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Home My WebLink About209-0457. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 02-33B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-045 50-029-22214-02-00 12820 Conductor Surface Intermediate Production Liner 8809 77 3441 9795 3158 9940 20" 9-5/8" 7" 4-1/2" 8401 40 - 117 39 - 3480 27 - 9822 9659 - 12817 40 - 117 39 - 3477 27 - 8290 8137 - 8809 12743 470 2020 5410 7500 9940 1490 3520 7240 8430 9826 - 12720 4-1/2" 12.6# 13Cr80 26 - 9665 8294 - 8821 Structural 4-1/2" Baker S-3 Perm , 9546 , 8031 No SSSV 9546 8031 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028308 26 - 8143 513 528 49141 23006 39 8 0 0 963 385 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:12 am, Oct 14, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.10.10 13:42:47 - 08'00' Bo York (1248) RBDMS JSB 101524 DSR-10/14/24WCB 2-7-2025 ACTIVITYDATE SUMMARY 9/10/2024 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD UNIT #61 ***WSR CONT. ON 09-11-2024*** 9/11/2024 ***WSR CONT. FROM 09-10-2024*** PULLED 4-1/2'' DREAM CATCHER FROM XN-NIP @ 9653'MD (missing 1 key & most of catcher fingers) RAN 4-1/2BLB & 2.60'' MAG TO DEVIATION @ 10617'SLM (no recovery) DRIFTED FREELY w/ 3.68'' BARBELL TO 10,000'SLM DRIFTED FREELY w/ 30' x 2-7/8'' DMY GUNS (3.16'' od) TO 10,000'SLM ***WELL LEFT S/I ON DEPARTURE*** 9/14/2024 T/I/O = 2400/100/0 Temp=S/I (Assist E-Line with Load & Test) Pumped 200 bbls Crude down TBG for load. Further pumped 1.8 bbls Crude to reach test pressure of 503 psi. Passing test per EL Yellowjacket E-Line in control of well upon TFS departure FINAL WHPS = 380/250/0 9/14/2024 ***WELL S/I ON ARRIVAL*** (SET PLUG / ADPERF) RIG UP YJ ELINE. THUNDERBIRD PT PCE 300 PSI LOW /3000 PSI HIGH THUNDERBIRD LOAD THE WELL W/200 BBLS OF CRUDE MAX RATE ~5 BPM MAX PRESSURE=2450 PSI SET 3.5" OD CIBP AT 9940', CCL TO MID ELEMENT=12.3' CCL STOP DEPTH= 9927.7'. TAG AFTER SET THUNDERBIRD TEST THE PLUG W/500 PSI FOR 10 MIN (PASS) PERFORATE INTERVAL 9826'-9854' WITH 2.875'' GEO RAZOR 6spf 60 DEG PHASE CCL TO TOP SHOT=9.9' CCL STOP DEPTH= 9816.1', CONFIRM SHOTS FIRED GAMMA RAY CCL CORRELATION PASESS SENT TO OE AND GEO IN TOWN TO CORRELATE SAG PERFS (THERE IS NO DECENT REFERENCE LOG) WELL CONTROL DRILL WITH WSL WELL TURND OVER TO DS READY TO POP *** WELL S/I ON DEPARTURE*** 9/19/2024 *****WELL FLOWING ON ARRIVAL***** SPOT IN *****CONT WSR ON 09/20/24***** 9/20/2024 T/I/O = 1250/VAC/100. Temp = SI. T & IA FL (SL request). No AL. T FL @ 2300', 100' below X- Nip, 35 bbls). IA FL near surface. Slickline in control of valves upon departure. 10:00 9/20/2024 *****CONT FROM 09/19/24*****(kick off gas lift design) FUNCTION TEST WLV=PASS SET 4-1/2" WHIDDEN CATCHER @ 9,653' MD PULL STA #1 1" BK-DGLV FROM 6,681'MD PULL STA #2 1" BK-DGLV FROM 3,725'MD SET STA #2 1" BK-LGLV @ 3,725'MD SET STA #1 1" BK-SOGLV @ 6,681' MD PULL 4-1/2" WCS FROM XN @ 9,653' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** Daily Report of Well Operations PBU 02-33B SET 3.5" OD CIBP AT 9940', PERFORATE INTERVAL 9826'-9854 STATE OF ALASKA A-. .SKA OIL AND GAS CONSERVATION COMk..,,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubin❑ Operations shutdown ❑ Performed Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casini I ] Change Approved Program ❑ Plug for Rednll ❑'erforate New Pool ❑ Repair Well n Re-enter Susp Well ❑ Other Mill Plug C/GP n 2 Operator 4 Well Class Before Work 5.Permit to Dnll Number Name BP Exploration(Alaska),Inc Development 2 Exploratory ❑ 209-045-0 3 Address P O Box 196612 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-22214-02-00 7 Property Designation(Lease Number). 8 Well Name and Number ADL0028308 PBU 02-33B 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10.Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12820 feet Plugs measured Nonefelt"E C E I V E D true vertical 8809 1 feet Junk measured 12743 feet MAY 282015 Effective Depth measured 12737 feet Packer measured See Attachment feet /'rO��A (V' true vertical 8760 26 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 77 7 20"91.5#H-40 39 5-117 2 39 5-117 2 1490 470 Surface 3440 6 9-5/8"36#J-55 39-3479 6 39-3476 68 3520 2020 Intermediate 9794 23 7"26#L-80 27 3-9821 53 27 3-8290 22 7240 5410 Production None None None None None None Liner 3158 46 4-1/2"12 6#L-80 9658 89-12817 35 8136 69-8809 41 8430 7500 Perforation depth Measured depth 10585-10685 feet 10730-10970 feet 11040-11570 feet 116.20-11840 feet 12500-12540 feet 12580-12720 feet True Vertical depth 8872 7-8902 44 feet 8909 97-8918 39 feet 8916 16-8908 13 feet 8906.31 -8895 12 feet 8849 82-8844 13 feet 8838 64-8820 89 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 26 1 -9665 28 26.1-8142 7 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary. Intervals treated(measured) Treatment descriptions including volumes used and final pressure SCANNED j LIL 0 42015 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 479 35423 0 0 897 Subsequent to operation 611 36458 0 0 972 14.Attachments(required per 20 MC 25 070 25 071,&25 283) r 15 Well Class after work Daily Report of Well Operations ❑ Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 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 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerha s• b•.com Printed Name Nita Summerhays Title Data Manager Si' Aort.rri vj ��c ' �i� Phone 564-4035 Date 5/28/2015 I,-ri- 4./iVI5- RBDMS JUN - 3 2015 '4 C--- Form 10-404 Revised 10/2012 Submit Onginal Only Daily Report of Well Operations ADL0028308 ACTIIVITYDATE I SUMMARY CTU#6 1.75"CT Job Objective: Mid IBP MIRU. MU & RIH w/ Baker 2-7/8" motor& 3.71" 5-bladed mill. Tag CIBP at 12341'. Begin milling CIBP and push it downhole to 12743'E/12753'M, confirm tag. POOH. FP well w/31 bbls of 50/50 methanol down backside of coil. 5/2/2015 ***In Progress*** CTU#6 - 1.75" CT Job Objective: Mill CIBP RDMO. 5/3/2015 ***Job Complete*** FLUIDS PUMPED BBLS 112 50/50 METH 138 1% SLICK KCL W/SAFELUBE 378 1% KCL 628 TOTAL C) Q0000o O N O �n N- O in N ti 0 y 0 0 0 0 0 O co N co V N V 1.0 a CO CO CO N — O N N t CO I� O O O N O O I" N CO V CO CO CO CA I— O CC) CO O M O M N N CO N N- O LU Nco CO CO co .1- CO O N N CO O) t) 0 aFf Qo l� in rn 6 Co N CD M N N O) 2-2 I— C O Q o ` o CO LO CY) co 4) J CO N N N . (O CC 0) N CO U - - O N N O) V ct CO _ ChCO O V co C I— r- V CO J O) co M W rY Q H W LLJ 0 0 cC Z_ Z LLJ LU O Z > 0 Z U) I— Packers and SSV's Attachment ADL0028308 SW Name Type MD TVD Depscription 02-33B PACKER 9545.61 8030.19 4-1/2" Baker S-3 Perm Packer 02-33B PACKER 9545.61 8030.19 4-1/2" Baker S-3 Perm Packer 02-33B PACKER 9545.61 8030.19 4-1/2" Baker S-3 Perm Packer 02-33B PACKER 9545.61 8030.19 4-1/2" Baker S-3 Perm Packer 02-33B PACKER 9658.89 8136.69 5" Baker ZXP Top Packer TFREF CI = 4 1/16" W 4 _=TY NOTES***4-1/2"CHROME TBG& AWB_LFE D= K FlkiC C 02-33B IVFPPI FS***WELL ANGLE>70"@ 10611.***DRAG OKB _ 1' W H18 02-33A NOT SHOWN BELOW BF.BIV= 31.30' 2 WHPSTOCK*** KOP= 3194' max Angle= 98"0 12397' 20"COPD, — 73' Datum MD= 105550' 91.5#,H-40, Datum TVD= 8800 SS D=19.124" 7.=---H 1959' - 9-5/8'ECS' ' 2201' - 4-112"HE X PW,D=3.813 GAS LFT MANDRELS Minimum ID = 3.725" @ 9653' ST MD TVD DEV TYPE VLV LATCH PORT DATE ' 4-1/2" HES XN NIPPL7E 2 3725 3717 15 CAMCO DMY BK 0 06/12/101 6681 5922 46 CAMCO DMY BK 0 06/12/10 9-5/8"WHPSTOCK(05/22/09) H 3194' FALLOUT WrDOW(02-33B) 3194'-3211' i �{ 9516' - 4-1/2"FES XNP,D=3.813 9-5/8"CSG,36#,J-55,D=8.921" H 3478' 9640' —7"X 4-1/2"BKR 5-3 PKR,D=3.870" 4; ES 9580' - 4-1/2"HX PP,D=3.813 \ \ �i 9653' - 4-1/2"HES XN NP,D=3.725" 9660' - 7"X 5"HRD ZXP \TPwflESACK LV,D=4.400" 4-1/2"DREAM CATCHER ON XN LOCK(05/20/15) H 9653' 4-1/2"WLEG,D=3.958" 7'CSG,26#,L-80 TCI XO TO L-80 BTC-M — 9659' - 7"X 5"BKR FLE XLOCK 4-1/2"TBG,126#,13CR-80VAMTOP,.0152bpf,D=3.958' — 9655' LNRHGR D=4.430" PEORATION S1MARY692' —sx4 52xo, D=3.94" LOG:MAD GR LOG ON 05/26109 ANGEATTOPP :67"L'+ 10585' ,26#,L-80 BTC-M, J Note:Rfer to Roduction DB for historical pert data PISIZE SPF NTERVAL OpMSgz DATE S07 D=6.2761.56" 6 10585-10685 O 07/06/082-7/8" 6 10730-10970 O 06/06/0912743' —FFt C8P 2-7/8" 6 11040-11570 O 06/06!09 OH2-7/8" 6 11620-11840 O 06/06/09 (05/02/15) 2-7/8" 6 12500-12540 O 06/06/09 ; 2-718" 6 12580-12720 0 06/06/09 * 1\ PB'TD 12737' 4-1/2"LNR, 12.6#,L-80 BT-M,.0152 bpf,D=3.958" — 12818' DATE REV BY COMMENTS DATE REV BY COMMENTS PRJ.DHDE BAY tN'T 10/29/91 AUDI 1 ORIGINAL COMPLETION 06/14/10 CJPYSV GLV C/O(06/12/10) WEL: 02-33B 09/17/00 N CDRI SIDETRACK(02-33-AT-- 07/09/14 AD ADDED CONDUCTOR PFO PBRIVIff No: 2090450 1 06/10109 N9ES SIDETRACK(02-338) 03/02/15 JJUJM0 SET COP(02/25/15) API No: 50-029-22214-02-00 06/13/09 MBM✓TLH GLV C/O 05/06/15 TTR/JMD FISHt MLLES)CBP DH(05/02115) SEC 36,T11N,R14E,626'FN.&861'FWL 07/25/09 CSR/PJC PERF CORRECTIONS 05/20/15 RIK/PJC SET DREAM CATCHER 04/22/10 MS/JMJ DRG DRAFTS BP Exploration(Alaska) STATE OF ALASKA • ;KA OIL AND GAS CONSERVATION COW_ JION REPORT OF SUNDRY WELL OPERATIONS • 1.Operations Abandon U Repair Well❑ Plug Perforations U Perforate U Other( rvy Lam/ /--7 Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions 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 ❑ 209-045-0 3 Address P 0 Box 196612 Stratigraphic❑ Service ❑ 6 API Number Anchorage,AK 99519-6612 50-029-22214-02-00 7 Property Designation(Lease Number) 8 Well Name and Number: ADL0028308 PBU 02-33B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071). 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12820 feet Plugs measured 12310 aECEIVED true vertical 8809 1 feet Junk measured None feet MAR 2 4 2015 Effective Depth measured 12310 feet Packer measured None feet true vertical 8875 1 feet true vertical None feet OG CC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 74 20"91 5#H-40 36-110 36-110 1490 470 Surface 3440 6 9-5/8"36#J-55 37 8-3478 4 37 8-3475 5 3520 2020 Intermediate None None None None None None Production 9794 23 7"26#L-80 27 3-9821 53 27 3-8290 22 7240 5410 Liner 3158 46 4-1/2"12 6#L-80 9659 54-12818 8137 3-8809 33 8430 7500 Perforation depth Measured depth 10585-10685 feet 10730-10970 feet 11040-11570 feet 11620-11840 feet 12500-12540 feet 12580-12720 feet True Vertical depth 88727-8902 44 feet 8909 97-8918 39 feet 8916.16-8908 13 feet 8906 31 -8895 12 feet 8849 82-8844 13 feet 8838 64-8820.89 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 26 1 -9665 28 26 1-8142 7 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) ��YY NE Treatment descriptions including volumes used and final pressure �Y'►1a�L 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure - Prior to well operation 740 45672 0 0 1086 Subsequent to operation 498 28700 0 0 914 14 Attachments 15 Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work: Oil 0 Gas ❑ WDSPII 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 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhays( bp.com Printed Name Nita SummerhaJs Title Petrotechnical Data Engineer Signa �� / .." / ;/� Phone 564-4035 Date 3/24/2015 411RBDMS APR - 6 201 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028308 ACTIVITYDATE T.9 '1.7'5'"CT Job Scope: Set CIBP for GSO MIRU. RIH w/3.70"x 4' CIBP drift w/o issues. Tag TD at 12,748' CTM. POOH. 2/24/2015 RIH w/4.5" CIBP OD 3.55" & Hydr setting tool ***Job in progres*** CTU#9 1.75"CT Job Scope: Set CIBP for GSO ***Continue WSR from 2/24/15 *** Set CIBP @ 12310' set 3 k down on plug POOH At surface ball has been recovered 2/25/2015 RDMO FLUIDS PUMPED BBLS 100 1% KCL 190 1% KCL W/SAFELUBE 107 60/40 METH 397 TOTAL Packers and SSV's Attachment ADL0028308 SW Name Type MD TVD Depscription 02-33B PACKER 9546.26 8030.81 4-1/2" Baker S-3 Perm Packer 02-33B PACKER 9659.54 8137.3 5" Baker ZXP Top Packer TREE= 4-1/16"CNV WELLHEAD= FMC = TY NOTES"""4-12"CHROME TBG& ACTUATOR= BAKER C 02-33B NIPPLES'""W ELL ANGLE>70°@ 10611"""ORIG 6103 B_EV_ 1, WELL&02-33A NOT SHOWN BELOW BF.BEV= 31.30' 2 I WHIPSTOCK"'" KOP= 3194' Max Angle= 98"@ 12397' 20'CX)ND, — 73' Datum ASD= 10550' 91.5#,11-40, Datum TVD= 8800'SS O=19.124" —. 1959' - 9-5/8"ECP ' 1 2201' - 4-1/2"HES X NP,D=3.813 1 GAS LFT MANDRELS Minimum ID =3.726" @ 9663' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4-1/2" HES XN NIPPLE LI 2 3725 3717 15 CAMCO DMY BK 0 06/12/10 1 6681 5922 46 CAMCO DMY BK 0 06/12/10 9-5/8'W-IPSTOCK(05/22/09) — 3194' MLLOUT VITDOW(02-33B) 3194'-3211' V f0 9616' - 4-1/2'11MXNP,D=3.813 9-5/8'CSG,36#,J-55,D=8.921" H 3478' }--1 ` 9546' —7'X 4-1/2"BKR S-3 PKR,D=3.870' �� 9680 - 4-12"HES XNIP,D=3.813 4i 9653' - 4-1/2"HES XN NP,D=3.725' 11 9660' - 7'X 5'I-RD ZXP LTP w RIBA CK SLV,D=4.400' 9665' - 4-1/2"VVLEG,D=3.958' 7'CSG,26#,L-80 TCI XO TO L-80 BTC-M --I 9659' A 9682' - 7'X 5'BKR FLEXLOCK 1k LNR I-IGR,D=4.430' 4-1/2'TBG, 12.64, 13CR-80 VAM TOP,.0152 bpi,ID=3.958' — 9665' *' 9692' —5'X4-1/2-X0, PERFORATION SUIW ARY REF LOG:MVV[)GR LOG ON 05/26/09 ` D=3.94' ANGLE AT TOP PERE:67°@ 10585' ` Note:Refer to Roduction DB for historical pert data 7'CSG,26#,L-80 BTC-M, — 9822' SIZE SPF INTERVAL Opn/Sqz DATE SOZ ID=6.276' ` 12310' —4-1/2'CEP 1.56' 6 10585- 10685 0 07/06/08 (02/25/15) 2-7/8" 6 10730- 10970 0 06/06/09 ,...# ` 2-7/8" 6 11040- 11570 0 06/06/09 2-7/8" 6 11620- 11840 0 06/06/09 ` 2-7/8" 6 12500-12540 C 06/06/09 2-7/8" 6 12580- 12720 C 06/06/09 .1\44; PI TD H 12737' 4-1/2'LIQ 12.6#,L-80 BT-M,.0152 bpi,D=3.958' H 12818' DATE REV BY ' COMMENTS ' DATE REV BY COMMEIIIS PRUDHOE BAY UNIT 10/29/91 AUDI 1 ORIGINAL COMPLETION 06/14/10 CJWSV GLV C/O(06/12/10) WELL: 02-33B 09/17/00 N COR1 SIDETRACK(02-33A) 07/09/14 JA/1) ADDED CONDUCTOR INFO FERMTT No: 2090450 06/10/09 N9ES SIDETRACK(02-33B) 03/02/15 JJUJMD SET CUP(02/25/15) API No: 50-029-22214-02-00 06/13/09 WBPNTLH GLV C/O SEC 36,T11N, R14E,626'FTL&861'FVUL 07/25/09 CSR/PJC PERF CORRECTIONS 0422/10 MS/JMD DRLG CRAFT CORRECTIONS BP Exploration(Alaska) • 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 (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: .,~.ard muiiiiiuiiuii DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Re.~a~~eeded iiiiiiiiiw~iiiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: (~ (J /s/ 1 Project Proofing II I II ~I II I I III I I III BY: Maria Date: /s/ ti P i x 30 = o' ~v + ~/ ~ =TOTAL PAGES repara on ng Scann ,_ ~~ BY: Maria ~ 1 ~ Date: ~V 1 / CJ (Count does not i ~S~ude cover sheet)~ ~ Production Scanning Stage 1 BY: Stage 7 BY: Page Count from Scanned File: (Count does include r sheet) Page Count Matches Number in Scannin Prep ration: YES NO Date: g 3 ~ I ~ lsl If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: /s/ .... _........ , .... Scanning is complete at this point unless rescanning is required. ReScanned III IIIIIIIIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III (I'I III 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 4 August 22, 2011 406 9 ?0 �A Mr. Tom Maunder 8. Alaska 333 We Avenue Conservation Commission tr • - ;ss'v 4 Anchorage, Alaska 99501 oy s Subject: Corrosion Inhibitor Treatments of GPB DS -02 0 d` 3-&B Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 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, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -086 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -326 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -346 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -356 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02-40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 DATA SUBMITTAL COMPLIANCE REPORT 8/25/2010 Permit to Drill 2090450 Well Name/No. PRUDHOE BAY UNIT 02-33B Operator BP EXPLORATION (ALASK/y INC MD 12820 TVD 8809 Completion Date 6/6/2009 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION API No. 50-029-22214-02-00 UIC N Mud Log No Samples No Directional Survey( .Yes DATAINFORMATgN Types Electric or Other Logs Run: DIR / GR / PWD, DIR ! GR / NEU /DEN (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / I Mea/rrmL rvumcer Name acme mcuia rvo arar[ atop ~.n rtecervea a.vnun~nw Log Sonic 5 Col 34 3820 Case 7/20/2009 USIT, CCL, GR 19-May- 2009 ~ C Pds 18312~nic 34 3820 Case 7/20/2009 USIT, CCL, GR 19-May- 2009 ~ D ~ C Lis 18467 I" nduction/Resistivity 3009 12815 Open 9/1/2009 LIS Veri, GR, ROP, FET, DRHO, NPHI, TRPM, Plus Graphics og Induction/Resistivity 25 Blu 3011 12768 Open 9/1/2009 MD Vision Service 3-Jun- 2009 og Induction/Resistivity 25 Blu 3011 12768 Open 9/1/2009 TVD Vision Service 3-Jun- 2009 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? "~fld' Analysis `~/ N Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~'/ N Formation Tops ~ N •i •I DATA SUBMITTAL COMPLIANCE REPORT 8/25/2010 Permit to Drill 2090450 Well Name/No. PRUDHOE BAY UNIT 02-33B Operator BP EXPLORATION (ALASi(A) INC MD 12820 TVD 8809 Completion Date 6/6/2009 Completion Status 1-OIL Current Status 1-OIL Comments: Compliance Reviewed By: Date: API No. 50-029-22214-02-00 UIC N i •I OPERABLE: 02-33b(PTD #209045 'ping Integrity Restored ~ Page 1 of 2 Regg,. James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com) Sent: Monday, .June 14, 2010 1:36 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS3 DS Operators; AK, OPS FS1 DS2 Operator; AK, OPS FS1 Operators; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Well Integrity Coordinator Cc: Quy, Tiffany; Prowant, Josh L (CH2M Hill); Holt, Ryan P (ASRC) Subject: OPERABLE: 02-33~(PTD #2090450) Tubing Integrity Restored Attachments: Producer 02-306-08-2010 TIO Plot.doc; Producer 02-3~'(PTD #2090450) schematic.pdf All, c; z-3 ,/ Producer (PTD #2090450) passed an MIT-IA on 6/13/2010 after setting two DGLVs. The passing test confirms that tubing integrity has been restored. The well has been rec assl~ie as Operable. Please take caution when returning the well to production, as the IA is liquid packed. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Tuesday, June O8, 2010 10:48 PM To: 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; 'Regg, James B (DOA)'; AK, OPS FSl OSM; AK, OPS FSl Facility OTL; AK, OPS FSl DS Ops Lead; AK, OPS FS3 DS Operators; AK, OPS FS1 DS2 Operator; AK, OPS FSl Operators; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Well Integrity Coordinator Cc: Quy, Tiffany; Prowant, Josh L (CH2M Hill); Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: 02-33 (PTD #2090450) Confirmed TxIA Communication All, U Z3;3 Producer 0.?.~3~ (PTD #2090450) was confirmed to have TxIA communication with a failed TIFL after exceeding MOASP during proration. The Tubing/IA/OA on 5 812010 were 836/2400/260 psi. The well has been reclassified as Under Evaluation. Plan forward: 1. Install dummy gas lift valves 2. MIT-IA to 2500 psi Enclosed are a wellbore schematic and TIO plot for reference. «Producer 02-33 06-08-2010 TIO Plot.doc» «Producer 02-33 (PTD #2090450) schematic.pdf» 7/20/2010 OPE-~ZABLE: 02-33 (PTD #2090450) ~ing Integrity Restored ~ Page 2 of 2 Please call if you have questions or concerns. Thank you Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 7/20/2010 PBU 02-33B PTD #2090450 6/14/2010 TIO Pressures Plot ~r~~~] ~~.llQ~l tr~0~ 1,~]~l0 bell: 02-~3 -~ Tb~ --f- IA -~- ~~ ~~~ __ ~Q~~ - ~] n 0~~~'7 ;~~11=~ ~~r'~~,~~ ~ ~4r 1 I]r 1 ~ ~4 ~z~~7 Q ~~~ ~1~;10 ~~r'?~ ~1 ~ O~r~~~~1 Q TREE ~ r: 4-1 / 16" CM W~ILHEAD= FMC ACTUATOR= BAKERC KB. ELEV BF. ELfti' - 31.30' KOP = 3194' Max Angle- 98° @ 12397 Datum MD = 10550' Datum TVD = 8800' SS SAFEfYES ***4-1 /2" CHROME TBG & ~ NIPPLE ELL ANGLE> 70° @ 10611'***ORIG WELL & 02-33A NOT SHOWN BELOW WHIPSTOCK*** 1959' - 9-518" ECP Minimum ID _ 3.725" @ 9653' 4-~~2" HES xti N1PP~E 9-518" WHIPSTOCK (05/22/09} ~-~ 3194' 7" CSG, 26#, L-80 BTGM, ID = 6.276" 4-112" HES X NIP, ID = 3.813 9-5/8" CSG, 36#, J-55, ID = 8.921" ~-{ 3478' 7" CSG, 26#, L-80 TCII XO TO L-80 BTGM (4-1i2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: MWD GR LOG ON 05!26109 A NGLE AT TOP PERF: 83° @ 10730' Note: Refer to Production DB far historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7i8" 6 10730 - 10970 O 06/06/09 2-718" 6 11040 - 11570 O 06/06/09 2-7/8" 6 11620 - 11840 O 06!06/09 2-7/8" 6 12500 - 12540 O 06/06/09 2-7/8" 6 12580 - 12720 O 06106/09 MIILOUT WINDOW (02-338) 3194' - 3211' ~TD 4-112" LNR, 12,6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 46" -~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.870" 96$0' - 4-112" HES X NIP, ID = 3.813... 9653' - 4-1/2" HES XN NIP, ID = 3.725" 9660' - 7" X 5" HRD ZXP LTP w /TIEBACK SLV, ID = 4.400" 9665° 4-112" WLEG, ID = 3.958" 9682'- 7" X 5" BKR FLEXLOCK LNR HGR, ID = 4.430" 9692' 5" X 4-112" XO, ID - 3.94" 12737' 12$18' DATE REV BY COMMENTS 10/29/91 AUDI 1 ORIGINAL COMPLETION 09/17!00 N CDR1 SIDETRACK (02-33A} 06/10!09 N9ES SIDEt'RACK (02-33B} 06!13(09 MBIWTLN GLV CIO 07125!09 CSRtPJC PERF CORRECTIONS 04/22110 MS/JMD DRLG DRAFT CORRECTIO DATE REV BY PRUDHOE BAY UNIT WELL: 02-338 PERMff No: 2090450 API Na: 50-029-22214-02-00 SEC 36, 711 N, R14E, 626' FNL & 861' FWL BP Exploration (Alaska} 4-112" NES X NIP, ID = 3.813 C,AS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3725 6681 3717 5922 15 46 CAMCO CAMCO DOME SO BK BK 16 20 06/13!09 06113/09 ~~~~~ Alaska Data & Consuking Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date 08/27/09 N0.5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT ~- 07/26/09 1 1 L2-06 ANHY-00101 PRODUCTION PROFILE ~ ~ 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK C' 07/16/09 1 1 M-O6A AZCM-00034 PRODUCTION LOG j ` - 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE ~ 07/21/09 1 1 02-11A AYS4-00084 LDL - ~ 07/20/09 1 1 W-212 B3S0-00011 INJ PROFILE W/WFL - 07/20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL ~ - 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL -6C L 07/24/09 1 1 H-29A AYOO-00027 RST '~ 05/19/09 1 03-28 B14B-00067 RST / - 1.{ 07/17/09 1 1 B-27A AXBD-00029 MCNL 06/12/09 1 1 C-15A AWJI-00038 MCNL - 06/25/09 1 1 O-04A 61JJ-00023 MCNL -- 05/28/09 1 1 V-05 08AKA0024 OH MWD/LWD T 10/13/08 1 1 07-066 02-33B 14-23A AWJI-00042 09AKA0149 09AKA0035 MCNL OH MWD/LWD EDIT OH MWD/LWD EDIT 07/21/09 06/03/09 05/12/09 1 1 1 1 1 1 H-19B B2WY-00004 MCNL (REPLACEMENT) L 05/07/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING vertu ttt ~ urtnmtU uNt rrurr twcn i u: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 i ~~ e>I~kll~~~~~ NO.5310 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite a00 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnke;n ATT~: Beth 333 West 7th Ave, SuitE~ 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD S 07/14/09 Z-20 AP3O-00043 SBHP SURVEY 06/17/09 1 1 P2-31 AZCM-00029 LDL l.~ ~ 06/17/09 1 1 12-03 AY1M-00022 SBHP SURVEY 06/15/09 1 1 Z-14B AYOO-00036 TEMP SURVEY & BHP 06/23/09 1 1 N-16 AP3O-00042 SBHP SURVEY ` ~ 06/16!09 1 1 V~Qa.,:,, 11999053 USIT 10!12/08 1 1 ' N-11C AP3O-00042 SBHP SURVEY 06/16/09 1 1 `°"`°93-12 AY3J-00030 LDL ~ 06/12/09 1 1 L1-30 AVY5-00049 PRODUCTION PROFILEnj dd 06/22/09 1 1 _ 17-07B AYOO-00031 SBHP SURVEY `~ tS 06/11/09 1 1 OS-25B AP3O-00040 SBHP SURVEY ~ 06/11/09 1 1 B-27A AXED-00028 MEM INJ PROFILE 06/12/09 1 1 11-36 B14B-00066 CROSSFLOW & IBP C s 06/23/09 1 1 ~-21A 6148-00065 SBHP SURVEY 06/21/09 1 1 X-17 AYTU-00043 PROD PROFILE - ~ 06/08/09 1 1 Z-25 AWL8-00018 LDL ~~(~° '~j - 05/28/09 1 1 02-33B AYTU-00033 USIT 05/19/09 1 1 P2-07 AVY5-00051 PRODUCTION PROFILE ~ ~ 06/25/09 1 1 13-03 AWL8-00020 LDL 06/01/09 1 1 3-17F/K-30 B2NJ-00008 MEM INJ PROFILE 06/15/09 1 1 MPS-08 AYS4-00080 LDL 06/15/09 1 1 13-12 AViH-00019 LDL 07/05/09 1 1 01-25 AYTU-00046 USIT , ~~ b 06/28/09 1 1 W-39A AWL8-00023 STATIC TEMP SURVEY - , 06/26/09 1 1 Z-35 AYTO-00022 SBHP SURVEY - ~ 06/29/09 1 1 ~-16 AV1H-00017 SBHP SURVEY f ~~j 06/29/09 1 1 18-20 8581-00004 LDL ,_ ,~ 06/27/09 1 1 Z-29 AVY5-00053 SBHP SURVEY ~ ~~ ~.~~a 2 ~ ~ ~' 07/03/09 1 1 L5-09 AYQO-00032 RST (, `- I ~ 06/13/09 1 1 07-10A B1JJ-00022 MCNL .- ~~ 05/26/09 1 a ~~~~+~- ........ e - c~.o. ~ o. anawn~aa ravv nc r ~nwnvaa vnc ~.vri cia~.n 1 v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. r, I I ,. ~ d ~ , ., ~ ,: r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~~ ~iv~a • STATE OF ALASKA ~ ~ "~ ~-(~~ 0 ~ 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO;k~ ~:~ `~ ~~s Cons. Commission Artch(or e 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. Well Class: zoAAC 2s.,os zoAAC zs.,,o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aban~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6'2009 209-045 - 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 5/23/2009 ~ 50-029-22274-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 6/3/2009 ~ PBU 02-336 626' FNL, 861' FWL, SEC. 36, T11N, R14E, UM Top of Productive Horizon: 8. KB (ft above MSL): 58.6' 15. Field /Pool(s): 2306' FNL, 1460' FEL, SEC. 26, T11 N, R14E, UM Ground (ft MSL): 30.1' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Oil Pool 551' FNL, 2631' FEL, SEC. 26, T11 N, R14E, UM 12737' 8819' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 687604 y- 5950575 Zone- ASP4 12820' 8809' ADL 028308 ~ TPI: x- 685192 y_ 5954116 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 683976 y- 5955841 Zone- ASP4 None 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): S bm' I r nic nd rin in rmation r 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit'e"le~ctronic and printed information p r 20 AAC 25.071): DIR / GR / PWD, DIR / GR / NEU /DEN vv//VOON~ 9~%'7 ..3~J9 .s~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PERFT. GRADE TOP BOTTOM .TOP BOTTOM 'SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 urface 110' Surfa 110' 30" 11 ds Arcticse g- / rf 1 12-1/4" 1920 cu ft CS III, 348 cu ft'G', 89 cu ft CS II 7" 26# L-80 27' 9 22' 2T 8291' 8-3/4" 237 c ft Class ' ' 4-1 /2" 12.6# L- 12818' 1 8 6-1/ " cu ft I s'G' 23. Open to production or injection? ®Yes ^ No 24. TUBING RecoRD If Yes, list each interval open SIZE DEPTH SET MD PACKER SET MD (MD+TVD of Top 8 Bottom; Perforation Size and Number): 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9665' 9546' MD TVD MD TVD 10730' - 10970' 8910' - 8918' 2~j, ACID, FRACTURE, .CEMENT $QUEEZEy ETC. 11040' - 11570' 8916' - 8908' 11620' -11840' 8906' - 8895' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 12500' - 12540' 8850' - 8844' 2200' Freeze Protect w/ 75 Bbls of Diesel 12580' - 12720' 8839' - 8821' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 22, 2009 Gas Lift Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 6/23/2009 10 TEST PERIOD g77 g,g37 21 84 11,328 Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 769 1,200 24-HOUR RATE 2,105 23,848 50 Not Available 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per-~&Al~ ?.5E1071. C~ ..,,,. ~~~~0 ~ None 1 ~ '_ ' i Form 10-407 Revised 02/2007 ~ ~ CpNTINUED ON REVERSES ~ ~ ~ 2000 r ~~ y1~ L ~ 28. GE?' QPa1C MARKERS (LIST ALL FORMATIONS AND MAr ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 4871' 4632' None West Sak 6739' 5962' Colville Mudstone 7366' 6395' Top HRZ 9417' 7909' Base HRZ 9617' 8097' Sag River 9823' 8292' Shublik 9868' 8334' Sadlerochit 9942' 8403' 42S6 /Zone 4A 10034' 8487' Top CGL 10120' 8561' Base CGL 10199' 8628' 23S6 10284' 8701' 22TS 10352' 8754' 21TS 10430' 8800' Zone 1 B 10552' 8859' TDF /Zone 1A 10688' 8903' Base Sadlerochit 12125' 8887' Base Sadlerochit 12210' 8881' Formation at Total Depth (Name): TDF /Zone 1A 12210' 8881' 30. List of Attachments: Summary of Daily Drilling Reports, Wetl Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~7 ~~/ ~ Signed Terrie Hubble itle Drilling Technologist Date PBU 02-33B 209-045 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Mark Staudinger, 564-5733 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 02-33 Common Name: 02-33 , - - --- Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW~- Surface Pressure Leak Off Pressure (BHP) EMW -- ---- 5/22/2009 LOT 3,194.0 (ft) 3,193.5 (ft) 9.20 (ppg) 778 (psi) 2,304 (psi) 13.89 (ppg) 5/30/2009 LOT 9,814.0 (ft) 8,283.1 (ft) 8.40 (ppg) 1,120 (psi) 4,734 (psi) 11.00 (ppg) L Printed: 6/22/2009 2:12:16 PM BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date From - To ~' Hours Task 'Code NPT Spud Date: 10/6/1991 Start: 5/17/2009 End: 6/8/2009 Rig Release: 6/9/2009 Rig Number: 9ES Phase Description of Operations 5/16/2009 17:00 - 00:00 7.00 MOB P PRE PJSM. Take pits and shops from 14-23A to 02-33B. LD derrick and jockey 9ES off of well. Leave DS14 C~? 23:30hrs; proceed west down Spine. 15/17/2009 00:00 - 05:30 5.50 MOB P PRE PJSM. Rig sub en route to DS02-33B from DS14-23A; turn on Oxbow, Oxbow to West Dock. Right on West Dock to DS02 access road. 05:30 - 13:00 7.50 RIGU P PRE Spot rig sub over 02-33B; lay down mats and herculite. Spot and level pits, MU interconnect. Inspect and raise derrick. Take on seawater ~ 10:30hrs. 13:00 - 16:00 3.00 WHSUR P DECOMP Rig Accept ~ 13:OOhrs. Handle bridle lines and RU pipe shed chute. 16:00 - 19:30 3.50 WHSUR P DECOMP Pressure test: RU second kill line to OA, pressure test lines to 3500psi; good. Pressure up to test OA; pressure broke over at 1700psi and bled down to 1050psi; pump 1 bpm for 30min. Final pressure 920psi; bleed off to open top tank 19:30 - 20:30 1.00 WHSUR P DECOMP RU and test DSM lubricator to 1000psi; good. Pull BPV, LD lubricator. 20:30 - 00:00 3.50 WHSUR P DECOMP RU to circulate out freeze protect. 5/18/2009 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM. Reverse circulate 33bbls of diesel from tubing, taking returns to the open top tank. Circulate 50bbls of diesel from annulus, and circulate clean, chasing warm seawater with Safe-O-Surf. Install BPV and test from below via the IA to 1500psi; good. 01:00 - 03:00 2.00 W HSUR P DECOMP ~ tree and adapter flange. Functioned LDS, bleed off control lines. 9" ACME threads: 4.5 turns to MU. 4" ACME threads: 8.5 turns to MU. -Install Blanking Plug 03:00 - 07:00 4.00 BOPSU P DECOMP NU BOPs~ RU to test. AOGCC rep Chuck Shieve waived witness of BOP test ~ 02:28hrs. 07:00 - 14:30 7.50 BOPSU P DECOMP Test BOP equipment to 250psi low, 3500psi high for 5min each; chart all tests. Test witnessed by WSL Blair Neufeld and Nabors TP Bruce Simonson. Test using 4" and 3.5" test joints; good test. Remove blanking plug and blow down surface equipment. 14:30 - 17:00 2.50 BOPSU P DECOMP Prep cellar and wellhead. RU DSM lubricator to pull BPV. Test lubricator to 1000psi; good. Make 3 attempts to pull BPV; unsuccessful. RD lubricator and drain stack; plug discovered laying sideways in stack. 17:00 - 18:00 1.00 BOPSU N SFAL DECOMP PJSM. Fish BPV out of stack utilizing t-bar and sash cord noose. 18:00 - 19:00 1.00 PULL P DECOMP RU FMC tools to pull tubing hanger. MU 9" ACME crossover to drillpipe and MU assy to tubing hanger. PU and un-seat hanger at 70k up. Pull hanger to floor. 19:00 - 20:00 1.00 PULL P DECOMP Circulate 230psi @ 5bpm; small amount of gas breaking out at surface. Shut in and monitor for 10min; static. 20:00 - 00:00 4.00 PULL P DECOMP PJSM w/ SLB hand. RU to spool control line; RU power tongs to LD 3.5" 9.2# 13Cr FOX tubing. Pull tubing from cut C~3 3800' 5/19/2009 00:00 - 02:00 2.00 PULL P DECOMP PJSM. Finish pulling 3.5" 13Cr FOX tubing from cut at 3500' to rig floor.. Change out elevators, clean and clear floor of third party equipment. Pulled 85 joints, 1 cut joint (24.92'), 1 SSSV, 3 pup joints and 1 GLM. All 52 control bands retrieved. Tubing in fairly good condition with no noticeable corrosion or pitting. Printed: 6/22/2009 2:12:23 F'M BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code ~ NPT Phase Description of Operations 5/19/2009 02:00 - 04:00 2.00 BOPSU P DECOMP PU 4" test joint to test lower VBRs (2-7/8" x 5"). Test to 250psi low, 3500psi high; good. Test witnessed by WSL Amanda Rebol and Nabors Tool Pusher Roy Hunt. RD testing equipment. 04:00 - 05:30 1.50 CLEAN P DECOMP PU Baker 7" casina cleanout assemblv:: Used 6 1/8" Hughes Christensen bit, 7" casing scraper, two 4 3/4" boot baskets, bit sub and 4 3/4" lubricated bumper sub. 05:30 - 09:00 3.50 CLEAN P DECOMP RIH with 7" casing cleanout BHA #1 with 4" DP singles from 25' MD and tagged 3.5" tubing stump at 3831' MD. PUW 95k, SOW 95k. 09:00 - 10:00 1.00 CLEAN P DECOMP POH from 3831' MD to 3640' MD. Circulate one bottoms up at 7 bpm with 545 psi. - MW in 8.5 ppg / MW out 8.5 ppg 10:00 - 11:00 1.00 CLEAN P DECOMP POH with 7" casing clean out assembly from 3640' MD to 25' MD. - MW in 8.5 ppg / MW out 8.5 ppg 11:00 - 12:00 1.00 CLEAN P DECOMP LD 7" casing clean out assembly. Both 4 3/4" boot baskets were empty. 12:00 - 13:30 1.50 EVAL P DECOMP RU E-line. Stage truck unit, RU sheaves and air line wiper. PJSM on E-line operations. 13:30 - 17:00 3.50 EVAL P DECOMP RIH with E-line for USIT /CCL looaina from 3820' MD io USIT indicated possible cement up to 3300' MD. POOH and LD USIT /CCL. 17:00 - 20:00 3.00 DHB N DFAL DECOMP 131H ~a~ith Halliburton EZSV bridoe ol~a on E-line to 3500' MD. Unable to set EZSV. Repeated #ir~-sectaeNSe-t~3r imes without success. Decision made to POH and inspect tools. 20:00 - 21:30 1.50 DHB N DFAL DECOMP POH and LD CCL and Firing Head. Found shorted Thru Rod in CCL which prevented the firing signal to get to the Firing Head. Replaced CCL and Ignitor. Trouble shoot all equipment. 21:30 - 00:00 2.50 DHB N DFAL DECOMP RIH with Halliburton EZSV bridge plug on E-line to 3500' MD. Unable to set EZSV. Repeated firing sequence three times without success. Contacted Schlumberger E-line supervisor, decision made to POH and inspect tools. '~ 5/20/2009 00:00 - 01:00 1.00 DHB ~ N DFAL DECOMP POH and LD CCL and Firing Head. Inspect equipment - no issues found. Rebuilt firing head and re-wired entire system. Inspect E-line cable, cut approximately 100 ft of 7-46 E-line cable. Trouble shoot all equipment. 01:00 - 02:00 1.00 DHB N DFAL DECOMP RIH with Halliburton EZSV bridge plug on E-line to 3500' MD. Unable to set EZSV. Mobilize tools for setting EZSV with 4" DP. 02:00 - 03:30 1.50 DHB N DFAL DECOMP POH and LD CCL and Firing Head. Inspect tools. Change Ignitor (same style but different batch). 03:30 - 05:00 1.50 DHB P DECOMP F~IH with Halliburton 7" EZSV bridoe olua and set at 3499' MD (tom element) 29' above casing collar at 3528' MD and 14' below casing collar at 3485' MD. Positive indication at surface of set. Tension in E-line lost 290 lbs. PU and SO on EZSV 100 Ibs to confirm set. POH and verified tension sleeve in EZSV setting tool sheared. 05:00 - 06:00 1.00 DHB P DECOMP Pressure test EZSV plug to 3500 psi for 10 minutes -good test. Rig down testing equipment. Rig down E-line unit. 06:00 - 06:30 0.50 STCTPL P DECOMP Make up 5 1/2" multi string cutter assembly: 5 1/2" Multi String cutter, 4 11/16" pump out sub, XO sub. 06:30 - 08:00 1.50 STCTPL P DECOMP RIH with 5 1/2" multi string cutter to 3144' MD. Printed: 6/22/2009 2:12:23 PM ' ~ ~ BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Common W Event Name Contractor Rig Name: Date ' I Name: 0 ell Name: 0 : R Name: N N From - To ', 2-33 2-33 EENTE ABOBS ABOBS Hours R+COM ALASK 9ES Task PLET A DRI Code E LLING NPT Start I Rig Rig N Phase Spud Date: 10/6/1991 : 5/17/2009 End: 6/8/2009 Release: 6/9/2009 umber: 9ES Description of Operations _- - - ___ 5/20/2009 08:00 - 08:30 0.50 STCTPL P DECOMP Service Top Drive, Drawworks, Crown and Blocks. 08:30 - 09:00 0.50 STCTPL P DECOMP RIH from 3144' MD to 3218' MD (casing collar found at 3218' MD). Pick up to 3216' MD to avoid cutting collar at 3218' MD. PUW 85k, SOW 85k. 09:00 - 09:30 0.50 STCTPL P DECOMP Displace well from seawater to 9.2 ppg brine at 6 bpm with 1190 psi. 09:30 - 10:30 1.00 STCTPL P DECOMP Pump at 5 bpm with 575 psi while rotating at 95 rpm with 0.5k - 1.5k ft-Ibs torque to open knives and make cut. Positive indication that 7" casing was cut with a pressure drop of 350 psi and immediate fluid returns from OA (7" x 9 5/8" annulus). Spot 32 bbls of hot 9.2 ppg brine (130 deg F) with Safe-Surf-O at the cut point and close annular preventer. Circulate until returns from the OA clean up at 6 bpm with 450 psi. Approximately 80 bbls of diesel circulated out of OA. 10:30 - 13:00 2.50 STCTPL P DECOMP POH from 3216' to surface. LD multi string casing cutter. 13:00 - 13:30 0.50 STCTPL P DECOMP Remove wear bushing, pull wear ring and install test plug. 13:30 - 14:30 1.00 STCTPL P DECOMP Change out upper set of rams from 3.5" x 6" to 7". „ ; 14:30 - 15:00 0.50 STCTPL P DECOMP Test upper rams to 3500 psi High / 250 psi Low for 5 minutes ttilh' and chart -good test. Test witnessed by BP WSL Blair. Neufeld. 15:00 - 16:00 1.00 STCTPL P DECOMP MU spear assembly with: 4 1/4" Bull Nose, 6 1/16" Spear Pack Off, 5 11/16" Itco Spear, 5 3/4" Spear Extension, 8 1/8" Stop Sub, XO subs. Stab into 7" mandrel hanger, back out lock down screws. Pull the 7" casing hanger free with 118k lbs. 16:00 - 17:30 1.50 STCTPL P DECOMP Rig up 7" casing handling equipment. Change out rotary tongs to Off Driller's Side. Break out spear and LD. LD 7" mandrel hanger and pack off. 17:30 - 18:00 0.50 STCTPL P DECOMP Circulated one bottoms up of 9.2 ppg brine at 6 bpm with 110 psi. Mointor well for 10 minutes -static. RU to pull 7" casing while circulating. 18:00 - 00:00 6.00 STCTPL P DECOMP Pull 7" 26# L- LT PUW 115k, SOW 105k. Break out all joints with 18k - 22k ft-Ibs torque. Recovered 73 joints of 7" casing and one cut joint of 42.90'. Bow Spring centralizers with stop ring on every third joint. Casing in good condition. 5/21/2009 00:00 - 01:00 1.00 STCTPL P DECOMP RD 7" casing handling equipment. 01:00 - 02:00 1.00 BOPSU P DECOMP Change out upper set of rams from 7" to 3.5" x 6". 02:00 - 03:00 1.00 BOPSU P DECOMP RU testing eauipment and test upper rams with 4" test joint to 3500 psi High / 250 psi Low for 5 minutes and chart -good test. Test witnessed by BP WSL Eli Vazquez and Nabors Tour Pusher Roy Hunt. 03:00 - 03:30 0.50 BOPSU P DECOMP RD testing equipment. Install 9.125" wear ring. 03:30 - 06:00 2.50 CLEAN P DECOMP PU Baker 9 5/8" casing cleanout assembly: 5" Bull Nose, XO, 9 5/8" Casing Scraper, two 7" Boot Baskets, Bit Sub, 8 3/4" Upper Mill, 6 1/4" Lubricated Bumper Sub, 6 1/4" Oil Jar, nine 6 1 /4" DC, XO. 06:00 - 08:00 2.00 CLEAN P DECOMP .RIH ~~~ith Rakar 9 S/R" Cacin~(aaannut RHA #d with 4" DP singles from 328' MD to 3194' MD. PUW 105k, SOW 105k. Tag 7" casing stump at 3216' MD. 08:00 - 08:30 0.50 CLEAN P DECOMP Circulate one surfrce to surface at 247 gpm with 250 psi. Shakers look clean. - MW in 9.2 ppg brine / MW out 9.2 ppg brine. 08:30 - 09:30 1.00 CLEAN P DECOMP Cut 91' of drilling line. Pflfltetl: ti/'L"L/'LUUy L:12:2J YM 02-33 02-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 5/21 /2009 09:30 - 11:00 11:00 - 14:00 14:00 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 18:30 18:30 - 21:00 21:00 - 22:00 22:00 - 00:00 5/22/2009 00:00 - 01:00 01:00 - 03:00 03:00 - 05:00 05:00 - 06:00 06:00 - 07:30 07:30 - 08:30 08:30 - 13:00 Hours Task Code NPT 1.50 CLEAN P 3.00 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 2.00 CLEAN P 0.50 CLEAN P 2.50 CLEAN P 1.00 CLEAN P Page 4 of 17 Spud Date: 10/6/1991 Start: 5/17/2009 End: 6/8/2009 Rig Release: 6/9/2009 Rig Number: 9ES Phase Description of Operations DECOMP POH from 3216' MD to 328' MD standing back 4" DP in stands (30 stands stood back). - MW in 9.2 ppg brine / MW out 9.2 ppg brine. DECOMP RIH with Baker' 9 5/8" Casing Cleanout BHA #4 with 4" DP singles from 328' MD to 3194' MD. PUW 105k, SOW 105k. Tag 7" casing stump at 3216' MD. DECOMP Displace well from 9.2 ppg brine to 9.2 ppg LSND Milling Fluid. First bottoms up brought back black scale and asphaltenes (Schmoo). Circulated until returns cleaned up for a total of two bottoms up circulated. DECOMP POH from 3216' MD to 328' MD standing back 4" DP in stands (30 stands stood back). - MW in 9.2 ppg LSND / MW out 9.2 ppg LSND. DECOMP LD Baker 9 5/8" Casing Cleanout BHA #4. All components in gauge and both boot baskets were empty. DECOMP - ircul tion Valve, 4 1/2" x 3 1/2" IF XO, HT 40 x 3 1/2" IF drill pipe pup. DECOMP RIH with RTTS BHA #5 from 20' to 593' MD with 4" DP singles (18 4" DP singles picked up). Continue to RIH from 593' MD to 3173' MD with 4" DP stands. DECOMP Set RTTS Packing Element at 3205' MD (middle of planned whipptock ramp depth). PUW 88k, SOW 85k. pr cc ,P r~rP._tPSt G /Q~~ n.~c~nn 4rnm ohnvo Oho QTTC fn ~~nn nci fnr zn mini doe good test, lost 0 psi during entire test. Release RTTS, blow down kill line. 2.00 CLEAN P DECOMP POOH from 3205' MD to surface and LD RTTS BHA #5. - MW in 9.2 ppg LSND / MW out 9.2 ppg LSND 1.00 CLEAN P DECOMP Finished LD RTTS BHA. Clean and clear rig floor. 2.00 STWHIP P WEXIT Make u 9 5/8" whi stock BHA #6 with 8 5/16" Bottom Trip Anchor, Baker Gen II 9 5/8" whipstock, 8 1/2" window mill, 8 5/8" lower string mill, 4 7/8" flex joint., 8 3/4" upper watermellon mill, float sub, UBHO sub, 1 jt 5" HWDP, bumper sub, nine 6 1/4" DC, XO. Orient Whipstock Slide to UBHO Sub. 2.00 STWHIP P WEXIT RIH with whipstock BHA on 4" DP from 369' MD to 3203' MD. 1.00 STWHIP P WEXIT Fill pipe and circulate to clean 4" DP and BHA from any debris in preparation for Gyro Run. RU Gyro Data Sheaves and take and record slow pump rates while circulating at 213 gpm with 288 psi. 1.50 STWHIP P WEXIT Run Gyro to UBHO Sub at 3153' MD. Orient Baker Gen II 9 5/8" whipstock 330 degrees azmith. POH with Gyro. 1.00 STWHIP P WEXIT Tag 7" casing stump at 3216' MD and SO 20k to set bottom trip anchor. Pick up to confirm anchor set and saw no overpull. SO and moved down freely. Rotated and saw no increase in torque. Picked up and confirmed mills had sheared from whipstock assembly at same time as anchor had set with 20k. PUW 105k, SOW 150k. 4.50 STWHIP P WEXIT Mill 8 3/4" window in 9 5/8" casin with the followin parameters: 345 gpm and 470 psi, weight on mills 1 k - 8k Ibs, torque on bottom 2k - 5k ft-Ibs at 70 - 100 rpm. PUW 107k, SOW 105k, ROT 105k. Pump 20 bbl Hi Vis Super Sweep at middle of window - no considerable increase of cuttings with return of Hi Vis Super Sweep. Printed: 6/22/2009 2:12:23 PM ~ ~ BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 0 ell Name: 0 e: Name: From - To ~~~ 2-33 2-33 REENTE NABOBS NABOBS Hours R+COM ALASK 9ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 10/6/1991 : 5/17/2009 End: 6/8/2009 Release: 6/9/2009 Number: 9ES Description of Operations 5/22/2009 08:30 - 13:00 4.50 STWHIP P WEXIT -~~qf window at 3194' MDR t 3211' MD f i d B tt ow a . om o w n - o - Cement found behind casing. 13:00 - 15:00 2.00 STWHIP P WEXIT Drill new formation from 3211' MD to 3234' MD (the 8 3/4" mill stopped at 3214' MD) with the following parameters: PUW 107k, SOW 105k, ROTW 105k, pump at 345 gpm with 470 psi off and 530 psi on, rotate at 100 rpm with 0.8k ft-Ibs torque off and 1.2k ft-Ibs torque on, 1 Ok WOB. 15:00 - 16:00 1.00 STWHIP P WEXIT Circulate one surface to surface with a 20 bbl Hi Vis Super Sweep to clean metal debris from wellbore at 345 gpm with 470 psi, 105 rpm with 0.9k ft-Ibs torque. Work mills through the window several times with rotation with no issues. No considerable increase of cuttings with return of Hi Vis Super Sweep. 16:00 - 16:30 0.50 STWHIP P WEXIT Pull Window Mill BHA #6 inside 9 5/8" casing at 3173' MD and erform LOT to EMW f 1 the hole at a depth of 3194' TVD. Formation leaked off at a surface pressure of 778 psi. 16:30 - 19:00 2.50 STWHIP P WEXIT POH from 3173' MD to 368' MD and lay down 9 drill collars. - MW in 9.2 ppg / MW out 9.2 ppg 19:00 - 20:30 1.50 STWHIP P WEXIT Lay down Window Milling BHA #6. Upper string mill 1/16" under gauge and missing a 9" carbide cutter strip. Joint of 5" HWDP was grooved at the pin end. Contact town, decision made to PU 8 3/4" Mill Tooth Bit to get kicked off and drill to end of curvature. 20:30 - 21:30 1.00 STWHIP P WEXIT Pull wear bushing and jet BOP stack. Clean and clear rig floor. Function rams. 21:30 - 23:30 2.00 STWHIP P WEXIT MU 8 3/4" drilling BHA #6 with: 8 3/4" XR+C Smith, 1.5 deg Mud Motor, UBHO, NMDC, Steel Float Sub, 1 jt 5" HWDP, XO, 2 stds 4" HWDP. 23:30 - 00:00 0.50 STWHIP P WEXIT RIH with 8 3/4" drilling BHA #6 on 4" DP stands from 397' MD to 1066' MD. 5/23/2009 00:00 - 01:00 1.00 STWHIP P WEXIT Continue to RIH with drilling BHA #7 from 1066' MD to 3168' MD. PUW 100k, SOW 95k. 01:00 - 04:00 3.00 STWHIP P WEXIT RU to run Gyro and Side Entry Sub in preparation to orient drilling BHA #7. RIH with Gyro and latch up to UBHO Sub at 3138' MD. 04:00 - 05:00 1.00 STWHIP P WEXIT Orient drilling BHA #7 350 deg azimuth. Slide through window and encountered 10k drag at 3194' MD. Pick up and re-orient. Slide again through window with no issues. Found 11 k drag at 3206' MD. Wash down from 3213' MD to 3234' MD (under gauge section). 05:00 - 10:00 5.00 DRILL P INT1 Drill ahead in 8 3/4" hole from 3234' to 3430' MD - 500 gpm, 1262 psi on, 1222 psi off - 4k WOB and no rotation due to Side Entry Sub - 102k PUW, 95k SOW - ADT 3.28 hrs, ART 0.0 hrs, AST 3.28 hrs, Bit 3.28 hrs, Jars 100.3 hrs - Diluting 9.2 ppg LSND mud with new 9.2 ppg LSND 15 YP mud to reduce viscocity. - No fluid loss noted. - MW in /out - 9.2 ppg 10:00 - 10:30 0.50 DRILL P INTi Circulate one bottoms up at 521 gpm with 1315 psi for a total Printetl: 6/222009 2:12:[3 NM ~ ~ BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 'From - To 02-33 02-33 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 9ES Hours Task II Code NPT Spud Date: 10/6/1991 Start: 5/17/2009 End: 6/8/2009 Rig Release: 6/9/2009 Rig Number: 9ES Phase Description of Operations 5/23/2009 10:00 - 10:30 0.50 DRILL P INTi 10:30 - 11:00 0.50 DRILL P INT1 11:00 - 12:00 1.00 DRILL P INTi 12:00 - 13:30 1.50 DRILL P INTi 13:30 - 15:00 1.50 DRILL P INTi 15:00 - 16:00 1.00 DRILL P INT1 16:00 - 16:30 0.50 DRILL P INT1 16:30 - 17:00 0.50 DRILL P INT1 17:00 - 18:00 1.00 DRILL P INTi 18:00 - 18:30 0.50 DRILL P INT1 18:30 - 21:00 2.50 DRILL P INTi 21:00 - 00:00 3.00 DRILL P INT1 5/24/2009 00:00 - 12:00 12.00 DRILL P INT1 12:00 - 00:00 12.001 DRILL P INT1 5/25/2009 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P ~ ~ INTi of 262 bbls pumped. Monitor well -static. MW in /out 9.2 ppg POH from 3430' MD to 3168' MD, no drag seen coming through the window. MW in /out 9.2 ppg. POH with Gyro. RD Side Entry Sub and Gyro. POH from 3168' MD to 398' MD. Monitor well -static. MW in /out 9.2 ppg. Stand back 8 3/4" drilling BHA #7. Inspect bit: Grade 1-1-NO-A-E-I-NO-BHA. MU drilling BHA #8 with: 8 3/4" DTX-619-D2 Hycalog bit, 1.5 deg bend Motor, NMLC, Telescope MWD, UBHO, NMDC, NM Stabilizer, NMDC, Steel Float Sub, 1 jt 5" HWDP, Jars, 1 jt 5" HWDP, 2 stds 4" HWDP. RIH with drilling BHA #8 from 453' MD to 937' MD. Shallow test MW D at 434 gpm with 736 psi -good test. Continue to RIH from 937' MD to 3134' MD. Service Top Drive. MAD Pass down at 300 ft/hr from 3070' MD to 3164' MD. RIH from 3164' MD to 3430' MD with 10k drag when passing through the 9 5/8" window. MAD Pass in the UP direction at 300 ft/hr from 3430' MD to 32220' MD as per town geologist. RIH to TD at 3430' MD. Drill ahead in 8 3/4" hole from 3430' MD to 3708' MD. - 580 gpm, 1650 psi on, 1535 psi off - 15k WOB, 60 rpm, 2k ft-Ibs torque on, 1 k ft-Ibs torque off - 110k PUW, 105k SOW, 105k ROT Wt -ADT 0.97 hrs, ART 0.47 hrs, AST 0.50 hrs, Bit .97 hrs, Jars 101.3 hrs - No water being added, continue to dilute Hi Vis Mud in 100 bbls increments with new mud. - No fluid loss noted. - MW in /out - 9.2 ppg Drill ahead in 8 3/4" hole from 3708' MD to 5333' MD. - 580 gpm, 2010 psi on, 1716 psi off - 18k WOB, 80 rpm, 5k ft-Ibs torque on, 3k ft-Ibs torque off - 130k PUW, 110k SOW, 120k ROT Wt -ADT 7.7 hrs, ART 3.85 hrs, AST 3.85 hrs, Bit 8.69 hrs, Jars 109 hrs -Added water at 20 bph - No fluid loss noted. -MW in/out-9.2ppg Drill ahead in 8 3/4" hole from 5333' MD to 7326' MD. - 585 gpm, 2950 psi on, 2590 psi off - 20k WOB, 100 rpm, 8k - 11 k ft-Ibs torque on, 7k ft-Ibs torque off - 165k PUW, 120k SOW, 140k ROT Wt -ADT 6.89 hrs, ART 4.12 hrs, AST 2.77 hrs, Bit 15.58 hrs, Jars 115.89 hrs -Added water at 30 bph - No fluid loss noted. - MW in /out - 9.2 ppg Drill ahead in 8 3/4" hole from 7326' MD to 8661' MD. - 587 gpm, 3510 psi on, 3144 psi off Printed: 6/22/2009 2:12:23 PM s • BP EXPLORATION Page 7 of 17 ~ Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 02-33 02-33 Spud Date: 10/6/1991 REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 NABOBS ALASKA DRILLING I Rig Release: 6/9/2009 NABOBS 9ES Rig Number: 9ES Date II From - To it Hours ~ Task Code NPT 5/25/2009 100:00 - 12:00 12.001 DRILL P 12:00 - 00:00 I 12.001 DRILL I P 5/26/2009 100:00 - 06:30 6.501 DRILL ~ P Phase Description of Operations INT1 - 18k WOB, 100 rpm, 10k ft-Ibs torque on, 8k ft-Ibs torque off - 190k PUW, 125k SOW, 145k ROT Wt -ADT 8.01 hrs, ART 5.03 hrs, AST 2.98 hrs, Bit 23.59 hrs, Jars 123.87 hrs -Added 30 - 40 bbls of water per hour - No fluid loss noted. - MW in /out - 9.3 ppg Pumped 25 bbl Hi Vis Sweep at 7047' MD, approximately 50% increase in cuttings (especially clay paddies). No shale noted so far. Lotorq and Lube 776 added as needed to control torque and drag, current concentration of 1.5% v/v. Large pieces of coal (baseball size) seen accros the shakers at -8500' MD with return of Hi Vis Sweep. INT1 Drill ahead in 8 3/4" hole from 8661' MD to 9578' MD. - 530 gpm, 3650 psi on, 3450 psi off - 15k WOB, 80 rpm, 11 k ft-Ibs torque on, 8.7k ft-Ibs torque off - 210k PUW, 135k SOW, 165k ROT Wt -ADT 7.52 hrs, ART 3.27 hrs, AST 4.25 hrs, Bit 31.09 hrs, Jars 131.39 hrs -Added 30 bbls of water per hour - No fluid loss noted. - MW in /out - 9.4 ppg prior to spike up. MW in /out 102 ppg after spike up Started to slowly add 11.7 ppg spike fluid at 9000' MD to raise mud weight from 9.4 ppg to 102 ppg. Mud weight of 102 ppg in and out was achieved at 9150' MD after 2 full circulations and with a total of 290 bbls of spike fluid. No significant increase in cuttings with return of spike fluid. Up to 9578' MD shakers look clean and no shale splinters seen. INTi Drill ahead in 8 3/4" hole from 9578' MD to 9815' MD. , - 541 gpm, 3760 psi on, 3620 psi off - 10k WOB, 100 rpm, 12k ft-Ibs torque on, 11 k ft-Ibs torque off - 220k PUW, 135k SOW, 168k ROT Wt -ADT 2.35 hrs, ART 2.35 hrs, AST 0 hrs, Bit 33.70 hrs, Jars 133.95 hrs -Added 15 -20 bbls of water per hour - No fluid loss noted. - MW in /out 102 ppg Offset well logs indicate Top of Sag River can be at -9780' MD -plan to stop drilling at that depth. Saw decrease in ROP of 30 ft/hr at 9775' MD while maintaining constant 120 RPM and 11 k Ibs WOB. Stopped drilling at 9775' MD for sample collection as per geologist. BU samples show 10% sand and less than 1 %gluconite and rest kignak shale. Drilled ahead from 9775' MD to 9790' MD and circulated BU for geological samples. BU shows 95% shale, 5% sand and less than 1%gluconite. Drilled ahead from 9790' MD and stopped at 9805' MD due to Printed: 6/22/2009 2:12:23 PM ' ~ ~ BP EXPLORATION Page 8 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date !From - To I Hours Task Code NPT Phase I Description of Operations 5/26/2009 00:00 - 06:30 6.50 DRILL P INT1 sudden decrease in BOP. Circulated 1.5 BU and found 1 sand, and mostly shale with slight increase of gluconite. Decided to drill ahead from 9805' MD to 9815' MD. 06:30 - 08:00 1.50 DRILL P INT1 Circulate samples for geologist at 546 gpm with 3548 psi while rotating at 100 rpm and reciprocating. ROTW 170k, PUW 230k, SOW 135k. Samples showed 2 - 3% gluconite, with 30 - 40% Sag River sand, mostly shale. Monitor well -static. 08:00 - 08:30 0.50 DRILL P INTi POH fro 9815' MD to 9330' MD with no drag or overpull. RIH from 9330' MD to 9815' MD. MW in /out 10.2 ppg. 08:30 - 11:00 2.50 DRILL P INT1 Circulate 50 bbl Hi Vis Sweep at 560 gpm with 3695 psi, 100 rpm and 11 k ft-Ibs torque. PU 235k, SOW 140k, ROTW 170k. 100% increase in cuttings with return of Hi Vis Sweep. Monitor well -static. MW in /out 10.2 ppg. 11:00 - 13:00 2.00 DRILL P INT1 POH on elevators from 9815' MD to 7419' MD. PUW 230k, SOW 130k. Saw 50k overpull at 7419' MD. Attempt to work through tight spot with no sucess. MW in /out 10.2 ppg. 13:00 - 16:00 3.00 DRILL P INTi Backream out from 7419' MD to 6900' MD at 80 rpm with 5k - 14k ft-Ibs torque and ROTW 135k, pumping at 194 gpm with 2760 psi. At 6900' MD saw substantial reduction in torque, CBU while backreaming slowly to 6574' MD. MW in /out 10.2 PPg• 16:00 - 20:30 4.50 DRILL P INTi POH on elevators from 6574' MD to 452' MD with no issues. MW in /out 10.2 ppg. 20:30 - 23:00 2.50 DRILL P INTi LD 8 3/4" drilling BHA #8. Inspect bit; grade 1-1-CT-S-X-I-WT-TD. No significant wear or damage to any of the BHA components and all in gauge. Clear and clean rig floor of all 8 3/4" BHA and handling equipment. 23:00 - 00:00 1.00 BOPSU P INT1 Flush BOP stack and remove blower hose. Pull wear ring. 5/27/2009 00:00 - 02:00 2.00 BOPSU P INT1 Chan a out u er ram from 3.5" x 6" to 7". Test u er rams with 7" test joint and test plug to 250 psi low and 3500 psi high. Record on chart. Good test. 02:00 - 04:30 2.50 CASE P INTi RU to run 7", 26#, L-80, TC-II Intermediate Long String. Change bails and RU 7" casing handling tools, torque turn equipment, and Frank's fill-up tool. 04:30 - 11:00 6.50 CASE P INT1 PJSM and run in the hole with 7", 26#, L-80, TC-II to 3178; torque each connection to 10100 ft-Ibs. Filled every joint using the Frank's tool and circulated down every 10th joint at 4 bpm. String weight at 3178' - 110K Ibs up, 105k Ibs down. 11:00 - 12:00 1.00 CASE P INTi Staged pumps up to 5 bpm and 310 psi and circulated -150 bbls. 12:00 - 18:00 6.00 CASE P INT1 Continue running in the hole from 3178' to 6370'. String weight at 6370' - 200K Ibs up, 140K Ibs down. Losing down weight and gaining up weight. 18:00 - 18:30 0.50 CASE P INT1 Circulated down 3 joints, from 6370' to 6450', at 5 bpm and 595 psi. 18:30 - 21:30 3.00 CASE P INT1 Continue running in the hole from 6450' to 7910'. String weight at 7910' - 275K Ibs up, 150K Ibs down. Losing down weight, crossed friction factor lines on the iCenter broomstick plot. 21:30 - 22:30 1.00 CASE P INT1 Circulated down 5 joints, from 7910' to 8110', at 5 bpm and 700 psi. 22:30 - 00:00 1.50 CASE P INT1 Continue running in the hole from 8110' to 8512'. String weight at 8512' - 275K Ibs up, 150K Ibs down. 5/28/2009 00:00 - 00:30 0.50 CASE P INTi Continue to run in the hole with 7", 26#, L-80, TC-II casing to Printed: 6/22/2009 2:12:23 PM BP EXPLORATION Page 9 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours ', Task Code NPT Phase ', Description of Operations 5/28/2009 00:00 - 00:30 0.50 CASE P INT1 9200'. 00:30 - 01:30 1.00 CASE P INTi Circulated a bottoms up at 9200' before entering the HRZ. Packed off, work string at 9200', cleared the pack off and circulated another 1.5 times bottoms up. 01:30 - 07:00 5.50 CASE P INT1 Continued to run in the hole with the 7", 26# TC-II casing to 9815'. Pick up 1' to set casing shoe at 9814' MD. Average MU torque on TC-II is 10100 ft-bls. PUW 325k, SOW 160k. 07:00 - 09:30 2.50 CASE P INT1 PJSM with SLB, crew, WSL, Toolpusher. MU cement head. Circulate to condition mud as follows by staging pumps as follows: 2 bpm: ICP of 583 psi, FCP of 542 psi. MW in 10.2 ppg, MW out 10.7 3 bpm: ICP of 638 psi, FCP of 624 psi. MW in 10.2 ppg, MW out 10.7 4 bpm: ICP of 748 psi, FCP of 748 psi, MW in 10.4 ppg, MW out 10.7 5 bpm: ICP of 863 psi, FCP of 711 psi, MW in 10.3 ppg, MW out 10.6 6 bpm: ICP of 826 psi, FCP of 739 psi, MW in /out 10.4 ppg 09:30 - 12:00 2.50 CEMT P INTi Cement casing per SLB cement plan. - Pump 5 bbls of MudPUSH II at 13.0 ppg - Pressure test cement lines to 4500 psi with MudPUSH II. i~j - Pump 27.3 bbls of MudPUSH II at 13.0 ppg - Drop Bottom Plug; positive indication plug left head. - PiimnA226 hhls. 204.54 sx at 1.16 cuft/sx of 15.8 DDO Class G tail cement as follows: - 2.7 bbls away at 2.2 bpm with 339 psi - 6 bbls away at 5.1 bpm with 360 psi - 20 bbls away at 4 bpm wtih 378 psi - 42.26 bbls away at 4.4 bpm with 280 psi - Drop Top Plug and kick out with 5 bbls water; positive indication plug left head - Switch to rig pumps and displace cement with 372 bbls of 10.4 ppg LSND mud as follows: - 8 bbls away at 6 bpm with 410 psi - 50 bbls away at 6 bpm with 510 psi - 100 bbls away at 6.5 bpm with 540 psi - 200 bbls away at 6.5 bpm with 610 psi - 300 bbls away at 6.5 bpm with 707 psi - 350 bbls away at 6.0 bpm with 1051 psi - Slowed down to 3.0 bpm to bump plug at 367 bbls with 1500 psi. Bleed off pressure and check floats -floats holding. Full returns throughout the job. Cement in place at 11:10 hrs. Attempt to pressure test 7" intermediate casing to 3500 psi'and bled 250 psi in 4 minutes -abort test. NOTE: Tail cement 500 psi compressive strength 5:34 hrs and 1000 psi compressive strength at 7:04 hrs. 12:00 - 14:00 2.00 CEMT P INT1 Monitor OA (7" x 9 5/8" annulus) prior to ND BOP and Tubing Spool in preparation for setting 7" casing slips and 7" pack off. Rig down cementing head and blow down lines. Flush BOP with water. f' ~`F~ ,~1r" Printed: 6/22/2009 2:12:23 PM ~ ~ BP EXPLORATION Page 10 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To II Hours Task Code NPT Phase Description of Operations 5/28/2009 14:00 - 16:00 2.00 WHSUR P INT1 Split wellhead at base flange and pick up 4' to allow installation of 7" FMC Emergency Slips. 16:00 - 18:00 2.00 WHSUR P INT1 Install 7" x 10 3/8" FMC emergency slips with 75k set down weight. Cut 7" casing with Wachs cutter and lay down cut joint (9.78'). Install Condition B 7" Pack off (part # 12150009) and run in lock down screws to energize seals. 18:00 - 20:00 2.00 WHSUR P INT1 NU BOP and Tubing Spool. 20:00 - 21:00 1.00 WHSUR N SFAL INT1 Attempt to pressure test 7" pack off to 4300 psi (80% collapse of new 7", 263, L-80 casing). Bleed off rapidly. Mobilize FMC to get a new 7" Packoff while continuing to pressure test 7" packoff. Check pumping equipment and wellhead - no visual leaks. 21:00 - 22:00 1.00 BOPSU P INT1 Change upper rams from 7" to 3 1/2" x 6" variable rams. 22:00 - 22:30 0.50 WHSUR N SFAL INT1 Pull 7" pack off through the BOP stack. Install New 7" FMC Packoff (part # P1000001903) through the BOP stack. 22:30 - 23:00 0.50 WHSUR P INT1 Pressure test to 4300 psi (80% collapse of new 7", 26#, L-80 casing) for 30 minutes -good test with zero psi bleed throughout entire test. 23:00 - 00:00 1.00 BOPSU P INT1 RU to test BOP and install 10 3/4" test plug. 5/29/2009 00:00 - 07:30 7.50 BOPSU P INT1 T sti a ui me twit 4 1/2" and 4" test.' in s to 2 0 i / 3500 psi. Tested John Crisp of AOGCC waived witness of test. Test witnessed by WSLs Eli Vazquez,Joey LaBlanc, Brett Anderson and Toolpusher Bruce Simonson. 07:30 - 08:00 0.50 BOPSU P INT1 Pull 10-3/4" test plug, rig down BOP testing equipment, and blow down surface equipment. 08:00 - 08:30 0.50 BOPSU P INTi Install wear bushing, ID = 6.9375", and rigged up to pick up BHA #9. 08:30 - 11:00 2.50 DRILL P PROD1 Picked up and made up BHA #9, 6-1/8" build BHA, and adjusted motor bend angle. 6-1/8" build BHA consists of: 6-1/8" Smith XR20D bit, 1.83 deg mud motor and float, 4-3/4" NM flex collar, Impulse MWD, ADN4, (2) 4-3/4" NM flex collars, (1) 4-3/4" NM flex collar with a corrosion ring, 4-3/4" PBL, XO, (1) joint 4" HWDP, Hydraulic jars, and (1) joint 4" HWDP. Total lenght of BHA # 9 = 283.16'. 11:00 - 12:00 1.00 DRILL P PROD1 Run in hole with BHA #9 on 4", HT-40 DP, picked up 1x1 from the pipe shed, from 283' to 750'. Surfaced tested MWD tools at 5.8 bpm and 1423 psi; Up weight - 51 k Ibs, Down weight - 50k lbs. 12:00 - 13:30 1.50 DRILL P PROD1 Continue to run in hole with 4", HT-40 DP from 750' to 2837'. PJSM with Little Red Services and rig crew. LRS rigged up to the OA and pressure tested their lines to 3000 psi. At 12:47 LRS began pumping 95 degree F dead crude down the OA at 2.5 bpm with their charge pump to fill the OA. 12:51 pumping at 0.3 bpm and 120 psi. 8.8 bbls away. 13:01 pumping at 2.6 bpm and 775 psi. 25 bbls away. 13:13 pumping at 2.7 bpm and 875 psi. 55 bbls away. 13:20 pumping at 2.7 bpm and 1000 psi. 75 bbls away. 13:32 pumping at 2 bpm and 900 psi. 106 bbls away. Total of 106 bbls of crude was bullheaded down the 9-5/8" x 7" annulus. Printed: 6/22/2009 2:12:23 PM ~ ~ BP EXPLORATION Page 11 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 6/9/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task '~ Code !, NPT ' Phase ~' Description of Operations 5/29/2009 13:30 - 17:00 3.50 DRILL P PROD1 Continued to run in the hole with 4" DP from 2837' to 9423'. Up weight - 220k Ibs, Down weight - 115k lbs. 17:00 - 18:00 1.00 CASE P PROD1 Pressure tested 7" 26# casing with 3500psi for 30 charted minutes -good test. 0 min: 3600psi 5 min: 3500psi 15min: 3480psi 30min: 3470psi 18:00 - 19:00 1.00 DRILL P PROD1 PJSM, cut and slip 98' of drilling line and service the top drive. 19:00 - 20:00 1.00 DRILL P PROD1 Continue to run in the hole from 9423' to 9517'. Began washing down from 9517' to float collar at 9731' with 5 bpm and 2208 psi. 20:00 - 21:00 ~ 1.00 ~ DRILL ~ P 21:00 - 23:00 I 2.001 DRILL I P 23:00 - 00:00 I 1.001 DRILL I P 5/30/2009 100:00 - 02:00 I 2.001 DRILL I P 02:00 - 03:30 1.501 DRILL P 03:30 - 04:00 I 0.501 DRILL ( P 04:00 - 12:00 I 8.001 DRILL I P 12:00 - 13:30 I 1.501 DRILL I P PROD1 II r cement from 9739' t 9806' with 30 rpm and 5 bpm at 2208 psi on bottom and 2107 psi off bottom. Tor=10k ft-Ibs, PU=230k Ibs, S0=117k Ibs, Rot=145k lbs. PROD1 Displaced 10.4ppg LSND mud with 8.4ppg FloPro in preperation for drilling ahead into production interval. Pumped 50bbls of fresh water followed by a 50bb1 High-vis spacer and then the 8.4ppg FloPro at 5.4bpm, 1589psi, while rotating at 40rpm. PU=170k Ibs, S0=145k lbs. PROD1 Ri crew erformed a well control drill. Slow pump rates were taken at 9798' MD, 8268' TVD: Pump 1:670 psi @ 2 bpm, 800 psi C~? 3 bpm. Pump 2: 660 psi @ 2 bpm, 790 psi ~ 3 bpm. Crews closed in the well and lined up on the choke manifold. Each crew member took a turn manipulating the choke until they were comfortable with the operation. PROD1 Continue to drill out shoe track from 9806' MD to 9815' MD. Drill 20' of new hole from 9815' MD to 9835' MD at 232 gpm with 1700 psi off and 1760 psi on, 35 rpm with 3.9k ft-Ibs torque off, 4.6k ft-Ibs torque on. PUW 172k, SOW 143k, ROTW 162k. PROD1 POH from 9835' MD and set back one stand. Pump 50 bbl 10% Steel Lube EP sweep while rotating and reciprocating at 235 gpm with 1580 psi, with 18 rpm at 3.9k ft-Ibs. Circulate surface to surface until Steel Lube sweep out of hole. NOTE: Surface torque was reduced from 3.9k ft-Ibs to 3.Ok ft-Ibs with Steel Lube EP sweep. PROD1 onduct FIT to an EMW of 11.0 8283.11' TVD, 9814' MD, 1120 psi -good test. PROD1 Drill ahead in 6 1/8" hole from 9,835' MD to 10,084' MD. - 250 gpm, 1882 psi on, 1780 psi off - 18k - 20k WOB, 40 rpm, 4.8k ft-Ibs torque on, 3.8k ft-Ibs torque off - 170k PUW, 145k SOW, 165k ROT Wt - ADT 5.73 hrs, ART 4.35 hrs, AST1.38 hrs, Bit 5.73 hrs, Jars 5.73 hrs -Added 10 bbls of water per hour - No fluid loss noted. -MW in/out-8.4ppg PROD1 Drill ahead in 6 1/8" hole from 10,084' MD to 10,282' MD. - 259 gpm, 1850 psi on, 1644 psi off, 18k WOB - 185k PUW, 140k SOW, 165k ROT Wt at 40 rpm with 4k ft-Ibs Printed: 6/22/2009 2:12:23 PM BP EXPLORATION Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To Hours Task Code NPT - __ 5/30/2009 12:00 - 13:30 ~ 1.50 DRILL P 13:30 - 15:30 I 2.001 DRILL I P 15:30 - 21:00 I 5.501 DRILL I N 21:00 - 00:00 I 3.001 DRILL I N 5/31/2009 100:00 - 02:30 I 2.501 DRILL I N Page 12 of 17 Spud Date: 10/6/1991 Start: 5/17/2009 End: 6/8/2009 Rig Release: 6/9/2009 Rig Number: 9ES Phase Description of Operations PROD1 PROD1 DFAL PRODI DFAL I PROD1 DFAL IPRODI 02:30 - 07:30 I 5.001 DRILL I N I DFAL I PROD1 07:30 - 08:30 I 1.001 DRILL I N I DFAL I PROD1 08:30 - 09:00 I 0.501 DRILL I N I DFAL I PROD1 09:00 - 12:00 I 3.001 DRILL I P I I PROD1 12:00 - 00:00 I 12.001 DRILL I P I I PROD1 torque -ADT 1.95 hrs, ART 1.95 hrs, AST 0 hrs, Bit 7.69 hrs, Jars 7.69 hrs -Added 10 bbls of water per hour - No fluid loss noted. - MW in /out - 8.4 ppg Decrease of 500 psi surface pump pressure seen after having put bit on bottom at 10,282' MD with 225 psi motor differential. MWD signal was lost at the same time as the pressure drop occurred. Surface equipment was inspected and pressure tested with no issues. Different pump rates were used while alternating pumps without succeding to bring MWD tool back online. POH from 10,282' MD to 283' MD. POH wet on all connection and no washout found in the 4" DP. - MW in /out 8.4 ppg. POH to 4 3/4" PBL while inspecting all BHA components. Inspect 4 3/4" PBL -tool was closed. RIH with 4 3/4" PBL to just below the rotary table and pump at 266 gpm with 830 psi - neither flow or leaking was observed through PBL ports nor a pressure drop occurred. MWD signal was not gained. LD 4 3/4" PBL. Continue laying down BHA. No external evidence as to cause of failure on any of the BHA components. Inspect bit: grade 1-8-BT-G-E-1-CT-DTF. MU 6 1/8" drilling BHA #10 with the following components: 6 1/8" XR20D Smith Insert Bit, 1.83 deg bent mud motor, NM Flex LC, Impulse MWD, ADN4, 3 jts NM Flex LC, 4 3/4" PBL, 1 jt 4" HWDP, Jars, 1 jt 4" HWDP. Note: 1.83 deg bent housing mud motor, MWD and PBL are not the same from BHA #9. Total length of BHA #10 is 281.25'. RIH with 6 1/8" drilling BHA #10 on 4" DP stands from 283' MD to 750' MD. Shallow test MWD at 750' MD at 220 gpm with 869 psi -good test. Continue to RIH from 750' MD to 9795' MD. - MW in /out 8.4 ppg. PJSM, service top drive and install blower hose, service drawworks and crown. Continue to run in hole with 6 1/8" drilling BHA #10 from 9795' to 10,177'. Washed down from 10,177' to 10,282' at 6 bpm and 1860 psi while rotating at 40 rpm, and 3.7k ft-Ibs of torque. PUW 202k; SOW 148k; ROTW 165k. Drill ahead in 6 1/8" hole from 10,282' MD to 10,370' MD. - 250 gpm, 2020 psi on, 1850 psi off - 18k - 20k WOB, 40 rpm, 4.8k ft-Ibs torque on, 4.2k ft-Ibs torque off - 185k PUW, 144k SOW, 165k ROT Wt -ADT 1.18 hrs, ART 0.00 hrs, AST 1.18 hrs, Bit 1.18 hrs, Jars 9.05 hrs - Added 10 bbls of water per hour - No fluid loss noted. - MW in /out - 8.5 ppg Drill ahead in 6 1/8" hole from 10,370' MD to 10,995' MD. Pumping a survey at every joint. Printed: 6/22/2009 2:12:23 PM ~ ~ BP EXPLORATION Operations Summary Report Page 13 of 17 Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT ; Phase ~ Description of Operations 15/31/2009 12:00 - 00:00 12.001 DRILL P 16/1/2009 100:00 - 04:30 I 4.501 DRILL I P 04:30 - 05:00 I 0.501 DRILL I N I DFAL I PROD1 05:00 - 12:30 I 7.501 DRILL I N I DFAL I PROD1 12:30 - 14:00 I 1.501 DRILL I N I DFAL I PROD1 14:00 - 16:00 2.00 DRILL N DFAL PROD1 16:00 - 21:00 I 5.001 DRILL I N I DFAL I PROD1 21:00 - 22:00 1.00 DRILL P PROD1 22:00 - 23:00 1.00 DRILL N DFAL PROD1 23:00 - 00:00 1.00 DRILL P PROD1 PRODi - 252 gpm, 2084 psi on, 1965 psi off - 18k - 20k WOB, 40 rpm, 5k ft-Ibs torque on, 5k ft-Ibs torque off - 185k PUW, 144k SOW, 160k ROT Wt - ADT 7.19 hrs, ART 4.42 hrs, AST 2.77 hrs, Bit 8.37 hrs, Jars 16.24 hrs -Added 10 bbls of water per hour - No fluid loss noted. - MW in /out - 8.5 ppg Slow pump rates taken at 10,559' MD (8,866' TVD): - Pump 1:670 psi at 2 bpm, 780 psi at 3 bpm. - Pump 2: 680 psi at 2 bpm, 780 psi at 3 bpm. Drill ahead in 6 1/8" hole from 10 995' MD to 11 196' MD. - 250 gpm, 2080 psi on, 1960 psi off - 18k WOB, 40 rpm, 5.4k ft-Ibs torque on, 4k ft-Ibs torque off - 185k PUW, 144k SOW, 160k ROT Wt -Added 10 bbls of water per hour - No fluid loss noted. - MW in /out - 8.5 ppg There was rapid decrease in surface pump pressure (303 psi) and an increase in pump flow rate (12 gpm) in 3 minutes while sliding ahead with i8k WOB at 11,196' MD. MWD signal was lost immediately after the pressure drop. Surface equipment was inspected and pressure tested with no issues. POH wet from 11,196' MD to 11,016' MD . POH from 11,016' MD to 8,855' MD dry. Screw in top drive and pump at drilling rate at 9,795' MD and 8,855' MD at 254 gpm with 1147 psi without succeeding to bring MWD on. Continue to POH wet from 8,855' MD to 469' MD. POH dry from 469' MD to BHA (281' MD). POH to 4 3/4" PBL at 188' MD while inspecting all BHA components. Inspect 4 3/4" PBL -tool had a 1/2" plug missing located just below the spring allowing a flow path from the spring-loaded inner mandrel to the annulus. Continue laying down BHA. Inspect bit: grade 1-1-ER-A-E-I-WT-DTS. MU 6 1/8" drilling BHA #11 with the following components: 6 1/8" MX2011-A2 Hycalog PDC Bit, 1.50 deg bent mud motor AIM, NM Stabilizer, NM Flex LC, Impulse MWD, ADN4, 3 jts NM Flex DC, 4 3/4" PBL, 1 jt 4" HWDP, Jars, 1 jt 4" HWDP. Note: MWD and PBL are not the same from BHA #10. RIH with 6 1/8" drilling BHA #11 on 4" DP stands from 293' MD to 9807' MD. Shallow test MWD at 1987' MD at 247 gpm with 854 psi -good test. Continue to RIH from 1987' MD to 9807' MD. - MW in /out 8.4 ppg. Cut and slip 59' of drilling line. Service Top Drive. RIH from 9807' MD to 10880' MD. - MW in /out 8.4 ppg. MAD Pass in the UP direction from 10880' MD to 10570' MD at 720 ft/hr while pumping at 257 gpm with 1786 psi and rotating at 50 rpm with 5.Ok ft-Ibs torque. PUW 190k, SOW 140k, ROTW 160k. PROD1 Printed: 6/22/2009 2:72:23 PM ~ ~ BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task ' Code I NPT Phase Description of Operations i - 6/1/2009 23:00 - 00:00 1.00 --_ _. DRILL _ P _ _ __ __ PROD1 - MW in /out 8.4 ppg. 6/2/2009 00:00 - 01:00 1.00 DRILL N DFAL PROD1 RIH from 10,570' MD to 11,196' MD. Wash and ream to bottom; no fill encountered. 01:00 - 12:00 11.00 DRILL P PROD1 Drill ahead 6 1/8" production hole from 11,196' MD to 11,588' MD. 185k up, 140k down, 161 k rotating. 1995psi on, 1740psi off @ 250gpm. Torque: 6.3k on, 4.1 k off C~ 80rpm. MW in/out = 8.5ppg. No problems losing fluid; added 10 bbls of water per hour to mud system. Lube 776 concentration up to 2% v/v for torque and drag control. AST = 3.4hrs, ART = 1.95hrs. 12:00 - 00:00 12.00 DRILL P PROD1 Drill ahead from 11,588' MD to 12,074' MD. 185k up, 135k down, 160k rotating. 2489psi on, 2190psi off @ 252gpm. Torque: 7k on, 4k off C~ 80rpm. MW in/out = 8.6ppg; pump 25-50bb1 high-tube and Alpine bead sweeps for torque and drag control. Lube 776 concentration increased to 3% v/v. AST = 3.58hrs, ART = 2.93hrs. 6/3/2009 00:00 - 12:00 12.00 DRILL P PROD1 PJSM. Drill ahead from 12,074' MD to 12,350' MD in 6-1/8" production hole. Pump pressure over last 12 hrs has increased -700psi; potentially due to clogged nozzles; arctic bead sweeps aiding in sliding. 185k up, 135k down, 160k rotating. 2225psi on, 1995psi off @ 252gpm. Torque: 7.6k on, 4.3k off C~ 17k WOB and 80rpm. 12:00 - 17:30 5.50 DRILL P PROD1 Drill 6-1/8" production hole from 12.350 to interval TD Co3 i 12,820' MD, 8810' TVD. 195k up, 130k down, 160k rotating. 2052psi off, 2351 psi on ~ 254gpm. Torque: 8k on, 5k off, 80rpm and 12k WOB. AST = 4.62hrs, ART = 6.30hrs. 17:30 - 19:00 1.50 DRILL P PROD1 Circulate and reciprocate to clean hole before backreaming out. Pump 10ppg sweep; 2050psi C~ 252gpm, reciprocating in 55' strokes. 190k up, 135k down, 160k rotating (205k up, 140k down w/o circ). 5k torque, 80 rpm. 19:00 - 00:00 5.00 DRILL P PROD1 Backream out from 12,820' to 10,284'. 1809psi ~ 252gpm and 80rpm. 200k up, 150k down. No difficulty backreaming or excessive overpulls throughout backreaming section. 6/4/2009 00:00 - 00:30 0.50 DRILL P PRODi PJSM. Backream out from 10,284' to inside the 7" shoe C~ 9821' MD. 00:30 - 01:30 1.00 DRILL P PROD1 Drop 1.5" vinyl ball to function and open PBL sub; pressure before sub opens = 1625psi, pressure after opening = 960psi ~ 252gpm. Circulate bottoms-up at max rate of 450gpm through open PBL sub to clean casing. 01:30 - 02:30 1.00 DRILL P PROD1 Drop two steel balls to close PBL sub and pump down; no pressure indication that balls hit and functioned sub. 02:30 - 03:00 0.50 DRILL P PROD1 Pump dry job; once dry job is pumped away, drop 2-5/16" drift down DP and prep to POOH wet. 03:00 - 08:30 5.50 DRILL P PROD1 POOH from 7" shoe ~ 9821' MD to 3960' MD, racking back 4" DP; pipe pulled dry for -14 stands, then wet for remainder of POOH. 08:30 - 12:00 3.50 DRILL P PROD1 Break out 6-1/8" drilling BHA and LD Hycalog MX2011-A2 bit, 1.5deg bend motor, stabilizers and Impulse MWD. Bit grade: 1-1-PN-S-X-I-CT-TD. PBL sub balls all found in ball catcher; tool in closed position. Rubber (suspected from mud motor) found in drill bit nozzle. Clean and clear floor of third party tools. 12:00 - 13:00 1.00 CASE P RUNPRD PJSM. RU for 4.5", 12.6# L-80 IBT roduction liner run. RU air slips, c/o elevators. Printed: 6/22/2009 2:12:23 PM BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date 6/4/2009 From - To 'Hours Task ', Code'' NPT 13:00 - 17:00 4.00 CASE P 17:00 - 19:00 19:00 - 00:00 6/5/2009 00:00 - 05:30 05:30 - 07:30 07:30 - 11:00 2.001 CASE I P 5.001 CASE I P 5.501 CASE I P 2.001 CEMT I P 3.501 CEMT I P Phase Description of Operations RUNPRD MU and run 74 joints of 4.5" solid production liner from surface to 3199' MD. Baker-Lok connections below the landing collar, and lock down a centralizer on the first joint of the shoe track, 5' from bottom. Check floats; good. Fill on the fly, top off liner every 10 joints while running. RUNPRD MU Baker liner top hanger, ZXP liner top packer and DP joint w/liner running tool. Pour PalMix and allow to set for 30min. RIH w/liner and running tool. Circulate 1.5 of liner volume 344psi, 213gpm. Liner: 75k up, 70k down. RUNPRD RIH w/ 4.5" production liner from 3199' MD to 9000' MD on 4" DP; fill DP every 10 stands and record up and down weights. RUNPRD PJSM. Run 4.5" production liner from 9000' MD to just inside 7" liner shoe C~ 9821'. Circulate annular volume to surface before continuing into open hole. RIH w/liner on 4" DP from 9821' to production hole TD ~ 12,820' MD. Hole taking weight starting (~ -12,000' MD; likely due to dogleg build and Kavik shale formation. Work pipe down slowly- breaking over C~? 225k up weight, slacking off to block weight. Attempt to wash liner down with mixed results; pumping at 2bpm, pressure building to 1200psi and falling off to around 800-900psi. Full returns when pumping. Work down last 7 stands in this manner. RUNPRD Tag up w/ 4.5" production liner ~ 12,820' MD; PU two feet off bottom. MU cement head on top of DP single in prep for cement job. Stage up pumps and break circulation; circulate 2x annular volume, reciprocating in 10' strokes. Circulate and condition 1525psi C~ 210gpm. RUNPRD PJSM w/SLB cementers. Pump production liner cement iob as follows: 07:31 Pump 5bbl 11.0 MudPush, test lines to 4500psi; good. 07:41 Pump 15bb1 11.Oppg MudPush away. 07:46 Start pumping 15.8ppg Class G cement w/ GasBlok ~ 5bbl/min. 07:53 30bb1 cement away, 5.4bpm, 1712psi 07:58 59bb1 cement away, 5.6bpm, 1566psi 08:00 69bb1 cement away, 5.6bpm, 1566psi 08:03 Finished cement pumping: 81.5bbls Class G cement pumped. 08:04 Isolate SLB unit and knock cement line off DP. 08:16 Install 1502 cap on cement head and drop dart. Kick plug out with pert pill and displace job with rig pumps. Positive indication that dart dropped. 08:32 Chase cement; 5bpm, 1280psi. 08:38 Slow pump rate from 5bpm to 3bpm. 08:41 Plug latched up ~ 1657strokes, 96.6bbls away. 08:57 Plug bump ~ 2458strokes, 143bb1s away. Final pumping rate of 3bpm, final pumping pressure 1820psi. CIP l~ 08:57hrs Printed: 6/22/2009 2:12:23 PM • BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To ~ Hours Task Code NPT 6/5/2009 107:30 - 11:00 I 3.501 CEMT I P Phase Description of Operations --_. . RUNPRD At plug bump, continue to pressure up to 2800psi to set liner hanger as per Baker hand. Set down 85k; hanger did not set. Pressure up to 3000psi and set down 80k; hanger set. Pressure up to 4100psi and hold to release running tool. Bleed off pressure before picking up to expose dog sub and slack off to set ZXP liner top packer. Pick up out of liner top and circulate at max rate to clean liner top; 1680psi ~ 520gpm. Reciprocate pipe in 15' strokes while circulating; 19bbls cement returned to surface. 11:00 - 13:00 ~ 2.00 CEMT ~ P 13:00 - 19:00 I 6.001 CEMT I P 19:00 - 19:30 ~ 0.50 ~ CASE ~ P 19:30 - 00:00 4.501 PERFOf3~ P 6/6/2009 100:00 - 01:00 I 1.001 PERFOBI P 01:00 - 02:00 ( 1.001 PERFOB~ N WAIT 02:00 - 04:30 ~ 2.501 PERFOB~ P 04:30 - 06:00 I 1.501 PERFOf31 P 06:00 - 12:00 I 6.001 PERFOf31 P 12:00 - 13:00 I 1.001 PERFOBI P 13:00 - 15:00 2.00 ~ PERFOB~ P 15:00 - 23:30 I 8.501 PERFOBI P Cement job volume: 81.5 bbls Class G cement w/ Gas Blok, 408 sacks C~3 1.17cuft/sx. No losses during cement job. RUNPRD RD cementing head and circulate wellbore over to clean 8.5ppg seawater before POOH. Clean possum belly and troughs of any residual cement. Monitor well; static. RUNPRD POOH from 4.5" production liner top @ 9659' MD to surface. LD 93 joints of 4" DP and rack back remaining DP for upcoming perforation run. Break out and LD Baker liner running tool; dog sub sheared. RUNPRD Close blind rams and pressure up by pumping down the kill; pressure test 4.5", 12.6# production liner to 3500psi for 30 min. Chart test; good. Omin = 3550psi 15min = 3550psi 30min = 3550psi ~~j OTHCMP PJSM with SLB perforating crew; RU pert gun running eauinment~nd PU 2-7/8" Omega PowerShot, 6spf perforating guns. Run guns spaced out with 2-7/8" FOX tubing. OTHCMP PJSM. Continue to RIH w/ perforating assembly and 2-7/8" FOX tubing. Run a total of 1170' live guns. OTHCMP Perf gun disconnect damaged; unable to properly torque to gun assembly. Wait on new disconnect to be delivered to rig. OTHCMP RIH w/ 2-7/8" OmegaPowerJet pert guns on 2-7/8" FOX tubing, from surface to 3410' MD. OTHCMP RD handling equipment for 2-7/8" FOX tubing. RU 4" DP handling equip, MU crossover to HT40 connection. OTHCMP RIH w/ perforating assembly and FOX tubing on 4" DP from 3410' to tag-up depth C~3 12,736'. Minimize pipe dope use to prevent clogging firing head. Allow pipe to fill w/ 8.5ppg seawater via ported sub while running in. OTHCMP Tag landing collar ~ 12,736'; 185k up, 145k down. PU 15' over upweight to bring guns on depth. Initiate firing sequence as per SLB hand; first set of guns fired ~ 12:55hrs, second set of guns fired ~ 12:56hrs. Good indication at surface that guns ~ fired. 3bbl initial fluid loss after firing. Top shot C~ 10,730' MD, bottom shot ~ 12,720' MD. OTHCMP Pull up above perforations to 10,662' MD and circulate; 1065psi ~ 277gpm. Lost 20bbls of fluid while circulating. OTHCMP TOH w/ pert gun assy, FOX tubing and 4" DP. Lay down all drill pipe in prep for completion run. Printed: 6/22/2009 2:12:23 PM • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: 02-33 Common Well Name: 02-33 Spud Date: 10/6/1991 Event Name: REENTER+COMPLETE Start: 5/17/2009 End: 6/8/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/9/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours ' Task Code NPT i Phase 6/6/2009 23:30 - 00:00 0.50 PERT 6/7/2009 00:00 - 08:30 8.50 PERT 08:30 - 09:30 1.00 PER 09:30 - 12:00 2.50 RUN 12:00 - 00:00 12.00 RUN I 6/8/2009 00:00 - 03:30 3.50 RUN 03:30 - 05:30 I 2.001 RUN 05:30 - 08:00 I 2.50 08:00 - 10:00 2.00 BUNCO P 10:00 - 13:00 3.00 BOPSU P 13:00 - 16:30 3.50 WHSUR P 16:30 - 19:30 3.00 WHSUR P 19:30 - 00:00 4.50 WHSUR P Description of Operations P OTHCMP Change out to 2-7/8" FOX tubing handling equipment and POOH, laying down FOX tubing. P OTHCMP PJSM. POOH w/ 2-7/8" PowerJet 9606 6spf pert assy spaced out with 2-7/8" FOX tubing. LD FOX while POOH. Additional PJSM w/ SLB perforating crew before bringing guns to surface. All shots fired on guns. P OTHCMP RD pert gun running equipment, dispose of pert debris, clean and clear rig floor of third party tools. P RUNCMP Prep for completion run; pull wear ring and flush BOP stack. RU to run 4.5" 12.6# 13Cr-80 VamTop completion; RU power tongs, compensator and stabbing board. P RUNCMP PJSM w/ Nabors casing hand. Run 4.5" 13Cr-80 VamTop tubing from surface to 8417' MD. BakerLok all connections below Baker S-3 Packer. Utilize compensator and stabbing board to MU joints. Torque-turn all connections to 4440ft-Ibs. P RUNCMP PJSM. Run 4.5", 12.6# 13Cr-80 VamTop completion from 8417' MD to depth inside PBR (bottom Cad 9671'MD). Completion weight; 147k up, 115k down. Tag up inside PBR and LD three joints of tubing; PU 9.86' and 7.84' pups and space out completion. PU final joint and tubing hanger. MU landing joint and RIH; land completion. P RUNCMP RILDS as per FMC hand. LD landing joint and break circulation. Reverse circulate 148bb1s clean seawater, 43bbls corrosion inhibited seawater and 124bb1s clean seawater; pump 275psi @ 3bpm. P RUNCMP MU landing joint, and drop 1-7/8" ball and rod. Close rams, and pressure up against ball and rod to 3500psi to set Baker S-3 rod. acker. Hold ressure for 30min to test tubin ,and chart; good. Bleed tubin to 2000 si; ressure u annulus to _ 3500 si to test for 30min. Chart test; ood. Bleed tubing and shear DCK valve; good indication of shear. Bleed off pressure ~_, and establish circulation through DCK; pump 2bbls eac way. 700psi circulating pressure. RUNCMP Install TWC w/ T-bar as~per F~MC~~ Test from below and above o psi, iUmi'n eac ; gh ood. Blow down surface lines and drain stack in prep for ND. RUNCMP ND BOPs: null mouse hole, riser, turnbuckles. RUNCMP NU ada ter flan a an 4-1/1 " t RU DSM and test lubricator to 500psi; lubricate out TWC. RUNCMP RU LRHOS; reverse circulate 85bbls diesel to freeze protect well to 2200' TVD. Allow diesel to U-tube from annulus to tubing. RUNCMP RU DSM and install BPV; test from below to 1000psi. Prep to RDMO. Rig release ~ OO:OOhrs, 6/9/09. Printed: 6/22/2009 2:12:23 PM ---- --- - - - Sc lu ~~ air u~u~-ssa purve y rieport ,. Report Date: 5-Jun-09 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 322.800° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: DS-02102-33 TVD Reference Datum: Rotary Table Well: 02-33 TVD Reference Elevation: 58.60 ft relative to MSL Borehole: 02-336 Sea Bed /Ground Level Elevation: 30.10 ft relative to MSL UWI/API#: 500292221402 Magnetic Declination: 22.784° Survey Name !Date: 02.338 /June 5, 2009 Total Field Strength: 57714.509 nT Tort /AHD / DDI / ERD ratio: 324.846° / 6714.12 ft / 6.496 / 0.753 Magnetic Dip: 80.919° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: May 24, 2009 Location LaULong: N 701611.302, W 148 28 57.770 Magnetic Declination Model: BGGM 2008 Location Grid NIE Y/X: N 5950574.700 ftUS, E 687604.160 ftUS North Reference: True North Grid Convergence Angle: +1.42824852° Total Corr Mag North -> True North: +22.784° Grid Scale Factor: 0.99993998 Local Coordinates Referenced To: Well Head CJ Comments Measured D h Inclination Azimuth Subsea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Eastin L tit d L it d ept True Section Departure True North True North g a u e ong u e ft de de ft ft ft ft ft ft it de 100 ft ftUS ftUS Projected-Uo 0.00 0.00 n nn -5R hn n nn n nn n nn n nn n nn ., ~., „ ~~ ~,,.-,.~~. ~„ ,...~,.,,..., .. _...,.....__ ....._ __ __ ___ WRP 28.60 - -- 0.00 ---- 0.00 -- -30 -- .00 -'-- 28.60 0.00 0.00 0.00 0.00 0.00 v.VV 0.00 oJOVO/w./V 5950574.70 o0/OV4.Ib 687604.16 IV /U Ib 11.3UZ VV 1425 N 70 16 11.302 W 148 Z23b/ 28 57 .//U .770 BOSS GYRO 92.60 0.29 340.40 34 .00 92.60 0.15 0.16 0.16 0.15 -0.05 0.45 5950574.85 687604.10 N 70 16 11 .304 W 148 28 57 .772 192.60 0.37 1.30 134 .00 192.60 0.65 0.73 0.73 0.71 -0.13 0.14 5950575.41 687604.01 N 70 16 11 .309 W 148 28 57 .774 292.60 0.26 278.40 234 .00 292.60 1.06 1.19 1.13 1.07 -0.35 0.43 5950575.76 687603.78 N 70 16 11 .313 W 148 28 57 .780 392.60 0.09 320.70 334 .00 392.60 1.30 1.49 1.32 1.16 -0.62 0.20 5950575.85 687603.51 N 70 16 11 .313 W 148 28 57 .788 492.60 0.23 301.10 434 .00 492.60 1.57 1.77 1.57 1.33 -0.84 0.15 5950576.01 687603.28 N 70 16 11 .315 W 148 28 57 .795 592.60 0.27 285.10 534 .00 592.60 1.94 2.20 1.94 1.49 -1.24 0.08 5950576.16 687602.88 N 70 16 11 .317 W 148 28 57 .806 692.60 0.25 258.50 633 .99 692.59 2.22 2.65 2.26 1.51 -1.69 0.12 5950576.17 687602.44 N 70 16 11 .317 W 148 28 57 .819 792.60 0.30 123.70 733 .99 792.59 2.07 2.95 2.14 1.32 -1.68 0.51 5950575.98 687602.45 N 70 16 11 .315 W 148 28 57 .819 892.60 0.55 83.70 833. 99 892.59 1.58 3.66 1.58 1.23 -0.99 0.37 5950575.90 687603.14 N 70 16 11 .314 W 148 28 57 .799 992.60 0.63 81.50 933. 99 992.59 1.07 4.69 1.36 1.36 0.03 0.08 5950576.06 687604.16 N 70 16 11 .315 W 148 28 57 . 1092.60 0.46 118.10 1033. 98 1092.58 0.44 5.61 1.56 1.26 0.93 0.38 5950575.98 687605.06 N 70 16 11 .314 W 148 28 57 .~ 1192.60 0.39 127.90 1133. 98 1192.58 -0.26 6.35 1.78 0.86 1.55 0.10 5950575.60 687605.69 N 70 16 11 .310 W 148 28 57 .725 1292.60 0.32 131.90 1233. 98 1292.58 -0.86 6.97 2.08 0.46 2.03 0.07 5950575.21 687606.18 N 70 16 11 .307 W 148 28 57. 711 1392.60 0.45 95.30 1333. 97 1392.57 -1.40 7.62 2.64 0.24 2.63 0.27 5950575.00 687606.78 N 70 16 11 .304 W 148 28 57. 694 1492.60 0.34 102.40 1433. 97 1492.57 -1.89 8.31 3.31 0.14 3.31 0.12 5950574.92 687607.47 N 70 16 11 .303 W 148 28 57. 674 1592.60 0.08 166.00 1533. 97 1592.57 -2.18 8.65 3.62 0.01 3.62 0.31 5950574.80 687607.78 N 70 16 11 .302 W 148 28 57. 665 1692.60 0.21 252.20 1633. 97 1692.57 -2.18 8.87 3.46 -0.12 3.46 0.22 5950574.67 687607.62 N 70 16 11 .301 W 148 28 57. 670 1792.60 0.33 195.10 1733. 97 1792.57 -2.30 9.30 3.24 -0.45 3.21 0.28 5950574.33 687607.38 N 70 16 11 .298 W 148 28 57. 677 1892.60 0.31 140.70 1833. 97 1892.57 -2.75 9.82 3.44 -0.94 3.31 0.29 5950573.85 687607.49 N 70 16 11 .293 W 148 28 57. 674 1992.60 0.36 .89.80 1933. 97 1992.57 -3.21 10.37 3.96 -1.15 3.79 0.29 5950573.65 687607.98 N 70 16 11 .291 W 148 28 57. 660 2092.60 0.79 38.10 2033. 96 2092.56 -3.22 11.31 4.57 -0.60 4.53 0.63 5950574.21 687608.71 N 70 16 11 .296 W 148 28 57. 638 SurveyEditor Ver SP 2.1 Bld( users) 02-33\02-33\02-336\02-336 Generated 7/1/2009 11:29 AM Page 1 of 6 2192.60 0.65 22.20 2133.95 2192.55 -2.76 12.56 5.19 0.47 5.17 0.24 5950575 .29 687609 .32 N 70 16 11 .307 W 148 28 57 .621) 2292.60 0.62 25.40 2233.95 2292.55 -2.22 13.67 5.81 1.48 5. 62 0.05 5950576 .32 687609 .74 N 70 16 11 .317 W 148 28 57 .607 2392.60 0.70 23.60 2333.94 2392.54 -1.67 14.82 6.60 2.53 6. 09 0.08 5950577 .38 687610 .19 N 70 16 11 .327 W 148 28 57 .593 2492.60 1.04 32.20 2433.93 2492.53 -1.05 16.34 7.84 3.86 6. 82 0.36 5950578 .72 687610 .88 N 70 16 11 .340 W 148 28 57 .572 2592.60 1.47 55.20 2533.91 2592.51 -0.79 18.50 9.93 5.36 8. 36 0.65 5950580 .26 687612. 38 N 70 16 11 .355 W 148 28 57 .527 2692.60 1.69 72.60 2633.87 2692.47 -1.34 21.24 12.64 6.53 10. 82 0.53 5950581 .50 687614. 81 N 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8698.44 8757.04 3988.85 4294.94 3996.65 3328.12 -2212.86 22.04 5953846.43 685309.17 N 70 16 44.031 W 148 30 2.21 10388.09 53.22 338.36 8718.24 8776.84 4012.01 4318.99 4020.17 3350.46 -2221.75 17.33 5953868.54 685299.73 N 70 16 44.251 W 148 30 2. 10419.69 57.74 338.81 8736.15 8794.75 4037.06 4345.02 4045.62 3374.70 -2231.25 14.35 5953892.53 685289.63 N 70 16 44.489 W 148 30 2.751 10452.42 58.90 338.32 8753.33 8811.93 4063.86 4372.87 4072.87 3400.62 -2241.43 3.77 5953918.19 685278.81 N 70 16 44.744 W 148 30 3.048 10483.46 59.25 340.16 8769.29 8827.89 4089.40 4399.49 4098.85 3425.52 -2250.87 5.21 5953942.84 685268.76 N 70 16 44.989 W 148 30 3.323 10515.23 61.84 338.07 8784.91 8843.51 4115.95 4427.15 4125.87 3451.36 -2260.73 9.96 5953968.43 685258.25 N 70 16 45.243 W 148 30 3.611 10547.23 66.20 337.76 8798.92 8857.52 4143.71 4455.91 4154.09 3478.01 -2271.55 13.65 5953994.80 685246.78 N 70 16 45.505 W 148 30 3.926 10579.21 66.30 336.11 8811.80 8870.40 4172.10 4485.19 4182.91 3504.94 -2283.01 4.73 5954021.43 685234.64 N 70 16 45.770 W 148 30 4.260 10610.71 70.21 336.81 8823.47 8882.07 4200.52 4514.44 4211.76 3531.76 -2294.70 12.58 5954047.95 685222.30 N 70 16 46.033 W 148 30 4.600 10642.96 73.74 336.23 8833.45 8892.05 4230.31 4545.10 4242.00 3559.88 -2306.91 11.08 5954075.76 685209.38 N 70 16 46.310 W 148 30 4.957 10674.85 76.64 335.99 8841.60 8900.20 4260.31 4575.93 4272.45 3588.07 -2319.40 9.12 5954103.62 685196.20 N 70 16 46.587 W 148 30 5.320 10706.24 80.35 335.71 8847.86 8906.46 4290.27 4606.68 4302.85 3616.13 -2331.98 11.85 5954131.36 685182.92 N 70 16 46.863 W 148 30 5.687 10738.97 83.50 336.87 8852.46 8911.06 4321.78 4639.08 4334.85 3645.80 -2345.01 10.24 5954160.69 685169.16 N 70 16 47.155 W 148 30 6.067 10769.11 83.87 336.33 8855.77 8914.37 4350.87 4669.04 4364.41 3673.29 -2356.91 2.16 5954187.88 685156.58 N 70 16 47.425 W 148 30 6.414 10801.90 87.52 334.97 8858.23 8916.83 4382.74 4701.73 4396.76 3703.07 -2370.39 11.87 5954217.31 685142.36 N 70 16 47.718 W 148 30 6.806 10834.28 88.66 331.45 8859.31 8917.91 4414.56 4734.09 4428.95 3731.95 -2384.97 11.42 5954245.82 685127.07 N 70 16 48.002 W 148 30 7.231 10866.17 90.24 328.89 8859.62 8918.22 4446.19 4765.98 4460.79 3759.61 -2400.83 9.43 5954273.08 685110.52 N 70 16 48.274 W 148 30 7.694 10897.78 90.82 328.92 8859.33 8917.93 4477.61 4797.59 4492.39 3786.68 -2417,15 1.84 5954299.73 685093.53 N 70 16 48.540 W 148 30 8.169 10930.06 89.14 331.12 8859.34 8917.94 4509.64 4829.87 4524.64 3814.64 -2433.28 8.58 5954327.27 685076.71 N 70 16 48.815 W 148 30 8~ 10961.96 89.41 330.63 8859.74 8918.34 4541.22 4861.77 4556.48 3842.50 -2448.81 1.75 5954354.74 685060.50 N 70 16 49.089 W 148 30 9. 10993.27 91.23 329.69 8859.57 8918.17 4572.27 4893.07 4587.75 3869.66 -2464.39 6.54 5954381.50 685044.25 N 70 16 49.356 W 148 30 9.546 11025.84 93.05 329.47 8858.35 8916.95 4604.58 4925.62 4620.28 3897.73 -2480.87 5.63 5954409.14 685027.07 N 70 16 49.632 W 148 30 10.026 11057.41 93.77 327.69 8856.47 8915.07 4635.94 4957.13 4651.78 3924.62 -2497.29 6.07 5954435.61 685009.98 N 70 16 49.896 W 148 30 10.505 11121.54 92.12 329.69 8853.18 8911.78 4699.64 5021.18 4715.81 3979.33 -2530.57 4.04 5954489.48 684975.35 N 70 16 50.434 W 148 30 11.474 11153.16 92.43 329.66 8851.92 8910.52 4731.01 5052.77 4747.39 4006.60 -2546.52 0.98 5954516.34 684958.73 N 70 16 50.703 W 148 30 11.939 11186.17 92.75 330.58 8850.43 8909.03 4763.71 5085.75 4780.33 4035.20 -2562.95 2.95 5954544.52 684941.59 N 70 16 50.984 W 148 30 12.418 11218.31 92.30 332.15 8849.02 8907.62 4795.46 5117.86 4812.37 4063.38 -2578.34 5.08 5954572.30 684925.51 N 70 16 51.261 W 148 30 12.866 11250.37 92.20 331.69 8847.76 8906.36 4827.09 5149.89 4844.31 4091.64 -2593.42 1.47 5954600.18 684909.73 N 70 16 51.539 W 148 30 13.306 11281.98 91.38 332.56 8846.77 8905.37 4858.27 5181.49 4875.81 4119.57 -2608.19 3.78 5954627.73 684894.27 N 70 16 51.813 W 148 30 13.736 11313.60 91.21 332.94 8846.05 8904.65 4889.41 5213.10 4907.30 4147.67 -2622.66 1.32 5954655.46 684879.10 N 70 16 52.090 W 148 30 14.158 SurveyEditor Ver SP 2.1 Bld( users) 02-33\02-33\02-338\02-336 Generated 7/1/2009 11:29 AM Page 4 of 6 11345.51 91.24 333.20 8845.37 11376.69 89.66 334.28 8845.13 11409.30 89.11 334.18 8845.48 11441.36 88.15 334.87 8846.24 11472.52 87.88 334.77 8847.32 11503.47 87.98 334.69 8848.44 11536.55 88.91 333.91 8849.34 11568.31 90.35 331.39 8849.54 11600.22 92.68 329.36 8848.70 11632.38 93.26 330.13 8847.03 11663.63 93.06 329.77 8845.31 11695.81 92.85 329.74 8843.65 11727.80 92.61 329.12 8842.13 11759.59 92.75 327.88 8840.64 11791.42 93.06 325.43 8839.03 11823.41 92.89 325.22 8837.37 11855.34 93.09 326.04 8835.70 11887.19 93.61 327.44 8833.84 11919.86 93.61 327.42 8831.78 11951.19 91.99 329.12 8830.25 11982.81 90.49 326.27 8829.57 12014.58 90.35 325.82 8829.34 8903.97 4920.80 8903.73 4951.41 8904.08 4983.37 8904.84 5014.75 8905.92 5045.21 8907.04 5075.47 8907.94 5107.88 8908.14 5139.16 8907.30 5170.78 8905.63 5202.66 8903.91 5233.62 8902.25 5265.52 5245.00 5276.18 5308.79 5340.84 5371.98 5402.91 5435.98 5467.73 5499.63 5531.75 5562.95 5595.09 4939.06 4970.07 5002.47 5034.30 5065.21 5095.93 5128.79 5160.44 5192.31 5224.41 5255.60 5287.72 8900.73 5297.26 5627.04 5319.66 8899.24 5328.86 5658.80 5351.42 8897.63 5360.57 5690.59 5383.19 8895.97 5392.49 5722.53 5415.10 8894.30 5424.34 5754.42 5446.96 8892.44 5456.06 5786.21 5478.75 8890.38 5488.55 5818.82 5511.35 8888.85 5519.70 5850.11 5542.64 8888.17 5551.20 5881.72 5574.25 8887.94 5582.91 5913.49 5606.00 12046.33 90.07 324.52 8829.22 8887.82 5614.64 5945.24 5637.71 12077.87 90.01 323.31 8829.20 8887.80 5646.17 5976.78 5669.17 12111.19 90.55 323.75 8829.04 8887.64 5679.49 6010.10 5702.39 12141.85 91.88 321.99 8828.39 8886.99 5710.14 6040.75 5732.92 12174.41 95.33 323.18 8826.34 8884.94 5742.63 6073.24 5765.28 12206.22 95.88 323.98 8823.23 8881.83 5774.28 6104.90 5796.84 12238.06 93.44 323.12 8820.64 8879.24 5806.01 6136.63 5828.49 12269.32 91.94 317.71 8819.18 8877.78 5837.20 6167.86 5859.44 12301.75 94.92 317.18 8817.24 8875.84 5869.42 6200.23 5891.28 12333.33 96.46 315.62 8814.11 8872.71 5900.65 6231.65 5922.10 12365.11 97.26 315.42 8810.31 8868.91 5931.95 6263.20 5952.95 12397.44 98.30 316.71 8805.93 8864.53 5963.76 6295.24 5984.33 12429.13 98.26 315.88 8801.37 8859.97 5994.92 6326.59 6015.09 12524.52 98.19 315.82 8787.72 8846.32 6088.63 6421.00 6107.59 12579.05 97.74 316.34 8780.17 8838.77 6142.26 6475.01 6160.56 12619.15 97.44 316.85 8774.87 8833.47 6181.78 6514.76 6199.64 12715.35 96.91 317.08 8762.85 8821.45 6276.73 6610.20 6293.60 Last Survey 12765.93 96.74 317.79 8756.84 8815.44 6326.73 6660.42 6343.13 TD (Projected) 12820.00 96.74 317.79 8750.50 8809.10 6380.22 6714.12 6396.15 Survey Type: Definitive Survey NOTES: BOSS Gyro - (Sperry-Sun BOSS gyro multishot -- Sperry Sun BOSS multishot surveys ) 4176.12 -2637.11 4204.08 -2650.91 4233.44 -2665.08 4262.38 -2678.87 4290.56 -2692.12 4318.53 -2705.32 4348.32 -2719.66 4376.53 -2734.25 4404.26 -2750.02 4432.00 -2766.20 4459.01 -2781.82 4486.77 -2798.01 4514.28 -2814.26 4541.36 -2830.86 4567.91 -2848.33 4594.18 -2866.50 4620.50 -2884.50 4647.09 -2901.94 4674.57 -2919.49 4701.18 -2935.95 4727.90 -2952.84 4754.25 -2970.59 4780.31 -2988.72 4805.80 -3007.30 4832.59 -3027.10 4857.03 -3045.60 4882.83 -3065.34 4908.31 -3084.14 4933.83 -3102.99 4957.89 -3122.88 4981.73 -3144.77 5004.49 -3166.44 5027.00 -3188.55 5050.06 -3210.77 5072.73 -3232.44 5140.47 -3298.20 5179.37 -3335.66 5208.25 -3362.97 5278.02 -3428.11 5315.01 -3462.08 5354.78 -3498.16 0.82 5954683.53 6.14 5954711.14 1.71 5954740.14 3.69 5954768.72 0.92 5954796.56 0.41 5954824.19 3.67 5954853.62 9.14 5954881.45 9.68 5954908.77 2.99 5954936.10 1.32 5954962.71 0.66 5954990.06 2.08 5955017.16 3.92 5955043.81 7.75 5955069.92 0.84 5955095.73 2.64 5955121.59 4.68 5955147.73 0.06 5955174.76 7.49 5955200.95 10.18 5955227.24 1.48 5955253.14 4.19 5955278.74 3.84 5955303.75 2.09 5955330.04 7.19 5955354.01 11.21 5955379.31 3.04 5955404.31 8.12 5955429.36 17.94 5955452.91 9.33 5955476.20 6.92 5955498.40 2.59 5955520.36 5.10 5955542.86 2.59 5955564.98 0.10 5955631.06 1.25 5955669.01 684863.95 684849.46 684834.56 684820.06 684806.11 684792.21 684777.14 684761.85 684745.40 684728.53 684712.24 684695.36 684678.43 684661.17 684643.05 684624.22 684605.57 684587.48 684569.25 684552.13 684534.58 684516.19 684497.41 684478.21 684457.74 684438.64 684418.26 684398.84 684379.36 684358.87 684336.40 684314.17 684291.51 684268.72 684246.49 684179.07 684140.65 N 70 16 52.369 W 148 30 14.57~d N 70 16 52.644 W 148 30 14.982 N 70 16 52.933 W 148 30 15.395 N 70 16 53.218 W 148 30 15.797 N 70 16 53.495 W 148 30 16.183 N 70 16 53.770 W 148 30 16.568 N 70 16 54.063 W 148 30 16.986 N 70 16 54.340 W 148 30 17.411 N 70 16 54.613 W 148 30 17.870 N 70 16 54.886 W 148 30 18.342 N 70 16 55.151 W 148 30 18.797 N 70 16 55.424 W 148 3019.269 N 70 16 55.695 W 148 30 19.743 N 70 16 55.961 W 148 30 20.2 N 70 16 56.222 W 148 30 20. N 70 16 56.480 W 148 30 21. N 70 1656.739 W 148 30 21.790 N 70 16 57.000 W 148 30 22.298 N 70 16 57.271 W 148 30 22.810 N 70 16 57.532 W 148 30 23.289 N 70 16 57.795 W 148 30 23.782 N 70 16 58.054 W 148 30 24.299 N 70 16 58.310 W 148 30 24.827 N 70 16 58.561 W 148 30 25.369 N 70 16 58.824 W 148 30 25.946 N 70 16 59.065 W 148 30 26.485 N 70 16 59.318 W 148 30 27.061 N 70 16 59.569 W 148 30 27.608 N 70 16 59.820 W 148 30 28.158 N 70 17 0.056 W 148 30 28.738 N 70 17 0.291 W 148 30 29.375 N 70 17 0.514 W 148 30 30.007 N 70 17 0.736 W 148 30 30~ N 70 17 0.963 W 148 30 31.299 N 70 17 1.185 W 148 30 31.930 N 70 17 1.851 W 148 30 33.847 N 70 17 2.234 W 148 30 34.938 1.47 5955697.19 684112.63 N 70 17 2.518 W 148 30 35.735 0.60 5955765.31 684045.78 N 70 17 3.203 W 148 30 37.633 1.43 5955801.44 684010.90 N 70 17 3.567 W 148 30 38.623 0.00 5955840.30 683973.85 N 70 17 3.958 W 148 30 39.674 SurveyEditor Ver SP 2.1 Bld( users) 02-33\02-33\02-336\02-336 Generated 7/1/2009 11:29 AM Page 5 of 6 GYD GC SS -( Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) fftUSl Easting (X) (ftUSl Surface : 4653 FSL 4419 FEL S36 Ti 1 N R14E UM 5950574.70 687604.16 BHL : 4727 FSL 2634 FEL S26 T11 N R14E UM 5955840.30 683973.85 • SurveyEditor Ver SP 2.1 Bld( users) 02-33\02-33\02-33B\02-33B Generated 7/1/2009 11:29 AM Page 6 of 6 WELLHEAD =- FMC Gen 5 ACTL(ATOR = ~-. _ KB. ELEV = 58.6 BF. ELEV = _ 28.5 KOP = 3194 Max Angle = 93° @ 12397 Datum MD = --- 10550' Datum TVD = 8800' SS TOP OF 9-5/8" WHIPSTOCK ~-~ 3194' 9-5/8" CSG, 36#, J-55, ID = 8.921" ~ 3478' 7" ¢ sv 3499' Minimum ID = 3.725" @ 9653' HES XN NIPPLE 7" CSG, 26#, L-80, ID = 6.276" 8615' 02-336 4-1/2" TBG, 12.6#, 13CR-80, VAM TOP, .0152 bpf, ID = 3.958" 9665' 7" CSG, 26#, L-80, BTGM x TCII, ID = 6.276" 9822' PERFORATION SUMMARY REF LOG: BHCS ON 10/19/91 ANGLE AT TOPPERF: 83° @ 10730' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10730-10970 O 06/08/09 2-7/8" 6 11040-11570 O 06/08/09 2-7/8" 6 11620-11840 O 06/08/09 2-7/8" 6 12500-12540 O 06/08/09 2-7/8" 6 12580-12720 O 06/08/09 .1~~ r~5 ~~ ~i~`,~l ~~ 1 4-1/2" LNR, 12.6#, L-80, IBT-M, ID = 3.958" I~ 12818' grj46' - 7"x4-1/2" BKR S-3 PKR, ID = 3.87" 9580' - 4-1/2" HES X-NIP, ID = 3.813" 9653' - 4-1/2" HES XN-NIP, ID = 3.725" 9660' - 7"x5" BKR ZXP LTP, w /12' TBR, ID = 4.40" 9664' - 4-1/2" WLEG, ID = 4.654" 96$2' - 7"x5" BKR FLEX LOCK LNR HGR, ID = 4.43" 9693' - 5"x4-1 /2" XO, ID = 3.94" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/29/91 AUDI 1 ORIGINAL COMPLETION 09/17/00 N CDR1 SIDETRACK (02-33A) 06/10/09 N9ES SIDETRACK (02-33B) 06/13/09 MBMITLH GLV C/O SA~NOTES: ***CHROMETBG&JEWELRI"`** 2201' - 4-1/2" HES X-NIP, ID = 3.813" GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 2 3725 3716 15 CAMC DOME BK 16 06/13/09 1 6681 5922 46 CAMCO SO BK 20 06/13/09 MILLOUT WINDOW (02-33B) 3194' - 3211' 9516' - 4-1/2" HES X-NIP, ID = 3.813" PRUDHOE BAY UNfI' WELL: 02-336 PERMIT No: 2090450 API No: 50-029-22214-02 SEC 36, 711 N, R14E, 626' FNL & 861' FEL BP Exploration (Alaska) 02-33B Intermediate Hole • Maunder, Thomas ~ (QQA) From: Staudinger, Mark [Mark.Staudnger~bp.com] Sent: Thursday, June 04, 2009 3:14 PM To: Maunder, Thomas ~ {13UA) Cc: Trpaek, Robert l3 Subject: RE: 02338 {209-045)lntermediate Mole ~~ Tom- Page 1 of 2 You are correct, this job was originally planned to cover 5000' of open hose when the Permit to Dri!! was written. ! apologize for not notifying you of the change earlier, but notifying the state was inadvertently overlooked during the changes to the cement design. Due to a recent study, our views of the exact cause of corrosion has changed, and we fee! it is no longer necessary to cover the Cretaceous interval with cement. This has been determined with evidence that shows we rarely obtain quality cement jobs across the Cretaceous, yet we only have a sma#l percentage of we!!s that have corrosion leaks in the Cretaceous interval. This recent study has led us to change our strategy on casing and cementing intermediate hole sections. We will be running premlum threads on our intermediate casings and cementing with 1000' of class 'G' slurry. Please let me know if you have further questions. Regards, Mark Frorn: Maunder, Thomas E {DQA) [mailto.tom.maunder@alaska.gov] Ser~#: Thursday, June 04, 2049 2:57 PM T4: Staudinger, Mark Cc: Tirpack, Robert l3 Subject; RE: OZ,336 (209,445) Intermediate Mole From: Staudnger, Mark [mallt©:Mark,Statadinger@bp.com3 aert#: Thursday, .lone 04, 2009 2:.21 RM To: Maunder, Thomas E ([>QA) Cc: Trpack, Robert 6 suilrje~x: 02-336 Intermediate Hole Tom- 1 wanted to !e# you knave that we changed the design for the interm~ate casing string .and cement 4n 02-33B being drilled by Labors 9es. We ran premium TCII thread connections for the entire casing run, then pumped a 7/82009 02-33B Intermediate Hole ~ ~ Page 2 of 2 1000' slung of class'G' cement at the 7" casing shoe. There are no zones in the intermediate section that the AOGCC requires us to cover with cement. Please let me know if you have any questions. Thanks, Mark Staudinger BP Exploration Alaska Operations Drilling Engineer GPB Rotary Drilling (907) 564-5733 (907) 440-7403 cell 7/8/2009 .-~ -, ~ SARAH PAL/N, GOVERNOR .... t~i1t~~7~ OII/ tiny GA5 t/ 333 W 7th AVENUE, SUITE 100 C01~51''iRQA'rIO1~T COh'II~'II55I01'1T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-33B BP Exploration Alaska Inc. Permit No: 209-045 Surface Location: 626' FNL, 861' FWL, SEC. 36, Tl 1N, R14E, UM Bottomhole Location: 689' FNL, 2512' FEL, SEC. 26, T11N, R14E, UM Dear Mr. TYrpack: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill doe;> 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, TYtle 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) 659-3607 (pager). r Sincerely, ~i~~~ Cathy . Foerster Commissioner DATED this ~ day of April, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMIS~N PERMIT TO DRILL 20 AAC 25.005 tr~~~ ~ s ~ao9 °> iF ~S~il 4J VaS~ CJ V1?II I~IJJIV I€ 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 02-336 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12733 TVD 8810 ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028308 Oil Pool FWL, SEC. 36, T11N, R14E, UM 626 FNL, 861 Top of Productive Horizon: R14E UM 1476' FEL SEC. 26 T11N 2248' FNL 8. Land Use Permit: 13. Approximate Spud Date: May 1, 2009 , , , , , Total Depth: 689' FNL, 2512' FEL, SEC. 26, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18600' 4b. Location of Well (State Base Plane Coordinates): Surface: x-687604 y-5950575 Zone-ASP4 10. KB Elevation (Height above GL): 66' feet 15. Distance to Nearest Well Within Pool: 720' 16. Deviated Wells: Kickoff Depth: 3435 feet Maximum Hole An le: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3866 Surface: 3040 'n r m: n T `- in h- 6 tt m .f o Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data - /4" 7" 26# L-80 T -II 4656' 2 ' 29' 4685' 4 1 05 u Lie r t 8-3/4" 7" 26# L-80 BTC-M 275 4685' 4596' 60' 8 1 22 c ft Clas ' 19, PRESE NT WELL CONDITION S UMMARY (To be completed for Redrilland Re-entry Operations),' Total Depth MD (ft): 10872' Total Depth TVD (ft): Plugs (measured): 46' None Effective Depth MD (ft): 10833' Effective Depth TVD (ft): 8944' Junk (measured): None Casn Length Size Cement Volume MD TVD Conductor /Structural 1 11 1 ' Surface 3478' 9-5/8" 1 20 cu ft CS III 348 c ft ' 89 c S I I 3478' 3477 Intermediate 8615' 7" 7 2 u ft Clas 8615' 845 ' Pr i Liner 802' 1 cu ft Class ' 13' - 115' 8 84' - 88 7' Lin r 2711' 2-3/ " 20-1/ B I 1 .8 LARC 8143' - 1 4' 8 7' - 894 ' Perforation Depth MD (ft): 9220' - 10770' Perforation Depth TVD (ft): 8955' - 8948' 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 Mark Staudinger, 564-5733 Printed Name Ro rt Tirpack Title Engineering Team Leader Prepared By NerneMumber. Si nature Phone 564-4166 Date °~ ~~~~ Sondra Stewman, 564-4750 Commission Use Onl Permit To Drill N r: O y~ API Number. 50-029-22214-02-00 Permit Approval See cover letter for a : err uir m nts 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: ,,! 35~~. ~esv-`~5~- i - ~, Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ l~(jes l~No ~~^~ ` ~~ v~av~vv-~.Cl~hse~alK~ ~ ~- HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other:~~c=C.J ~~~~~`-5~~ ~..-~ ~c L~@°~e,~~ ~ s~ ~~~...t~~ ,~-~~`~~ APPROVED BY THE COMMISSION Date ¢~ ~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~~ Submit In Duplicate by To: Alaska Oil & Gas Conservation Commission From: Mark Staudinger, ODE Date: April 15, 2009 Re: 02-33B Sidetrack Permit to Drill The 02-33B well is scheduled to be drilled by Nabors Rig 9ES which is currently scheduled to move onto the location ~OS/O1/09. The plan is to exit the parent 02-33A wellbore from the 9-5/8" casing at 3435' MD with an 8-3/4" BHA. The 8-3/4" hole will then be drilled to the top of the Sag River formation where a 7" casing string will be run and cemented. A 6-1/8" hole will then be drilled building to horizontal in the Ivishak Zone 1. The planned well then runs horizontally for approximately 1,860' to a final well TD at 12,733' MD. A solid 4-1/2" production liner will be run and cemented in place. Please note the following Well Summary as detailed on the next few pages: 02-336 Permit to Drill Application Page 1 Manned Well Summary Well 02-33B Well Horizontal Target Zone 1 T e Sidetrack Ob'ective API Number: 50-029-22214-01 Current Status 02-33A Shut-In and P&A Procedures commencing Estimated Start Date: Ma , 1 S 2009 Time to Com lete: 27.75 Da s Surface Northin Eastin Offsets TRS Location 5,950,575 687,604 626' FNL / 861' FWL 11 N, 14E, 36 Target Northing Easting TVDss Offsets TRS Locations 5,954,174 685,174 -8,860 2248' FNL / 1476' FEL 11 N, 14E, 26 Bottom Northin Eastin TVDss Offsets TRS Location 5,955,707 684,099 -8,810 689' FNL / 2512' FEL 11 N, 14E, 26 Planned KOP: 3435'MD / 3376'TVDss Planned TD: 12,733'MD / 8,810' TVDss Ri Nabors 9es BFE: 30.0' RTE: 58.5' Directional - Schlumberger P07b KOP: 3435' MD Maximum Hole Angle: ~50° in the 8-3/4" intermediate section ~92° in the 6-1/8" horizontal section C~ TD Surve Pro ram: MWD Standard + IFR / MS Nearest Pro ert Line: 18,600' to the PBU propert line Nearest Well within Pool: 02-176 is the closest well at 720'. Contacts Name Phone # Drilling Engineer Mark Staudinger 564-5733 Geologist Priya Maraj 564-4181 Pad Engineer Claudia Rico Hernandez 564-5626 E-mail Mark.Staudin eg r@bp.com Priya.Maraj @bp.com Claudia.Hernandez @ bp.com 02-336 Permit to Drill Application Page 2 Formation Markers 02-33B (~ed on SOR) Estimated Formation To s Uncertain Commercial Hydrocarbon Bearin ? Estimated Pore Press. Formation (7'VDss) (Feet) (Yes/No) ( EMW / Psi) SV5 -2750 40' no SV4 -2892 40' no KOP -3435 SV 1 -4041 40' no UG4 -4587 40' no UG3 -5219 40' no UGl -5629 40' no WS2 -5895 40' no WSl -6117 40' no CM3 -6300 40' no CM2 -6810 40' no CM1 -7454 40' no THRZ -7851 20' no BHRZ -8038 20' no TJA -8150 20' no TSGR -8256 20' es TSHU -8282 20' no TSAD -8383 20' es 42SB -8482 20' TCGL -8539 20' es BCGL -8608 20' es 23SB -8682 20' es 22TS -8730 20' 21TS -8773 20' es TZ1B -8820 20' es 3223 si @ 8800' TDF -8848 20' es (7.0 EMW) Casing/Tubing Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 8-3/4" 7" 26# L-80 TC-II 7,240 5,410 4685' 28.5' / 28.5' 4,685' / 4,596 8-3/4" 7" 26# L-80 BTC-M 7,240 5,410 5275' 4,685' / 4,596 9,960' / 8,319 6-1/8" 4'/z" 12.6# L-80 IBT-M 8,430 7,500 2g23' 9,810' / 8,179 12,733' / 8869 Tubing 4 ~/z" 12.6# 13Cr- 80 Vam Top 8,430 7,500 9,810' 28.5' / 28.5' 9'810 ,/ 8,179 02-33B Permit to Drill Application Page 3 Mud Program Whi stock Millin Mud Pro erties: LSND Whip Stock. Window 9-5/8", 36# Densit PV YP API FL HTHP FL MBT PH 9.2 15-22 30-40 6-8 N/C <10 9.0-9.5 Intermediate Mud Pro erties: LSND 8-3/4" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH 3,435'-9,524' 9.2 - 9.5 10-18 18-28 <6.0 N/C <15 9.0-10 9,524'-9,960' HRZ to Sa 10.2 12-22 18-28 4.0-6.0 <10.0 <20 9.0-10 Production Mud Pro erties: FLOPRO SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densi PV YP LSVR API FI H MBT 9,960'-12,733' 8.5 - 9.0 6-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 3 Logging Program 8-3/4" Intermediate: Drilling: Dir/GR/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drillin Dir/GR/Neu/Den Open Hole: None Cased Hole: None Cement Program Casin Size: 7" 26#, L-80 Intermediate Liner Basis: Lead: 4,775' of open hole with 40% excess Lead TOC: 4,185' MD 750' from the window Tail: 1,000' of open hole with 40% excess, plus 80' shoe track Tail TOC: 8960' MD 1000' above 7" shoe de th Total Cement Volume• Spacer 40 bbls of viscosified, weighted Spacer (Mud Push 11) Lead 179.0 bbls, 1005 cuft, 286 sks 11.0 Ib/ al LiteCrete 3.51 cuft/sk tanned Tail 40.5 bbls, 228 cuft, 196 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Tem BHST =173° F, BHCT TBD b Schlumber er Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: 2773' of open hole with 40% excess, 80' shoe track, 150' 4-'h" x 7" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 9,610' MD (200' above Liner Top) Total Cement Volume: Spacer 40 bbls of viscosified, weighted Spacer (Mud Push II) Lead None Tail 73.7 bbls, 414 cuft, 357 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Tem BHST =186° F, BHCT TBD b Schlumber er 02-33B Permit to Drill Application Page 4 Surface and Anti-Collin Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface 02-14 and 02-13 are on 60' center to center spacing from 02-33B. Close Approach Shut-in Wells: Three wells fail major risk anti-collision criteria in Schlumberger P07b. A Tolerable Collision Risk Worksheet will be filled out for all wells that fail the major risk anti-collision criteria, and the corresponding wells will be shut-in as necessary. Hydrogen Sulfide Drill Site 02 is not designated as an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Date of Readina #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Faults 02-13B 10 m 1/3/2007 02-14A 18 m 7/27/2008 02-08B 14 m 6/26/2008 02-32B 16 m 10/10/2008 02-11 A 30 m 11 /8/2006 Formation Where Encounter Fault MD Intersect SSTVD Intersect Est. Throw Throw Direction Uncertaint Zone lA 11800 -8840 15' U thrown 100 ft Zone lA 12350 -8825 20' U thrown 100 ft 02-33B Permit to Drill Application Page 5 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for 02-33B will be 14 days during drilling phase and 7 days during de- completion work. Dverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3866 si C~ 8260' TVDss 9.0 EMW Maximum surface ressure 3040 si .10 si/ft as radient to surface Kick tolerance 51.4 bbls over 11.0 FIT assumin 9.0 reservoir and 4" drill i e Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 7" Casin Test 3500 si ressure test Inte ri Test - 8-1/2" hole Minimum 11.0 FIT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3223 si ~ 8800' TVDss 7.0 EMW Maximum surface ressure 2338 si .10 si/ft as radient to surface Kick tolerance Infinite with a 9.5 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 4-1/2" Liner Test 3500 si surface ressure Inte rit Test - 6-1/8" hole Minimum 9.5 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Disposal No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: All Class II liquid waste (including drilling muds and/or brines that have been downhole) are to be hauled to GNI at DS-04 for injection. For the disposal of Class I wastes, contact the GPB Environmental Advisors (659-5893) for the appropriate disposal method at Pad 3 or GNI. NOTE: Generally, Class I solids will be directed to the GNI on DS-04 and Class I liquids will be directed to Pad 3. 02-336 Permit to Drill Application Page 6 Drilliri~Hazards and ContingLficies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control A. The Ivishak Zone in 02-33B is expected to be under-pressured at 7.0 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Faults /Lost Circulation /Breathing A. Although 02-33B is expected to cross two faults in Zone 1A near 11800 ft and 12350 ft, lost circulation risk is considered low. The lost circulation occurrence in surrounding wells is average in the production zone. Lost circulation is normally not a problem in the intermediate section on DS02. B. Normal precautions should be taken if wellbore breathing occurs while drilling the Shublik, but normally wellbore breathing is not a problem on Drill Site 02. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 51 bbls with a 11.0 ppg FIT out of the 9-5/8" window. The production hole section's kick tolerance is infinite with a 9.5 ppg FIT. These given FIT's will be our minimum for kick tolerance, and may increase due to ECD management. B. Integrity Testing Test Point Test Depth Test EMW (Ib/gal) t e 9 5/8" 20-ft minimum from the 9-5/s" FIT 11.0 minimum window window 7" shoe 20-ft minimum from the 7" shoe FIT 9.5 minimum IV. Stuck Pipe A. Previous DS 02 wells encountered stuck pipe problems in the production section. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. Drill Site 02 is not designated as an H2S site since current levels are below the 100 ppm threshold to be considered an H2S pad. However, standard precautions will be followed at all times. VII. Anti-Collision Issues A. Three wells fail major risk anti-collision criteria in Schlumberger P07b. A Tolerable Collision Risk Worksheet will be filled out for all wells that fail the major risk anti-collision criteria, and the corresponding wells will be shut-in as necessary. CONSULT THE DRILL SITE 02 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 02-336 Permit to Drill Application Page 7 operations Summary Current Condition and history: • This well is completed with 3-1/2" 13Cr-80 tubing with a 2-3/8" L-80 liner and is currently shut-in. • Tubing: A caliper log from 8/26/07 shows the 3-1/2" and 2-3/8" liner in good condition (max penetration of 22%). An SCMT log found cement at the top of the 2-3/8" liner and the TOC C«~ 8190'. • MIT-IA Passed to 3000 psi 03/31/09 • MIT-OA Failed to with a LLR of 0.9 bpm ~ 1050 psi 04/09/09 Scope Notify the field AOGCC representative with intent to plug and abandon Pre-rip prep work: O 1 Line the Cellar around the wellhead with im ermeable, s ra -sealed Herculite. F 2 Fluid ack the tubin and inner annulus w/seawater/diesel. C 3 1. P & A the perforations in the 02-33A wellbore with cement from 10,833' MD to 9,000'. a. CEMENT CALCULATIONS i. 1833' of 2-3/8", 4.6# liner: .003866 bbls/ft = 7.1 bbls TOTAL = 7.1 bbls WOC and test cement lu to 2,250 si for 10 minutes. S 4 RU, drift for Tubin Punch and Jet Cutter. Ta to of 2-3/8" liner. E 5 Punch holes in the 3-1/2" tubin in the middle of a full ~oint above 2-3/8" liner to . F 6 Circulate the well to seawater through the tubing cut. Freeze protect the IA and tubing with diesel to 2,200' E 7 Jet cut the 3-1/2" tubin in the middle of a full ~oint at 3800' MD. F 8 CMIT - T x IA to 2,250 si for 30 minutes revious MIT-IA test assed 3/31/2009 D 9 Bleed all casin and annulus ressures to zero si. W 10 Function all tubing and casing lock down screws. Repair and replace as necessary. PPPOT - IC and PPPOT - T. V 11 Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well re aration cost on the handover form. Proposed Procedure: 1. MIRU. 2. MIT - OA to 2000 psi for 30 minutes (expect failure and obtain the LLR). CMIT - TxIA to 2,250 psi for 30 minutes. 3. Pull BPV. Circulate out freeze protection and displace well to seawater. 4. Set BPV using a T-bar and test from below to 1000 psi for 10 minutes (also tests TxIA). 5. Nipple down tree. Install a blanking plug into the tubing hanger's lifting threads. Nipple up and test BOPE to 3,500 psi. Remove the blanking plug using the retrieval sub and a joint of drill pipe. Pull BPV. 6. RU and pull the 3-1/2", 9.2#, 13Cr-80, FOX tubing from the pre-rig jet cut. Spool up the control lines. Test the lower set of pipe rams. 7. PU 4" drillpipe and 7" clean-out assembly and clean-out well to tubing stub. 8. Run a CCUUSIT in cement evaluation mode from tubing stub to surface. 9. With E-line, run a 7" EZSV for 26# casing. Set the EZSV at 100' below proposed 7" casing cut and test to 3500 psi for 10 minutes. Rig down E-line. 10. Pull 7" packoff through the BOP Stack. 11. MU amulti-string casing cutter. Run in hole and cut the 7" casing above the 9-5/8" surface casing shoe, without cutting a collar. 12. Establish circulation through the casing cut and circulate out the dead crude through the cut with seawater. 02-336 Permit to Drill Application Page 8 13. Spear the 7" casing from~ndrel hanger. Circulate as required to ~r the annulus. Pull and lay down.. i 14. Perform a 9-5/8" cleanout/scraper run to the top of the 7" casing stub. 3 ~~ ~ 6~- 15. PU 9-5/8" whipstock, bottom trip anchor and 8.75" window milling assembly (to include full gauge string mills). RIH to the top of the 7" casing stub. Orient and set the whipstock. Swap the well over to 8.8 ppg fresh water LSND milling fluid. 16. Mill a window in the 9-5/8" casing above the 9-5/8" casing shoe plus 20' of formation from mid- window. Perform LOT. 17. MU an 8-3/4" drilling BHA with MWD/LWD package and bent housing motor. RIH. Kick off and drill intermediate interval to 7" casing point at the top of the Sag River. CBU, perform short trip, RIH back to TD, circulate well clean and POOH. NOTE: The mud will need to be weighted up with spike fluid. Ensure that the mud weight ~~ is sufficient for shale stability prior to drilling into the HRZ and Kingak formation. ~ ~ t 18. •Run and cement 7", 26#, L-80, BTC-M x TCII casing from top of the Sag River Formation to surface ~~~ ?1~\ Cement the casing in one stage bringing the estimated TOC to 750' below the window. NOTE: Establish infectivity and freeze protect the 7" x 9-5/8" annulus off the critical path. 19. MU a 6-1/8" BHA with MWD/LWD package and RIH. Wash down to the shoe track in the 7" casing. Swap the well over to 8.5 ppg FloPro SF drilling fluid. 20. Pressure test the 7" casing to 3500 psi for 30 minutes and chart. 21. Drill out the remaining shoe track plus 20' of formation. Perform an FIT. 22. Drill ahead per plan to TD in Zone 1 B. Plan on a bit/BHA trip after drilling the Conglomerates. 23. Circulate bottoms up as necessary, short trip, circulate until clean and POOH. 24. Run and fully cement a 4-1/2", 12.6#, L-80, IBT-M, liner throughout the 6-1/8" wellbore with 150' liner lap. Set liner top packer and displace well to clean seawater above the liner top. NOTE: A perf pill will be left in the 4-1/2"liner. 25. Pressure Test the 4-1/2" liner to 3500 psi for 30 minutes once sufficient compressive strength has been achieved. Chart the test. 26. RIH with DPC pert guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and pert guns. 27. Run the 4-1/2", 12.6#, 13Cr-80, Vam Top completion. Tie into the 4-1/2" liner top. 28. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes each. 29. Set and test TWC. 30. ND BOPE. NU and test the tree to 5,000 psi. 31. Freeze protect the well with diesel to 2200' MD. Set a BPV. 32. RDMO. 02-33B Permit to Drill Application Page 9 TREE= 3-1/8" FMC WELLHEAD = FMC ACTUATOR = OTIS-SHORT KB. ELEV..- __ 6E' BF. ELEV_- KOP= M8x Angle = 97° @ 10537 Datum MD = 9092' Datum TV D = 8800' SS ~ 02-33A a 9-5/8" CSG, 36#, J-55, ID = 8.921 " ~~ 347$' Minimum ID =1.995" @ 8143 2-3/8" LINER TOP TOP OF 2-3/8" LNR TOP OF 5" LNR I 3-1/2" TBG, 9.2#, 13CR-80, .0087 bpf, ID = 2.992" 8327' 7" CSG, 26#, L-80, ID = 6.276" 8615' PERFORATION SUMMARY REF LOG: BHCS ON 10/19/91 ANGLE AT TOP PERF: 64° @ 9220' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9220 - 10020 O 09/17/00 1-11/16" 6 9400 - 9500 O 07/07/08 1-11/16" 6 9680 - 9730 O 07/07/08 1-11/16" 6 9790 - 9830 O 07/07/08 1-11/16" 6 9940 - 9985 O 07/07/08 1-11/16" 4 10440 - 10720 O 09/17/00 1-11/16" 6 10585 - 10685 O 07/06/08 1-9/16" 6 10720 - 10770 O 08/04/03 S OTES: ***CHROME TBG &LNR*** 3-1/2" OTIS FMX TRSV SSSV NIP, ID = 2.81" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3098 3098 2 MMG-2 DOME RK 16 10/06/00 2 4904 4902 1 MMG-2 DOME RK 16 10/06/00 3 6138 6134 8 MMG-2 DMY RK 0 09/17/00 4 6945 6918 21 MMG-2 DOME RK 16 10/06/00 5 7408 7345 23 MMG-2 DMY RK 0 09/17/00 6 7697 7612 20 MMG-2 DMY RK 0 09/17/00 7 7900 7802 21 MMG-2 SO RK 20 10/06/00 8 8102 7989 24 MMG-2 EO DMY RKP 0 09/28/00 $143' 2.70' DEPLOY SLV, ID = 1.969" (LOGGED 09/10/00) 8212' 7" X 3-1/2" OTIS BWD PERM PKR, ID = 4.00" 8216' SEAL BORE EXTENSION, ID = 4.00" $232' S-1/2" MILLOUT IXTENSION, ID = 4.67" 8238' S-1/2" X 3-1/2" XO, ID = 2.992" $2$3' 3-1/2" PARKER SWN NIP, ID = 2.75" 8313' 7" X 5" TMI LNR HGR, ID = ? 8327' 3-1/2" TUBING TAIL $327' ELMD LOGGED xx/xw'xx MILLOUT WINDOW (02-33A) 9115' - 9122' I PBTD I I TD I 5" LNR, 15#, 13CR-80, .0189 bpf, ID = 4.408" ~ 9384' 2-3/8" LNR, 4.6#, FL4S, L-80, .0039 bpf, ID = 1.995" I 10853' I DATE REV BY COMMENTS DATE REV BY COMMENTS 10/29/91 AUDI 1 ORIGINAL COMPLETION 09/17/00 N CDR1 SIDETRACK (02-33A) 11/10/06 JPK/TLH GLV C/O CORRECTION (10/6/00) 07/18/08 ?/JMD GLV C/O CORRECTION (10/6/00) 07/25/08 PJC DRAWING CORRECTIONS PRUDHOE BAY UNIT WELL: 02-33A PERMIT No: 2001230 API No: 50-029-22214-01 SEC 36, 711 N, R14E, 626' FNL & 861' FEL BP Exploration (Alaska) TREE= 4-1/8" FMC S~OTES• **"CHROMETBG""* WELLHEAD = FMC ACTUATOR = KB. ELEV BF. ELEV..- KOP = Max Angle Datum MD = Datum TVD = 02-3 Proposed 2200' - 4-112" HES X-NIP: ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE ~ KOP-Top of Whipstock ~~ 9-5/8" CSG, 36#, J-55, ID = 8.921" -{ ~ 9-518°' Ezsv JET CUT TUBING PUNCH TOP OF 2-3/8" LNR 2.70' DEPLOY SLV, ID = 1.969" (LOGGED 09/10/00) 7" X 3-1/2" OTIS BWD PERM PKR, ID = 4.00" SEAL BORE IXTENSION, ID = 4.00" - 5-1/2" MILLOUT IXTENSION, ID = 4.67" 5-1/2" X 3-1/2" XO, ID = 2.992" - 3-1/2" PARKER SWN NIP, ID=2.75" 7" x 5" TM/ LNR HGR, ID=? - 3-1/2" TBG, 9.2#, 13CR-80, .0087 bpf, ID = 2.992" - 3435° 3478' / 3750` 3800' 8100' 8143' 8212' 8216' 8232' 8238' 8313' 8313' T~ ~ ~ ~~o; ~~~~ I-I 8615 TOC ~-~ -9000' PERFORATION SUMMARY REF LOG: BHCS ON 10/'F9/91 ANGLE AT TOP PERF: 64° @ 9220' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 5" LNR, 15#, 13CR-80, .0189 bpf, ID = 4.408" ~~ 9384' ~ 2-3/8" LNR, 4.6#, FL4S, L-80, .0039 bpf, ID = 1.995" 1 2 ini tam l = 3.725" xxxx' ~ - IP 4-1f2" HES X-NIP, ID = 3.813" ~ xxxx BAKERS-3 PROD PKR xxxx 4-112'° HES X-NIP, ID = 3.813" xxxx 4-112°` HES XN-NIP, ID = 3.725" xxxx 4-112" TB{~, 12,6#, 13Cr-80, V 9810° BAKERZXPLINER TOP PKR X9810° 7" CSG, 26#, L-80, BTC-M x TCII ~-~ 9980` 4-1?2" LNR, 12.6#, L-80, IBT-M 12733' MILLOUT WINDOW (02-33A) 9115' - 9122' I PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 10/29/91 AUDI 1 ORIGINAL COMPLETION 09/17/00 NCDR1 SIDETRACK(02-33A) 11/10/06 JPK/TLH GLV GO CORRECTION (10/6/00) 07/18/08 ?/JMD GLV GO CORRECTION (10/6/00) 07/25/08 PJC DRAWING CORRECTIONS 04/07/09 MIS Proposed ST PRUDHOE BAY UNfT WELL: 02-33A PERMIT No: 2001230 API No: 50-029-22214-01 SEC 36, T11 N, R14E, 626' FNL & 861' FEL BP F~cploration (Alaska) ~'~~ J ~,~ Report Date: April 7, 2009 Survey I DLS Computation Method: Minimum Curvature I Lt Client: BP Exploration Alaska Vertical Section Azimuth: 326.760° Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: DS-02I 02-33 ® ®, ~ i ~~ ND Reference Datum: Rotary Table Well: 02-33 ®~ ~ K~~ C~ ND Reference Elevation: 58.50 ft relative to MSL Borehole: Plan 02-33B ~'~ ~ ~ u Sea Bed 1 Ground Level Elevation: 30.00 ft relative to MSL UWIIAPI#: 500292221401 Magnetic Declination: 22.797° Survey Name I Date: 02-33B (P7b) /April 7, 2009 Total Field Strength: 57713.568 nT Tort 1 AHD 1 DDI I ERD ratio: 211.539° 16534.57 ft / 6.295 10.733 Magnetic Dip: 80.919° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: May 15, 2009 Location LaULong: N 70.26980612, W 148.48271396 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 5950574.700 ftUS, E 687604.160 ftUS North Reference: True North Grid Convergence Angle: +1.42824852° Total Corr Mag North -> True North: +22.797° DS02-33B (P7b) Proposal Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS Tie-In Survey aayz.ou 4.vu aa. ru sass. is saa i.aa - i r.oa o.w~ wU.JO 77.w/IVI V.OJ L./J O~JVJO I.IL VO/ VY4.JV IV / V.LVJOL V~J VV IYO.4oL JOI V~ Top Whipstock 3435.00 4.34 102. 82 3375.58 3434.08 -19.75 4.84 43.40 121.53M 0.96 2.77 5950580.62 687647.43 N 70.26981933 W 148.48236300 Base Whipstock 3451.00 5.43 121. 53 3391.52 3450.02 -20.87 4.31 44.64 --- 12.00 2.85 5950580.12 687648.67 N 70.26981788 W 148.48235301 Crv 4/100 3464.00 5.43 121. 53 3404.46 3462.96 -21.98 3.66 45.69 LS 0.00 2.86 5950579.50 687649.74 N 70.26981613 W 148.48234452 3500.00 3.99 121. 53 3440.34 3498.84 -24.66 2.12 48.21 LS 4.00 2.93 5950578.02 687652.30 N 70.26981190 W 148.48232413 3600.00 0.01 301. 53 3540.26 3598.76 -27.80 0.30 51.17 3O1.53M 4.00 3.06 5950576.27 687655.31 N 70.26980693 W 148.48230017 3700.00 4.01 301. 53 3640.18 3698.68 -24.63 2.13 48.19 3O1.53M 4.00 3.17 5950578.03 687652.28 N 70.26981194 W 148.48232430 3800.00 8.01 301. 53 3739.61 3798.11 -15.17 7.60 39.27 HS 4.00 3.31 5950583.27 687643.23 N 70.26982688 W 148.48239642 3900.00 12.01 301. 53 3838.06 3896.56 0.55 16.68 24.46 HS 4.00 3.46 5950591.99 687628.20 N 70.26985170 W 148.48251616 Crv 4/100 3964.00 14.57 301. 53 3900.35 3958.85 13.85 24.37 11.92 16.00E 4.00 3.55 5950599.36 687615.47 N 70.26987271 W 148.48261754 4000.00 15.96 300. 08 3935.08 3993.58 22.37 29.22 3.78 14.61 L 4.00 3.61 5950604.00 687607.21 N 70.26988595 W 148.482 4100.00 19.85 297. 11 4030.22 4088.72 49.42 43.86 -23.24 11.78E 4.00 3.76 5950617.96 687579.84 6 N 70.26992593 W 148.4829 SV1 4111.48 20.30 296. 84 4041.00 4099.50 52.84 45.64 -26.75 11.53E 4.00 3.77 5950619.66 687576.29 N 70.26993082 W 148.482930 4200.00 23.78 295. 09 4123.04 4181.54 81.34 60.15 -56.62 9.90E 4.00 3.90 5950633.42 687546.06 N 70.26997045 W 148.48317181 4300.00 27.73 293 .61 4213.09 4271.59 118.00 78.02 -96.21 8.57E 4.00 4.03 5950650.30 687506.04 N 70.27001928 W 148.48349197 4400.00 31.69 292 .48 4299.93 4358.43 159.20 97.39 -141.82 7.58E 4.00 4.15 5950668.52 687459.96 N 70.27007219 W 148.48386075 4500.00 35.66 291 .57 4383.13 4441.63 204.74 118.16 -193.22 6.83E 4.00 4.27 5950688.00 687408.07 N 70.27012892 W 148.48427637 4600.00 39.63 290 .83 4462.29 4520.79 254.41 140.23 -250.16 6.24E 4.00 4.37 5950708.64 687350.60 N 70.27018920 W 148.48473679 4700.00 43.61 290 .20 4537.04 4595.54 307.95 163.48 -312.36 5.77E 4.00 4.47 5950730.34 687287.85 N 70.27025273 W 148.48523977 End Crv 4734.91 45.00 290 .00 4562.02 4620.52 327.51 171.86 -335.25 --- 4.00 4.50 5950738.14 687264.75 N 70.27027562 W 148.48542493 UG4 4770.24 45.00 290. 00 4587.00 4645.50 347.53 180.41 -358.73 --- 0.00 4.52 5950746.10 687241.07 N 70.27029896 W 148.48561478 Crv 41100 5234.91 45.00 290 .00 4915.57 4974.07 610.76 292.79 -667.49 98.87R 0.00 4.75 5950850.74 686929.63 N 70.27060591 W 148.48811155 chlumberger WeIlDesign Ver SP 2.1 Bld( users) 02-33\02-33\Plan 02-336\02-338 (P7b) Generated 4/7/2009 8:56 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS b3UV.UV 44.bb L`J3.bb 4`Jb-I./4 VUL V.L4 040.3/ 3U~.04 -! IU.V/ yO.LIR 4.VV 4.l~ U.7U VOOU./J OOOOOU.OJ IV lV.Gl VOUL4~ VY I40.'i004JU5L 5400.00 44.36 299.35 5033.08 5091.58 708.87 341.09 -772.75 92.21 R 4.00 4.85 5950896.41 686823.19 N 70.27073786 W 148.48896285 5500.00 44.35 305.08 5104.61 5163.11 772.41 378.33 -831.85 88.11 R 4.00 4.91 5950932.16 686763.19 N 70.27083957 W 148.48944079 5600.00 44.62 310.77 5175.99 5234.49 838.68 421.37 -887.08 84.O5R 4.00 4.96 5950973.80 686706.91 N 70.27095713 W 148.48988741 UG3 5660.59 44.93 314.19 5219.00 5277.50 880.02 450.18 -918.54 81.63R 4.00 4.99 5951001.82 686674.74 N 70.27103583 W 148.49014184 5700.00 45.18 316.39 5246.85 5305.35 907.35 470.00 -938.16 80.07R 4.00 5.01 5951021.14 686654.63 N 70.27108998 W 148.49030055 5800.00 46.00 321.87 5316.86 5375.36 978.10 523.99 -984.85 76.23R 4.00 5.06 5951073.95 686606.61 N 70.27123745 W 148.49067818 5900.00 47.07 327.18 5385.67 5444.17 1050.58 583.07 -1026.93 72.58R 4.00 5.11 5951131.96 686563.09 N 70.27139884 W 148.49101847 6000.00 48.39 332.28 5452.95 5511.45 1124.43 646.96 -1064.17 69.14R 4.00 5.15 5951194.89 686524.26 N 70.27157336 W 148.49131976 6100.00 49.92 337.17 5518.38 5576.88 1199.29 715.33 -1096.42 65.95R 4.00 5.20 5951262.44 686490.32 N 70.27176015 W 148.49158058 End Crv 6101.90 49.95 337.26 5519.60 5578.10 1200.72 716.67 -1096.98 --- 4.00 5.20 5951263.77 686489.73 N 70.27176381 W 148.491 UG1 6271.90 49.95 337.26 5629.00 5687.50 1328.67 836.69 -1147.28 --- 0.00 5.24 5951382.48 686436.46 5 N 70.27209167 W 148.4919 WS2 6685.27 49.95 337.26 5895.00 5953.50 1639.78 1128.51 -1269.58 --- 0.00 5.32 5951671.15 686306.92 N 70.27288885 W 148.49298152 WS1 7030.26 49.95 337.26 6117.00 6175.50 1899.44 1372.06 -1371.66 --- 0.00 5.39 5951912.06 686198.82 N 70.27355416 W 148.49380738 CM3 7314.65 49.95 337.26 6300.00 6358.50 2113.47 1572.82 -1455.80 --- 0.00 5.43 5952110.65 686109.71 N 70.27410259 W 148.49448820 CM2 8107.20 49.95 337.26 6810.00 6868.50 2709.97 2132.33 -1690.29 --- 0.00 5.54 5952664.11 685861.36 N 70.27563099 W 148.49638575 Crv 4/100 8760.73 49.95 337.26 7230.54 7289.04 3201.83 2593.69 -1883.65 LS 0.00 5.62 5953120.48 685656.57 N 70.27689128 W 148.49795066 8800.00 48.38 337.26 7256.22 7314.72 3231.05 2621.10 -1895.13 LS 4.00 5.63 5953147.59 685644.41 N 70.27696613 W 148.49804362 8900.00 44.38 337.26 7325.20 7383.70 3302.21 2687.85 -1923.11 LS 4.00 5.65 5953213.61 685614.78 N 70.27714847 W 148.49827002 9000.00 40.38 337.27 7399.06 7457.56 3368.47 2750.00 -1949.15 LS 4.00 5.68 5953275.09 685587.20 N 70.27731824 W 148.49848080 CMl 9070.67 37.55 337.27 7454.00 7512.50 3412.15 2790.98 -1966.32 LS 4.00 5.70 5953315.63 685569.02 N 70.27743018 W 148.49861976 9100.00 36.38 337.27 7477.44 7535.94 3429.50 2807.25 -1973.13 LS 4.00 5.70 5953331.72 685561.80 N 70.27747462 W 148.49867492 9200.00 32.38 337.28 7559.96 7618.46 3485.00 2859.31 -1994.94 LS 4.00 5.72 5953383.23 685538.70 N 70.27761686 W 148.49885144 9300.00 28.38 337.28 7646.21 7704.71 3534.71 2905.95 -2014.47 LS 4.00 5.74 5953429.36 685518.02 N 70.27774424 W 148.49900951 9400.00 24.38 337.29 7735.78 7794.28 3578.38 2946.92 -2031.62 LS 4.00 5.76 5953469.89 685499.85 N 70.27785616 W 148.49914834 9500.00 20.38 337.30 7828.23 7886.73 3615.80 2982.03 -2046.31 LS 4.00 5.78 5953504.62 685484.29 N 70.27795207 W 148.49926727 End Crv 9509.40 20.00 337.30 7837.06 7895.56 3618.99 2985.02 -2047.56 --- 4.00 5.78 5953507.58 685482.96 N 70.27796025 W 148.49927740 THRZ 9524.24 20.00 337.30 7851.00 7909.50 3623.97 2989.70 -2049.52 --- 0.00 5.78 5953512.21 685480.89 N 70.27797304 W 148.49929325 9709.40 20.00 337.30 8025.00 8083.50 3686.24 3048.13 -2073.96 --- 0.00 5.79 5953570.00 685455.00 N 70.27813263 W 148.4994 BHRZ 9723.24 20.00 337.30 8038.00 8096.50 3690.89 3052.49 -2075.79 --- 0.00 5.79 5953574.32 685453.07 N 70.27814455 W 148.4995 TJA 9842.43 20.00 337.30 8150.00 8208.50 3730.96 3090.10 -2091.52 --- 0.00 5.79 5953611.52 685436.41 N 70.27824728 W 148.49963321 TSAG 9955.23 20.00 337.30 8256.00 8314.50 3768.89 3125.69 -2106.41 --- 0.00 5.80 5953646.73 685420.64 N 70.27834451 W 148.49975373 7" Csg 9959.50 20.00 337.30 8260.01 8318.51 3770.33 3127.04 -2106.97 --- 0.00 5.80 5953648.06 685420.04 N 70.27834818 W 148.49975829 Crv 10/100 9979.40 20.00 337.30 8278.72 8337.22 3777.02 3133.32 -2109.60 1.23R 0.00 5.80 5953654.28 685417.26 N 70.27836534 W 148.49977956 TSHU 9982.90 20.35 337.32 8282.00 8340.50 3778.21 3134.43 -2110.06 1.21R 10.00 5.80 5953655.38 685416.76 N 70.27836838 W 148.49978332 10000.00 22.06 337.42 8297.94 8356.44 3784.29 3140.14 -2112.44 1.12R 10.00 5.80 5953661.02 685414.24 N 70.27838398 W 148.49980258 End Crv 10052.10 27.27 337.64 8345.27 8403.77 3805.64 3160.23 -2120.75 --- 10.00 5.82 5953680.89 685405.44 N 70.27843884 W 148.49986980 TSAD 10094.55 27.27 337.64 8383.00 8441.50 3824.74 3178.21 -2128.14 -- 0.00 5.83 5953698.69 685397.60 N 70.27848797 W 148.49992969 42S8 10205.92 27.27 337.64 8482.00 8540.50 3874.85 3225.40 -2147.56 --- 0.00 5.83 5953745.38 685377.01 N 70.27861688 W 148.50008685 TCGL 10270.05 27.27 337.64 8539.00 8597.50 3903.70 3252.58 -2158.74 --- 0.00 5.83 5953772.26 685365.16 N 70.27869110 W 148.50017734 We1lDesign Ver SP 2.1 Bld( users) 02-33\02-33\Plan 02-338\02-338 (P7b) Generated 4/7/2009 8:56 AM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND TVD Vertical NS EW Mag I Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS ~(.GL 7U.S4 /.ptl L/.L/ JJ/.O4 OOUO.UU OOOO.JV JyJO.OJ JC0.7.~f/ -LI/L.L/ --- V.VV J.O`F Jy:JJOV4.OV VO:JJJV.OL IV /V.L/O/OV~Y YY I`FO.:JVVLOVO/ Crv 12.5/100 10351.60 27.27 337.64 8611.49 8669.99 3940.39 3287.13 -2172.95 2.97E 0.00 5.84 5953806.45 685350.09 N 70.27878549 W 148. 50029241 10400.00 33.31 337.07 8653.26 8711.76 3964.38 3309.64 -2182.35 2.48E 12.50 5.86 5953828.72 685340.13 N 70.27884699 W 148. 50036855 23S8 10435.32 37.72 336.76 8682.00 8740.50 3984.57 3328.51 -2190.40 2.22E 12.50 5.87 5953847.38 685331.62 N 70.27889853 W 148. 50043368 22TS 10499.70 45.77 336.32 8730.00 8788.50 4026.78 3367.80 -2207.46 1.90E 12.50 5.90 5953886.23 685313.58 N 70.27900585 W 148. 50057181 10500.00 45.80 336.32 8730.21 8788.71 4026.99 3367.99 -2207.55 1.90E 12.50 5.90 5953886.42 685313.49 N 70.27900638 W 148. 50057250 21 TS 10566.58 54.12 335.98 8773.00 8831.50 4077.24 3414.57 -2228.15 1.68E 12.50 5.93 5953932.47 685291.74 N70.27913361 W148. 50073926 10600.00 58.30 335.84 8791.58 8850.08 4104.66 3439.92 -2239.48 1.60E 12.50 5.94 5953957.52 685279.78 N 70.27920285 W 148 .50083101 TZ18 10663.22 66.20 335.60 8821.00 8879.50 4159.88 3490.88 -2262.48 1.49E 12.50 5.97 5954007.89 685255.52 N 70.27934206 W 148. 50101715 10700.00 70.79 335.47 8834.48 8892.98 4193.69 3522.02 -2276.64 1.44E 12.50 5.99 5954038.66 685240.59 N 70.27942710 W 148 .50113182 TDF 10744.26 76.32 335.33 8847.00 8905.50 4235.64 3560.60 -2294.31 1.40E 12.50 6.01 5954076.79 685221.97 N 70.27953249 W 148. 501 10800.00 83.29 335.16 8856.86 8915.36 4289.87 3610.39 -2317.26 1.37E 12.50 6.03 5954125.99 685197.78 N 70.27966849 W 148 2 .5014 Tgt 1 10853.70 90.00 335.00 8860.00 8918.50 4342.88 3658.98 -2339.84 59.59E 12.50 6.05 5954174.00 685174.00 N 70.27980122 W 148 .50164343 End Crv 10875.06 91.35 332.70 8859.75 8918.25 4364.08 3678.15 -2349.25 --- 12.50 6.06 5954192.93 685164.11 N 70.27985359 W 148 .50171963 Crv 6/100 11454.81 91.35 332.70 8846.08 8904.58 4940.55 4193.17 -2615.11 88.93E 0.00 6.13 5954701.13 684885.52 N 70.28126034 W 148 .50387188 Tgt 2 11499.75 91.40 330.00 8845.00 8903.50 4985.33 4232.59 -2636.65 90.81 L 6.00 6.14 5954740.00 684863.00 N 70.28136802 W 148 .50404627 11500.00 91.40 329.99 8844.99 8903.49 4985.58 4232.80 -2636.77 90.81 L 6.00 6.14 5954740.21 684862.87 N 70.28136860 W 148 .50404727 11600.00 91.31 323.98 8842.63 8901.13 5085.51 4316.59 -2691.22 90.95E 6.00 6.17 5954822.61 684806.36 N 70.28159746 W 148 .50448802 End Crv 11617.38 91.29 322.94 8842.24 8900.74 5102.85 4330.55 -2701.56 --- 6.00 6.17 5954836.31 684795.67 N 70.28163558 W 148 .50457174 Crv 6/100 12154.45 91.29 322.94 8830.14 8888.64 5638.59 4759.04 -3025.13 24.53E 0.00 6.23 5955256.57 684461.54 N 70.28280583 W 148 .50719109 Tgt 3 12160.12 91.60 322.80 8830.00 8888.50 5644.25 4763.56 -3028.56 26.97E 6.00 6.24 5955261.00 684458.00 N 70.28281819 W 148 .50721882 End Crv 12167.66 92.00 322.59 8829.76 8888.26 5651.77 4769.55 -3033.13 --- 6.00 6.24 5955266.88 684453.29 N 70.28283456 W 148 .50725579 TD 14-1/2" Lnr 12733.04 92.00 322.59 8810.00 8868.50 6215.31 5218.40 -3376.36 --- 0.00 6.30 5955707.00 684099.00 N 70.28406037 W 148 .51003459 Legal Description: Northing (Y) fftUSl Easting (X) fftUSl Surface : 4653 FSL 4419 FEL S36 T11 N R14E UM 5950574.70 687604.16 Tgt 1 : 3032 FSL 1476 FEL S26 T11N R14E UM 5954174.00 685174.00 TD / BHL : 4591 FSL 2512 FEL S26 T11 N R14E UM 5955707.00 684099.00 ,r u WeIlDesign Ver SP 2.1 Bld( users) 02-33\02-33\Plan 02-336\02-33B (P7b) Generated 4/7/2009 8:56 AM Page 3 of 3 E t~ SChlu WELL DS02-33B (P7b) FIEF Prudhoe Bay Unit - EOA STRUCTURE DS-02 MagireUC Parametxa Surtace Location NNJ2] Nasky State Planes, Zane 04, US Feel Misr~laneous Mpeel: BGGM 2008 Dip: 80.919° Date: May 15, 2009 Lal: N]0 tfi 11.302 NoMkg: 59505]4.]0 flUS Grq Corry: 1142824852° SbL 02-33 TVD Ref: Ralary Table (58.50 X above MSL) Map Dec: X22.]9]° FS: 5]]13.6 nT W148285].]]0 EasDn9: fie]fi04.1fi 1fl1S Scala FaG: 0.999939981fi PWn: 02-330 (P]D) Srvy Date: Apri10], 2009 0 1000 2000 3000 4000 5000 6000 0 0 0 .c 0) N U 4000 End C .._.._.._.._.. .i«.._.._ ~a .._.._.. 5000 .............................................. 6000 .,.,,.....,.;.:....;.,... 7000 8000 9000 ._.._.._.._ ._..®......_..®..®.._ _..-..~......-.._.. _..®.. _..-.--......_.. _.2 ......®.. _.. ®.._.._..® _ _......--.-......_..-.. ._.._.._..®.._.. _.. _.._ .._.._..-... Crv 41100 Fnd Crv ...... _.. _.. ®.-.._.._.._ ......,..._ _.._.._.._.._.._.._.... .,_.._.._.._.._.._.._. _ _.._.._...... Ham.. _.._.._..-.._.._.. _.._ ..,.._...........,..,....... ............. ......_.._.,_.;®.._.._..-..>.. ..,..._.._i..,.®.._................~....g.®.....®..®.._.._..-..-.,y.,.....,. r......-.. .HRZ ..p 7 Cs.~._.._.._..-.._..-...r......_..r.._..-......_..».i........ _.._.. ....,...,..... _.:...,-.._.,®,.®....,. ,._,._.:._.,®..-..-„®....,...,._...,:._.._.._.._.,-..-....,.,....;..-..®.....,-,,.... Crv 10/100 ......,...-.._ ._..-......-..«.. ._ _.._.._.._ _..»..«. ..-.._.._.._..-.._.._..-c.................. «......... ~ End Crv .....» .................._.. ..... _,..... .i_. sA:~' tiv'1.2~.b'7f8b..-..T9~Z.y.. ..-.._.._.._.~_,._,.>.._.._.. _.. _.. _.~~ _.. _,._..®.._..<.._.._. _ _.._.._.._.._.._.._.._...y.._.._.._.._..._.._.._.,_.,...1"._,._..®..~SY~/:~~~_ :-..FJ1A.CfX.._.._.._t~.~1FS-.i,0 ~_ . .. GL. - - - - - - - - - - - - - - - - - - - - - - - - - - ~ _ - - ;T ~ - - - - - - - - - - _:~ - - m ..c,.m.. ,.- - .<..®..e..r..®.. -.. c.r - _ _ -.._.. _. ^ <.,c..a..v..v.. _.. c,... c..c..,..-..-..~.. z,.a _ _ _ _ _ _ -.. m%9~c _.._. .._. ,.,,.. ..a„ Crv 6N 00 End Crv 2-33 T9t ~ End Crv Tgt 3 -In Survey 3 Whipstock se Whipstock 4N 00 41100 rv Crv 4)100 tcrv ._., .-..®..-,.-. .t ®3®,.-,.-..-..®..® ...-...-..-,.-..-..-...- -..®.. ®,..".-..-..-,a .....-..-,.....-..®..®..v s- ,-...®..-,.. 1000 i000 1000 7000 8000 9000 C~ 0 1000 2000 3000 4000 5000 6000 Vertical Section (ft) Azim = 326.76°, Scale = 1(in):1000(ft) Origin = 0 N/-S, 0 E/-V ~' ' „~, ' chlumher WELL DS02-33B (P7b) FIELD Prudhoe Bay Unit - EOA STRUCNRE DS-02 MagnMic Patamelers Motlel: OGGM 2006 Dip: 80.919' Dale: ay t5, 2009 Surface Location NAD2] Nmka Slala Fl Lal: N]0 tfi 11 301 Noflbing: 59505]4 ]0 XUS anes, Zone 00, US Feet Gritl Donv: wi A2619651° Miscellaneous Slof OZ-33 NO Rai: RoUry Table (56.50 fl a6ore MSL) Mag Dec: X22.]9]" FS: 5]]13.fi nT Lon: W196285].])0 Easgrg: 68]~4.ifi flUS Srale Fact: 09999399816 Plan: 02-33B IP]b) Srvy Dale: Ppn10]. 1009 -3200 -2400 -1600 -800 0 4800 4000 n 3200 Z O O C ~ 2400 V V V V 1600 800 0 TD 14.1/2" lnr -3's8 (P7~) / End Crv Tgt 3 C 6/100 ~@A ~jHf = `~ EndCrv 02-3§B Fit B 882 s Sgt 2 Crv fi1100 02-338 Rl 7 40 ss ° ` 02-33B Flt 5 8855s~ I 02-338 Flf 48 885 s 2- B FIl 2 8475ss 02-33B Flt 87 s `. End Crv Tgt1 Crv 12.5/100 ~ - .........................<.. E.......,.......-.......°...°,..,,, G..... «... 02,336 F,Ib9.806056.....,,,,...........,.".,... .,.. ~ .... ,...,,.",,.,..-....z..,a".-.,,, End Crv C ' Crv 101100 \ End Crv 7" Csg 02-3yi8 Flf 3 8465 Cry' 41700 End Crv Crv 41f 41100 ;rv 4/100 ~...,... 4800 4000 3200 2400 1600 800 0 -3200 -2400 -1600 -800 0 «< W Scale = 1(in):800(ft) E »> - - n Ico Islon eport Company: North America -ALASKA - BP Local Co-ordinate Reference: L'Veil 02-33 Project: Prudhoe Bay ND Reference: 02-338 Plan Q 58,50ft (Nabors XES) Reference Site: PB DS 02 MD Reference: 02-336 Pian ~ 58.50ft (Nabors XES) Site Error: O:OOff North Reference: True Reference Well: 02-33 Survey Calculation Method: Minimum Curvature Well Error: QOOft Output errors are at 1.00 sigma Reference Wallbore Plan 02-336 Database: EDM .16 -Anc Prod - WH24P Reference Design: Plan #7 02-338 Offset ND Reference: Offset Datum 2eference Plan #7 02-33B =filter type: GLdBAL FILTER APPLIED: All wellpaths with in 200`+ 100/1000 of refen nterpolation Method: MD Interval S.OOft Error Model: ISCWSA depth Range: 3,435.00 to 12,733.04ft Scan Method: Trav. Cylinder North 2esults Limited by: Maximum center-centerdistance of 1,470.45ft Error Surface: Elliptical Conic __ Survey Tool Program _ _ _ _ __ Date 4/6/2009 From To (ft) (ft) Survey [Wellbore) Tool Name Description 92.50 3,392:.50 02-33 Srvy 1 BOSS GYro (02-33) BOSS-GYRO Sperry-Sun BASS gyro rnultishot j 3,392.50 4,800.00 Plan #7 02-33B (Plan 02-336) MWD MWD -Standard 3,392.50 9,900.00 Plan #7 02-336 (Plan 02-336) MWD+IFR+MS MWD +IFR + Multi Station 9,900A0 12,733.04 Plan #7 02-336 (Plan 02-336) MWD+IFR+MS MWD +IFR + Multi Station 4/&/2009 3:58.25PM Page 2 of 5 COMPASS 2003.16 Build 70 • • n Ico Ilslon epo _.__ Company: North America -ALASKA.. - BP Local Co-ordinate Reference: 11+e11 Q2-33 Project: Prudhoe Bay ND Reference: 02-338 Plan Q 58,BOft {Nabors XES) Reference Site: PB DS 02 MD Reference: 42-338 Plan ~ 5$.50ft {Nabors XES) Site Error: O.OOft North Reference: True Reference Well: 02-33 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at L00 sigma Reference Wellhore Plan 02-336 Database: EDM .1 ti -Anc Prod. - WH24P Reference Design: Plan #7 02-338 Oftset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allovrable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore -Design {ft} (ft) (ft) (ftJ RB [~S 02 02-05 - 02-05 - 02-05 4,734.91 5,320.00 556.57 81.32 483.78 Pass -Major Risk 02-05 - 02-05A - 02-05A 4,734.91 5,320.00 556.57 81.32 483.78 Pass -Major Risk 02-05 - 02-05A -Plan #9 4,734.91 5,320.00 556.57 81.43 483.67 Pass -Major Risk 02-05 - 02-05AP61 - 02-05APB1 4,734.91 5,320.00 556.57 81.32 483.78 Pass -Major Risk 02-08 - 02-08 - 02-08 4,962.79 5,160.00 450.21 136.77 349.11 Pass -Major Risk 02-08 - 02-08A - 02-08A 10,375.00 11,008.00 670.29 565.71 322.52 Pass -Major Risk 02-08 - 02-08AP61 - 02-08AP61 4,961.86 5,155.00 450.22 136.70 349.11 Pass -Major Risk 02-08 - 02-08B - 02-086 10,459.24 11,575.00 722.54 509.01 263.73 Pass -Major Risk 02-09 - 02-09 - 02-09 3,971.82 4,160.00 470.74 82.90 387.92 Pass -Major Risk 02-09 - 02-09A - 02-09A 3,971.82 4,160.00 470.74 83.01 387.81 Pass -Major Risk 02-09 - 02-09APB1 - 02-09AP61 3,971.82 4,160.00 470.74 82.90 387.92 Pass -Major Risk 02-09 - 02-09AP62 - 02-09AP62 3,971.82 4,160.00 470.74 82.90 387.92 Pass -Major Risk 02-09 - 02-096 - 02-096 3,971.82 4,160.00 470.74 83.01 387.81 Pass -Major Risk 02-09 - 02-09BP61 - 02-09BPB1 3,971.82 4,160.00 470.74 82.90 387.92 Pass -Major Risk 02-09 - 02-09C - 02-09C 3,972.37 4,160.00 470.80 82.96 387.91 Pass -Major Risk 02-09 - 02-09C - 02-09C Wp09 3,972.37 4,160.00 470.80 82.96 387.91 Pass -Major Risk 02-10 - 02-10 - 02-10 3,629.36 3,635.00 418.11 70.37 347.74 Pass -Major Risk 02-10 - 02-10A - 02-10A 3,629.36 3,635.00 418.11 70.37 347.74 Pass -Major Risk 02-10 - 02-10AP61 - 02-10APB1 3,629.36 3,635.00 418.11 70.37 347.74 Pass -Major Risk 02-10 - 02-10B - 02-10B 3,630.79 3,635.00 418.11 70.37 347.74 Pass -Major Risk 02-10 - 02-10B - 02-10b Wp5 3,630.79 3,635.00 418.11 70.37 347.74 Pass -Major Risk 02-11 - 02-11 - 02-11 3,458.49 3,490.00 711.84 58.53 654.58 Pass -Major Risk 02-11A - 02-11A - 02-11A 3,458.49 3,490.00 711.84 96.95 624.43 Pass -Major Risk 02-12 - 02-12 - 02-12 3,435.00 3,435.00 278.47 90.19 188.78 Pass. -Major Risk 02-12 - 02-12A - 02-12A 3,435.00 3,435.00 278.47 90.19 188.78 Pass -Major Risk 02-12 - 02-12APB1 - 02-12AP81 3,435.00 3,435.00 278.47 90.19 188.78 Pass -Major Risk 02-12 - 02-126 - 02-126 3,435.00 3,435.00 278.47 90.19 188.78 Pass -Major Risk 02-12 - 02-126 -Plan #4 3,435.00 3,435.00 278.47 89.92 189.05 Pass -Major Risk 02-i 3 - 02-13 - 02-13 3,555.71 3,560.00 70.97 83.47 -12.26 FAIL -Major Risk 02-13 - 02-13A - 02-13A 3,555.71 3,560.00 70.97 83.47 -12.26 FAIL -Major Risk 02-13 - 02-136 - 02-136 3,552.11 3,550.00 70.98 83.47 -1226 FAIL -Major Risk 02-13 - 02-13B - 2-13B wp07 3,552.11 3,550.00 70.98 83.37 -12.15 FAIL -Major Risk 02-14 - 02-14 - 02-14 3,438.53 3,450.00 65.04 51.61 14.05 Pass -Major Risk 02-14 - 02-14A - 02-14A 3,435.00 3,440.00 6423 51.59 13.31 Pass -Major Risk 02-14 - 02-14A - 2-14A wp05 3,435.00 3,440.00 64.29 51.59 13.31 Pass -Major Risk 02-15 - 02-15 - 02-15 3,435.00 3,460.00 20925 70.41 139.35 Pass -Major Risk 02-15A - 02-15A - 02-15A 3,435.00 3,460.00 209.25 70.41 139.35 Pass -Major Risk 02-15AP61 - 02-15AP61 - 02-15APB1 3,435.00 3,460.00 209.25 70.41 139.35 Pass -Major Risk 02-16 - 02-16 - 02-16 Out of range 02-16 - 02-16A - 02-16A Out of range 02-16 - 02-166 - 02-166 Out of range 02-16 - 02-16C - 02-16C 11,186.89 13,604.00 785.92 798.68 x.25 FAIL -Major Risk 02-16 - 02-16CP61 - 02-16CPB1 Out of range 02-16 - 02-16CPB1 -Plan #4 11,071.95 13,557.00 871.18 168.49 712.09 Pass -Major Risk 02-17 - 02-17 - 02-17 11,295.33 10,395.00 841.45 774.82 67.13 Pass -Major Risk 02-17 - 02-17A - 02-17A 11,156.53 10,205.00 829.88 706.82 136.06 Pass -Major Risk 02-17 - 02-176 - 02-176 11,156.53 10,205.00 829.88 706.82 136.06 Pass -Major Risk 02-27 - 02-27 - 02-27 4,736.21 4,685.00 123.67 72.85 52.19 Pass -Major Risk 02-27A - 02-27A - 02-27A 4,736.21 4,685.00 123.67 72.85 52.19 Pass -Major Risk 02-28 - 02-28 - 02-28 6,507.01 6,305.00 246.49 89.89 174.44 Pass -Major Risk 02-28 - 02-28A - 02-28A 6,507.01 6,305.00 246.49 89.89 174.44 Pass -Major Risk 02-28 - 02-28AP61 - 02-28AP61 6,507.01 6,305.00 246.49 89.89 174.44 Pass -Major Risk 02-28 - 02-28APB1 -Plan #13 6,507.01 6,305.00 246.49 89.92 174.42 Pass - Major Risk 4/&/2009 3~58.25PM Page 3 of 5 COMPASS 2003.1 S Build 70 ' • n Ico Islon epo Company: North America -ALASKA. - BP Local Co-ordinate Reference: Well 02-33 Project: Prudhoe Bay ND Reference: 02-336 Plan Q 58,50ft (Nataors XES} Reference Site: PB DS 02 MD Reference: 02-336 Plan ~ 58.50ft (Nabors XESj Site Error: O.OOft North Reference: True Reference Well: 02-33 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 1 AO sigma Reference Wellbore Plan 02-336 Database: EDM .16 -Ane Prod - WH24P Reference Design: Plan #T 02-336 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore -Design (ft} (ftj (ft) (ft) PB DS 02 02-30 - 02-30 - 02-30 12,449.10 10,630A0 501.09 247.21 254.74 Pass -Major Risk 02-30 - 02-30A - 02-30A 12,733.04 11,380.00 123.57 249.70 -111.71 FAIL -Major Risk 02-30 - 02-30B - 02-30B 11,167.45 10,560.00 18.03 197.52 -169.54 FAIL -Major Risk 02-30 - 02-30BPB1 - 02-306P61 11,175.98 10,565.00 14.01 197.75 -180.63 FAIL -Major Risk 02-32 - 02-32 - 02-32 4,669.81 4,595.00 510.70 56.35 455.31 Pass -Major Risk 02-32 - 02-32A - 02-32A 4,669.81 4,595.00 510.70 56.46 455.20 Pass -Major Risk 02-32 - 02-32AP61 - 02-32AP61 4,669.81 4,595.00 510.70 5635 455.31 Pass -Major Risk 02-32 - 02-32APB2 - 02-32AP62 4,669.81 4,595.00 510.70 56.35 455.31 Pass -Major Risk 02-32 - 02-32AP83 - 02-32AP63 4,669.81 4,595.00 510.70 56.35 455.31 Pass -Major Risk 02-32 - 02-326 - 02-326 4,671.49 4,585.00 510.75 56.40 455.31 Pass -Major Risk 02-32 - 02-326 - 2-326 WP04 4,671.49 4,585.00 510.75 56.40 455.31 Pass -Major Risk 02-33 - 02-33 - 02-33 3,447.50 3,455.00 0.15 10.66 -10.50 FAlL -Major Risk 02-33 - 02-33A - 02-33A 3,447.50 3,455.00 0.15 10.66 -10.50 FAIL -Major Risk 02-35 - 02-35 - 02-35 3,607.66 3,615.00 252.59 44.26 208.34 Pass -Major Risk 02-35 - 02-35A - 02-35A 3,604.50 3,600.00 252.58 44.25 208.34 Pass -Major Risk 02-35 - 02-358 - 02-356 3,604,50 3,600.00 252,58 44.25 20$,34 Pass -Major Risk PB p515 15-32 -15-32A -Plan #2 10,351,43 9,180,00 213.93 603.41 -340.07 FAIL -Major Risk PBDS18 18-05 -18-05 -18-05 Out of range 4/6/2009 3:58:25PM Page 4 of 5 COMPASS 2003.1 fi Buifd 70 f~I Project: Prudhoe Bay Site: PB DS 02 Well: 02-33 Wellbore: Plan 02-33B Design: Plan #7 02-336 From kop to TD Scan interval 100 ft Scale 1:100 02-13, 02-16 Risk 1:200 0 02-30A, BP61, and B Risk 1::20 aol~~_~,-''_~_'_ --~ ._-- ~ -~l~;a - ~__ 4317 sass a5a:i ,,E, 330 ;_ ~ ,, - _~ 3 ~~ r •- ~ ~- ~ zso`-~----~ ~ ~ " /` aolt \~ ~~ \ -, : ~ ~~ _. ?~~~ ~ 300 ~'r~ a3 2 \~ 80 ~, ~t4o3 \` 3467 "-TS~~ i 1101- 3574 3 5 3$12 6414 ~,. 3932 t0 ~ J4U53 .~3~ ~ ~ ~ ~ fi745 , 117k ~ (~ _ _. .. g ~~ 5 35 ~ ~' t . i~~~ ~ ~ ~~ ~ 573G I ~ ~ 234 4 98 ~ ~ ~ 27(7-~----' a4$8 , ~5~" sue, 90 ~',, t$ 3494 11.7 7 378'1884 ~ x'324 3 ~ 11 75 3976 53"n ¢ f ;_` 45 $ ;~A9 ~~ , ,~ 5 ~4,^,65 / ! Fy113 -t ~~ l ~`' I 495 ~ - 7 152 ~~ ~~~~ ~,...~~ / 431. 0503 1 5722 a7 ~ ` 9110 2574. ` f~LC~t - ~-,._ ~'~286 7 059? ~ ag ^, , ~,, ~ \ A` ~ 02-33107-33A iir=i~10~ d08PB1 42485 °~ ~5 ti8i '~ ~ _ ; 0: 3G'0~ ~GB\ ~ ~8~. Q2-13;02-138 240 ...` ~~a, 391 4~~~ ~ Cr6~12 ~ ~ 72U 0[-15APB1lW ~ AP~~f '~ 1 a~,5g ~ 2G .5"i0G 1:?200 ~ ~~~~ ~ ~6777~ i, ~ / ~~ ~~ '$3~E. 3`s4E~ ; `_ ~ . 214 02.1-tfG2-14~. ~ - -- o~`' f~92 d~i02-35~PB1 ~ ~~ 1350 ,v~•--~"=~ ~~2'29102-28APB~ 1'.80 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [100 ftrn] Target: 02-376 7gt Poly Project: Prudhoe Bay Well: U2-33 Drilling Target Conf.: 90 Based on: Planned Programl'lan #7 02-338 Description: Vertical Uepth: 8918.5U tt below U2-738 Plxn Map Nortlting: 5954174.01 fi Local +N/-S: 3658.98 tt Map Fasting :685177.99 ft Local +FJ-W: -2339.64 ft LatiNde: 70° lb' 47284 N Longitude: 148° 30' 5.917 W Shape: Polygon b points ~~ao Sao goo ~ia~ ~~ ~ `Y~~V `i-~~ ~~~~ ~~t.J V l~ ~ ~ ~ ~ ~ Q l.~ ~ ~7 ~ C~ ~1 Q ...~ -~ r~ r~~ cv ~~ rv - ~ ~ ~ ~ ~ ~ ~ ~ Alaska Department of Natural ~burces Land Administration System + Page 1 of~ j ~~~;.Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Re3ources Alaska DNR Case Summary File Type: ADL File Number: 28308 ~ Pnn..table Case File. Summa. ry See Township, Range, Section and Acreage? =Yes~No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract ,,. File: ADL 28308 '`~' Search for Status Plat Updates As of 04/17/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784. OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS_ NORTH SLOPE Last Transaction: AA-NRB ASS IGNMENT APPROVED Meridian: U Township: Ol 1N Range: 014E Section: 25 Section Acres: 640 Search Plats Meridian: U Township: Ol1N Range: 014E Section: 26 Section Acres: 640 Meridian: U Township: O11N Range: 014E Section: 35 Section Acres: 640 Meridian: U Township: Ol1N Range: 014E Section: 36 Section Acres: 640 Legal Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* C14-129 11 N 14E UM 25, 26, 35, 36 2560.00 U- 3- 7 End of Case Summary Last updated on 04/17/2009. httn://dnr.alaska.aov/nroiects/las/Case Summarv.cfm?FileTvpe=ADL&FileNumber=2830... 4/17/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME /~-~"~~ Do?_3..~ PTD# 0?490~s ._~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~''•e~lD.s/DE" /~A 1~ POOL: ~~l,~DyD e' / y O A ~ /G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Lette r CHECK ADD-ONS WHAT (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing wel l (If last two digits in , API number are Permit No. ,API No. 50- - _ between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE [n accordance with 20 AAC 25.005 (cl r acquired for the pilot hole must be ea ly differentateda n bogh well name ( PH} and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Well Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Company Name) must contact the Commission to obtain advance a ro l f pp va o such water well testing ro ram. Rev: I / 11/2008 WELL PERMIT`CNECKt,lST Field & Pool PRUDHOE BAY, PRUDHDEOIL - 640150 Well Name: PRUDHOE BAY UNIT 02-336 Program DEV Well bore seg ^ PTD#:2090450 Company BP EXPLORATION (ALASKA) INC Initial ClassiType DEV! PEND GeoArea 890 Unk 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfeeatiached--- - --------- - --- -- - --- -- NA- -- -- -- -- ---- - - - - - - - -- - - ----- 2 lease numberapprgpriate ---------- -- ----- -- ------- Yes- ----- --- - - - -- --------- --- ----- - - -- -- - 3 Uniqueweli_nameandnumbe[-_______________________________-- Yes- -----------.----_----. ---------------------------------- - ---------------- 4 Well located ina_defrledpggl_------------------------------____-- Yes- -------------------------.- _--- 5 WelllocetedP[operdistance-f[omdrillin9unitboundary-- -------------------- Yes- ------------------------------------------------------------------- 6 Well located Proper distance f[om other welts - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 SuffigientecreegeaYeilahlendrillinqunit---- -- -- - ------ -- Y~ - ------ - ---- - - - -- -- --- -- --- - -- ---------- 8 If deviated, is-weliboreplatincluded__________________________-_---_- Yes- -----------------------------_. __-- 9 Ope[ato[onh/affegtedpartY----------- --- - - -- ------ - Yes ---- - - - -- -- -- ------ ------ -- --- - -- -- -- - -- 10 Ode[ato[hasappropriate_bondinforge------------------------------- Yes- ------131ertketBOnd#6184193•---------------------------------------------------- 11 Pe[mitcenbeissuedwithoutGOnservatigngrder_______________--_________- Yes- -_---_------_----_---_----_-_--_ --------------------------------------- Appr Date 12 Permit-r~nbeissuedwithoutadminist[ativeapproval------------------------ Yes- ------------------------------------------------------------------------ 13 Can pert+rit be approved befgre 15•day-wait - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 4!1712009 14 Wfllllocatedwithinareaandstrataauthorizedby-Injectign9tder-#(put_Ip#incomments)-(Fgr_ NA__ -_-----------------------------__-___-__-___--_--------------.--_---_- 15 All wells within114_mileareaofreYiewident~ed(Fg[servjceweUgnly)--------------- NA__ ____-_---____--__--__--_______________.___-__-_-_____--__-__---__--__- 16 Pte-prgducedinjectgr; duration of preproduotignlessthan3mgrtths_(Fgrservicewellonly)-- NA_- __________________________-___________-_________--______-_-__---_- 17 Nonconven. gas cgnfgrms to AS31:05.0$Qtj.1.A),fL2.A-D} - - - - - - - - - NA - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductorstring-ptovided______________--___-__--_-__------_--- NA-- ------Conductorset_inDSO~-33(191-116).---------------------------------------------- Engineerin9 19 Surface-cesir~g_protectsallkngwnUSDWg___-__----________________--_ NA_- _--_.Ngaquifers,AiQ46,cgnclusion5,_--______---_-_--_--__--__--_--__-______-___ 20 CMT_voladQquate_tggirculate_on_cgndugtg[8~&urfcsg-------------------___ NA-_ ______$urf_ar~casingsatin_DSQ2-33.--_--_---_------_----_---_-__-------------_-___- 21 CMT-vol-adequate_tg tie-irt long string to surf_ gsg- _ - - - - - - - - - - _ - _ _ - - - - - - - - - _ NA- - _ - - - _ _ Nriw prgduction cesingtg cemented tg ~ 750' belgw window- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT_will eoyer all known P[oductiya horizons- - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - 23 C-asingdesign8adequatefD[C,?,B&-permafrost--------------------------- Yes- -------------------..---------------------------------------------------- 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - . - - _ - -Rig equipped with steel pits, No reserve pit planned.- All waste tg approved disposal well(s). - _ . - - _ - - - - - 25 Ifa_re-d[ill,has_a10.403forabandgnmentbeenaRP--roved---------------------- Yes- ------309.126--------------------------------------.----------------------- 26 Adequatewellbore separationpropgsed- - - - - - - - - - - - - - - - - - - - - - - - _ - _ . Yes _ - - - _ - _ Proximityanalysis perfg[med, T[aveling cylinder path galeulated, _ _ - - _ - . _ _ - - - - - - - - - _ - - - _ - - _ 27 If_diverterrequited,doesitmeetregulatigns------------------------------- NA-_ ---_-_BOPStackwillalready-be inplaee._____-______-__-____--__-.___-_-__--___-__-__-- Appr Date 28 Drilling fluid-program schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - - . - - -Maximum expected fg[maiign pressu[e 9,0_EMW in Sag and 7.0 EMS-in zone._ MW uptg 1Q.2 ppg in 8 75"-hole-a_ TEM 411712009 29 BOPES,dotheymeetrQ9ulatign----------------------------------- Yes- -------B.QpRg-in zone,-------------------------------------------- 30 t30P~_press [sting appropriate; test to_(put psig in cgmments)- - - _ - - - - - - - _ - - - _ - Yes - _ _ _ _ _ _ _ _ _ _ _ _ _ _ . - _ - - - MASP caloulated a1304Q psi, 3500 psi_SOP tsstplanned_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 Chgke_manifoldgomplieswlAPI_RP-5$(_May64)____________________________ Yes_ _ _-___-_-___-_ 32 Work willgccu[withgutaperationshutdown--------------------------__-- Yes- .--------------------------------------------.--------------------.-- 33 Is presence of N2S gas_prgbabie - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ - - _ Low H2$is reported at DS Q2. -Mud_shguld preclude H2S an rig._ Rig has sensors and-alarms. - - - - - _ - - - - . - 34 -Mechanical conditiongfwellswithinAORyerified(Fgr-servicewellgnty)______________ NA-_ ___________-__-_-___.--______-______-___-___--__-__.----__------_--_--- 35 Pe[mlt_canbeissuedwlohydrogen-sultidemeasu[es_________________________ No-- -_---_MaxievelH~$on-Pad3Qppm._____________--___-_______-._._-_.-_--__-______._ Geology 36 Deta_presented gn potential gverpressure zgnes - - - - - - - - - - - - - - -- -- - NA -- - -- ------ ------- ----------- - .. - -- ------ - Appr Date 37 Seismic analysis ofshalfowgaszones- ------ - - -- -- -- - -- ~-- --- - ---------- --- -- --- --- - -- ------------ --- ----- ACS 411712009 38 Seabedcgnditignsurvey_(ifoff_-shore}--------------------------------- -NA-- -----------------..------.----------------------------------------------- 39 Contactnamelphonefolweekly-P.rogressrepgrls_(exPloratorygnty]-__-_-______--- NA__ ________________________--_-_-_-____-___-_-_______-_____-._--_---- Geologic Commissioner: Engineering Public Data: Co issioner• Date Commissioner Date ~~ ~9