400 psi. No Yes 9. Perforate liner based on log interpretation (-600'). No Yes 10. Freeze protect well to 2,500' MD. No Yes 11. Set BPV and RDMO. No Yes Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Set liner top packer with Slickline if needed.* 3. Set GLV's *Approved alternate plug placement per 20 AAC 25.112(i) David E. Johnston CTD Engineer 564-5985 CC: Well File Joe Lastufka • TREE= 41!16"CIYV • W�L ANGLE>^70° 10364'. WBIFFAD= FMC C-32 INITIAL,"A"AND"B"W ELLBORES NOT SHOWN • ACTUATOR= BAKEf2 NTIAL KB.HE_....___ 67.72 BELOW MILLOUT @ 9246" NTTAL BF.aE 39.93' ORIG KOP _500' Max Angle= 94°@ 10589' I ' 2272' --41/2"HES X NP,D=3.813" Datum MD 10168' GAS LIFT MANDRELS Datum1VD= 8800'SS ST MD Nt) DEV TYPE VLV LATCH PORT DATE r 5 3261 3009 35 MMG DMY RK 0 07/13/13 13-3/8"CSG,72#,L-80,D=12.347" H 2903' !/ 4 4483 4007 35 MMG DMY RK 0 07/13/13 3 6309 5517 34 MMG DMY RI< 0 12/09/04 2 7494 6488 34 MMG DMY RK 0 02/08/03 1 8675 7502 27 MMG DMY RK 0 02/08/03 Minimum ID =2.37" @ 10694' 3-3/16" x 2-7/8" STL XU 9085' —9-n518"X7"BKR ZXP& ,D LN2=6.27" w 6'Tt�ACK FMC HGR 9-5/8"MLLOUT WINDOW(C-32B): 9246'-9264' 9-5/8"CSG,47#,L-80,D=8.681" - 9246' — 1 ' 9438' —141/2"I-ES X N',D=3.813" I Er—I_ 9459' I-41/2"BKR S-3 FKR D=3.875" I I 9482' -41/2"I-ES X NP,D=3.813" 9503' —4-1/2"FES XN NP,D=3.80" MILLED(12118/06) 4-1/2"TBG,12.6#,L-80,BT,.0152 bpf,ID=3.958" - 9516' I 9505' —7"x 5"BKR ZXP LT PKR,ID=5.01" w/XX'TISACK&FMC LN2 HGR 7'LNR,26#,L-80,130=6.276" —I 9677' 4 • 9781' H MARKER Jam- 3-1/2"LMM,9.3#,L-80,STL,,0087bpf,D=2.992" —I 9961' V 9911' —1 3-1/2"DEPLOY MENT SLEEVE,ID=3.00" 4-1/2"LN2,12.611,L-80,BTC,.0152 bpf,D=3.958" — 10109' I 9930' H 3-1/2"HOWCO X NIP,D=2.813" PERFORATION SUMMARY �— 9961' —I 3-1/2"x 3-3/16"XO,D=2.441" REF LOG: MGR/CCUC.L 02/18/07 ANGLE AT TOP PERE: 33°Q 10241' Note:Refer to Production DB for historical pert data 41/2'MLLOtlT WINDOW(C-32C): 10109'-10115' SIZE SPF NTERVAL Opn/Sqz SHOT SQZ 2" 6 10241-10246 0 04/19/12 2' 6 10325-10340 C 12/08/11 10310' —13-3/2"HES CBP(04/18/12) I 2" 6 10352-10372 C 11/20/11 2" 6 10426 10436 C 07/07/11 2" 6 10450-10480 C 07/07/11 2" 6 10680-11330 C 02/19/07 L 10650' -3-3/16"BKRCBP(07/11/11) I 2" 6 11370-11400 C 02/19/07 2" 6 11440-11490 C 02/19/07 10696' —13-3/16"x 2-7/8"XO,D=2.37" 2" 6 11640-11700 C 02/19/07 3.3/16"LM,6.2#,L-80,TC1,.0076bpf,13=2.80" - 10696' I 2-7/8"LN2,6.4#,L-80,STL,.0058bpf,D=2.441" —I 11742' PBTD 11707' DATE REV BY COMMENTS DATE REV BY COMMENTS fS F RUDHOE BAY UNIT 09/21/98 CTD SIDETRACK(C-32A) 07/29/11 JKEY PJC CBP1 ADFERFS(07/07-11/11) WELL: C-32C 02/08/03 DAC/TLH RIG SIDETRACK(C-32B) 04/22/12 JCI Y PJC PAS/CBP(4/18-19/12) FERMI'No: 2061390 02/20/07 NORDIC1 CTD SIDETRACK(C-32C) 07/23/13 RICT/JMD GLV C/O(07/13/13) API No: 50-029-21559-03 03/06/07 KSBITLH GLV DO SEC 19,T11N,R14E,1700'FNL&883'FEL 03/29/08 KDC/SV GLV GO 03/19110 AK/SV FINAL DRAFT CORRECTIONS BP Exploration(Alaska) VVELLHE:AD= FMC C-2D Proposed S NOTES: WELL ANGLE>--70°@10364'. ACT OR= BAKER I L,"A"AND"B"WELLBORES NOT SHOWN ACTUATOR= N__IAL_KB__LE__ -6_7.-_ BELOW MILLOUT @ 9246' WRAC BF.ELE v 39.93' ORIG KOP 500' Max Angle= 94°@ 10599' I 2272' —14-1/2"I-ES X NP,ID=3.813" Datum MD= 10168' GAS LIFT MANDRELS Datum TV D= 8800'SS ST MD I,,iu DEV TYPE VLV LATCH FORT DATE 5 3261 3009 35 MUG DMY RK 0 07/131' 4 4483 4007 35 WMG DM' RK 0 07/13/' 13-3/8"CSG,72#,L-80,D=12.347" H 2903' 3 6309 5517 34 MUG DMY RK 0 12/09/I 2 7494 6488 34 WAG MAY RK 0 02/08/I 1 8675 7502 27 WMG DMY RK 0 02/08/1 Minimum ID = 2.37" @ 10694' 3-3/16" x 2-7/8" STL XO 9085' �9-5/$"X 7"BKRZxP ID=6.27" w R.6'TIEBACK 8 MAC LNR HGR 9-5/8"MLLOUT WIDOW(C-32B): 9246'-9264' 9-5/8"CSG,47#,L-80,ID=8.681" H I 9246' — 9438' —14-1/2"FES X NP,ID=3.813" , 9459' H4-1/2"BKR S-3 FKR,D=3.875" I9482' H4-1/2"F S X NP,ID=3.813" 9503' 4-1/2"HES XN NP,ID=3.80" MLLED(12/18/06) 4-1/2"TBG, 12.6#,L-80,BT,_0152 bpf,ID=3.958" 9516' J 9505' —7"x 5"BKR ZXP LT PKR,ID=5.01" I TSGR=-9675'MD w DO'TIEBACK&H v C LIB HGR 7"LNR,26#,L-80 ID=6.276" —I 9677' 1 3.1° L j --Top of liner and cement at-9,790' I I i 9781' ----1 MARKER JOINT 13.4° , 4-1/2"packer whipstock at 9,852' :::::,'L-80, D=2.992" 3-1/4"L-80 linerwith TD at 13,000' L-80, BTC,.0152 bpf,D=3.958" --I 10109' 1 ? " PERFORATION SUMMARY REF LOG: MGR/CCUCNL 02/18/07 9911' —13-1/2"DEPLOYMENT SLEB/E,D=3.00" ANGLE AT TOP PEW: 33°@ 10241' Note:Refer to Production DB for historical pert data 9930' 1/2"HOWCO X NP,D=2.813" SIZE SPF II1HRVAL Opn/Sqz SHOT SOZ $961' H3-1/2"x 3-3/16"XO.13=2.80" 2" 6 10241-10246 0 04/19/12 2" 6 10325-10340 C 12/08/11 4-1/2"MILLOUT W■DOW(C-32C): 10109'-10115' 2" 6 10352-10372 C 11/20/11 2" 6 10426-10436 C 07/07/11 ' 2" 6 10450-10480 C 07/07/11 2" 6 10680-11330 C 02/19/07 2" 6 11370-11400 C 02/19/07 2" 6 11440-11490 C 02/19/07 10310' —13-3/T FES CEP(04/18/12) 2" 6 11640-11700 C 02/19/07 ' 10650' H 3-3/16"BKR CIBP(07/11/11) 3-3/16"LNR,6.2#,L-80,TCH,.0076bpf,13=2.80" H 10696' J 10696' H 3-3/16"x 2-7/8"XO,13=2.37" 2-7/8"LNR,6.4#,L-80,STL,.0058bpf,ID=2.441" —I 11742' 1.V� PBTD H 1170T DATE REV BY COMMENTS DWTE REV BY COI W'TTS PRUDHOE BAY UNIT 09/21/98 i CTD SIDETRACK(C-32A) 07/29/11 JKD1 PJC CEP/ADPERFS(07/07-11/11) WELL: C-32C 02/08/03 DAC/TLH RIG SIDETRACK(C-32B) 04/22/12 JUN PJC PERFS/CEP(4/18-19/12) PE RMT No: 2061390 02/20/07 NORD)IC1 CTD SIDETRACK(C-32C) 07/23/13 RKT/JMO GLV GO(07/13/13) AR No: 50-029-21559-03 03/06/07 KSB/TLH GLV C/O SEC 19,T11N,R14E, 1700'FNL&883'FEL 03/29/08 KDC/SV GLV C/O 03/19/10 AK/SV FINAL DRAFT CORRECTIONS BP Exploration(Alaska) NORDIC CTD UNIT#2 CHOKE / REEL/ CIRCULATION MANIFOLD DIAGRAM = I --5 Cho a Panel Standpipe 2"Circulation Line ¢.� I CM Driller GauOe�. w0 M10 MMMB MM9 Manual Choke IgC Galicia / CIRCULATING MANIFOLD .� MM 16 `;,` / , r� I I MM 15 C --\-1.\,,, I SLB Transducer ® ,MM 8 ® 1 --�r, f— ;{ . PVT Sensor ,•,. `� a n rs � I ,,- - ras MM 7 ee Baker Choke ,� 0 MM 13 MM q MM 17 KILL SIDE MANUAL VALVE a 70 h„ MANUAL VALVE j 1 i� f KILL HCR i CHOKE HCR // Rev Cir Line 1 a/ ; I fA _Blow t* B, MM14 r ro I .rem Mme ' •� _ I •• .,. :II s cnoxe une 1 Coned mmne _ i i� I 1 1 Be rChoke K„Line 0 1 I MP2 0;. MPI p. • I ♦ .I -:i` I •01 I .2 I- k Kill Line I I V I \BOP 18 I , I HP11 HP10... Tranducers COILED TUBING 1 / ,..�.�, BOP 17 I / I ■ t CIRCULATING SYSTEM I ��' I+, l 1 I- G HP 18 I / I HP 14 P19 HP6 , , I - I To Inner Reel I 1 I Valve - b HP7 HP HP4 HPJ I I 1 ..1 . I P13 I HP , HP• HP —- �T -- -I I H P 18 7 I I cement line N2 SLB . , _ CHOKE MANIFOLD ,- '- = HP17 N2TrIFlow ,,,CM 85 MOs , ��� • • P�� i Gauge CM 29� I"N CHOKE LII GAS BUSTER a I Test Pump Inlet —CM JO - -_ . ..._- I 40 CMJ // e 4 el r I 7 HOtGaup PB1 I Flow it HC- // • 4Wav Block CM14 CM17 7 CMB 1.11 CM24 PB2 quid C CMb CMB 19 - — ois I Baker Choke Une . �. - — high 1- from wal �� _ — -U^. - CM2 - _ POSSUM BELLY I : 18 1: UL _000:— M4 ZZ M20 • nea rani I — 1.11■16V614-11.11.111 IF II cHOxe unE CM16 CM19 1 ill/ CM27 / . / TIGER TANK II' I ° I I - • • • STATE ALA O F ALASKA • RE S ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 2 201 REPORT OF SUNDRY WELL OPERATIONS GCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development © Exploratory ❑ - 206 -139 3. Address: • • • • =0x • • • Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029- 21559 -03 -00 7. Property Designation (Lease Number): 8. Well Name and Number: . ADLO- 028305 PBU C -32C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Prudhoe Bay Field / Prudhoe oil Pool 11. Present Well Condition Summary: Total Depth measured 11742 feet Plugs measured 10310, 10650 feet true vertical 9032 feet Junk measured NONE feet Effective Depth measured 11707 feet Packer measured SEE BELOW feet true vertical 9031 feet true vertical feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H -40 28' -108' 28' -108' 1490 470 Surface 2878' 13 -3/8" 72# L -80 27' -2905' 27' -2714' 4930 2670 Production 9220' 9 -5/8" 47# L -80 26'-9246' 26'-8015' 6870 4760 Liner 592' 7" 26# L -80 9085' -9677' 7870' -8420' 7240 5410 Liner 610' 4 -1/2" 12.6# L -80 9505'- 10115' 8255' -8823' 8430 7500 Liner 50' 3 -1/2" 9.3# L -80 9911' -9961' 8647' -8693' 10160 10530 Liner 735' 3- 3/16" 6.2# L -80 9961'- 10696' 8693' -9023' Liner 1 M 46' 2 -7/8" 6.4# L -80 10696'- 11742' 9023' -9032' Perforation depth Measured depth feet SEE ATTACHED True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25' -9516' 25'-8265' 7" Baker ZXP PKR 9085' 7870' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm PKR 9459' 8211' 5" Baker ZXP Top PKR 9505' 8255' 12. Stimulation or cement squeeze summary: Intervals treated (measured): St -A NED MAY 1 8 201Z 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: 16 1779 1 1268 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development © < Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil © Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 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: Contact Nita Summerhays Printed Name Nita Su;,,,k ays Title Data Manager Signature ���/ -- Phone 564 -4035 Date 05/01/2012 . _ � _� _� t, �BDMS MAY 03 2 1 S _ I ^JZ SubmitOri final Only Form 10-404 Revised 11/2011 I�" g y ;e -016_ C -32C 206 -139 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C -32C 2/19/07 PER 10,680. 11,330. 9,023.95 9,029.49 C -32C 2/19/07 PER 11,370. 11,400. 9,029.05 9,027.57 C -32C 2/19/07 PER 11,440. 11,490. 9,025.49 9,024.01 C -32C 2/19/07 PER 11,640. 11,700. 9,028.91 9,030.35 C -32C 8/1/07 BPS 2,272. 11,700. 2,182.17 9,030.35 C -32C 8/19/07 BPP 2,272. 11,700. 2,182.17 9,030.35 C -32C 7/7/11 BPS 10,650. 11,700. 9,025.55 9,030.35 C -32C 7/7/11 APF 10,426. 10,436. 9,024.98 9,025.52 C -32C 7/7/11 APF 10,450. 10,480. 9,025.75 9,027.54 C -32C 11/20/11 APF 10,352. 10,362. 9,006.75 9,010.91 • C -32C 11/20/11 APF 10,362. 10,372. 9,010.91 9,014.57 C -32C 12/8/11 APF 10,325. 10,340. 8,993.33 9,001.19 C -32C 4/18/12 BPS 10,310. 10,680. 8,984.4 9,023.95 C -32C 4/19/12 APF 10,241. 10,246. 8,931.87 8,936.08 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • C-32C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11411 ••t• "ITRW ‘" a ; 11 rrigiagl ' N 4/1812012* WELL SHUT IN ON ARRIVAL *** (E-LINE: DRIFT/PLUG/PERF) INITIAL T/1/0: 2600/1100/0. DRIFTED W/ ELINE TOOLSTRING & 2.34" CENTRALIZER TO DEV @ 10341' . SET HES 3-1/2" CIBP A 10310' (OAL = 2.24' / OD = 2.28") 1LAYED EQUIPMENT DOWN FOR NIGHT / WILL RETURN IN MORNING TO PERF !FINAL T/1/0: 2400/1100/0 ,*** JOB IN PROGRESS. CONTINUED ON 19-APR-2012 *** 4/19/2012*** JOB CONTINUED FROM 18-APR-2012 *** INITIAL T/I/0 = 2350 / 1100 / 0 RUN #3: PERFORATED INTERVAL 10241' - 10246' WITH 5' OF 2" PJ 2006 GUN 'FINAL T/I/O = 1250/750/0 ***JOB COMPLETE*** FLUIDS PUMPED BBLS 5 DIESEL 5 TOTAL TREE = 4-1/16" CNN • SAFONOTES: INITIAL, "A" AND "B 1AELLHEAD = = FIX C -3 2 C ,c,f0A—foR BAKER- WELLBORES NOT SHOWN BELOW MILLOUT @ INITIAL kEi, — -6:721 9246' iNITIAI,9F. ELE 36:9' — OM KOP 500' - A‘x Angle = 14° Cg 1 1 2272' 1--141/2" HES X NIP, ID = 3.813" Dium 'kb = 10166 GAS LIFT MANDRELS DaturriTVD = 8600' SS ST MD ND DEV TY PE VLV LATCH PORT DATE 5 3261 3009 35 MIVG DOME RK 16 07/16/11 13-3/8" CSG, 72#, L-80, 0 = 12.347" H 2903 IP 4 4483 4007 35 MM3 SO RK 20 07/16/11 3 6309 5517 34 WIG DMY RK 0 12/09/04 2 7494 6488 34 MMG DMY RK 0 02/08/03 1 8675 7502 27 /AVG DMY RK 0 02/08/03 Minimum ID = 2.37" @ 10694' 9085' 1- 9-5/8" X 7" BKR ZXP, D = 6.27" 3-3/16" x 2-7/8" STL X0 w/7.6' TIEBACK & HMC LNR HGR 9-5/8" VILLOUT WINDOW (C-3213): 9246'- 9264' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9246' • 9438' — /2" HES X NIP, ID = 3.813" ■•:. 27-1 9459' —14-1/7' BKR S-3 PKR, ID = 3.875" 1 1 1 9482' H4-1/2" HES X NIP, ID = 3.813" 1 I 1 — 4-1/2" FES XN NIP, ID = 3.90" 9503' ' r-----------"4 MILLED (12/18(06) 1 4-1/2" TBG, 12.6#, L-80, IBT, .0152 bpi, ID = 3.958" H 9516' C .---- -I 9505' I — 7" x 5" BKR ZXP LT PKR, ID = 5.01" w /XX' TIEBACK & FRAC LNR HGR 17" LNR, 26#, L-80, ID = 6.276" 1-1 9677' 1 IL 1 9781' MA R11— <8110INT 13-1/2" LNR, 9.3#, L-80, STL, .0087bpf, ID = 2.992" H 9961' I 9911' 1 DEPLOYMENT SLEEVE, ID = 3.00" 1 4-1/2" LNR 12.6#, L-80, BTC,.0152 bpf, ID = 3.958" 1-1 10109' 1 9930' 1-13-1/2" HOWCO X NIP, ID = 2.813" 1 PERFORATION SUMMARY ..... ......------1 9961' H3-1/7' x 3-3/16" X0, ID = 2.441" 1 REF LOG: MGR/CCL/CNL 02/18/07 ANGLE AT TOP PERF: 33° @ 10241' Note: Refer to Production 06 for historical perf data 4-1/2 FALLOUT WINDOW (C-32C): 10109' - 10115' SIZE SFF INTERVAL Opn/Sqz ' DATE --- --- -----..... 2" 6 10241 - 10246 0 04/19/12 2" 6 10325 - 10340 C 12/08/11 . 1 4 ----- lu - - 1 " 2" 6 10352 - 10372 C 11/20/11 — — 10310' H3-3/2" HES CIBP (04/18/12) \, 2" 6 10426 - 10436 C 07/07/11 1 ' 2' 6 10450 - 10480 C 07/07/11 1 ___-----"L_____----- 2" 6 10680 - 11330 C 02/19/07 1 2" 6 11370 - 11400 C 02/19/07 ::-- 10650' —13-3/16" BKR GBP(07/11/11) 1 2" 6 11440 - 11490 C 02/19/07 1 10696' H3-3/ 16" x 2-7/8" X0, ID = 2.37' 1 2" 6 11640 - 11700 C 02/19/07 . I 13-3/16" L NR 62#, L-80, TGI, ,0076bpf, ID = 2.80" H 10696' 1 1 1 2-7/8" LNR, 6.4#, L-80, STL,.0058bpf, ID = 2.441" H 11742' 1 14 1 PBTD —1 11707' 1 DATE REV BY ,. COMNENTS DATE - REV BY COMMENTS PRUDHOE BAY UNIT 09121198 CTD SIDETRACK (C-32A) 07/29/11 JKD/ PJC CIBPI A DPERFS (07/07-11/11) WELL: C-32C 02/08/03 DAC/TLH RIG SIDETRACK (C-329) 07/29/11 GJB/ PJC GLV C/0 (07/16/11) PERVIIT No: 2061390 02/20107 NORDIC1 CTD SIDETRACK (C-32C) 12/16/11 SKY PJC PERFS (11/20(11) API No 50-029-21559-03 03/06/07 KSB/TLH GLV GO 12/16/11 TTR/ PJC 'PEWS (12/08/11) SEC 19, T11N, R148 1700' FNL & 883' FEL 03/29/08 KDC/SV GLV C/0 11 04122/12 , JCIVV PJC PEWS/ GBP (4/18-19/12) 03/19/10 AK/SV FINAL DRAFT GORREC11ONS BP Exploration (Alaska) STATE OF ALAS ALASKA. AND GAS CONSER A COMMISSIO RECEIVED REPORT OF SUNDRY WELL OPERATIONS DEC 3 0 2011 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Tim extgnsipn; r: r � �+ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Neer" Name: Development 0 Exploratory ❑ 1 206 -1390 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21559 -03 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: w ADLO- 028305 r PBU C -32C 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11742 feet Plugs (measured) 10650 feet true vertical 9031.5 feet Junk (measured) None feet Effective Depth measured 11707 feet Packer (measured) 9085 9459 9505 feet true vertical 9030.54 feet (true vertical) 7870 8211 8255 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 28 - 108 28 - 108 1490 470 Surface 2878' 13 -3/8" 72# L -80 27 - 2905 27 - 2714 4930 2670 Production 9220' 9 -5/8" 47# L -80 26 - 9246 26 - 8015 6870 4760 Liner 592' 7" 26# L -80 9085 - 9677 7870 - 8420 7240 5410 Liner 610' 4 -1/2" 12.6# L -80 9505 - 10115 8255 - 8823 8430 7500 Liner 50' 3 -1/2" 9.3# L -80 9911 - 9961 8647 - 8693 10160 10530 Liner 735' 3- 3/16" 6.2# L -80 9961 - 10696 8693 - 9023 Liner 1046' 2 -7/8" 6.4# L -80 10696 - 11742 9023 - 9032 Perforation depth: Measured depth: SEE ATTACHED - - _ - True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25 - 9516 25 - 8265 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Packer 9085 7870 4 -1/2" Baker S -3 Perm Packer 9459 8211 5" Baker ZXP Top Packer 9505 8255 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: StrAtti6I1el) , ji, t\f `1 ' c. U1Z' 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 98 4633 7 176 Subsequent to operation: 16 1779 1 1268 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil — El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG El 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: NA Contact Joe Lastufka Printed Name oe Lastufk Title Data Manager Signatu Phone 564 -4091 Date 12/29/2011 Form 10-404 Revised 10/2 3DMS DEC 3 0 1011 Qi 7j- 7 1 /.11. / z Submit Original Only C -32C 206 -139 PERF ATTACHMENT Sw Name Operation Date Pelf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C -32C 2/19/07 PER 10,680. 11,330. 9,023.95 9,029.49 C -32C 2/19/07 PER 11,370. 11,400. 9,029.05 9,027.57 9,024.01 11 440. 11 490. 9 025.49 9 C -32C 2/19/07 PER , C -32C 2/19/07 PER 11,640. 11,700. 9,028.91 9,030.35 C -32C 8/1/07 BPS 2,272. 11,700. 2,182.17 9,030.35 C -32C 8/19/07 BPP 2,272. 11,700. 2,182.17 9,030.35 C -32C 7/7/11 APF 10,426. 10,436. 9,024.98 9,025.52 C -32C 7/7/11 APF 10,450. 10,480. 9,025.75 9,027.54 C -32C 7/7/11 BPS 10,650. 11,700. 9,025.55 9,030.35 C -32C 11/20/11 APF 10,352. 10,362. 9,006.75 9,010.91 C -32C 11/20/11 APF 10,362. 10,372. 9,010.91 9,014.57 • C -32C 12/8/11 APF 10,325. 10,340. 8,993.33 9,001.19 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • C -32C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/20/2011 * ** WELL SHUT IN ON ARRIVAL * ** (SCHLUMBERGER ELINE ADPERF) INITIAL TWO = 450/500/0 PSI PERFORATED INTERVAL = 10352' - 10372' . GUNS INFO: 2" 2006 PJ, HMX, 2 X 10', TIE -IN TO SLB MCNL 18 -FES -2007 FINAL T /I /O = 450/500/0 PSI WELL SHUT IN UPON DEPARTURE ** *JOB COMPLETE * ** E 1 12/8/2011 1 ** *WELL SHUT IN ON ARRIVAL * ** (ELINE PERF) INITIAL T /I /0= 1300/1350/0 'RIH WITH MH22 /ERS /SWVL/UPCT /20' 2" HSD GUN 15' LOADED OAL =29', OAW =220# FISHING NECKSIZE = 1.24" USED TIE -IN LOG (SLB MCNL 2/18/2007) J PERFORATION INTERVAL 10325'- 10340' CCL TO TOP SHOT = 8.25' CCL STOP DEPTH = 10316.75' 'VISUAL INDICATION OF SHOTS FIRED FINIAL T/I/0= 1300/1350/0 WELL LEFT SHUT IN SWAB, WING CLOSED AND OTG DSO AND PE NOTIFIED OF DEPARTURE i ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 2 DIESEL 5 METH 7 TOTAL TREE = 4 CNV • SAFETY ES: ORIGINAL, "A" AND "B" WELLREAD FMC ACTUATOR = BAKE R C -32 C WELLBORES NOT SHOWN BELOW MILLOUT @ ACTUAT ''ORIG KB. ELEV = 67.72' 9246' ORIG B F . ELEV 39.93' ORIG KOP .. 500' Max Angle = 94° @ 10599' ' I 2272' H4 -11 2" HES X NIP, ID = 3.813" I Datum MD = 10168' GAS LIFT MANDRELS Datum TVb = 8800' SS ST MD TV D DEV TYPE VLV LATCH PORT DATE 5 3261 3009 35 MMG DOME RK 16 07/16/11 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I-{ 2903' I-, 4 4483 4007 35 MMG SO RK 20 07/16/11 IIID 3 6309 5517 34 MMG DMY RK 0 12/09/04 2 7494 6488 34 MMG DMY RK 0 02/08/03 1 8675 7502 27 MMG DMY RK 0 02/08/03 Minimum ID = 2.37" @ 10694' - - 3- 3/16" x 2 -7/8" STL XO 9085' 119 -5/8" X 7" BKR ZXP, ID = 6.27" w /7.6' TIEBACK & HMC LNR HGR 9 -5/8" MILLOUT WINDOW (C -32B): 9246' - 9264' 9-5/8" CSG, 47 #, L-80, ID = 8.681" I-{ 9246' 9438' H 4_1/2" HES X NIP, ID = 3.813" _■ if---1 9459' H4 -1/ 2" BKR S -3 PKR, ID = 3.875" I 1 I 9482' 1-14-1/2" HES X NIP, ID = 3.813" 9503' I 4 -112" HES XN NIP, ID = 3.80" MILLED (12/18/06) 14 -1/2" TBG, 12.6 #, L 80, IBT, ,0152 bpf, ID = 3.958" H 9516' _ i---------1 9505' h 1 7 " 5 ' , 1 0 1 ' , w /XX' TIEBACK & HMC LNR HGR 17" LNR, 26 #, L -80, ID = 6.276" H 9677' • 9781' I-I MA RKER JOINT 1 • 1 9911 I- 13 -1/2" DEPLOYMENT SLEEVE, ID = 3.00" I I3 -1/2" LNR, 9.3 #, L -80, STL, .0087bpf, ID = 2.992" H 9961' 1 1 9930' H 3 -1/2" HOWCO X NIP, ID = 2.813" I 14 -1/2" LNR, 12.6 #, L -80, BTC,.0152 bpf, ID = 3.958" 1-1 10109' ____......---1_ 9961' 1-13-1/ 2" x 3- 3/16" XO, ID = 2.441" ( 13-3/16" LNR, 6.2 #, L -80, TCII, .0076bpf, ID = 2.80" I—i 10696' 4 -1/2" MILLOUT WINDOW (C -32C): 10109' - 10115' PERFORATION SUMMARY REF LOG: MGR/CCL /CNL 02/18/07 ANGLE AT TOP PERF: 86° @ 10426' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE ✓ I 10650' I-{3- 3 /16 " BKR CIBP(07 /11/11) 1 2" 6 10325 - 10340 0 12/08/11 I 10696' H3-3/16" x 2 -7/8" X0, ID = 2.37" I 2" 6 10352 - 10372 0 11/20/11 1 2" 6 10426 - 10436 0 07/07/11 2" 6 10450 - 10480 0 07/07/11 2" 6 10680 - 11330 C 02/19/07 2" 6 11370 - 11400 C 02/19/07 2" 6 11440 - 11490 C 02/19/07 2" 6 11640 - 11700 C 02/19/07 PBTD -I 11707' 1 I 2 -7/8" LNR, 6.4 #, L -80, STL,.0058bpf, ID = 2.441" I--I 11742' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/21/98 CTD SIDETRACK (C -32A) 07/29/11 JKD/ PJC CIBP/ ADPERFS (07/07- 11/11) WELL: C-32C 02/08/03 DAC/TLH RIG SIDETRACK (C -32B) 07/29/11 GJB/ PJC GLV C/O (07/16/11) PERMIT No: 2061390 02/20/07 NORDICI CTD SIDETRACK (C -32C) 12/16/11 SRD/ PJC PERFS (11 /20/11) API No: 50- 029 - 21559 -03 03/06/07 KSB/TLH GLV C/O 12/16/11 TTR/ PJC PERFS (12/08/11) SEC 19, T11 N, R14E, 1700' FNL & 883' FEL 03/29/08 KDC/SV GLV C/0 03/19/10 AK/SV FINAL DRAFT CORRECTIONS BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 t. +( August 22, 2011"' d. , Mr. Tom Maunder ��� Alaska Oil and Gas Conservation Commission s & Gas COM. � i 333 West 7 Avenue Anchorage, Alaska 99501 An-hauls Subject: Corrosion Inhibitor Treatments of GPB C -Pad c>1 r 113 7 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C - 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C - 20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C - 32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -358 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 1 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C-41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 STATE OF ALASKA • • • ALASKA 4IPAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations El Stimulate 0 Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ „ 206 -1390 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21559 -03 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028305 PBU C -32C 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11742 feet Plugs (measured) 10650 feet true vertical 9031.5 feet k (measured) None feet Effective Depth measured 11707 feet ' 7 ^', > W Packer (measured) 9085 9459 9505 feet true vertical 9030.54 feet (true vertical) 7870 8211 8255 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 28 - 108 28 - 108 1490 470 Surface 2878' 13 -3/8" 72# L -80 27 - 2905 27 - 2714 4930 2670 Production 9220' 9 -5/8" 47# L -80 26 - 9246 26 - 8015 6870 4760 Liner 592' 7" 26# L -80 9085 - 9677 7870 - 8420 7240 5410 Liner 610' 4 -1/2" 12.6# L -80 9505 - 10115 8255 - 8823 8430 7500 Liner 50' 3 -1/2" 9.3# L -80 9911 - 9961 8647 - 8693 10160 10530 Liner 735' 3- 3/16" 6.2# L -80 9961 - 10696 8693 - 9023 Liner 1046' 2 -7/8" 6.4# L -80 10696 - 11742 9023 - 9032 Perforation depth: Measured depth: SEE ATTACHED - - True Vertical depth: _ _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25 - 9516 25 - 8265 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Packer 9085 7870 $I�lto5�1��� 4 -1/2" Baker S -3 Perm Packer 9459 8211 5" Baker ZXP LT PaU€SIWU 4 ` ( '1° 45 9895'' � "I 8255 12. Stimulation or cement squeeze summary: Intervals treated (measured): E I / ( 1 ! I 4 Treatment descriptions including volumes used and final pressure: p , % . a. ate, 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 560 31,944 52 1,228 Subsequent to operation: 571 38,084 51 1,137 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ffil , Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil „ IN Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 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: NA Contact Joe Lastufka Printed Na e Lastu Gk , 1 Title Petrotechnical Data Technologist Signatu MIN 1 114 V) Phone 564 -4091 Date 7/30/2011 Form 10 -404 Revised 1 01BBDMS AUG 02 20114 g L Q- Y' f( Submit Original Only A del /, C -32C 206 -139 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C -32C 2/19/07 PER 10,680. 11,330. 9,023.95 9,029.49 C -32C 2/19/07 PER 11,370. 11,400. 9,029.05 9,027.57 C -32C 2/19/07 PER 11,440. 11,490. 9,025.49 9,024.01 C -32C 2/19/07 PER 11,640. 11,700. 9,028.91 9,030.35 C -32C 8/1/07 BPS 2,272. 11,700. 2,182.17 9,030.35 C -32C 8/19/07 BPP 2,272. 11,700. 2,182.17 9,030.35 C -32C 7/7/11 APF 10,426. 10,436. 9,024.98 9,025.52 C -32C 7/7/11 APF 10,450. 10,480. 9,025.75 9,027.54 C -32C 7/7/11 BPS 10,650. 11,700. 9,025.55 9,030.35 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • C -32C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/7/2011 ICTU #9 w/ 1.75" CT: Job Scope: PPROF w/ GHOST, MCNL w/ Borax, Set CIBP, ;Perforate: Job continued from 06 July 11. Download and confirm good MCNL data. MU and RIH with 2.60" JSN drift BHA for CIBP. RIH w / baker 2.562" CIBP. Set CIBP at 10650'.RIH w / CBF firing head & 2" guns - 6 spf - 60 deg - PJ2006 HMX. Top shot 10450' Bottom shot 10480'. Verified all shots fired. MU and RIH with CBF ;firing head, 2" x 10' gun loaded 6 spf, 60 deg with PJ2006 HMX charges. Perforated i interval 10426' to 10436' corr. ** *Job continued on 08 July 11*** 7/8/20111CTU #9 w/ 1.75" CT: Job Scope: PPROF w/ GHOST, MCNL w/ Borax, Set CIBP, Perforate: Job continued from 07 July 11. POOH from final pert run. No injectivity, MU and RIH with 2.5" JSN for freeze protect. Freeze protect well from 2500' with 38 Bbls of 50/50 McOH. ** *Job Complete * ** 1 i 3 FLUIDS PUMPED BBLS 55 50/50 METH 188 1% SL KCL 243 TOTAL TREE= 4- 1/16" CM/ • WELLH D FMC • S AFETY NOTES: ORIGINAL, "A" AND "B" ACTUATOR = BAKER C -32C WELLBORES NOT SHOWN BELOW MILLOUT @ ORIG KB. ELEV = 67.72' 9246' ORIG BF. ELEV = 39.93' ' - - - ORIG KOP 500' Max Angle = 94° @ 10599' 1 1 1 2272' 1- -14 -1/2" HES X NIP, ID = 3.813" I Datum MD = 10168' Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3261 3009 35 MMG DOME RK 16 07/16/11 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2903' 1 — A 4 4483 4007 35 MMG SO RK 20 07/16/11 3 6309 5517 34 MMG DMY RK 0 12/09/04 L 2 7494 6488 34 MMG DMY RK 0 02/08/03 1 _8675 27 MMG DMY RK _ 0 _02/08/03 Minimum ID = 2.37" @ 10694' 9085' 119 -5/8" X 7" BKR ZXP, ID = 6.27° 3- 3/16" x 2-7/8" STL XO w /7.6' TIEBACK & HMC LNR HGR 9 -5/8" MILLOUT WINDOW (C -32B): 9246' - 9264' 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 1-1 9246' ' 11 ---1 9438' 1 - 14 - 1/2" HES X NIP, ID = 3.813" 1 S Er — 1 9459' J - - 1/2" BKR S -3 PKR, ID = 3.875" 1 ' ' 1 9482' 1 - 14 - 1/2" HES X NIP, ID = 3.813" I 9503' 1 — 4 -1/2" HES XN NIP, ID = 3.80" MILLED (12/18/06) 1 4 -1/2" TBG, 12.6 #, L -80, IBT, .0152 bpf, ID = 3.958" 1 - 1 9516' ( 9505' (1 7" x 5" BKR ZXP LT PKR, ID = 5.01" w /XX' TIEBACK & HMC LNR HGR 17" LNR, 26 #, L -80, ID = 6.276" 1 - 1 9677' 1 A ■ • 1 9781' H MARKER JOINT 1 1 9911' H3 -1/2" DEPLOYMENT SLEEVE, ID = 3.00" 1 1 9930' 1 HOWCO X NIP, ID = 2.813" 1 13 -1/2" LNR, 9.3 #, L-80, STL, .0087bpf, ID = 2.992" H 9961' 9961' — 13 - 1/2" x 3- 3/16" XO, ID = 2.441" ( 1 4 -1/2" LNR, 12.6 #, L -80, BTC,.0152 bpf, ID = 3.958" 1 - 1 10109' 13- 3/16" LNR, 6.2 #, L -80, TCII, .0076bpf, ID = 2.80" 1-1 10696' 4 -1/2" MILLOUT WINDOW (C -32C): 10109' - 10115' PERFORATION SUMMARY REF LOG: MGR/CCL /CNL 02/18/07 ANGLE AT TOP PERF: 86° @ 10426' , 1 10650' 1 BKR CIBP (07/11/11) 1 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 110696' 1 3-3/16" x 2 -7/8" XO, ID = 2.37" 2" 6 10426 - 10436 0 07/07/11 ' 2" 6 10450 - 10480 0 07/07/11 2" 6 10680 - 11330 0 02/19/07 1 2" 6 11370 - 11400 0 02/19/07 2" 6 11440 - 11490 0 02/19/07 1 2" 6 11640 - 11700 0 02/19/07 ' 1v$ PBTD --1 11707' 1 2 -7/8" LNR, 6.4 #, L -80, STL,.0058bpf, ID = 2.441" 1-1 11742' � DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/21/98 CTD SIDETRACK (C -32A) 07/29/11 JKD/ PJC CIBP / ADPERFS (07/07- 11/11) WELL: C-32C 02/08/03 DAC/TLH RIG SIDETRACK (C -32B) 07/29/11 GJB/ PJC GLV C/O (07/16/11) PERMIT No: 2061390 02/20/07 NORDICI CTD SIDETRACK (C -32C) AR No: 50- 029 - 21559 -03 03/06/07 KSB /TLH GLV C/0 SEC 19, T11 N, R14E, 1700' FNL & 883' FEL 03/29/08 KDC/SV GLV C/O 03/19/10 AK/SV FINAL DRAFT CORRECTIONS BP Exploration (Alaska) ~ ~~ :~ ~~'~ ,,~. ~, :~,,. ~~ `~~ ~~~ ., .~ .: .~ s ,~. o ~ ~.. MICRQFILMED- 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc ~~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061390 Well Name/No. PRUDHOE BAY UNIT C-32C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21559-03-00 MD 11742 TVD 9032 Completion Date 2/20/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWDD DIR / GR / RES, MCNL / GR /CCL Well Log Information: Log/ Electr Data Digital Dataset Tyge~ Med/Frmt Number Name D Asc Directional Survey Rp~f ED C Lis ~ ~ ~I5610 Directional Survey Neutron Log Neutron ~~/t 15730~amr~a~2ay' ~~'~ ~ ` `~''~ c ~ f/ED C Lis 15730 Gamma Ray rig Gamma Ray ~g Gamma Ray 'Log Gamma Ray I~wL/og See Notes C Las 15766 eduction/Resistivity Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval Start Stop OH / CH Received Comments 34 11742 Open 3/6/2007 34 11742 Open 3/6/2007 9276 11625 Open 10/26/2007 LIS Veri, GR, CNT w/PDS graphics 2 Blu 1 9276 11618 Open 10/26!2007 Mem CNL, CCL, GR 18- Feb-2007 10110 11742 Open 12/8/2007 LIS, GR, ROP, RPS 10110 11742 Open 12/8/2007 LIS, GR, ROP, RPS w/TXT, Meta Data Blu 10110 11742 Open 12/8/2007 GR 16-Feb-2007 Blu 10110 11742 Open 12/8/2007 MD GR, MPR 16-Feb-2007 Blu 10110 11742 Open 12/8/2007 TVD GR, MPR 16-Feb- 2007 Blu 10100 11650 Open 12/8/2007 Depth Shift Monitor Plot 9714 11742 Open 12/3/2007 ATR, RPM, GR, ROP, RPD w/PDF graphics Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061390 Well Name/No. PRUDHOE BAY UNIT C-32C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21559-03-00 MD 11742 TVD 9032 ADDITIONAL INFORMATION Well Cored? Y Chips Received? Yom' ~- Analysis Y / N Received? __ - - __ Comments: Completion Date 2/20/2007 Completion Status 1-OIL r~C~,u~rrent Status 1-OIL Daily History Received? \/"" Formation Tops ~/ N UIC N Compliance Reviewed By: _.__ Date: C-32C (PTD #2061390) Reclassi as Operable Page 1.~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ ~ ~,j~IC~ Sent: Sunday, March 30, 2008 8:24 PM 1\ ` To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wetls Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; NSU, ADW Well Integrity Engineer Cc: Townsend, S. Eliot; Julian, Jennifer Y; Bommarito, Olivia O Subject: C-32C (PTD #2061390) Reclassified as Operable All. Well C-32C passed a TIFL on 03126/08 after DGLVs Were set. The well has been reclassified as Operable and can be put on line When convenient. Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Wednesday, March 19, 2008 8:25 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Julian, Jennifer Y; Bommarito, Olivia O Subject: UNDER EVALUATION - C-32C (PTD #2061390) Slow TxIA Comm Hi all, Well C-32C (PTD #2061390) is exhibiting slow IA repressurization from the tubing. The wellhead pressures were tubing/IA/OA equal to 2350/2300/0 psi on 03/14/08. A TIFL was conducted and passed on 03/15/08 however there has been continued slow IA repressurization since then. The well has been reclassified as Under Evaluation on a 28 day clock. The plan forward includes: 1. D: TIFL -PASSED but shows slow IA repressurization 2. S: DGLV 3. D: Re-TIFL A wellbore schematic has been included for reference. 4/24/2008 UNDER EVALUATION - C-32C~TD #2061390) Slow TxIA Comm ~ Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ Sent: Wednesday, March 19, 2008 8:25 PM ,~~~'(~ 3l ~~1 ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Julian, Jennifer Y; Bommarito, Olivia O Subject: UNDER EVALUATION - C-32C (PTD #2061390) Slow TxIA Comm Attachments: C-32C.pdf Hi all, Well C-32C (PTD #2061390) is exhibiting slow IA repressurization from the tubing. The wellhead pressures were tubing/IA/OA equal to 2350/2300/0 psi on 03/14/08. A TIFL was conducted and passed on 03/15/08 however there has been continued slow IA repressurization since then. The well has been reclassified as Under Evaluation on a 28 day clock. The plan forward includes: 1. D: TIFL -PASSED but shows slow IA repressurization 2. S: DGLV 3. D: Re-TIFL A wellbore schematic has been included for reference. «C-32C.pdf» S~~ ~-e1 f Z3~Q~+ ~3`7~~,~" ~`(p . ~ 3 s`~~ o ~- ~~, Ce) ~ z..- 3i2gi2oos ~ d Co --13`~ • • ~ C ~ ~ 1 ~.:~L' N i~ c l r ; ~ ~ - ":'~ A 1 _~ IC's' ~ S~J~ `'t _ __. .__ ~'~I u i}~- . ~,,,y~ ~.hY} i~,, a ~ ~°~ ifs i`.'rD ~~17 ~a ~~' ~ ~ in :L ;-i7' - i~im~~ % = 2.37'° ~` ~ 94~' 2~71~~ `. 29Q3' H yyF ~ '~ r ~ L SA i;I~YTEzi: :aa ~.~:: ____v_ ___ _ ~_. >~~~~' -~--~.~-'1 1 iii X :<. ~~ 813 1 r - '_ __ ~ 1 ~, ~ x~t ~,r~ <~.~ ~ ,~,~ ,~~~ .. t , ~ ;;vj ~ ~ r, , ; J 248' Tc~f' ~~ ~"` L~tR ~ g~~ f p'_ ,' ~ fJl? 1ii# t ~:,0, .(}=6.1£'34" iQ52f}' __ ~. ~_~.r_ ,__ T~ P t~F 3-1 (2" X 3-. - 16 ;; L i~ ~ 3 'S ° SST "~F' ~JF Llf*(EFi CE~~f~T 991 ~' - :>-1i2" X 3-311" X-C?VF...t~ 9959' - i Pt~~:~~r~~*dIC1A[_V'`JI-Ifl'STG~wC '~(l1{~9' --- ~ Yt'4'!~lC:iC?VV 1(}1 f39' - '~ El115" F2A P[P TI`4G ~ 3 f~11' f'E~ C~Fir~? 1`1`J ~ilf~lh;'st~~y "3E'f [ .. C3 ta: (`. .' C f~I LIr C .C I JC It _ {~,~.' 2 i 1 ' G'41 s' ~ x [ e N 3 Y y ~ + / ' ~ ~ + 3 ~ ^ j [ -. t V .i_EL.w iE `i 3...1fs1, i3~~11L43V } f"[J>.+L~~v t1"dGLE F,T:. TC3Fa PERT=: X2,3" ia; ' 0,6II~' ?~t~t8: I~f3~8Y :C ~"Ot~i.lC€iCSYt ~2~ 3~~1 ?':IS CL31'iG B~ 6.?t?'s rr.21r 2" ~ 10,68G`-11,3:>G' flpY} G211~~i 2" i3 11,s?C:' - 1't r00' {;f?t~ 02r1:i,'i?"7 2" 6 11,440`-11,49G' CPt1 G2%19~~'07 fi 11;h4{;`-11,'it3G` v~rt U1.'10'i.}p _ __~ L~tli' J~w.JV ~ ~_`-~~ „4 __.__ t. -___ !35f}i' ~ ~°' '~` , tiP! FEU' li i is E X5€1.5' ~. ( .-,, Hen i L~_ _ _ ..... } L ~~ L ~~~~~~ ~-~ --ti l ~ iT L !r~ i,Jr ' ~.~7 ~ ~ i i L _ - -_ _.. - =- _ __ _- -•--^m^`"- ~~~°..._.~~tU ..frt.' ~ ~ r __ ~1B 1173?` f~C3T[:3 3-1r'?_" k 3-3r16" A 2-718" C~17`E>) & 1?t=f=;~ 1174.2' 124fl5' I-E PBTC1 12491' ~-{4_t12" LNR, 92.6#, L-80, .~1:~2 bpf, ID = 3.958" '~r~°f~ R~'=f B'~' Gf.s:`/+~IT`s' C}'tx~ RE1f ~''! (7.~Me cff:~-- 49Yttt98 CTV :;I[lEr?~ CK ('G-3261) Ca~ ^"t~a'0'7 ,;1'~ Td~I~C ,. :::' t ~ ' 8?rbAf~~ [+AL;;~EI f hl ~SfC)Ei~RF,CKjC-3213} ~31I}6tQ7 K~B~LH ~C31~;.~;J ~ ~ _;C F. v . .~ ~: I.fi*~CTIi?~i ;t Ca tC~ ;;tY ~A~tT?' t t?1T .t. ;1 ~'; 'r, ~~ ~ .~ ~ 21;9-~3 ~xp4z~raEitan ~A.as~a3 • ~• Transmittal Form INTEQ saKE~ HUGHES - ,-_ Anchorage GEOScience Center W _ `- To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: C-32C Contains the following: • • 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Directional Measured Depth Log 1 blueline - MPR/Directional TVD Log 1 blueline - MPR/Directional Measured Depth Log 1 blueline -Monitor Plot LAC Job#: 1346420 Sent By: Deepa Joglekar Date.c.~ 2007 _~' Received By: C~, Date: , .~~ ;R~ -, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & R~`~RNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~p(~ ~~39 * G J~~c d 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~.. ~...~ ---; .; ~_ - ,L ~, f -- -- ~,:' ~- BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) Date 11-30-2007 Transmittal Number:92922 nave any questions, please contact llou Delivery Contents 05-28BPB1 moo(,-0~9 ~ rS~-!o~ 1-39A/N-16o~-t~~ ! ~ ~o~ 15-12B --~o /-~~= C-32C~oio-l3q -~is-~6~ E-11B-no ~P3 E-11 BLi ~o~--oC~t '~ rj y.`~~ E-11BL_1-01 aU'a--UG2~(5 ~~ E-11 BL1 P61 ~o'~_oc~ r ~ rs-}~7 E-11BLiPB2ac,~-otol ~r$~~=~ E-196 ao~-o'~~ # i S~~- ~ G-256 2v~-b ~~ *' r S3~-~ NK-14A ~ aot~-o3 ~ +~ t~-~-3 NK-14AP61 hoc.-p3i ~ r~~~Ll NK-61A 26~-o3s- ~ t5~'3 S llortch at the YllC: at 564-4y /.5 ~~ ~ D. Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2- l 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 10/19/07 Sehlumberger NO. 4449 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99505-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay MPL-09 11767141 MEM INJECTION PROFILE - 09/16/07 S-400A 40015442 OH MWD/LWD EDIT ~ 09/14/07 1 12-12A 40015307 OH MWD/LWD EDIT 06/18/07 3 1 G-17A 40013619 OH MWD/LWD EDIT - 'a 06/18/07 3 1 S-400A 11855508 CH EDIT PDC GR (USIT) ~ 09/18/07 1 G-268 10942213 MCNL "-- L -it 05/23/05 1 1 C-32C 11628756 MCNL ~ 02/18/07 1 1 E-04A 11801079 RST / 06/23/07 1 1 07-076 11216202 MCNL - ~ 06/28/06 1 1 L2-11 11209603 MCNL ~ p 04/30/06 1 1 E-32A 11767130 MCNL _ ~)S'(epa 06/19/07 1 1 L-04 11603118 MCNL - 12/30/06 1 1 I E-196 11767134 _ MCNL ~- - ~'~ '~ i57,pU( 07/21/07 1 1 2-16/M-16 11846803 RST L j - ~. ~~ 08/13/07 1 1 1-39A/N-16 11628769 MCNL a ~ 04/15/07 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ,o,,, . _ ? ,~, ... Anchorage, Alaska 99508 Date Delivered: L~~ --'~ n~_{ 'r Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503- 3 ATTN: Beth Received by: _,~~~ l~i~l\/EC~ STATE OF ALASKA ~ ~~~ j 4 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO~s~a Oit ~ Gas Cons. Commissiotr Anchorage 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 2/20/2007 ~ ' '~ '~ 12. Permit to Drill Number 206-139 r 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/13/2007 13. API Number 50-029-21559-03-00 , 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/16/2007 14. Well Name and Number: PBU C-32C / 1700 FNL, 883 FEL, SEC. 19, T11 N, R14E, UM r Top of Productive Horizon: 2573' FNL, 3693' FWL, SEC. 20, T11N, R14E, UM 8. KB Elevation (ft): 67.72 15. Field /Pool(s): ~ Prudhoe Bay Field / Prudhoe Bay Total Depth: 2993' FNL, 2483' FWL, SEC. 20, T11N, R14E, UM ~ 9. Plug Back Depth (MD+TVp) 11707 + 9031 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664506 y- 5959522 Zone- ASP4 10. Total Depth (MD+TVD) 11742 + 9032 Ft 16. Property Designation: ADL 028305 TPI: x- 669103 y- 5958751 Zone- ASP4 Total Depth: x- 667903 y- 5958304 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: ~Jj^/dpw JOl1.S'M 88-~3"7'Y MWD DIR / GR / RES, MCNL / GR / CCL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTHTVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM S¢E CEMENTING RECORD PULLED 20" Insulated Conductor Surface 110' Surfac 110' 26" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2904' Surface 2713' 17-1/2" 4074 cu ft COldset II - /8" 47# L-80 Surf 24 ' S rf 015' 12-1/4" 57 u Class'G' 7" 26# L-80 9085' 9678' 7870' 8421' 8-1/2" 210 cu ft Class'G' 4-1/2" 12.6# L-80 9505' 1 8255' 8818' 6-1/8" 421 cu ft Class'G' a-vz° x 3-3/16° x z-~ie° .3# ! 6.2# / 6.4# -8 9 11' 11742' 864T 9 3 ' 4-1 / " 13 c I ss 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9516' 9459' MD TVD MD TVD 10680' - 11330' 9024' - 9029' 11370' - 11400' 9029' - 9028' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11440' - 11490' 9025' - 9024' DEPTH INTERVAL MD AMOUNT Hr KIND OF MATERIAL USED 11640' - 11700' 9029' - 9030' 2500' Freeze Protect w/ McOH 26. PRODUCTION TEST Date First Production: March 7, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 3/8/2007 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 324 GAS-MCF 982 WATER-BBL 5 CHOKE SIZE 96 GAS-O!L RATIO 3,030 FIOW TUbing Press. 300 CaSing PreSSUre 1,460 CALCULATED 24-HOUR RATE• OIL-BBL 1,944 GAS-MCF 5,891 WATER-BBL 31 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". _ None ~?o?O.O~~ °: ~~ Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~'~ ~~TINUED ON REVERSE SIDE - - ~IaJ ~~ ~ ~ NiAR :~ 2D07 28 y ~ 29. ~ T GEOLOGIC (VIARKE ESTS ORMATION Include and briefly summarize test results. List intervals tested, NAME MD ND and attach detailed supporting data as necessary. If no tests were conducted, state "None". 22TS 10153' 8855' None 21TS /Zone 2A 10202' 8898' Zone 1 B 10312' 8986' TDF /Zone 1A 10540' 9031' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore99ing is true and correct to the best of my knowledge. ~ ~ Signed Terrie Hubble ~ Title Technical Assistant Date ~ Q PBU C-32C 206-139 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. oriaing Engineer: Robert Laughlin, 564-4080 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM ia: 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Legal Well Name: C-32 Common Well Name: C-32 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task ~ Code NPT 2/10/2007 09:30 - 11:15 1.75 MOB P 11:15 - 11:30 0.25 MOB P Start: 11 /15/2006 Rig Release: 2/20/2007 Rig Number: N1 Pagel of12~ Spud Date: 3/3/1986 End: Phase Description of Operations - _ _ _ PRE Prep rig for turnkey rig move PRE PJSM w/ all involved personnel reviewing individual 11:30 - 16:15 4.75 MOB P PRE 16:15 - 17:15 1.00 MOB P PRE 17:15 - 17:30 0.25 MOB P PRE 17:30 - 18:00 0.50 MOB P PRE 18:00 - 18:15 0.25 BOPSU P 18:15 - 20:30 2.25 BOPSU P 20:30 - 20:45 0.25 BOPSU P 20:45 - 00:00 3.25 BOPSU P 2/1 v2oo7 I oo:oo - 07:0o I 7.00 BOPSUp P 07:00 - 07:45 0.75 BOPSU~ P 07:45 - 08:30 0.75 BOPSU P 08:30 - 09:30 1.00 BOPSU P 09:30 - 12:30 3.00 BOPSU P 12:30 - 13:30 1.00 BOPSU P 13:30 - 14:00 0.50 STWHIP P 14:00 - 16:00 I 2.001 STWHIPI P 16:00 - 17:00 I 1.001 STWHIPI P 17:00 - 17:15 0.25 STWHIP P 17:15 - 19:30 2.25 STWHIP P PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE WEXIT WEXIT assignments, good communication and operational procedures Turnkey rig move from G-24 to C-32, Performed pre pad inspection, prep cellar for rig PJSM with crew on spotting rig over well. Back rig over well, position cellar drip pan, set rig in place, spot cutting tanks, lower stairs, ACCEPT RIG AT 18:00 HRS ON 02/10/2007. PJSM for N/U BOPE. N/D tree cap. N/U BOPE. Grease tree valves & R/U to PT ROPE. PJSM for P/T BOPE. Perform initial BOPE pressure /function test. AOGCC test witness waived by Bob Noble. Test witnessed by BP WSL, John Egbejimba. Meanwhile held PJSM with Veco crew on CT reel swap. Release reel drive bushings. P/U eline-free CT reel with bridgre crane & lower onto Veco trailer. P/U replacement eline CT reel into reel house with bridge crane & align drive pins & bushing. Install internal grapple in CT Spot outside trailers. Continue performing initial BOPE pressure /function test. Have to retest HCR valve & choke manifold valves # 12 & 15. Meanwhile R/U hardline to tiger tank & PT to 4000psi - OK. M/U hardline to reel. PU Lubricator and stem for pulling BPV to rig floor, MU stem to lubricator PJSM with DSM and crew on operational proceddures for retrieving BPV RU lubricator, pulled BPV, RD lubricator, offload from rig floor, load out on DSM trailer Change out Baker choke on std pipe manifold, rebuilt choke manifold valve #17 in which the seat was washed out, greased reel manifold valves Pressure test choke manifold valves # 17, 15, 12, 3 and HCR valve to 250 - 3500psi for 5 mins each test PJSM w/ rig and SLB personnel reviewing operational procedure on stabbing coil Pull test internal CTC, Pull coil thru inj, cut off CTC Offload 307 bbls of 2ppg Biozan 2%KCL double slick milling fluid in pits WEXIT Clamp off CT stub, with base plate, brk out stuffing box, clean off and c/o packoff WEXIT PJSM on filling CT, reviewed pumping procedures w/ crew WEXIT RU to pump down CT, line up choke to take returns to tiger tank, Flush coil with 15 bbls of McOH, 5 bbls of water, test surface lines to inner reel valve, followed with Biozan /KCL water at 1.13 bpm, 619 psi. Calculated a-coil Volume 58.9 Printed: 2/26/2007 7:52:17 PM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: C-32 Common Well Name: C-32 Spud Date: 3/3/1986 Event Name: REENTER+COMPLETE Start: 11/15/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2/20/2007 Rig Name: NORDIC 1 Rig Number: N1 i Date From - To Hours ~ Task ~ Code NPT Phase Description of Operations 2/11/2007 17:15 - 19:30 2.25 STWHIP P WEXIT bbls, Mud returns at surface after pumping 70 bbls thru a-coil. micro motion still need calibration In Rate and BBL count not working properly. 19:30 - 21:30 2.00 STWHIP N WAIT WEXIT Waiting on 2 20' high pressure hoses from DSM needed to reverse circ thru CT taking returns to pits 21:30 - 22:15 0.75 STWHIP P WEXIT Install 20' hi-pressure hose for reverse circ thru CT to pits. P/Test the 3 Baker SPD 3" (10k) gate valves C~ the pipeshed pump manifold to 3500psi. All 3 valves leaked slightly however will not effect slack managment pumping. Will repair valves while cutting CT during slack management. 22:15 - 22:30 0.25 STWHIP P WEXIT Held PJSM for pumping eline slack management. 22:30 - 23:05 0.58 STW HIP P WEXIT Reverse circ 80bbls of 2% KCL @ 4.1 bpm/3300psi. Audible sound of cable movement stopped after 10bbls pumped. Stopped pump, restart pumps & reverse circ an additional 10bbls of fluid @ 4.Obpm/3300psi. S/B injector. 23:05 - 00:00 0.92 STWHIP P WEXIT R/U hydraulic cutter to cut CT for slack management. Cut 90' of CT until a-line cable is exposed. Have 15525' of eline CT left on reel. Circ C~ min rate to warm up CT. Meanwhile dismantle gate valves & observe cuts in the valve seats -seems like that the gates were wrongly installed leading to a cut in the valve seats. Redress all 3 valves with new valve seats. 2/12/2007 00:00 - 02:15 2.25 STWHIP P WEXIT Behead & install SLB CTC. Pull test to 35k. Circ @ min rate to warm up CT. Allow for 2.5' of eline. M/U UOC & rehead eline. Conduct eline conductivity test - OK. Meg eline - OK >20megs. M!U cap &circ to warm up CT. P/Test CTC & UOC to 3500psi. 02:15 - 03:30 1.25 STWHIP P WEXIT Pump one CT vol back into the reel in normal circ mode to complete slack management. P/Test inner reel valve to 3500psi - OK. P/Test the 3 redressed Baker SPD 3" gate valves @ the pipeshed pump manifold to 3500psi - 2 valves leaked slightly & isolation valve passed. 03:30 - 03:45 0.25 STWHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan, potential hazards & milling BHA M/U procedures. 03:45 - 04:30 0.75 STWHIP P WEXIT M/U window milling BHA #1 with a 3.80" HC DSM, 3.79" diamond string reamer, Baker straight Xtreme motor, BHI DPS, EDC, P&C & LOC. M/U injector. 04:30 - 07:00 2.50 STWHIP P WEXIT RIH with milling BHA #, pumping at 2.65bpm, 2175 psi, circ pressure frozen at 667 psi, Tag top of whipstock at 10121' SLB 2x, corrected depth to 10115' setting depth of whipstock, synchronizing depths with BHI. Circ ~ min rate & take returns to the tiger tank. SLB and Baker depth counter not in sync. Up wt 40k, Dn wt 20k, FS at 2300 psi w/ 2.65psi 07:00 - 08:00 1.00 STWHIP N SFAL WEXIT Troubleshoot circ pressure gauge on SLB unit not responding, checked out surface equipment, found reel house manifold transducers above the micro motion, whitey valves and micro motion was froze u thawed out 08:00 - 18:15 10.25 STWHIP P WEXIT Mill 3.8" window thru 4-1/2" from 10115' - 10120.8', 2.6 bpm, 2589 -3014 psi, 1 fph, 2-4K WOB. Top of window at~Q,1~b'-' PVT 316bb1s, IA 680 psi, OA 500psi, note: bled OA down from 750 to 300psi 2 x this tower L-3~ C Printed: 2/26/2007 1:52:17 PM BP EXPLORATION Page 3 of 12 ~ Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: C-32 C-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Spud Date: 3/3/1986 Start: 11 /15/2006 End: Rig Release: 2/20/2007 Rig Number: N1 Date ;From - To i Hours I Task Code I NPT 2/12/2007 18:15 - 18:45 0.50 STWHIP P 18:45 - 21:20 2.58 STWHIP P 21:20 - 22:50 I 1.501 STWHIPI P 22:50 - 00:00 I 1.171 STWHIPI P 2/13/2007 100:00 - 01:30 I 1.501 STWHIPI P 01:30 - 01:45 0.25 STWHIP P 01:45 - 03:00 1.25 STWHIP P 03:00 - 03:30 I 0.501 DRILL I P 03:30 - 05:00 I 1.501 DRILL I P 05:00 - 07:00 I 2.001 DRILL I P 07:00 - 08:30 I 1.501 DRILL I P 08:30 - 09:30 1.00 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 12:00 2.00 DRILL P 12:00 - 14:15 2.251 DRILL P 14:15 - 15:15 I 1.001 DRILL I P 15:15 - 15:20 0.08 DRILL P 15:20 - 17:15 1.92 DRILL P 17:15 - 18:00 0.75 DRILL P Phase Description of Operations WEXIT Control mill & exit into formation ~ 10121' with 2.5/2.5bpm, 2300/2450psi & 0.6k DWOB. Up Wt = 38k, Down Wt = 21 k. WEXIT Mill 10' of formation io 10131' with 2.5/2.5bpm, 2300/2500psi, 5fph ave ROP & 3.5k DWOB. Meanwhile changeout BHI depth encoder. WEXIT Swap wellbore to new 8.6ppg flopro mud with 10ppb K-G & 3% L-T. Meanwhile backream/dress window/rat hole 3x & drift 2x. Window looks clean. Geo seeing formation in BUS. Tentative window depths are: TOWS/TOW = 10115', BOW = 10121', RA Pip tag = 10124'. WEXIT Paint EOP @ 9600' & POOH window milling BHA #1, while displacing well to mud. Observe O/pull & motorwork ~ 9501' (suspect XN nipple). RBIH to 9522'. PUH &backream thru tight spot clean. RBIH to 9510'. Continue POOH clean. WEXIT Continue POOH window milling BHA #1 synchronizing BHI & SLB depths. Recalibrated BHI depth encoder & reduced depth discrepancy with SLB CTDS to 0.2' for every 800'. WEXIT Held PJSM for VD milling BHA#1. WEXIT UD BHA #1 & inspect mills. Both window mill & string mill gauge 3.79" go / 3.78" no-go. Wear on window mill face indicate center crossed the liner wall. PROD1 Held pre-spud meeting. Review well sidetrack objectives, risks, potential hazards & drilling BHA M/U procedures. PROD1 M/U drilling BHA #2 with BHI UOC, LOC, P&C, EDC, DPS, DGS, HOT, 3.4deg X-treme motor & new Hughes 3-3/4" x 4-1/8" RWD2ST bicenter bit #2. Scribe tools & M/U injector. PROD1 RIH drilling BHA #2 to 8870', Baker and SLB depth is not in sync PROD1 Calibrate Baker depth counter to SLB depth. Physical strap on 2 3/8" CT was taking and marked of 61', Baker counter was 61.03', SLB depth was 61.09'. 10000' interval -SLB would be 14.7' long, Baker would be 4.9' long, Baker and SLB will need to correct their k factors once the diameter of the counter wheel is confirmed. PROD1 Tie-in log f/ 9760' - 9839', -10' correction PROD1 RIH w/ drilling BHA #2 to 9960', Dn wt 22k, FS 2950 psi at 2.44bpm, orient TF to 175L, RIH pass window without pumps at 10115' to 10122' PROD1 Drill with TF at 178R - 154R, 2.47/2.50bpm, 2900/3010psi, ROP 17 - 25'. Saw RA pip tag C~ 10118'. Adjusted window depths to: TOWS/TOW = 10109', BOW = 10115', RA Pip tag = 10118'. PROD1 Drill to 10213' with 85-105R TF, 2.55/2.55bpm, 2800/3000psi, 2k DWOB & 20fph ave ROP. Up wt = 39k. Run-in wt = 22k. PVT = 316bb1s. IAP = 650psi. OAP = 490psi. PROD1 Drill to 10252' with 105R TF, 2.55/2.55bpm, 2800/3050psi, 3.5k DWOB & 40fph ave ROP. PROD1 Short BHA wiper. RBIH to btm. PROD1 Drill to 10303' with 15R TF, 2.55/2.55bpm, 2800/2950psi, 3k DWOB & 35fph ave ROP. PROD1 Drill to 10350' with 35L TF, 2.55/2.55bpm, 2800/2950psi, 3k DWOB & 35fph ave ROP. Meanwhile bleed down the IAP from 770psi to 280psi & OAP from 750psi to 220psi. Printed: 2/26/2007 1:52:17 PM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ - -_ -- 1 Name: ell Name: e: Name: From - To ~ _ _ C-32 C-32 REENTE NORDIC NORDIC Hours __ - R+COM CALIST 1 ~ Task PLET A Code E NPT ~ ~ Start Rig Rig Phase Spud Date: 3/3/1986 : 11/15!2006 End: Release: 2/20/2007 Number: N1 Description of Operations 2/i3/2007 18:00 - 18:30 0.50 DRILL P - - PROD1 Wiper trip to window. RBIH to btm. 18:30 - 19:45 1.25 DRILL P PRODi Drill build /turn section, 2.5 bpm, 2700-3300 psi, 2K wob, 50R, 68 incl, 60 fph. Drilled to 10,410'. 19:45 - 21:40 1.92 DRILL P PROD1 Drill build /turn section, 2.6 bpm, 2800-3400 psi, 2K wob, 90R, 90 incl, 60 fph. Drilled to 10495'. 21:40 - 22:15 0.58 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 22:15 - 23:10 0.92 DRILL P PROD1 Drill build /turn section, 2.6 bpm, 2850-3400 psi, 4K wob, 60R, 85 incl, 20 fph. Geo did see HOT stains in samples. Come up with TF back to 90 deg incl. Drilled to 10,522'. 23:10 - 00:00 0.83 DRILL P PROD1 POH with build BHA. 36K up wt. Flag coil at 10000' EOP. Open circ sub, circ at 3 bpm while POH. 2/14/2007 00:00 - 01:30 1.50 DRILL P PROD1 POH with build BHA. Circ at 3.0 bpm thru open circ sub. 01:30 - 02:00 0.50 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA. 02:00 - 04:30 2.50 DRILL P PROD1 C/O BHA. M/U re-built HCC bicenter bit #3, adjust motor to 1.2 ', deg, M/U MWD with RES tool OAL = 78.88'. 04:30 - 06:00 1.50 DRILL P PROD1 RIH with lateral BHA #3 with 1.2 deg motor, HCC BC bit, RES Circ. at 0.4 bpm, 950 psi. 06:00 - 06:30 0.50 DRILL P PROD1 Correct CTD -8.93' &BHI depth by +9.56' @ the EOP flag. Orient TF to 145R & run clean thru window without pumps to 10125'. 06:30 - 06:45 0.25 DRILL P DFAL PROD1 Log down GR @ 200fph to tie-into the RA PIP tag. Observe electric short in the system -likely in the BHA. 06:45 - 09:15 2.50 DRILL N DFAL PROD1 POOH with drilling BHA to investigate short in BHA. ', 09:15 - 09:30 0.25 DRILL N DFAL PRODi OOH. Held PJSM & THA for L/D BHA. ', 09:30 - 10:00 0.50 DRILL N DFAL PROD1 S/B injector. B/O UQC & observe arcing & shot in connection carrier between the flow sub in the UQC & LOC. C/O the connection carrier in LOC. 10:00 - 10:30 0.50 DRILL N DFAL PROD1 Conduct full BHA function test - OK. 10:30 - 11:10 0.67 DRILL N DFAL PROD1 C/O flow sub in the UQC. M/U injector. 11:10 - 13:30 2.33 DRILL N DFAL PROD1 RBIH with lateral BHA #3. Correct CTD -10' &BHI depth by +25' @ the EOP flag. Orient TF to 170R & run clean thru window without pumps to 10125'. 13:30 - 14:00 0.50 DRILL P PROD1 Log down GR C~3 200fph & tie-into the RA PIP tag with +1' correction. 14:00 - 15:00 1.00 DRILL P PROD1 Log down & MAD pass for RES data ~ 500fph to TD tagged @ 10522'. 15:00 - 15:30 0.50 DRILL P PRODi Drill to 10550' with 80R TF, 2.55/2.55bpm, 2850/3150psi, 2k DWOB & 80fph ave ROP. Up wt = 38k. Run-in wt = 20k. PVT = 300bb1s. IAP = 5psi. OAP = Opsi. 15:30 - 15:45 0.25 DRILL P PROD1 Drill to 10576' with 20-45R TF, 2.55/2.55bpm, 2850/3450psi, 2k DWOB & 80fph ave ROP. 15:45 - 16:15 0.50 DRILL P SFAL PROD1 Observe electric short in the system. POOH above window to troubleshoot short. 16:15 - 16:45 0.50 DRILL N SFAL PROD1 Troubleshoot surface equipment -from BHI unit to connecting box in reelhouse is good. Short seems to be somewhere between the connection box & the collector or between the collector & the eline inlet into the CT. Printed: 2/26/2007 1:52:17 PM BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: C-32 Common Well Name: C-32 Spud Date: 3/3/1986 Event Name: REENTER+COMPLETE Start: 11/15/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2/20/2007 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours I Task Code NPT Phase Description of Operations 2/14/2007 16:45 - 17:45 1.00 DRILL N SFAL PROD1 W.O. SLB Electric Tech to arrive rig. 17:45 - 18:45 1.00 DRILL N SFAL PRODi Remove piece of eline from collector to inside junction box & 18:45 - 19:45 1.00 DRILL P 19:45 - 20:30 0.75 DRILL P 20:30 - 22:30 I 2.001 DRILL I P 22:30 - 23:20 0.83 DRILL P 23:20 - 00:00 0.67 DRILL P 2/15/2007 100:00 - 03:00 I 3.001 DRILL I P 03:00 - 05:45 05:45 - 06:45 06:45 - 07:15 2.751 DRILL I P 1.00 DRILL P 0.50 DRILL P 07:15 - 07:25 07:25 - 07:35 07:35 - 08:15 08:15 - 08:40 08:40 - 09:10 09:10 - 09:35 09:35 - 10:00 10:00 - 10:15 10:15 - 10:45 10:45 - 11:00 11:00 - 11:20 11:20 - 11:45 11:45 - 12:00 12:00 - 12:15 12:15 - 12:25 0.17 DRILL P 0.17 DRILL P 0.67 DRILL P 0.42 DRILL P 0.50 DRILL P 0.42 DRILL P 0.42 DRILL P 0.25 DRILL P 0.50 DRILL P 0.25 DRILL P 0.33 DRILL P 0.42 DRILL P 0.25 DRILL P 0.25 DRILL P 0.17 DRILL P observe an insulation cut that probably led to the short. Prep & C/O eline piece. Tested OK. Check BHI tools OK. PROD1 RIH clean to bottom. Check surveys while RIH. PROD1 Drill lateral, 2.6 bpm, 3050-3700 psi, 90R, 92 incl, 60 fph, 1-2K wob, 10.0 ECD Drilled to 10,628'. PROD1 Drill lateral, 2.6 bpm, 3050-3700 psi, 90R, 92 incl, 60 fph, 1-2K wob, 10.0 ECD, Several stalls starting at 10690'. Drilled to 10,700'. PROD1 Wiper trip to window. Clean hole, full returns. RIH clean to bottom. PROD1 Drill lateral, 2.6 bpm, 3000-3600 psi, 100L, 92 incl, 20 fph, 1-2K wob, 10.1 ECD, Drilled to 10,710'. PROD1 Drill lateral, 2.6 bpm, 3000-3400 psi, 105R, 91 incl, 1 K wob, 20 fph, 10.1 ecd. Drilled to 10,762'. PROD1 Drill lateral, 2.7 bpm, 3050-3400 psi, 100R, 89 incl, 1K wob, 30 fph, 10.2 ecd. Drilled to 10,850'. PROD1 Wiper trip to window. Clean hole. Full returns. Up wt = 37K. RBIH clean to btm. PROD1 Drill to 10870' with 100R TF, 2.55/2.55bpm, 2950/3100psi, 2k DWOB & 55fph ave ROP. Up wt = 38k. Run-in wt = 18k. PVT = 290bb1s. IAP = 685psi. OAP = 600psi. PROD1 Wt stacking. Conduct short BHA mini-wiper trip. Geo wants to aim for 8959'sstvd. PROD1 Drill to 10874' with 100R TF, 2.55/2.55bpm, 2950/3100psi, 1 k DWOB & 30fph ave ROP. PROD1 Drill to 10925' with 55-70R TF, 2.55/2.55bpm, 2950/3100psi, 2k DWOB & 75fph ave ROP. PROD1 Drill to 10950' with 90-95R TF, 2.55/2.55bpm, 3000/3200psi, 1.5k DWOB & 65fph ave ROP. PRODi Drill to 10985' with 40-60R TF, 2.55/2.55bpm, 3050/3150psi, 1 k DWOB & 75fph ave ROP. Stall 2x @ 10985'. PROD1 Drill to 11010' with 80-95R TF, 2.55/2.55bpm, 3050/3300psi, 2k DWOB & 60fph ave ROP. Stall 4x ~ 11010'. PROD1 Wiper trip clean to window. PROD1 Log down GR & tie-into the RA pip tag -add 4.4' to CTD. PROD1 RBIH clean to btm tagged ~ 11013'. PROD1 Drill to 11030' with 120E TF, 2.55/2.55bpm, 3050/3300psi, 2k DWOB & 70fph ave ROP. PROD1 Drill to 11043' with 110E TF, 2.55/2.55bpm, 2950/3350psi, 1.5k DWOB & 40fph ave ROP. PROD1 Drill to 11080' with 95L TF, 2.55/2.55bpm, 2950/3350psi, 1.5k DWOB & 95fph ave ROP. PROD1 Drill to 11105' with 85L TF, 2.55/2.55bpm, 2950/3350psi, 1.5k DWOB & 125fph ave ROP. PROD1 Drill to 11145' with 100-110L TF, 2.55/2.55bpm, 3000/3250psi, 1k DWOB & 135fph ave ROP. PROD1 Drill to 11160' with 120E TF, 2.55/2.55bpm, 3000/3250psi, 1-2k Printed: 2/26/2007 1:52:17 PM BP EXPLORATION Operations Summary Report Legal Well Name: C-32 Common Well Name: C-32 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task ~~I Code NPT I 2/15/2007 12:15 - 12:25 0.17 DRILL P 12:25 - 13:15 0.83 DRILL P 13:15 - 15:30 I 2.251 DRILL I P 15:30 - 15:55 I 0.421 DRILL I P 15:55 - 16:15 ~ 0.33 ~ DRILL ~ P 16:15 - 17:15 I 1.001 DRILL I P 18:40 - 20:30 1.83 DRILL I P Start: 11 /15/2006 Rig Release: 2/20/2007 Rig Number: N1 Phase PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PRODi 20:30 - 21:15 0.75 DRILL P PROD1 21:15 - 21:30 0.25 DRILL P PRODi 21:30 - 22:30 1.00 DRILL P PROD1 22:30 - 23:30 1.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 2/16/2007 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:30 1.00 DRILL P PROD1 01:30 - 02:15 0.75 DRILL P PROD1 02:15 - 03:15 1.00 DRILL P PROD1 03:15 - 04:20 1.08 DRILL P PROD1 04:20 - 06:00 I 1.671 DRILL I P I I PROD1 06:00 - 06:35 I 0.581 DRILL I P I I PRODi 06:35 - 08:10 1.58 DRILL P PROD1 08:10 - 08:25 0.25 DRILL P PROD1 08:25 - 11:10 2.75 DRILL P PROD1 11:10 - 13:40 2.50 DRILL P PROD1 13:40 - 14:00 0.33 DRILL P PROD1 14:00 - 15:15 1.25 DRILL P PROD1 15:15 - 15:45 0.50 DRILL P PROD1 Page 6 of 12 ~ Spud Date: 3/3/1986 End: Description of Operations DWOB, 10.2ppg ECD & 120fph ave ROP. Wiper trip clean to window. RBIH clean to btm. Up wt = 38.5k. Run-in wt = 17k. PVT = 290bb1s. IAP = 730psi. OAP = 680psi. Drill to 11222' with 100E TF, 2.55/2.55bpm, 3050/3350psi, 2.5k DWOB, 10.2ppg ECD & 30fph ave ROP. Drill to 11230' with 95L TF, 2.55/2.55bpm, 3000/3300psi, 1.5k DWOB, 10.2ppg ECD & 20fph ave ROP. Drill to 11238' with 95L TF, 2.55/2.55bpm, 3000/3300psi, 1,5k DWOB, 10.2ppg ECD & 25fph ave ROP. Start pumping down new 8.6ppg flopro mud with 3% L-T & 10ppb K-G. Drill to 11300' with 90-85L TF, 2.55/2.55bpm, 3100/3450psi, 1.5k DWOB, 9.88ppg ECD & 65fph ave ROP. Wiper trip clean to window. RBIH clean to btm. Drill Z1 B Lateral, 2.5 bpm, 3000-3400 psi, 80L, 90 deg incl, 100 fph, Drilled to 11450'. Wiper trip to window. Clean hole. Log GR tie-in at RA tag. Add 1' CTD. RIH clean to bottom. Dwn wt. = 16K. Drill Z1 B Lateral, 2.5 bpm, 3000-3400 psi, 90R, 90 deg incl, 3-4K wob, 80 fph, 10.1 ECD Drilled to 11,550'. Held spill drill in pipe shed with crew. Good response. Drill Z1 B Lateral, 2.5 bpm, 3000-3400 psi, 90R, 90 deg incl, 4K wob, 50 fph, 10.1 ECD Drilled to 11,600'. Drill Z16 Lateral, 2.5 bpm, 3000-3400 psi, 90R, 90 deg incl, 50 fph, 10.1 ECD Drilled to 11,600'. Wiper trip to window. Clean hole. Change out SWS level wind hydraulic valve. Test OK. RIH clean to bottom. Drill ZiB Lateral, 2.5 bpm, 2900-3500 psi, 90R, 88 deg incl, 60 fph, 10.1 ECD Drilled to 11,660'. Drill Z16 Lateral, 2.5 bpm, 2900-3500 psi, 90R, 88 deg incl, 2-4K wob, 30 fph, 10.1 ECD Drilled to 11,715'. Drill to TD @ 11740' (8964'tvdss -end of polygon) with 90R TF, 2.55/2.55bpm, 2900/3550psi, 2.5k DWOB, 10.2ppg ECD & 30fph ave ROP. Wiper trip clean to window. ', Log down GR & tie-into the RA pip tag -add 5' to CTD. Log down & MAD pass for RES data @ 1700fph from 10130' to 10500' & C~2 600fph from 10500' to TD tagged C 11742'. Meanwhile pump down 22bbls of fresh liner pill downhole. Got a lot of noise in realtime MAD pass RES data?? POOH drilling BHA#3 laying in liner pill in OH. OOH. Held PJSM & THA for UD drilling BHA. UD drilling BHA#3. Bit grade - 2/2/1. Conduct rig evacuation drill. Good response by the crew. Review procedure for rig evacuation & identify changes to be made to current procedure. Review roles and responsibilities Printed: 2/26/2007 1:52:17 PM BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: C-32 Common Well Name: C-32 Spud Date: 3/3/1986 Event Name: REENTER+COMPLETE Start: 11/15/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2/20/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To 2/16/2007 15:15 - 15:45 15:45 - 16:30 16:30 - 16:45 16:45 - 17:00 17:00 - 17:15 17:15 - 19:30 19:30 - 19:45 19:45 - 21:45 21:45 - 22:15 Hours Task 0.50 DRILL 0.75 CASE Code I NPT I Phase P P Description of Operations PRODi during rig evacuation. RUNPRD M/U side jet nozzle to CTC & stab injector on well. Shut in swab. Meanwhile R/U cementers. RUNPRD PJSM for B/D CT with N2. RUNPRD P/T N2 lines - OK. RUNPRD Pump 20bbls of water ahead followed by 10bbls of McOH spacer. RUNPRD Blow down CT with N2. Bleed down. Pick injecter and prep end of coil for internal grapple. M/U grapple. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pulling E-coil to reel and securing it. Reviewed written procedure and made 2 small changes to procedure. RUNPRD Pull test grapple and cable. Pull coil stub to reel. Secure coil on reel. Prep reel to pick. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for lowering reel onto trailer with bridge crane. Reviewed written procedure and made one change to procedure. RUNPRD Clean bombay doors, prep to operate bridge crane. RUNPRD Try to operate bridge crane. Driller side winch would not work. Reset hydraulic breakers and winch worked. Adjust hydraulic feed rate to even out both winches, so they operate at the same speed. RUNPRD Lower E-Coil reel to trailer. Swap trailers. RUNPRD Pick E-free coil reel off trailer. Raise into reel house. Close bombay door. Secure reel on support pins. R/U cable grapple to pull to reel. Pull test. Pull coil to injecter head. Cut off grapple. Stand back injecter head. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running 2-7/8" liner. Reviewed procedure, no changes. RUNPRD Run 2-7/8", 6.4#, L-80, STL Liner with BOT Indexing guide shoe, float cllr, jt, float cllr and Landing Cllr. RIH with 32 jts of 2-7/8" liner. Torque each connection to 1500 ft-Ibs. RUNPRD Swap to 3-3/16" elevators and fill liner. RUNPRD Crew change &PJSM for running liner. Review procedure for running liner & includ some additions hazards into the procedure. RUNPRD Continue M/U 2-7/8" STL x 3-3/16" TCII X/O sub. M/U 24jts of 3-3/16" 6.2# L-80 TCII, XO, 1 jt of 3-1/2" 9.3# L80 STL, X nipple, 3-1/2" pups. M/U Baker Deployment sleeve & CTLRT. OAL - 1840.8'. RUNPRD P/U injector. Cut CT. M/U Baker CTC. Pull test to 40k . RUNPRD Pump 5bbls of McOH ahead & 5bbls of water behind. P/test hardline to reel to 3500psi - OK. Pump & fill CT with mud. P/test inner reel valve to 3500psi - OK. Load/launch wiper dart. Chase dart with mud & pig CT. Dart bumped on catcher 57.8bbls. P/test CTC to 4000psi - OK. M/U injector. Nordic MM reading correct densities for mud, water & McOH. RUNPRD RIH with liner on coil circ ~ min rate thru the cementing 0.25 CASE P 0.25 CASE P 0.25 CASE P 2.25 CASE P 0.25 CASE P 2.00 CASE P 0.50 CASE P 22:15 - 23:00 0.75 CASE P 23:00 - 00:00 1.00 CASE P 2/17/2007 00:00 - 01:30 1.50 CASE P 01:30 - 03:30 2.00 CASE P 03:30 - 03:45 I 0.251 CASE I P 03:45 - 05:45 I 2.001 CASE I P 05:45 - 06:00 0.25 CASE P 06:00 - 06:30 0.50 CASE P 06:30 - 08:30 I 2.001 CASE I P 08:30 - 09:15 0.75 CASE P 09:15 - 10:45 1.50 CASE P 10:45 - 11:15 I 0.501 CASE I P Printed: 2/26/2007 1:52:17 PM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: C-32 C-32 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 11 /15/2006 Rig Release: 2/20/2007 Rig Number: N1 Date j From - To Hours ; Task Code NPT Phase 2/17/2007 10:45 - 11:15 0.50 CASE P RUNPRD 11:15 - 12:15 1.00 CASE N RREP RUNPRD 12:15 - 14:45 2.50 CASE P RUNPRD 14:45 - 15:30 I 0.751 CASE I P I I RUNPRD 15:30 - 17:30 ~ 2.00 ~ CASE ~ P ~ ~ RUNPRD 17:30 - 18:30 ~ 1.00 ~ CASE ~ P ~ ~ RUNPRD 18:30 - 19:00 I 0.501 CEMT I P I I RUNPRD 19:00 - 19:50 ~ 0.83 (CEMT ~ P ~ ~ RUNPRD 19:50 - 20:00 I 0.171 CEMT 1 P I !RUNPRD 20:00 - 21:00 I 1.001 CEMT I P I I RUNPRD Page 8 of 12 Spud Date: 3/3/1986 End: Description of Operations high-pressure filters. Changeout burnt 24volt fuse for reel & injector brake. Continue RIH with liner on coil circ @ min rate. Wt check: Up = 38k. Run-in wt = 20k. Continue RIH smoothly ~ 50fpm thru window into OH. Set down @ 11216'., 11561', 11601' & 11681'. P/U & run thru. Tag btm C~3 11752' (CTDS) & 11738' (BHI). P/U 2x @ 48k & retag TD @ same depth. Reset depth to 11742'. Establish circ. Load 5/8" steel ball &circ with mud C 1.94/1.90bpm & 2400psi. Set down 10k down on CTLRT. Continue circ ball to seat. Slow down to 0.47/0.42bpm ~ 40bbls away. Ball on seat @ 48.9bbls. Pressure up to 4600psi & release CTLRT. P/U @ 32k & confirm release. Circ well to 2% KCL C~? 3.04/2.81 bpm & 2400psi. Send used FloPro to MI for reconditioning. Meanwhile R/U SLB cementers: Load balance 2% KCL into pits & mix 2ppb bio displacement pill. Meanwhile continue circulating 2% KCL around @ 3.05/2.76bpm & 2500psi. Circ. at 2.1 bpm with 2.0 bpm returns at 900 psi. Stack wt on liner. SAFETY MEETING. Review procedure, hazards and mitigation for pumping liner cement job. Batch mix 15.8 PPG, G Cement. Pump 3 bbls fresh water. Press test cement line to 4000 psi. Bleed off pressure. Stage 25 bbls, 15.8 PPG, G Cement, 2.1 bpm at 1500 psi, Nordic Micromotion shows 15.8 PPG. 10 bbl cmt, 2.0 bpm, 1.9 bpm returns, 2000 psi, 15.8 PPG 20 bbl cmt, 1.9 bpm, 1.9 bpm returns, 2400 psi, 15.8 PPG. 24.0 bbl cmt, 2.0 bpm, 2.0 bpm, 1.9 bpm returns, 2400 psi, 15.8 PPPG Stop pump at 24.6 bbls. Close inner reel valve, clean cement line with Biozan water. Insert dart, Zero in and out Micoromotion volumes. Launch dart with 500 psi, Check dart, dart is gone. Displace with 30 bbl Biozan, 2.6 bpm, 2.5 returns, 3300 psi. 10 bbl displ, 2.7 bpm, 2.5 returns, 3160 psi 20 bbl displ, 2.6 bpm, 2.4 returns, 2420 psi 30 bbl displ, 2.5 bpm, 2.4 returns, 2370 psi 40 bbl displ, 2.5 bpm, 2.3 returns, 2320 psi, 40 displ / 34 returns. Cement at shoe at 45.0 bbl, calculated, Zero micro out volume. 50 bbl displ, 2.5 bpm, 2.2 returns, 3400 psi 55 bbl displ, 2.6 bpm, 2.6 returns, 3200 psi. Slow pump to 1 bpm. 57.8 bbl, dart on LW P, Sheared at 3600 psi, Inc. pump to 2.5 bpm. 60 bbl displ, 2.4 bpm, 1.9 returns, 3900 psi 64 bbl displ, 2.1 bpm, 2.0 returns, 3910 psi 67 bbl displ, 2.1 bpm, 2.1 returns, 3500 psi Slow pump to 1.0 bpm, 2000 psi Bump LWP at 69.6 bbls. Press up to 2000 psi. Held pressure. Bleed off pressure. Check floats, OK. 23.8 bbls of cement Printed: 2/26/2007 1:52:17 PM BP EXPLORATION Page 9 of 12' Operations Summary Report Legal Well Name: C-32 Common Well Name: C-32 Spud Date: 3/3/1986 Event Name: REENTER+COMPLETE Start: 11/15/2006 End: Contractor Name: NORDIC CALISTA Rig Release: 2/20/2007 Rig Name: NORDIC 1 Rig Number: N1 i Date From - To Hours Task Code NPT Phase _~___ 2/17/2007 20:00 - 21:00 ~ 1.00 CEMT P 21:00 - 22:45 1.75 CEMT P 22:45 - 23:15 0.50 CEMT P 23:15 - 23:45 0.50 BOPSU P 23:45 - 00:00 0.25 CEMT P 2/18/2007 00:00 - 00:45 0.75 CEMT N 00:45 - 01:00 0.25 CEMT P 01:00 - 04:00 I 3.001 CLEAN I P 04:00 - 06:00 I 2.001 CLEAN I P 06:00 - 07:00 I 1.001 CLEAN I P 07:00 - 08:30 I 1.501 CLEAN I P 08:30 - 09:35 1.08 CLEAN P 09:35 - 11:45 2.17 CLEAN P 11:45 - 11:50 0.08 CLEAN P 11:50 - 11:55 0.08 CLEAN P 11:55 - 12:15 0.33 CLEAN P 12:15 - 12:25 0.17 CLEAN P 12:25 - 13:50 1.42 EVAL P 13:50 - 14:30 0.67 EVAL P 14:30 - 16:15 1.75 EVAL P 16:15 - 16:45 0.50 EVAL P 16:45 - 17:30 0.75 EVAL P 17:30 - 19:00 1.50 EVAL P 19:00 - 19:30 0.50 EVAL P 19:30 - 19:45 0.25 EVAL P 19:45 - 20:45 1.00 EVAL P RUNPRD ~ returns Description of Operations Press up to 800 psi, pick up on coil and sting out of liner at 33.5K. Cement job went very well. Bumped LW P at correct volume. RUNPRD POH at 65 fpm, pump 0.5 bpm, 0.1 bpm returns. RUNPRD Lay out CTLRT. BHA had some cement on it, indicating cement over top of liner. RUNPRD Performed weekly BOPE function test. Good test. RUNPRD Prep to pick up milling /logging BHA. RUNPRD Work on rig boilers. LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U milling and MCNL logging BHA. LOWERI M/U 2.30" mill, BOT motor, 2 jts CSH, SWS MCNL in carrier, circ sub, hyd disc, XO, 60 jts CSH, hyd disc, checks and CTC. OAL = 1,964.75'. LOWERI RIH with mill and MCNL logging BHA. Calibrate MCNL depth encoder while RIH. Pump 0.2 bpm, 320 psi. SWS cement sample in UCA at 500 psi at 0200 hrs. LOW ER1 Sat down on cement stringer at 8795'. Pick up and ream down at 400 fph to 8820'. RIH at 20 fpm to cmt stringer at 8925', ream down. LOW ER1 Mill cement stringers to 8945' ~ 1.5/1.5bpm 2300/2500psi, 2-3k WOB & 15fph. Mill to 8952' ~ 150fph. Tag hard cement ~ 8952'. Mili thru hard spot & continue washing ~ 180-255fph to 9013'. Mill to 9020' ~ 15fph. LOWERI Run/Wash in hole @ 200-1070fph to 9261'. Sweep well wth biozan hi-vis pills. LOWERI Tag ~ 9261'. Mill thru & continue milling/washing to 9750' C~ 50-550fph. LOW ER1 Continue milling/washing to 9950' C~? 900fph to 9910' (TOL). LOWERI RIH ~ 30fpm to 10000'. LOWERI PUH ~ 70fpm clean back to 8700'. LOWERI RBIH @ 70fpm clean to 9350'. LOWERI Log down MCNUCCUGR @ 30fpm from 9350'. Start pumping down 150kcps Flo-Pro perf pill. Log down to PBTD tagged 11705'. With mill C PBTD, the wellbore has been drifted with the 3-3/8" OD CTC down to ~ 9743' i.e. +/- 167' above TOL. Agree with ODE not to make a 3.80" cleanout run unless we need to set a LTP. LOWERI Log up ~ 60fpm from PBTD to 9350' while laying-in 150kcps perf pill in liner. Paint CT EOP flag @ 7000'. LOW ER1 POOH logging/cleanout BHA#5. Circ out cement contaminated KCL fluid. LOW ER1 OOH. Held PJSM & THA for UD & R/B CSH. Make changes & additions to current procedure. LOWERI S/B injector. UD upper MHA. Drop 5/8" ball & open up circ sub. B/D CSH with air. R/U for R/B 1-1/4" CSH. LOWERI R/B 30 stands of 1-1/4" CSH. LOW ER1 Crew change. Night crew did rounds, check all equipment LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for laying out SWS MCNL tools. LOWERI Lay out SWS MCNL and carrier. Lay out motor and mill, Printed: 2/26/2007 1:52:17 PM BP EXPLORATION Page 10 of 12 Operations Summary Report ',Legal Well Name: C-32 Common W ell Name: C-32 Spud Date: 3/3/1986 Event Nam e: REENTE R+COM PLET E Start : 11/15/2006 End: Contractor Name: NORDIC CALIST A Rig Release: 2/20/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To ~ Hours ' Task Code ~ NPT Phase Description of Operations 2/18/2007 19:45 - 20:45 1.00 EVAL P LOW ER1 recover 100% of BHA. 20:45 - 22:00 1.25 CEMT P PROD1 Pressure test 3-3/16" x 4-1/2" liner lap with 2000 psi for 30 minutes. Start press was 2018 psi, End press was 1990 psi. Very good test. Thawed kill line in rig cellar. Faxed MCNUGR log to Anc. Geo. No gas in open hole indicated. Geo approved perforating procedure. ~~ From log data, PBTD = 11706.5' & TOL =9911'. 22:00 - 23:00 1.00 CEMT P PRODi Jet stack with swizle stick to clean any cement from BOPE. Went up and down twice at 3 bpm. 23:00 - 00:00 1.00 PERFO P LOWERI Continue to load SWS 2" PJ 2006 perforating guns in pip shed and organize guns. Double check gun layout. OK. Prep rig floor to run pert guns. 12/19/2007 00:00 - 00:30 0.50 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for running SWS 2" pert guns. Reviewed steps of procedure and made a few small changes. 00:30 - 03:00 2.50 PERFO P LOW ER1 M/U 49, 2", PowerJet 2006, 6 SPF, guns and blanks. M/U SWS firing head, XO, Hyd Disc, XO and 1 jt CSH. 03:00 - 03:15 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for running stands of CSH workstring out of derrick. 03:15 - 04:15 1.00 PERFO P LOWERI RIH with total of 15 stds of CSH workstring. M/U SWS XO, Hyd Disc, Checks, NRJ and CTC. OAL = 1,986.9'. ii P/U injecter head. 04:15 - 06:00 1.75 PERFO P LOWERI RIH with perforating BHA # 6. Circ. at 0.6 bpm, 200 psi. Correct to EOP flag at 7000'. (-3' CTD). Continue to RIH. Up wt at 11,700' = 44K. Tag PBTD, get pick up wt at 11,702' and correct to 11,706.5'. Pump 15 bbls FloPro pert pill. Position reel. Insert 1/2" AL ball. R/U sonogram detector to injector for shot detection. 06:00 - 07:00 1.00 PERFO P LOWERI Load & launch 1/2" AL ball. Pump 5bbls of pert pill behind & chase ball ~ 1.90bpm/2250psi. Slow pumps to 0.96bpm/770psi ~ 42bbls. Batl on seat after 52.6bbls away. Gradually position bottom shot @ 11700' & same time pressure up. Ramp up to 3250psi & observe guns fire with good pressure drop indication & sonogram shot detection. Perforated interval = 10680' - 11330', 11370' - 11400', I 11440' - 11490', 11640' - 11700'. I Sc7` X00` POOH & observe circ pressure of 650psi @ 0.96bpm (previously had 770psi) indicating guns have fired. Continue POOH with pert gun BHA. 07:00 - 07:45 0.75 PERFO P LOWERI POOH with pert gun BHA ~ 30fpm pumping fresh. KCL down the CT C«~ 0.89bpm & 480psi. Observe 3bbls losses while POOH to TOL. 07:45 - 08:00 0.25 PERFO P LOWERI Flowcheck well for 15 mins -well stable. 08:00 - 09:30 1.50 PERFO P LOWERI POOH with pert gun BHA ~ 60fpm pumping down the CT ~ 1.24bpm & 820psi. Observe additional 2bbls losses while Printed: 2/26/2007 1:52:17 PM • • BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: C-32 Common Well Name: C-32 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To i Hours Task Code NPT -_ _ _ - -- 2/19/2007 ~ 08:00 - 09:30 ~ 1.50 (PERFOB P 09:30 - 09:45 0.25 PERFOBI P 09:45 - 10:15 0.50 PERFO P 10:15 - 11:15 1.00 PERFO P 11:15 - 11:45 0.50 PERFO P 11:45 - 12:15 0.50 PERFO P 12:15 - 14:00 1.751 PERFOB~ P 14:00 - 14:45 1 0.751 PERFOBI P 14:45 - 17:15 2.50 PERFO~ P 17:15 -18:00 0.75 PERFO P 18:00 - 18:45 0.75 CEMT P 18:45 - 19:15 0.50 CEMT P 19:15 - 19:30 0.25 CEMT P 19:30 - 22:00 ~ 2.50 ~ CEMT ~ P 22:00 - 00:00 I 2.001 CEMT I P 2/20/2007 100:00 - 01:15 I 1.251 CEMT I P 01:15 - 01:30 0.25 CEMT P 01:30 - 01:45 0.25 WHSUR P 01:45 - 02:30 0.75 WHSUR P 02:30 - 06:30 I 4.00 I W HSUR I N I SFAL Spud Date: 3/3/1986 Start: 11/15/2006 End: Rig Release: 2/20/2007 Rig Number: N1 Phase , Description of Operations LOWERI POOH to surface. LOWERI OOH. S/D pump & flowcheck well for 15 mins -well stable. LOW ER1 Held PJSM for R/B CSH. Review job procedure & conduct THA. LOWERI S/B injector. UD MHAs & R/B 15 stds of 1-1/4" CSH tbg. LOWERI R/U to UD perf guns. LOWERI Held PJSM for UD perf guns. Review LRC's mail on requirements for written THA's & reviewing procedures during PJSMs. Review job procedure & conduct THA. Make changes & additions to the current procedure. LOW ERi UD 16 jts of perf guns & blanks. ASF! Conduct valve drill while UD perf guns -refresh well control roles & responsibilities with SLB TCP personnel. LOWERI Nordic crew change. Conduct walkarounds. Review LRC's mail on requirements for written THA's & reviewing procedures during PJSMs. Held PJSM for R/B CSH. Review job procedure & conduct THA. LOW ER1 Continue UD 33 jts of perf guns & blanks. ASF! LOWERI Load out spent perf guns & blanks. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for reheading coiled tubing connector. Went thru steps of procedure and made 2 small changes to procedure. RUNPRD Re-head to BOT CTC. Pull and press test CTC. RUNPRD M/U BOT 3.8" milling BHA #7 with 3.8" Parabolic diamond mill, straight motor, circ valve, hyd disc, checks and CTC. OAL = 18.49'. RUNPRD RIH with cement cleanout milling BHA. RIH at 90 FPH, 0.4 bpm. RIH past both cement stringer depths with no wt loss or motor work. RIH clean with 0.4 bpm to 9507' CTD. Set down at XN Nipple depth. Picked up and circ at 2.3 bpm. RIH and did not see anything at 9507'. RIH saw motor work at 9515' at top of 4-1/2" liner. RIH, 2.3 bpm in / 2.5 bpm out, 1440 psi, RIH at 30 FPM clean. Tag top of 3.5" deployment sleeve at 9918' CTD. RUNPRD Back ream up to 8400', while circ 30 bbl High Vis pill to mill. RIH reaming to top of deployment sleeve. POH at 60 fph, while chasing out high vis sweep at 2.6 bpm. No motor work. RUNPRD POH with 3.80" mill and motor cleanout BHA. Chase 30 bbl high vis sweep to surface. Very little cement seen at surface. Cleaned pits. RUNPRD Lay out BOT mill and motor. Recover 100%. POST Jet stack with swizle stick. POST RIH with swizle stick to 2500' and freeze protect tubing with 25 bbl MEOH. POST Lost all rig power at 0230 hrs. Generator is running but no electricity. 3 tioga heaters blowing hot air into rig. Rig electrician from Printed: 2/26/2007 1:52:17 PM • • BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: C-32 Common Well Name: C-32 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To ~ Hours ~ Task Code NPT ---- 2/20/2007 02:30 - 06:30 4.00 ~ WHSUR ~ N SFAL 06:30 - 09:30 3.00 WHSUR N SFAL 09:30 - 10:45 1.25 WHSUR P 10:45 - 11:00 0.25 WHSUR P 11:00 - 11:30 0.50 WHSUR P 11:30-12:00 0.50 WHSUR P 12:00 - 17:00 5.00 WHSUR P 17:00 - 18:00 I 1.00 I W HSU R I P Spud Date: 3/3/1986 Start: 11 /15/2006 End: Rig Release: 2/20/2007 Rig Number: N1 Phase Description of Operations POST Nordic 2 working on electrical. Coil is freeze protected. Used a vac truck to empty all lines we could. Drain heaters. Gen-1 shut down due to overheat & would not restart. Gen-2 came up & flashed out. Manage to put Gen-2 back online after changing out a burnt diode & rectifying wrong wiring. Gen-2 was wrongly wired & this is the probable cause of the several burnt diodes we've had in the past weeks. POST Thaw out frozen heater lines & prep to resume operations. Meanwhile bring Gen-1 back on line. POST POOH from 1000' freeze protecting wellbore with 60/40 McOH. FP from 500' with 100% McOH. UD swizzle stick & S/B injector. POST PJSM for installing BPV. POST R/U dry rod & install BPV in THS. R/D dry rod. SI master & swab valves (23-1/2 turns each). Install SSV (useable cap. POST PJSM for N/D BOPE. Review job procedure & conduct THA. POST N/D BOP. Meanwhile got call from Wells Group that our next well will most likely be G-08. Agree with Nordic that we will move to G-08 with McOH in the CT reel as the differential wt is only 17kips & we've been running light @ the rig front end during moves. Clean rig pits. Clean cuttings tank with vac truck and supersucker. Steam tank. POST N/U Tree cap and press test. RELEASED RIG AT 1800 hrs. 02/20/07. TOTAL TIME ON WELL FROM ACCEPT TO RELEASE WAS 10 DAYS. Printed: 2/26/2007 1:52:17 PM • • by BP Alaska r Baker Hughes INTEQ Survey Report iNTE Q Company: $P Amoco Dates 2/22/2007 Time: 11:03:17 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference; WeIL C~2, True North Site:.. PB C Pad Vertical ('f VD) Refer~ce: G326: 67.7 Well: - C-32 Section (VS) Refereed: Well (O.OON,O,OOE,110.99Azi) Wellpath:. C-32C Survey Calculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: PB C Pad TR-11-14 UNITED STATES :North Slope Site Positiou: Northing: 5957218.72 ft Latitude: 70 17 22.367 N From: Map Eastiog: 662550.03 ft Longitude: 148 41 2.797 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: C-32 Slot Name: C-32 Weil Position: +N/-S 2260.61 ft Northing: 5959522.00 ft Latitude: 70 17 44.598 N +E/-W 2005.45 ft Eastiog : 664506.00 ft Longitude: 148 40 4.345 W Position Uncertainty: 0.00 ft Wellpath: C-32C Drilled From: C-326 500292155903 Tie-on Depth: 10108.21 ft Current Datum: C-32B: Height 67.72 ft Above System Datum: Mean Sea Level Magnetic Data: 2/1/2007 Declination: 24.07 deg Field Strength: 57656 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.72 0.00 0.00 110.99 Survey Program for Definitive Wellpath Date: 9/7/2006 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 102.42 9202.42 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 9247.25 10108.21 C-32B IIFR (9247.25-12420.82) MWD+IFR+MS MWD +IFR + Multi Station 10108.21 11742.00 MWD (10109.00-11742.00) MWD MWD -Standard Annotation MD TVD ft ft 10108.21 8817.40 TIP 10109.00 8818.01 KOP 11742.00 9031.51 TD Survey: MWD Start Date: 2/14/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path • by BP Alaska $ Baker Hughes INTEQ Survey Report 1NTE Q Company: $P Amoco Date: 2/22/2007 Time: 11.;03:17 Page: 2 Field; Prudhoe Bay Co-ordinate(NE) Reference:- Weil:: C-32, True- North Site: PB C Pad Vertical (1'VD) Reference: C-32B: 67.7 Well: C-32 Section (VS) Reference: Weil (O.OON,O.OOE,110.99Az) WeOpatb: C-32C Survey Calculation Method:. Minimum Curvature Db: Orade Survey MD Ind Azim TVD Sys TVD N/S E/VV MapN MapE VS DIS Tool ft deg deg ft ft ft ft ft ft ft degl100ft 10108.21 39.13 103.18 8817.40 8749.68 -785.55 4548.93 5958836.25 669070.72 4528.44 0.00 MWD 10109.00 39.23 103.18 8818.01 8750.29 -785.66 4549.41 5958836.15 669071.20 4528.93 12.66 MWD 10142.69 30.29 114.25 8845.69 8777.97 -791.60 4567.59 5958830.61 669089.50 4548.03 32.39 MWD 10171.05 25.99 127.76 8870.71 8802.99 -798.35 4579.04 5958824.11 669101.10 4561.14 27.02 MWD 10201.78 29.18 153.95 8898.05 8830.33 -809.25 4587.69 5958813.41 669109.98 4573.12 40.49 MWD 10230.59 31.33 176.56 8923.01 8855.29 -823.08 4591.23 5958799.66 669113.83 4581.38 40.03 MWD 10265.98 35.67 197.75 8952.62 8884.90 -842.17 4588.63 5958780.52 669111.64 4585.79 35.07 MWD 10301.75 48.66 199.76 8979.08 8911.36 -864.84 4580.88 5958757.69 669104.39 4586.67 36.51 MWD 10333.74 58.94 182.23 8998.04 8930.32 -890.03 4576.25 5958732.41 669100.31 4591.37 54.49 MWD 10363.50 67.32 176.25 9011.49 8943.77 -916.53 4576.65 5958705.92 669101.30 4601.24 33.36 MWD 10411.39 83.34 187.64 9023.62 8955.90 -962.59 4574.92 5958659.84 669100.57 4616.12 40.55 MWD 10448.46 90.11 202.63 9025.74 8958.02 -998.19 4565.27 5958624.04 669091.71 4619.87 44.29 MWD 10477.61 83.83 214.98 9027.29 8959.57 -1023.64 4551.29 5958598.29 669078.28 4615.93 47.46 MWD 10508.30 86.82 226.84 9029.80 8962.08 -1046.70 4531.29 5958574.79 669058.80 4605.52 39.72 MWD 10538.36 88.18 236.26 9031.11 8963.39 -1065.36 4507.80 5958555.63 669035.72 4590.27 31.63 MWD 10569.04 92.44 239.62 9030.95 8963.23 -1081.63 4481.81 5958538.79 669010.09 4571.84 17.68 MWD 10599.25 94.41 244.01 9029.14 8961.42 -1095.87 4455.23 5958523.97 668983.84 4552.13 15.90 MWD 10634.87 93.95 249.49 9026.55 8958.83 -1109.89 4422.61 5958509.24 668951.53 4526.69 15.40 MWD 10666.96 93.12 247.42 9024.57 8956.85 -1121.65 4392.82 5958496.83 668922.01 4503.09 6.94 MWD 10698.22 91.12 245.34 9023.41 8955.69 -1134.17 4364.20 5958483.70 668893.67 4480.86 9.23 MWD 10728.26 89.68 248.00 9023.20 8955.48 -1146.06 4336.62 5958471.20 668866.36 4459.37 10.07 MWD 10760.83 88.81 253.39 9023.63 8955.91 -1156.83 4305.89 5958459.77 668835.88 4434.54 16.76 MWD 10793.03 88.11 257.30 9024.50 8956.78 -1164.97 4274.76 5958450.95 668804.94 4408.38 12.33 MWD 10823.55 88.60 262.75 9025.37 8957.65 -1170.25 4244.72 5958445.01 668775.03 4382.24 17.92 MWD 10866.25 87.34 268.90 9026.89 8959.17 -1173.36 4202.19 5958440.97 668732.57 4343.63 14.69 MWD 10897.46 89.31 273.09 9027.80 8960.08 -1172.82 4171.00 5958440.83 668701.38 4314.32 14.83 MVVD 10933.53 87.93 277.64 9028.67 8960.95 -1169.44 4135.11 5958443.42 668665.43 4279.61 13.18 MWD 10962.43 89.71 282.34 9029.26 8961.54 -1164.43 4106.66 5958447.80 668636.88 4251.25 17.39 MWD 10991.07 92.48 286.55 9028.72 8961.00 -1157.29 4078.94 5958454.34 668609.01 4222.82 17.59 MWD 11023.02 91.37 289.82 9027.64 8959.92 -1147.33 4048.61 5958463.63 668578.47 4190.93 10.80 MWD 11052.88 89.46 285.53 9027.43 8959.71 -1138.27 4020.17 5958472.07 668549.84 4161.13 15.73 MWD 11083.02 90.29 282.41 9027.49 8959.77 -1130.99 3990.92 5958478.70 668520.45 4131.22 10.71 MWD 11114.00 91.24 278.16 9027.08 8959.36 -1125.46 3960.45 5958483.57 668489.86 4100.79 14.06 MWD 11143.00 90.84 274.85 9026.55 8958.83 -1122.18 3931.65 5958486.22 668460.99 4072.72 11.49 MWD 11172.84 90.02 270.88 9026.33 8958.61 -1120.69 3901.85 5958487.06 668431.18 4044.36 13.58 MWD 11204.33 89.74 266.81 9026.39 8958.67 -1121.32 3870.38 5958485.73 668399.72 4015.20 12.96 MWD 11250.89 89.43 261.50 9026.73 8959.01 -1126.06 3824.08 5958479.98 668353.54 3973.67 11.42 MWD 11281.36 86.97 257.10 9027.69 8959.97 -1131.71 3794.16 5958473.68 668323.76 3947.77 16.54 MWD 11313.56 88.05 253.74 9029.09 8961.37 -1139.81 3763.03 5958464.90 668292.82 3921.61 10.95 MWD 11345.64 90.23 249.54 9029.57 8961.85 -1149.91 3732.60 5958454.14 668262.61 3896.81 14.75 MWD 11375.57 92.66 247.32 9028.81 8961.09 -1160.91 3704.77 5958442.53 668235.04 3874.77 11.00 MWD 11413.00 93.44 242.63 9026.82 8959.10 -1176.71 3670.92 5958425.99 668201.54 3848.82 12.68 MWD 11446.41 91.89 237.01 9025.27 8957.55 -1193.49 3642.08 5958408.59 668173.08 3827.91 17.43 MWD 11478.77 91.58 233.19 9024.29 8956.57 -1211.99 3615.56 5958389.52 668146.97 3809.77 11.84 MWD 11508.07 90.81 238.67 9023.68 8955.96 -1228.39 3591.30 5958372.59 668123.08 3793.00 18.88 MWD 11540.82 87.59 242.23 9024.13 8956.41 -1244.54 3562.82 5958355.82 668094.96 3772.20 14.66 MWD 11573.00 87.34 247.14 9025.56 8957.84 -1258.28 3533.77 5958341.45 668066.22 3750.00 15.26 MWD 11605.19 86.42 250.60 9027.31 8959.59 -1269.87 3503.79 5958329.21 668036.50 3726.16 11.11 MWD 11637.43 88.17 255.73 9028.83 8961.11 -1279.19 3472.98 5958319.22 668005.90 3700.73 16.79 MWD 11670.10 88.97 260.51 9029.65 8961.93 -1285.91 3441.03 5958311.80 667974.11 3673.31 14.83 MWD 11696.15 88.42 265.32 9030.24 8962.52 -1289.12 3415.19 5958308.02 667948.35 3650.34 18.58 MWD 11742.00 88.42 265.32 9031.51 8963.79 -1292.86 3369.51 5958303.28 667902.77 3609.03 0.00 MWD TREE = 41 /16" (',NV WELLHEAD= FMC ACTUATOR = AXELSON KB. FLEV = 67.77 BF. FLEV = 39.93' KOP = _ 500' Max Angle = 94.41° ~ 10599' ___ - -- - Datum MD = 10178' Datum ND = 8800' SS C -3 2 C sA~rY N°~: DRLG DRAFT CTD Sidetrack 2272' 41 /2" HES X Nom, ID = 3.813" GA S LIFT MANDRELS 13-318" CSG, 72#, L-80, ID = 12.347' ~ 290: Minimum ID = 2.37" @ 10694' 2-7/8" STL LNR TOP OF WHPSTOCK 9246' 9-5/8 X 41/2 TIW HBBP PKR, ID=4.75" 9317' TOP OF 7" LNR ~~ 9 9-5/8" CSG, 47# 9665' L-80, 10 - 8.681" `~}/ ~7" LNR, 29tF, L-80, ID = 6.184" ~• TOP OF 3-1 2" X ;-~ t o" ;< 2-718" LNR 9911' EST TOP OF LINER CEMENT 9911' 3-1/2" X 3-3/16" X-OVER 9959' MECHANICAL WHIPSTOCK 10109' WINDOW -~ 10109' - 10115' RA PIP TA G 101 1 ;' PERFORATION SUMMARY REF LOG: MGR/CCL/CNL OF 2/18/2007 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 92.3° @ 10,680' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10.680' - 11,330' Opn 02119x07 2" 6 11,370' - 11,400' Opn 02/19/07 2" 6 11,440' - 11,490' Opn 02/19/07 2" 6 11,640' - 11,700' Opn 02/19/07 ST MD ND DEV NPE VLV LATCH PORT DATE 5 3261 3009 35 MMG DOME RK 16 03/06/07 4 4483 4007 35 MMG SO RK 20 03/06/07 3 6309 5517 34 MMG DMY RK 0 12/09/04 2 7494 6488 34 MMG DMY RK 0 02/08/03 1 8675 7502 27 MMG DMY RK 0 02/08/03 9085' ~~ 9-5/8" X 7" BKR ZXP LNR TOP PKR &HGR, ID = 6.27" ~ MILLOUT WINDOW 9246' - 9264' 943$' 41 /2" HES X NIP, ID = 3.813" 9459' 7" X 41/7' BKR S-3 PKR, ~ = 3.875" 9482' 4112" HES X NIP, ID = 3.813° 9503' 4112" HES XN NIP, ID =MILLED TO 3.8" 9505' T' X 5" BKR ZXP LNR TOP PKR 8 HGR, 9516' 4112" WLEG, ID = 3.958" 9526' S" X 41 Y2" XO, ID = 3.94" 9677' 7" LNR, 26/1, L-80, .0383 bpf, ID = 6.27" 9781' MARKERJT 9911' iBOT DEPLOY SLEEVE, 6' LONG. 3" ID 9926' 3-1 /2" X NIP, ID = 2.813" 10694' 3-3/16" x 2-7/8" X-OVER SUB 11707' PBTD 3-1/2" X 3-3116" X 2-7/8" CMTED & PERFED 11742' 12405' P-1 BTU 12491' 4-/12" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 09/21198 CTD SIDETRACK (C-32A) 02!19/07 JUE NORDIGI CTD SIDETRACK 02/08/03 DACffL RIG SIDETRACK (C-32B) 03!06/07 KSBlRH GLV GO 07!03103 CMO/TLP MAX A NGLE CORRECTION 09l15I03 CMO/TLP DATUM MD 8 REF LOG 10/16/03 JGMrTLP ADD PERFS 12/09/04 RWLRLP GLV GO PRLIDHOE BAY UNfT WELL: G32C PERMff No: 206-139 API No: 50-029-21559-03 SEC 19, T11 N, R14E, 1700' FNL 8 883' FEL BP Exploration (Alaska) L J d q ~ nn ~3$ _ ~ ~ ; ~, C~1~~~~'R~7CI~IfT C~ S~I~IiT Robert Caughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ,~ ~'~ FRANK H. MURKOWSKI, GOVERNOR if 333 W. 7r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-32C BP Exploration (Alaska) Inc. Permit No: 206-139 Surface Location: 1700' FNL, 883' FEL, SEC. 19, T11N, R14E, UM Bottomhole Location: 2904' FNL, 2553' FWL, SEC. 20, Tl 1N, R14E, UM Dear Mr. Caughlin: 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 (907) 6y~9-3607 (pager). DATED this day of October, 2006 cc: Department of Fish ~ Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ' ~ ALAS~L AND GAS CONSERVATION COMMI~N 1~ PERMIT TO DRILL 20 AAC 25.005 Cam- lof3~2:o'a~ ~~P ~ ~ 2006 Alaska Oi! ~ Gas Cons. Commiss+on Anchorage 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: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU C-32C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11667 TVD 8960ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section):. Surface: 883' FEL 711 N R14E 1700' FNL SEC 19 UM 7. Property Designation: ADL 028305 Pool , , . , , , Top of Productive Horizon: 2560' FNL, 3888' FWL, SEC. 20, 711 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 10, 2006 Total Depth: 2904' FNL, 2553' FWL, SEC. 20, 711 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 23,000 4b. Location of Well (State Base Plane Coordinates): Surface: x-664506 y-5959522 Zone-ASP4 10. KB Elevation (Height above GL): 67.72 feet 15. Distance to Nearest Well Within Pool: 700' 16. Deviated Wells: Kickoff Depth: 10115 feet Maximum Hole An le: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.00 Downhole: 3250 Surface: 2370 18. Casin P ram: S ec~catio ns To = Settin De th - Bo ttom uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4_1 /g^ 3-3/16" X zaia° 6.2# / 6.16# L-80 TCII / STL 1752' 9915' 8583' 11667 8960' 118 cu ft Class 'G' 1 g. PRESE NT: WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12491 Total Depth TVD (ft): ggsg Plugs (measured): None Effective Depth MD (ft): 12406 Effective Depth TVD (ft): 8970 Junk (measured): None Casing- Length Size Cement Volume MD ' TVD Conductor /Structural 110' 20" 8 cu ds Concrete 110' 110' Surface 2904' 13-3l8" 4074 cu ft Cold Set II 2904' 2713' Intermediate 9246' 9-518" 570 cu ft Class'G' 9246' 8015' Production Liner 593' 7" 210 cu ft Class'G' 9085' - 9678' 7870' - 8421' Liner 2986' 4-1/2" 421 cu ft Class'G' 9505' - 12491' 8255' - 8969' Perforation Depth MD (ft): 10461'. - 12370' Perforation Depth TVD (ft): 8999' - 8970' 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 certify that the foregoing is true and correct. Contact Robert Laughlin, 564-4080 Printed Name Robert Laughlin Title CT Drilling Engineer Prepared By Name/Number: Si natur Phone 564-4080 Date L~1-S, f-nb Terrie Hubble, 564-4628 .Commission Use Onl Permit To Drill Number: .. API Number: 50-029-21559-03-00 Permit ppro I See cover letter for Date: ~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: T'e s ~- ~ o f ~ C {-0 3 5'c~ 0 ~ ~tv • Samples Req'd: ^ Yes ~No Mud Log Req'd:_ ^ Yes ~No H2S Measures: ,Yes ^ No Dir nal Survey Req'd: Yes No Other: ^D~ APPROVED BY THE COMMISSION Date ~ ,COMMISSIONER Form 10-401 Revised 12/2005 `~ ~ ~ Submit In Duplicate ~~.~~~~~~~~r~ I BP • Prudhoe Bay C-32C CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: 1. O Passed tubing caliper inspection 5-Jul-06 2. O Passed MIT IA & MIT OA 17-Jul-06 3. O Passed PPPOT-IC, -T. Torqued LDS. 19-Jul-06 4. E Set Baker 4.5" monobore KB WS packer w LS(+/-30 degs) orientation @ 10,115' 5. O PT MV, SV, WV 6. O Blind and bleed lines, remove well house, level pad Rig Work: (scheduled to begin on December 10, 2006) ~. 1. MIRU and test BOPE to 250 psi low and 3500 psi high. ~ ', ~ 2. Mill XN nipple to 3.8" and 3.80" window at 10115' and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Build: 4.125" OH, 420' (40 deg/100 planned) with resistivity to a depth of 10535' MD ', ~ 4. Drill Lateral: 4.125" OH, 1132' (12 deg/100 planned) with resistivity to a depth of 11667' MD 'i C~ 5. MAD pass OH with resistivity tools in memory mode j ~ 6. Run 3-3/16" x 2-7/8" solid liner leaving TOL at~5' 7. Pump primary cement leaving TOC at 9915', /L l~bls of 15.8 ppg liner cmt planned 'i L 8. Cleanout liner and MCNL/GR/CCL log ~ 'I ~ 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions 0800') 11. Freeze protect well, RDMO '+~ Post-Rig Work: `~ 1. Re-install wellhouse and FL's. ~ 2. Test separator 0800' of prefs) `-~ Mud Program: • Well kill: 8.6 pp~ne • Milling/drilling 8. pg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/8" Casing Program: fully cemented liner • 3-3/16", L-80 6.2# TCII 9915' and - 10700' and • 2-7/8", L-80 6.16# STL 10700'md - 11667'md j • A minimum of 21 bbls 15.8 ppg cement will be used for liner cementing. TOC planned at 9915' Existing casing/tubing Information 13-3/8", L-80 72#, Burst 5380, collapse 2670 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 psi 7", L-80 26#, Burst 7240, collapse 5410 psi 4-1/2", L-80, 12.6#, Burst 8430, collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 92 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will~'e run. • Distance to nearest property - 23,000 ft. (North) • Distance to nearest well within pool - 700 ft. (C-02) Logging • MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run. Hazards The maximum recorded H2S level on C Pad is 20 ppm. Lost circulation risk is low. Reservoir Pressure • The max res. press. is estimated to be 3250 psi at 8800'ss 7 g EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface i 370 i. = 4-1/16" LHE4D= FMC CTUATOR= AXELSON B. l1EV = 67.72' F. ELEV = 39.93' OP = 500' Angle = ~5 @ 11489' tum MD = 10178' tum TVD = 8800' SS ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ Minimum ID = 3.725" @ 9503' 4-1 /2" XN NIPPLE 2272' f - j 4-1 /2" HES X N~, O = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3261 3009 35 MMG DMY RK - 02/17/03 4 4483 4007 35 MMG DMY RK - 12/09/04 6309 5517 34 MMG DMY RK - 12/09/04 2 7494 6488 34 MMG DMY RK ~ 02/08/03 1 8675 7502 27 MMG DMY RK _ 02/08/03 C-32B 9085' ~9-5/8" X 7" BKRZXP LNR TOP PKR & HGR, ID = 6.27" TOP OF WHIPSTOCK 9246' TOP OF 7" LNR H 9410' I 9-5/8" CSG, 47#, L-80, ID = 8.681" I ~ 7" LNR, 29#, L-80, ID = 6.184" I PERFORATION SUMMARY REF LOG: MWD GR ON 01/27/03 ANGLE AT TOP PERF: 87 (a3 10660' Note: Refer to Production DB for historical perf data SQE SPF BVTEI21/AL OprUSgz DATE 2-7/8" 6 10461 - 10486 O 10/16/03 2-7/8" 6 10496 - 10516 O 10/16/03 4 10660 - 10910 O 02/05/03 4 11570 - 11715 O 02/05/03 4 11820 - 11965 O 02/05/03 4 11985 - 12090 O 02/05!03 4 12135 - 12370 O 02/05/03 PBTD 12405' 4-/12" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 12491' 9482' 9503' 9526' 9677' 9781' DATE REV BY CONMAB~ITS DATE REV BY COMMENTS 09/21/98 CTD SIDETRACK (C-32A) 02/08/03 DACITLH RIG SIDETRACK (C-32B) 07/03!03 CMO/TLP MAX ANGLE CORRECTION 09/15!03 CMO/TLP DATUM MD & REF LOG 10/16/03 JGMITLP ADD PERFS 12/09/04 RWL/TLP GLV GO -14-1/2" HES X NIP, ID= 3.813" 4-1/2" HF~ XN NIP, ID = 3.725" 7" X 5" BKR ZXP LNR TOP PKR & HGR, ID=5.25" 4-1/2" WLEG, ID= 3.958" 5" X 4-1/2" XO,ID = 3.94" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.27" MARKER PRUDHOE BAY UNIT VNELL: G32B PERMff No: 2022460 API No: 50-029-21559-OS StB;19, T11 N, R14E, 1700' FNL &883' FEL BP Exploration (Alaska) MILLOUT WINDOW 9246' - 9264' 9438' H 4-1/2" HES X NIP, ID = 3.813" 9459' I-17" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 4-1/16" LHEAD= FMC CTUATOR = AXELSON B. ELEV = 67.72' F. REV = 39.93' OP = 500' x Angle = 35 @ 11489' tum MD = 10178' tum TV D = 8800' SS ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ Minimum ID = 3.725" @ 9503' 4-1 /2" XN NIPPLE mulled to 38 1 TOP OF WHIPSTOCK 9246' LNR TOP PKR 8 HGR, ID = 6.27" 9-5/8 X 4-1/2 TM/ HBBP PKR, ID=4.75" 9317' MILLOUT WINDOW 9246' - 9264' " " ' TOP OF 7" LNR 9410' HES X NIP, ID = 3.813 4-1/2 9438 9459' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" s-s/a° csG, 47# 9665' ~ L-80, ID = 8.681" 9482' 4-1/2" HES X NIP, ID= 3.813" ID = 3 8" 1/2" HES XN NIP 9503' 4 . - , (milled to 3-8'~) 9505' 7" X 5" BKR ZXP LNR TOP PKR 8 HGR, ID=5.25" 9516' 4-1/2" WLEG, ID= 3.958" 9526' S" X 4-1 /2" XO, ID = 3.94" 9677' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.27" 9781' MARKER JT 7" LNR, 29#, L-80, ID = 6.184" -i 10520' TOP of cEnnFJVT 9915' PB~FORATION SUMMARY REF LOG: MWD GR ON 01 /27/03 ANGLE AT TOP PERF: 87 ~ 10660' Note: Refer to Production DB for historical pert data SIZE SPF WT~2VAL OpNSgz DATE 2-7/8" 6 10461 - 10486 isolated proposed 2-7/8" 6 10496 - 10516 isolated proposed 4 10660 - 10910 isolated proposed 4 11570- 11715 isolated proposed 4 11820- 11965 isolated proposed 4 11985 - 12090 isolated proposed 4 12135 - 12370 isolated proposed PBTD 12405' 4-/12" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 12491' DATE REV BY COMMBVTS DATE REV BY COMMENTS 09/21198 CTD SIDETRACK (C-32A) 02/08103 DAC/TLH PoG SIDETRACK (C-32B) 07/03/03 CMOffLP MAX ANGLE CORRECTION 09/15/03 CMO/TLP DATUM MD 8 R~ LOG 10/16/03 JGMITLP ADD PERFS 12/09/04 RWL/TLP GLV GO 9915' ~~Top of 3-1/2" Liner, TOC 9925' 3-112" XN NIP, ID = 2.75' 3-3/16 x 2-7IS X-over 2-7/8" anted & perfed ~~ 11667' PRUDHOE BAY UNrr WELL: G32B PERMfT No: 2022460 AR No: 50-029-21559-OS SC-C 19, T11 N, R14E, 1700' FNL 8 883' FEL BP 6cploration (Alaska) C-32C [ Proposed CTD Sidetrack 4-1/2" HES X NIP, ~ = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3261 3009 35 MMG DMY RK - 02/17/03 4 4483 4007 35 MMG DMY RK - 12/09/04 6309 5517 34 MMG DMY RK - 12/09/04 2 7494 6488 34 MMG DMY RK - 02/08/03 1 8675 7502 27 MMG DMY RK - 02/08/03 • • Q F~ T ~~~~ F - ~f. -_ ~~~ i rrr ?'F ~l r to k, ~~ti IJ ;~~ i ~~ a-~ ~ ~'~ ~ ~ i iii 4 ~, /r. ~. '/ ~. / ~.. ~~ I~i~._. ~. I ~ j ~ i _~ , 1 i' `' r ~ i iil,~ ~ ~~ li ~4: ~Y ~~~~ I.~ii~~l~~ ~~:T1 iJi4 .t,' i ~~ i~" '+i ~I~ ~=~ ~" / r a .~ t (/ CI ~. {y ~ ~ ~ N C ~ gg ~ ~? a z ~ ~n~ fl$ ~~~~~ 1 s Q ~ ~~ ~ d `~ ~~~:~--~ ~ ~ F = ~ M W ~ F ~~ ~~ ~ ¢°e8¢i ~ 3>h8a + C (u~/ypp LI (~14HON/1•IV3no4 m ~3f.:Y ~~d r xe_~sssas '' i~~"sa~~zx -ca~ae.R 0 3 9x~^8A~R88 ~ __ ___ a Z 888888889 ~~~ s555iiY: g u~u~uxwxu~~~ t ~~~~~ g 9 i s a o % z 2a3.~a~.3_c^:.o ~ F8886RRRg 8888888 SSS'~"4R"85~~99 ltAY~~OA'+!A 4~2.. ,.5-...g (uyypp)4ad~0 ~~ ~b 0 •i °n w m .> a by ~ BP Alaska Baker Hu hes INTE Planntn Re ort g Q g P ~rrr sNAU~s INTEQ Company; BP Amoco Date:. 9/26/2006 Time: 09:25:36 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeII: C-32, True North Site: PB C Pad Vertical (T'VD} Reference: C-328: 67.7 Well:. C-32 Section (VS}Reference: Well (t}.OON,I).OOE,265 OOAzi) Wellpath: Ptan 4, C-32G SurvegCalculatioo Method< Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: PB C Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5957218. 72 ft Latitude: 70 17 22.367 N From: Map Easting: 662550. 03 ft Longitude: 148 41 2.797 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: C-32 Slot Name: C-32 Well Position: +N/-S 2260.61 ft Northing: 5959522. 00 ft Latitude: 70 17 44.598 N +E/-W 2005.45 ft Easting : 664506. 00 ft Longitude: 148 40 4.345 W Position Uncertainty: 0.00 ft Wellpath: Plan 4, C-32C Drilled From: C-326 500292155903 Tie-on Depth: 10 108.21 ft Current Datum: C-328: Height 67. 72 ft Above System Datum: Mean Sea Level Magnetic Data: 7/25/2006 Declination: 24.46 deg Field Strength: 57606 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.72 0.00 0.00 265.00 Plan: Plan #4 Date Composed: 9/26/2006 Reduce number of stations from plan 3 Version: 15 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-- Latitude -> <- Longitude =--> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Dcg Min Sec Dip. Dir. ft ft ft ft ft C-32C Polygon 67.72 -1189.31 4429.34 5958430.00 668960.00 70 17 32.888 N 148 37 55.264 W -Polygon 1 67.72 -1189.31 4429.34 5958430.00 668960.00 70 17 32.888 N 148 37 55.264 W -Polygon 2 67.72 -1326.37 3836.16 5958280.00 668370.00 70 17 31.543 N 148 38 12.552 W -Polygon 3 67.72 -1289.04 3501.87 5958310.00 668035.00 70 17 31.912 N 148 38 22.293 W -Polygon 4 67.72 -1300.87 3356.57 5958295.00 667890.00 70 17 31.796 N 148 38 26.528 W -Polygon 5 67.72 -1165.34 3334.53 5958430.00 667865.00 70 17 33.129 N 148 38 27.169 W -Polygon 6 67.72 -958.47 4394.38 5958660.00 668920.00 70 17 35.158 N 148 37 56.278 W C-32C Fault 1 67.72 -1154.75 4450.10 5958465.00 668980.00 70 17 33.228 N 148 37 54.658 W -Polygon 1 67.72 -1154.75 4450.10 5958465.00 668980.00 70 17 33.228 N 148 37 54.658 W -Polygon 2 67.72 -1194.78 4679.30 5958430.00 669210.00 70 17 32.833 N 148 37 47.979 W C-32C Fault 3 67.72 -840.54 3576.71 5958760.00 668100.00 70 17 36.323 N 148 38 20.106 W -Polygon 1 67.72 -840.54 3576.71 5958760.00 668100.00 70 17 36.323 N 148 38 20.106 W -Polygon 2 67.72 -883.12 4150.96 5958730.00 668675.00 70 17 35.901 N 148 38 3.371 W C-32C Fault 2 67.72 -1585.27 4010.55 5958025.00 668550.00 70 17 28.996 N 148 38 7.474 W -Polygon 1 67.72 -1585.27 4010.55 5958025.00 668550.00 70 17 28.996 N 148 38 7.474 W -Polygon 2 67.72 -1330.57 4256.20 5958285.00 668790.00 70 17 31.500 N 148 38 0.312 W C-32C Fault4 67.72 -1032.77 3447.46 5958565.00 667975.00 70 17 34.433 N 148 38 23.876 W -Polygon 1 67.72 -1032.77 3447.46 5958565.00 667975.00 70 17 34.433 N 148 38 23.876 W -Polygon 2 67.72 -991.21 3833.49 5958615.00 668360.00 70 17 34.840 N 148 38 12.625 W C-32C Faults 67.72 -1399.54 3294.39 5958195.00 667830.00 70 17 30.826 N 148 38 28.341 W -Polygon 1 67.72 -1399.54 3294.39 5958195.00 667830.00 70 17 30.826 N 148 38 28.341 W -Polygon 2 67.72 -1393.81 3489.57 5958205.00 668025.00 70 17 30.882 N 148 38 22.653 W ' ap ~ BP Alaska Baker Hu hes INTE Plann><n Re ort g Q g P s~ ~~ Nuc~s INTEQ Company; BP Amoco Date: 9/26/2006 Tiroe: 09:25:36 Page: 2 Field: Prudhoe. Bay Co-ordinate(NE) Reference: Well: G-32, True North , Site: PB C Pad Verdeal (T~'D) Reference: C-328: 67.7 Well: C-32 Section (VS) Reference: Well (Q.OON,O.OOE,265. OOAzi) Wellpathc Plan 4, C-32C Survey Calculation Method: Minimum Curvature Db: Oracle ` Targets Map Map... <---- Latitude -~> <-- Longitude :=> Name Description TVD +N/-S +FJ-W Northing Fasting Deg Min 'Sec Deg :Min Sec Dip.. Dir. ft ft ft ft ft C-32C Target 2 9027.72 -1126.79 4360.69 5958491.00 668890.00 70 17 33.503 N 148 37 57.263 W C-32C Target 3 9027.72 -1193.31 3423.94 5958404.00 667955.00 70 17 32.854 N 148 38 24.563 W C-32C Target 1 9032.72 -1109.70 4448.09 5958510.00 668977.00 70 17 33.671 N 148 37 54.716 W Annotation MD TVD ft ft . 10108.21 8817.40 TIP 10115.00 8822.63 KOP 10135.00 8838.15 End of 9 Deg/100' DLS 10175.00 8872.30 4 10261.09 8948.74 5 10339.36 8997.40 6 10399.36 9015.05 7 10459.36 9023.39 8 10535.00 9030.20 End of 40 Deg/100' DLS 10615.00 9032.87 10 10715.00 9031.20 11 10945.00 9027.73 12 11045.00 9027.70 13 11402.00 9026.72 14 11667.00 0.00 TD Plan Section Information MD Incl Aziro TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft' deg 10108.21 39.13 103.18 8817.40 -785.55 4548.93 0.00 0.00 0.00 0.00 10115.00 39.99 103.25 8822.63 -786.54 4553.14 12.68 12.67 1.03 2.99 10135.00 38.19 103.25 8838.15 -789.43 4565.41 9.00 -9.00 0.00 180.00 10175.00 24.50 119.56 8872.30 -796.40 4584.79 40.00 -34.23 40.79 155.00 10261.09 35.70 188.80 8948.74 -831.08 4596.84 40.00 13.01 80.42 105.22 10339.36 66.40 197.00 8997.40 -889.40 4582.50 40.00 39.22 10.48 14.57 10399.36 79.67 176.02 9015.05 -945.96 4576.42 40.00 22.11 -34.97 300.00 10459.36 84.58 199.74 9023.39 -1004.37 4568.26 40.00 8.20 39.54 80.00 10535.00 85.32 230.11 9030.20 -1065.41 4525.62 40.00 0.98 40.15 90.00 10615.00 90.86 237.97 9032.87 -1112.30 4460.98 12.00 6.92 9.82 55.00 10715.00 91.05 249.97 9031.20 -1156.10 4371.30 12.00 0.19 12.00 89.00 10945.00 90.65 277.57 9027.73 -1180.84 4144.89 12.00 -0.17 12.00 90.60 11045.00 89.39 289.50 9027.70 -1157.48 4047.84 12.00 -1.26 11.93 96.00 11402.00 90.91 246.69 9026.72 -1169.08 3699.30 12.00 0.43 -11.99 272.00 11667.00 88.72 278.41 9027.59 -1203.02 3439.90 12.00 -0.83 11.97 93.90 by # BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P ~-.r sn~cNUSC ins INTEQ Company: BP.Amoco Date: 9/26/2006 Time: 09:25:36 Page: 3 Field: Prudhoe $ay Co-ordinate(NE) Reference: Well: G32, True North Site: PB C Pad Vertical (TVD) Reference. C-32B: 67.7 Well: C-32 Section (VS) Reference: Well (O.pON,Q.00E,265.00Azi) Wellpathc Pla n 4, G32C Survey Calculation Method: Minimum Curvature Db: Oracle' Survey MD Inch Azim SS TVI) N!S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft, ft - degJ100ft ft deg 10108.21 39.13 103.18 8749.68 -785.55 4548.93 5958836.25 669070.72 0.00 -4463.15 0.00 MWD 10115.00 39.99 103.25 8754.91 -786.54 4553.14 5958835.35 669074.95 12.68 -4467.26 2.99 MWD 10135.00 38.19 103.25 8770.43 -789.43 4565.41 5958832.73 669087.28 9.00 -4479.24 180.00 MWD 10140.00 36.39 104.67 8774.41 -790.16 4568.35 5958832.07 669090.24 40.00 -4482.10 155.00 MWD 10150.00 32.84 107.92 8782.64 -791.75 4573.80 5958830.60 669095.72 40.00 -4487.39 153.87 MWD 10160.00 29.39 111.85 8791.20 -793.49 4578.66 5958828.96 669100.62 40.00 -4492.08 151.19 MWD 10170.00 26.08 116.70 8800.05 -795.40 4582.91 5958827.15 669104.90 40.00 -4496.14 147.83 MWD 10175.00 24.50 119.56 8804.58 -796.40 4584.79 5958826.19 669106.80 40.00 -4497.93 143.53 MWD 10180.00 24.05 124.31 8809.13 -797.49 4586.53 5958825.14 669108.57 40.00 -4499.57 105.22 MWD 10190.00 23.60 134.16 8818.29 -800.03 4589.65 5958822.67 669111.75 40.00 -4502.46 100.90 MWD 10200.00 23.79 144.11 8827.45 -803.06 4592.27 5958819.70 669114.43 40.00 -4504.81 91.89 MWD 10210.00 24.59 153.68 8836.57 -806.56 4594.38 5958816.24 669116.61 40.00 -4506.60 82.77 MWD 10220.00 25.96 162.49 8845.62 -810.51 4595.96 5958812.32 669118.28 40.00 -4507.83 74.03 MWD 10230.00 27.81 170.35 8854.54 -814.90 4597.01 5958807.96 669119.42 40.00 -4508.49 66.06 MWD 10240.00 30.05 177.21 8863.29 -819.71 4597.52 5958803.17 669120.04 40.00 -4508.59 59.05 MWD 10250.00 32.59 183.15 8871.84 -824.90 4597.50 5958797.98 669120.13 40.00 -4508.11 53.04 MWD 10260.00 35.38 188.28 8880.13 -830.46 4596.93 5958792.41 669119.69 40.00 -4507.06 47.97 MWD 10261.09 35.70 188.80 8881.02 -831.08 4596.84 5958791.78 669119.61 40.00 -4506.91 43.71 MWD 10270.00 39.16 190.22 8888.09 -836.42 4595.94 5958786.42 669118.83 40.00 -4505.55 14.57 MWD 10280.00 43.06 191.58 8895.62 -842.88 4594.69 5958779.95 669117.72 40.00 -4503.75 13.44 MWD 10290.00 46.97 192.76 8902.69 -849.79 4593.20 5958773.00 669116.38 40.00 -4501.66 12.41 MWD 10300.00 50.89 193.79 8909.26 -857.12 4591.47 5958765.63 669114.81 40.00 -4499.29 11.58 MWD 10310.00 54.83 194.71 8915.30 -864.85 4589.50 5958757.87 669113.02 40.00 -4496.66 10.90 MWD 10320.00 58.76 195.55 8920.77 -872.92 4587.32 5958749.75 669111.01 40.00 -4493.78 10.34 MWD 10330.00 62.71 196.33 8925.66 -881.31 4584.92 5958741.31 669108.80 40.00 -4490.66 9.88 MWD 10339.36 66.40 197.00 8929.68 -889.40 4582.50 5958733.17 669106.55 40.00 -4487.55 9.51 MWD 10350.00 68.58 193.04 8933.76 -898.89 4579.96 5958723.62 669104.21 40.00 -4484.18 300.00 MWD 10360.00 70.71 189.43 8937.24 -908.09 4578.13 5958714.39 669102.59 40.00 -4481.56 301.52 MWD 10370.00 72.90 185.91 8940.36 -917.50 4576.87 5958704.95 669101.53 40.00 -4479.48 302.77 MWD 10380.00 75.16 182.48 8943.11 -927.09 4576.16 5958695.35 669101.04 40.00 -4477.95 303.87 MWD 10390.00 77.47 179.11 8945.48 -936.80 4576.03 5958685.64 669101.12 40.00 -4476.97 304.82 MWD 10399.36 79.67 176.02 8947.33 -945.96 4576.42 5958676.49 669101.71 40.00 -4476.56 305.61 MWD 10410.00 80.43 180.27 8949.17 -956.44 4576.76 5958666.03 669102.28 40.00 -4475.99 80.00 MWD 10420.00 81.20 184.25 8950.77 -966.30 4576.37 5958656.16 669102.11 40.00 -4474.74 79.27 MWD 10430.00 82.01 188.21 8952.23 -976.13 4575.30 5958646.31 669101.25 40.00 -4472.81 78.63 MWD 10440.00 82.85 192.15 8953.55 -985.89 4573.55 5958636.52 669099.71 40.00 -4470.22 78.05 MWD 10450.00 83.73 196.08 8954.71 -995.52 4571.12 5958626.84 669097.50 40.00 -4466.96 77.53 MWD 10459.36 84.58 199.74 8955.67 -1004.37 4568.26 5958617.92 669094.83 40.00 -4463.34 77.07 MWD 10470.00 84.60 204.02 8956.67 -1014.20 4564.31 5958608.01 669091.10 40.00 -4458.55 90.00 MWD 10480.00 84.64 208.04 8957.61 -1023.14 4559.95 5958598.97 669086.93 40.00 -4453.42 89.60 MWD 10490.00 84.71 212.05 8958.54 -1031.76 4554.96 5958590.25 669082.14 40.00 -4447.70 89.22 MWD 10500.00 84.80 216.07 8959.45 -1040.01 4549.39 5958581.88 669076.74 40.00 -4441.43 88.85 MWD 10510.00 84.92 220.08 8960.35 -1047.85 4543.24 5958573.91 669070.77 40.00 -4434.63 88.48 MWD 10520.00 85.06 224.10 8961.22 -1055.24 4536.57 5958566.37 669064.26 40.00 -4427.33 88.12 MWD 10530.00 85.23 228.11 8962.07 -1062.15 4529.39 5958559.31 669057.24 40.00 -4419.58 87.77 MWD 10535.00 85.32 230.11 8962.48 -1065.41 4525.62 5958555.97 669053.54 40.00 -4415.55 87.43 MWD 10550.00 86.36 231.59 8963.57 -1074.85 4514.02 5958546.27 669042.15 12.00 -4403.16 55.00 MWD 10575.00 88.09 234.05 8964.78 -1089.94 4494.13 5958530.75 669022.60 12.00 -4382.03 54.89 MWD 10600.00 89.82 236.50 8965.24 -1104.18 4473.59 5958516.07 669002.37 12.00 -4360.33 54.77 MWD 10615.00 90.86 237.97 8965.15 -1112.30 4460.98 5958507.68 668989.94 12.00 -4347.06 54.73 MWD 10625.00 90.88 239.17 8965.00 -1117.51 4452.44 5958502.28 668981.53 12.00 -4338.10 89.00 MWD 10650.00 90.93 242.17 8964.60 -1129.76 4430.66 5958489.56 668960.01 12.00 -4315.33 89.02 MWD 10675.00 90.98 245.17 8964.19 -1140.85 4408.26 5958477.99 668937.86 12.00 -4292.05 89.07 MWD by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P BAI~R s iNTEQ Company: BP Amoco Date: 9/26/2006 Time: 09:25:36 Pagc: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well`. G-32, True . North Site: PB C Pad Vertical (TVD) Reference: C-32B: 67.7 Well: C-32 Section (VS) Reference: Well (O.OON,Oi00E,265:00Azi) Wellpath: Pla n 4, C-32C Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SS TVI) N/S E/W MapN MapE DL5 VS TFO Tool ft deg deg ft ft ft ft ft deg/1OOft ft deg 10700.00 91.02 248.17 8963.75 -1150.75 4385. 31 5958467.59 668915.14 12.00 -4268.33 89.12 MWD 10715.00 91.05 249.97 8963.48 -1156.10 4371. 30 5958461.92 668901.25 12.00 -4253.91 89.17 MWD 10725.00 91.03 251.17 8963.30 -1159.43 4361. 87 5958458.39 668891.90 12.00 -4244.22 90.60 MWD 10750.00 91.00 254.17 8962.86 -1166.88 4338. 01 5958450.42 668868.21 12.00 -4219.81 90.62 MWD 10775.00 90.96 257.17 8962.43 -1173.07 4313. 80 5958443.71 668844.14 12.00 -4195.14 90.67 MWD 10800.00 90.92 260.17 8962.02 -1177.98 4289. 29 5958438.26 668819.75 12.00 -4170.30 90.73 MWD 10825.00 90.88 263.17 8961.62 -1181.60 4264. 56 5958434.10 668795.11 12.00 -4145.35 90.78 MWD 10850.00 90.84 266.17 8961.25 -1183.92 4239. 68 5958431.23 668770.28 12.00 -4120.36 90.82 MWD 10875.00 90.79 269.17 8960.89 -1184.94 4214. 70 5958429.67 668745.33 12.00 -4095.39 90.87 MWD 10900.00 90.74 272.17 8960.56 -1184.65 4189. 71 5958429.41 668720.34 12.00 -4070.52 90.91 MWD 10925.00 90.69 275.17 8960.25 -1183.05 4164. 76 5958430.46 668695.37 12.00 -4045.81 90.95 MWD 10945.00 90.65 277.57 8960.01 -1180.84 4144 .89 5958432.24 668675.45 12.00 -4026.20 90.99 MWD 10950.00 90.59 278.16 8959.96 -1180.15 4139 .94 5958432.82 668670.49 12.00 -4021.33 96.00 MWD 10975.00 90.27 281.15 8959.77 -1175.96 4115. 30 5958436.47 668645.76 12.00 -3997.14 96.01 MWD 11000.00 89.96 284.13 8959.72 -1170.49 4090. 90 5958441.40 668621.26 12.00 -3973.32 96.03 MWD 11025.00 89.64 287.11 8959.81 -1163.76 4066 .83 5958447.61 668597.04 12.00 -3949.93 96.03 MWD 11045.00 89.39 289.50 8959.98 -1157.48 4047 .84 5958453.47 668577.93 12.00 -3931.56 96.02 MWD 11050.00 89.41 288.90 8960.03 -1155.83 4043 .12 5958455.01 668573.17 12.00 -3927.00 272.00 MWD 11075.00 89.52 285.90 8960.27 -1148.36 4019 .27 5958461.96 668549.16 12.00 -3903.89 272.01 MWD 11100.00 89.62 282.90 8960.46 -1142.14 3995 .06 5958467.65 668524.82 12.00 -3880.31 272.03 MWD 11125.00 89.73 279.91 8960.60 -1137.20 3970 .56 5958472.05 668500.22 12.00 -3856.33 272.06 MWD 11150.00 89.84 276.91 8960.69 -1133.55 3945 .83 5958475.16 668475.42 12.00 -3832.02 272.07 MWD 11175.00 89.95 273.91 8960.74 -1131.19 3920 .94 5958476.97 668450.49 12.00 -3807.43 272.08 MWD 11200.00 90.06 270.91 8960.73 -1130.14 3895 .97 5958477.48 668425.50 12.00 -3782.64 272.09 MWD 11225.00 90.17 267.91 8960.68 -1130.39 3870 .97 5958476.68 668400.52 12.00 -3757.72 272.09 MWD 11250.00 90.28 264.92 8960.59 -1131.96 3846 .02 5958474.57 668375.61 12.00 -3732.73 272.08 MWD 11275.00 90.39 261.92 8960.44 -1134.82 3821 .19 5958471.16 668350.85 12.00 -3707.74 272.07 MWD 11300.00 90.49 258.92 8960.25 -1138.99 3796 .54 5958466.46 668326.30 12.00 -3682.83 272.06 MWD 11325.00 90.60 255.92 8960.01 -1144.43 3772 .15 5958460.48 668302.03 12.00 -3658.05 272.03 MWD 11350.00 90.70 252.92 8959.73 -1151.14 3748 .07 5958453.24 668278.11 12.00 -3633.48 272.00 MWD 11375.00 90.80 249.92 8959.40 -1159.11 3724 .38 5958444.77 668254.60 12.00 -3609.18 271.97 MWD 11402.00 90.91 246.69 8959.00 -1169.08 3699 .30 5958434.24 668229.74 12.00 -3583.33 271.93 MWD 11425.00 90.72 249.44 8958.67 -1177.67 3677 .97 5958425.19 668208.61 12.00 -3561.33 93.90 MWD 11450.00 90.52 252.43 8958.40 -1185.84 3654 .34 5958416.51 668185.17 12.00 -3537.08 93.94 MWD 11475.00 90.31 255.42 8958.22 -1192.76 3630 .32 5958409.06 668161.31 12.00 -3512.55 93.97 MWD 11500.00 90.10 258.42 8958.13 -1198.42 3605 .97 5958402.88 668137.09 12.00 -3487.80 93.99 MWD 11525.00 89.89 261.41 8958.13 -1202.79 3581 .36 5958397.96 668112.58 12.00 -3462.90 94.00 MWD 11550.00 89.68 264.40 8958.23 -1205.88 3556 .56 5958394.33 668087.85 12.00 -3437.92 94.00 MWD 11575.00 89.47 267.40 8958.41 -1207.67 3531 .62 5958392.00 668062.97 12.00 -3412.93 93.99 MWD 11600.00 89.26 270.39 8958.69 -1208.15 3506 .63 5958390.97 668037.99 12.00 -3387.99 93.97 MWD 11625.00 89.06 273.38 8959.05 -1207.33 3481 .65 5958391.24 668013.00 12.00 -3363.18 93.94 MWD 11650.00 .88.86 276.38 8959.51 -1205.20 3456 .75 5958392.82 667988.06 12.00 -3338.56 93.89 MWD / 11667.00 88.72 278.41 8959.87 -1203.02 3439 .90 5958394.64 667971.16 12.00 -3321.96 93.84 31/2" are L ~~_/ I..L Dowell of slaps Blind/Shears of pipes 2 3/8" combi ram/slips BAG TOTs ~ ~ --~ Mud Cross I I Mud Cross of flow cross variable bore pipe 3 1/2"-2 718" 2 3/8" combi ram/slips Swab Valve TOTs ~ Flow Tee • • Terri Hubble BP_Exptoration AK Inc. °Mastercard Check" PQ Box 1`96612 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF :.. Firsi National.Bank Alaska !~ Anchoaage, AK 99501 (; -__ n' MEMO ~ ~~~v iL25200060~:99L46227L556~~' 0305 89-6/1252. 3®rJ °° DATE s ~~. ~c°~ • • TRANSMITTAL LETTER CgIECKLIST WELL NAME /~~- ~, PTD# 2~-f~~ ~~ Development Service Exploratory Stratigraphic Vest Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT ~ (OPTIONS) APPLIES ~ TEXT FOR APPROVAL LETTER ~' MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ well ~ (If last two digits API nu b in ~ permit No. ,API No. 50- - - j m er are ~ ,' between 60-69) ;Production should continue to be reported as a function of the I I original API number stated above. PILOT HOLE j 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 (~0- - -_) from records, data and logs acquired for well SPACIiVG ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION 12~.05~. Approval to perforate and produce i infect is contingent I. upon issuance of a conservation order approving a spacing I 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 j 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 (name of well) until after (Com a~nv Name) has designed and I ' implemented a water well testing program to provide baseline data on water quality and quantity. (Com~anv Name) must contact the Commission to obtain advance approval of such water well testing Rev: l i 2~ 06 C^.jodyltransmittal checklist • • ~ i, ° I, ~ l , ~ N , ° ~ i 7 I. C ~ i,.. I I , II i i ~ i i ~. ° ~ , a I, I 'o ~,, ~', I v, ' MCI ~ '~, ~ ~ ~ ~I ~ ~'~ VI ~ '., ~, ~ ~ '~. m. O. '. W ~ I OI I N, DI O d' 'i a N of n ° ~ n •Q c I a~ I y. o U ' Z f0 7, ~ N ~ O, N it O Jil ~ ~ III ~ a ~ a~ ~~ ~, ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ N N y, N~ O~ N~ N~ N~ I tA' W. V1. V1. N~ N, N' O' U' N~ U' U' N' N' N' a~ a~, a~ a~ a~ a~ m a~ a~ a~ d, m. m. Q Q, Q. Q. Q Q Q Q: a~ a~ m. m a~ Q. m. m. a~ d a~ o Q o. Q. Q. 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E. i ~ ,~ a~' 3 ~ ° o ° ~ cx ~' _~ v~ m a>'i w -°o ~ Z' .a a c, a ~ ~' ° ~ ~, ~, ~, °, a~, ~ I > o' .o o ~ ~ ~ ~ a°. ~ a~ ~ ° o. m c a a ~ ~, a~ ~ Oi o c m o o. a~ ai ° °' E °' c° °~' Y y o, o w E d E w o a~ »- N, c, H~ o_ m °~ `m' `m ~' ~°> >' n c ° o a o a' a~ m rn o to •_ ° c o 0 ~S ~ o. m a n o: ° ° o. ui, vi: °- t' ~ .a~' N m ~ m m is ~6' ~ o o ~' of a '~ ° 3 2 a N o `~: o, o. a ~, ~ m ~ ° o. o ~ ~, m ~ m, c, ~ ~ ° ° ar ° a ~ o m ~ ~ c a 'rn a~ O! r~ a`r ~ .c a n ~ ~ x ° a~~ a~~ ~ 3' ~ a' °' c' a~i a~i >~~ of ~ m a~ ~ a w' °' ~ ° ~~ a. ~~ ~, v' ° ii ~ ~ a - a. a. a ~ ~ c' ° ~ a a ° y ~~ ~y t o, ~ ° ~ cr c, o, c' ~ al °, E a~, ~ ~ ~ co ~ o r, c c :?' ~3 ~ ~ I m ~ ~ ~ ~ = 3 w ~ ~, ° o. ~ ~ ~ ~ ~ ~ ~ ~" WI ~' ~ 3 ccai' cmi' cmi' ~ ~ `o o ~ c°i E cmi vi o c. ~: m o, o. - a m v m, ~ vi. °- ~ •3 ~ •~ I ° ar ° a. ~ J m~ E', a - a~ a~ a~ c ~ 3 c ~ c `t, '~n, °, ° o, o a m~ c, a~, ~ ~c, °` ~ o~ ~~, a a a a~ a~ m ° - ~ o, o ° ~ ~ ~` cu. a. °~ a. v = O. O, s a~ I ai m; a~~ a~, o, U ~a~~~~~cnooaac.~~¢az.v~vvc~,v.Q,=¢=o,mm,~~' ~'~;a,gcn,cnv, ~1.~ fl" O '- N M V to M n M W O ~ N M d' ~ M r O O O r N M V' ~ CO I~ W O ~ N M V ~ M ~ W O c- r r r r r ~ ~ N N N N N N N N N N M M M M M M M M M M O U m o 0 H m °o a; o ur o C, p C R N N N O N N ~ M ~~' ~ N W M R ~ r0 I C Or ~I O O L •L J N N II N I T J at ~ Q U I~ fl, ¢ I~ a U W ~ ~ Q ~ j tL Q ~ C7 Q ~ ~ a ¢ M, II " V w o ; a~ III a I O ill m O rn° c ~ 0 .~ ~ m .~ ~~ E ~~ WV ~''~ ca O „~ II `m U C ~ O .O N O O ~~ ', O U Well History File APPENDIX Information of detailed nature that is not particularly germane to the Welf Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efi(ort has been made to chronologically . organize this category of information. **** REEL HEADER **** MWD 07/12/04 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/02/16 134620 01 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!~!!!!!!!!!!!! Extract File: ldwg.las -Version Information VERS. 1.20: WRAP, N0: -Well Informa tion Block #MNEM,UNIT Data Type STRT,FT 10110.0000: STOP,FT 11742.0000: STEP,FT 0.5000: NULL, -999.2500: COMP, COMPANY: WELL, WELL: FLD FIELD: LOC LOCATION: CWLS log ASCII Standard -VERSION 1,20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. C-32C Prudhoe Bay Unit 70 deg 17' 44.598"N 148 deg 40' 4.345"W 1700' FNL, 883' FEL CNTY, COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3.0" CTK DATE. LOG DATE: 16-Feb-07 API API NUMBER: 500292155903 _Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF RKB FAPD.F 67.72 DMF RF EKB .F 0 EDF .F 67.72 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL --Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 a~-c3g ~ ~~~~ ~ ~ (1) All depths are Measured Depths (MD)unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (SSTVD) are Subsea corrected. (4} All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and Ultra Slim Resistivity Sub. (7) Data presented here is final and has been depth adjusted to PDCL (Primary Depth Control Log from Schlumberger MCNL dated 18-Feb-2007. A block shift of 4.5' was applied from 12617.5 ft.MD to TD. (8) The sidetrack was drilled from C-32B through a milled window in 4.5" liner. Top of window 10109 ft.MD (8750.0 ft.SSTVD) Bottom of window 10115 ft.MD (8754.0 ft.SSTVD) (9) The interval from 11702 to 11742 ft.MD (8962 to 8964 ft.SSTVD) was not logged due to sensor bit offset at TD. (10) Tied to C-32B at 10109 ft.MD (8750.0 ft.SSTVD) (11) MWD Run 3 is not presented. No logging data was collected during this Run. MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10115.6, 10118.2, ! 2.54199 10118.2, 10121.1, ! 2.90527 10150.7, 10154.5, ! 3.8125 10154.8, 10157, ! 2.17871 10182, 10182.9, ! 0.908203 10192.5, 10194.8, ! 2.36035 10193.9, 10197.4, ! 3.4502 10195.2, 10197.9, ! 2.72266 10199.6, 10202.7, ! 3.08594 10202.5, 10204.7, ! 2.17871 10245, 10247.2, ! 2.17871 10246.9, 10251.2, ! 4.35742 10251.6, 10254.5, ! 2.90527 10255.9, 10258.7, ! 2.72363 10271.8, 10274.9, ! 3.08691 10284.6, 10287.1, ! 2.54199 10311, 10315, ! 3.99414 10344.1, 10349.4, ! 5.26562 10438.4, 10439.7, ! 1.27051 10440.2, 10441.1, ! 0.907227 10441.5, 10442.4, ! 0.908203 10508.8, 10519.9, ! 11.0742 10515.9, 10520.8, ! 4.90234 10521.4, 10523.2, ! 1.81543 10526.8, 10524.1, ! -2.72363 10581.2, 10582.8, ! .1.63379 10584.5, 10585.4, ! 0.908203 10587.4, 10587.2, ! -0.181641 10593.9, 10598.3, ! 4.35742 10601.5, 10605.3, ! 3.8125 10602.5, 10606, ! 3.44922 10603.8, 10607.1, ! 3.26758 10610.4, 10614.9, ! 4.53906 10612.2, 10617.1, ! 4.90137 10614.5, 10618.2, 10617.1, 10620.2, 10619.1, 10622, 10620.3, 10624.3, 10622.3, 10626, 10636.4, 10639.6, 10637.5, 10640.9, 10638.9, 10641.5, 10650.2, 10656.5, 10652.9, 10658.2, 10662.1, 10666.9, 10664.1, 10670.1, 10668.5, 10672.1, 10670.4, 10677.6, 10714.7, 10721.4, 10788.1, 10793, 10799.2, 10803.9, 10831.8, 10837.8, 10837.9, 10844.8, 10840.1, 10845.9, 10841.9, 10846.8, 10853.5, 10860.9, 10857.9, 10863.7, 10860, 10865.5, 10863.9, 10870, 10870.4, 10877.3, 10874, 10880.9, 10875.7, 10881.7, 10876.6, 10882.9, 10881.1, 10887.8, 10883.8, 10891.1, 10886.6, 10893.8, 10888.7, 10895.8, 10931.6, 10940.5, 10934.1, 10943.9, 10938.3, 10945, 10939.6, 10946.7, 10987, 10986.5, 11018.4, 11022.4, 11021.5, 11024.6, 11031.9, 11032.9, 11039.8, 11041.7, 11048, 11046.9, 11049.1, 11048.4, 11051.6, 11051.5, 11059.5, 11056.4, 11063.1, 11060.4, 11064.4, 11062, 11065.8, 11065.1, 11090.2, 11086.4, 11096.5, 11092.6, 11101.7, 11103, 11117.7, 11120, 11153.4, 11159.7, 11155.2, 11161.7, 11157.2, 11163.4, 11177.8, 11184, 11180.6, 11186, 11186, 11190.2, 11188.2, 11195.1, 11194.6, 11199.1, 11195.3, 11201, 11197.1, 11201.7, 11201.7, 11206.6, 11218, 11223.3, 11333.7, 11341.3, 11343.7, 11353.1, 3.63086 3.08691 2.9043 3.99414 3.63086 3.26758 3.4502 2.54102 6.35449 5.26465 4.7207 5.99121 3.63086 7.26172 6.71777 4.90234 4.71973 5.99121 6.89844 5.80957 4.90137 7.44336 5.80957 5.44629 6.17285 6.89844 6.89844 5.99121 6.35352 6.71777 7.26172 7.26172 7.08008 8.89648 9.80371 6.71777 7.08105 -0.544922 3.99414 3.08594 1.08887 1.81543 -1.08984 -0.725586 -0.181641 -3.08594 -2.72266 -2.36035 -0.726562 -3.8125 -3.99414 1.27051 2.36035 6.35449 6.53613 6.17285 6,17285 5,44629 4.17578 6.89844 4.53906 5,62793 4.53906 4.90137 5.26465 7.625 9.44043 11350.4, 11358.4, ! 7.98926 11352.4, 11359.9, ! 7.44434 11353.9, 11360.4, ! 6.53613 11355.5, 11363.1, ! 7.625 11357.7, 11364.4, ! 6.71777 11364.4, 11368.6, ! 4.17578 11365.3, 11369.8, ! 4.53906 11396.6, 11401.7, ! 5.08398 11400.9, 11403.1, ! 2.17871 11404.1, 11408.6, ! 4.53809 11407.2, 11411, ! 3.8125 11409.7, 11412.1, ! 2.36035 11414.4, 11419, ! 4.53906 11424, 1 1427.5, ! 3.44922 11425.5, 11429.1, ! 3.63086 11426.7, 11430.9, ! 4.17578 11431.4, 11433.1, ! 1.63379 11496.8, 11496.8, ! 0 11537.5, 11538.5, ! 1.08984 11542.6, 11543, ! 0.363281 11547.1, 11549, ! 1.81543 11549, 11550.4, ! 1.45215 11550.6, 11552.4, ! 1.81641 11557.9, 11560.6, ! 2.72266 11569.1, 11574, ! 4.90234 11577.9, 11581.9, ! 3.99414 11579.3, 11583.3, ! 3.99414 11594.8, 11600, ! 5.26562 11607.7, 11612, ! 4.35742 11612.7, 11617.5, ! 4.71973 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 204 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN C-32C 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN C-32C APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ~ ~ The data presented here is final and has been depth shifted to a PDCL of Schlumberger MCNL dated 18-Feb-2007 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPS 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 91 Tape File Start Depth = 10110.000000 Tape File End Depth = 11742.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 104 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN C-32C.xtf LCC 150 CN BP Exploration (Alaska) WN C-32C APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0.0 ROPS ROPS ROPS 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 ROPS MWD 68 1 F/HR 3 RACL MWD 68 1 OHMM 4 RACH MWD 68 1 OHMM 5 RPCL MWD 68 1 OHMM 6 RPCH MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 • Total Data Records: 182 Tape File Start Depth = 10110.000000 Tape File End Depth = 11742.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 195 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/02/16 134620 01 **** REEL TRAILER **** MWD 07/12/04 BHI 01 Tape Subfile: 4 2 records... i Minimum record length: 132 bytes Maximum record length: 132 bytes C~ Tape Subfile 1 is type: LI5 • Tape Subfile 2 is type: LIS DEPTH GR ROP RPD RPS 10110.0000 80.2941 -999.2500 0.4467 0.3024 10110.5000 81.1040 -999.2500 0.6969 0.1696 10200.0000 62.7629 28.9003 24.8204 25.6693 10300.0000 25.3226 44.8035 19.7593 18.3267 10400.0000 87.3000 68.4882 21.5834 22.7054 10500.0000 93.8266 44.0591 19.8390 19.5587 10600.0000 152.8946 73.9553 17.9270 16.2400 10700.0000 48.9320 53.1378 17.4070 18.0100 10800.0000 60.3913 42.9651 17.4070 17.0985 10900.0000 28.0258 156.7312 15.9486 15.4661 11000.0000 38.0000 111.6616 15.5100 15.2330 11100.0000 35.3191 96.2396 15.2280 14.3821 11200.0000 150.6686 46.3551 15.5524 14.2575 11300.0000 46.9217 207.2961 18.4934 18.1090 11400.0000 30.4274 108.6010 12.3352 12.5610 11500.0000 119.9921 87.5754 21.8050 20.0549 11600.0000 75.3402 27.2576 17.1500 15.3380 11700.0000 35,0000 39.5000 23.5650 24.7250 11742.0000 -999,2500 83.2000 -999.2500 -999.2500 Tape File Start Depth = 10110.000000 Tape File End Depth = 11742.000000 Tape File Level Spacing = 0.500000 RAD RAS 0.3555 2869.1050 0.5475 479.0717 37.3085 25.1594 39.2968 26.2649 36.3735 24.9979 35.9083 24.9116 38.6899 23.4112 24.3816 20.3319 28.2302 20.0115 24.5529 18.8880 22.7730 18.3959 26.4996 18.2844 26.5529 21.3823 29.2465 22.2890 17.4473 13.1091 47.0246 30.7252 37.6686 20.5807 45.2940 28.5880 -999.2500 -999.2500 • Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RPCL RPCH 10110.0000 77.7000 -999.250C 10.7420 30.2790 10110.2500 84.3500 -999.250C 8.9680 25.3470 10200.0000 32.2000 18.6000 26.5030 27.3760 10300.0000 21.9000 53.7000 20.5510 20.3450 10400.0000 77.2000 64.3000 19,8390 20.3450 10500,0000 135.4000 49.8000 19,5370 21.4600 10600,0000 69.1000 66.8000 17.3530 15.3530 10700.0000 50.4000 25.3000 16.4980 17.7880 10800.0000 65.2000 43.8000 16.8530 16.4390 10900.0000 24.6000 223.0000 14.9920 14.0250 11000.0000 30.4000 105.2000 15.3520 15.4100 11100.0000 36.2000 96.6000 15.1960 14.3160 11200.0000 93.3000 33.9000 17.9890 18.0100 11300.0000 56.1000 123.3000 18.1140 17.6960 11400.0000 140.2000 426.5000 12.6170 13.5560 11500.0000 119.9000 90.2000 21.8460 20.0950 11600.0000 81.6000 57.1000 17.7190 16.1660 11700.0000 -999.2500 49.2000 24.3920 25.7070 11742.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth - 10110.000000 Tape File End Depth = 11742.000000 Tape File Level Spacing = 0.250000 RACL 2212.9961 2212.9961 65.5510 40.3610 34.1260 23.1040 37.5740 22.9990 27.8910 23.9340 22.3150 26.4620 27.5700 29.2120 16.5620 47.1790 38.0550 41.3880 -999.2500 RACH 4420.6865 3679.1943 40.2680 26.5780 22.6950 22.3960 23.5490 17.1960 19.7060 18.2330 18.1750 18.2900 21.4590 21.9450 12.3970 30.7780 21.6830 28.1390 -999.2500 • Tape File Depth Units = feet Tape Subfile 4 is type: LIS
